EXHIBIT 13.3
2003 Annual Report
Public Service Company of New Hampshire
Index
Contents Page
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Management's Discussion and Analysis of Financial
Condition and Results of Operations.............................. 1
Independent Auditors' Report....................................... 12
Consolidated Balance Sheets........................................ 14-15
Consolidated Statements of Income.................................. 16
Consolidated Statements of Comprehensive Income.................... 16
Consolidated Statements of Common Stockholder's Equity............. 17
Consolidated Statements of Cash Flows.............................. 18
Notes to Consolidated Financial Statements......................... 19
Consolidated Quarterly Financial Data (Unaudited).................. 32
Selected Consolidated Financial Data (Unaudited)................... 32
Consolidated Statistics (Unaudited)................................ 33
Bondholder Information............................................. Back Cover
MANAGEMENT'S DISCUSSION AND ANALYSIS
FINANCIAL CONDITION AND BUSINESS ANALYSIS
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OVERVIEW
Public Service Company of New Hampshire (PSNH or the company), a wholly owned
subsidiary of Northeast Utilities (NU), earned $45.6 million in 2003,
compared with $62.9 million in 2002 and $81.8 million in 2001. The 2003
decline in earnings is due to a lower level of regulatory assets earning a
return, the positive resolution of certain contingencies related to a
regulatory proceeding decided in 2002, and higher pension costs. 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, 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 purchased all of NAEC's entitlement to the capacity and
output of the Seabrook nuclear unit (Seabrook) under two full cost recovery
contracts (Seabrook Power Contracts) through the sale of Seabrook on
November 1, 2002.
During 2003, pre-tax pension expense for PSNH increased $6.2 million, from
$0.6 million in 2002 to $6.8 million in 2003. Of the $6.8 million and $0.6
million of pension expense recorded during 2003 and 2002, $4.8 million and
$0.4 million, respectively, were recognized in the consolidated statements of
income. The remaining $2 million in 2003 and $0.2 million in 2002 relate to
employees working on capital projects and were reflected as capital
expenditures. The pre-tax $4.4 million increase in pension expense was
reflected evenly throughout 2003, resulting in a decline of $0.7 million in
net income per quarter during 2003.
PSNH's revenues for 2003 decreased to $888.2 million from $947.2 million in
2002. The decrease in revenues is primarily due to lower wholesale revenues
as a result of NAEC's sale of its share of Seabrook in November 2002, the
cancellation of the Seabrook Power Contracts and PSNH's related loss of
Seabrook output, some of which was sold. The reduction in wholesale revenues
was partially offset by increases in electric sales in 2003 as compared to
2002.
As a result of an adjustment to estimated unbilled electric revenues
resulting from a process to validate and update the assumptions used to
estimate unbilled revenues, 2003 PSNH retail electric sales increased 4.7
percent compared to 2002. Absent that adjustment, PSNH retail electric sales
increased 4 percent. The adjustment to PSNH's estimated unbilled revenues
increased PSNH's net income by $3.3 million for 2003. For further
information regarding the estimate of unbilled revenues, see "Critical
Accounting Policies and Estimates - Unbilled Revenues," included in this
Management's Discussion and Analysis.
FUTURE OUTLOOK
PSNH is expected to have reduced earnings in 2004 compared to 2003 partially
as a result of a continued increase in pension expense. In 2004, PSNH is
projecting to record pre-tax pension expense of approximately $10.6 million
as compared to pension expense of $6.8 million in 2003. Pension expense is
annually adjusted during the second quarter based on updated actuarial
valuations, and the 2004 estimate may change.
PSNH's 2004 earnings will also be impacted by uncertainties over the outcome
of a pending PSNH rate case before the New Hampshire Public Utilities
Commission (NHPUC) and the outcome of the transmission rate case before the
Federal Energy Regulatory Commission (FERC). Management expects both cases
to be decided in the second half of 2004.
LIQUIDITY
PSNH's net cash flows provided by operating activities totaled $82.2 million
in 2003 as compared to $325 million in 2002 and $271.7 million in 2001. Cash
flows provided by operating activities in 2003 decreased due to decreases in
working capital items. Seabrook was sold on November 1, 2002 and taxes of
$93 million were paid in March of 2003. The decrease in these working
capital items were offset by an increase in regulatory recoveries in 2003
as compared to 2002, primarily associated with PSNH's Stranded Cost Recovery
Charge (SCRC). For a description of the costs recovered through this
mechanism, see Note 1G, "Summary of Significant Accounting Policies -
Regulatory Accounting," to the consolidated financial statements.
Cash flows provided by operating activities increased in 2002 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 comparable level of investing and financing activity in 2003 as
compared to 2002, except for $37 million for the repurchase of common shares
and the issuance of rate reduction bonds in 2002. The level of common
dividends totaled $16.8 million in 2003, $45 million in 2002 and $27 million
in 2001.
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 and rate
reduction bonds.
Aside from the rate reduction bonds outstanding, no PSNH debt issues mature
during the eight-year period of 2004 through 2011.
Capital spending at PSNH totaled $105.6 million in 2003, compared with $108.7
million in 2002. In 2003, PSNH spent over $20 million to buy down contracts
with 14 small power producers and funded $30.1 million to acquire the assets
of Connecticut Valley Electric Company (CVEC) and buy out a related wholesale
power contract. The $30.1 million was placed in escrow at December 31, 2003
and is included in special deposits on the accompanying consolidated balance
sheets. PSNH expects to increase its capital spending to approximately $160
million in 2004, assuming it receives satisfactory regulatory approval for a
$70 million conversion of a 50 megawatt generating unit at its Schiller Station
to burn wood chips. Such a level of spending is likely to require PSNH to
issue in 2004 its first new debt since it exited bankruptcy in 1991.
In November 2003, PSNH renewed a $300 million credit line under terms similar
to the previous arrangement that expired in November 2003. PSNH can borrow
up to $100 million and had $10 million in borrowings outstanding on this
credit line at December 31, 2003.
Rate reduction bonds are included on the consolidated balance sheets of PSNH,
even though the debt is non-recourse to PSNH. At December 31, 2003, PSNH had
a total of $472.2 million in rate reduction bonds outstanding, compared with
$510.8 million outstanding at December 31, 2002. All outstanding rate
reduction bonds of PSNH are scheduled to fully amortize by May 1, 2013.
Interest on the bonds totaled $29.1 million in 2003, compared with $30.5
million in 2002 and $20.7 million in 2001, the year of issuance. Cash flows
from the amortization of rate reduction bonds totaled $40 million in 2003,
compared with $42.7 million in 2002 and $26.8 million in 2001. Over the next
several years, retirement of rate reduction bonds will increase, and interest
payments will steadily decrease, resulting in no material changes to debt
service costs on the existing issues. PSNH fully recovers the amortization
and interest payments from customers through stranded cost revenues each
year, and the bonds have no impact on net income. Moreover, as the rate
reduction bonds are non-recourse, the three rating agencies that rate the
debt of PSNH do not reflect the revenues, expenses, or outstanding securities
related to the rate reduction bonds in establishing the credit ratings of
PSNH.
The retirement of rate reduction bonds does not equal the amortization of
rate reduction bonds because the retirement represents principal payments,
while the amortization represents amounts recovered from customers for future
principal payments. The timing of recovery does not exactly match the
expected principal payments.
BUSINESS DEVELOPMENT AND CAPITAL EXPENDITURES
PSNH capital spending totaled $105.6 million in 2003 and is projected to
total $160 million in 2004. The primary reason for the increase is PSNH's
proposal to convert a 50 megawatt oil and coal burning unit at Schiller
Station in Portsmouth, New Hampshire to burn wood chips. The $70 million
project will commence if PSNH receives satisfactory approval from the NHPUC.
PSNH believes that the conversion can be accomplished without impacting
retail rates because of certain government incentives to promote renewable
resource projects. Another reason for the projected increase in capital
spending is PSNH's transmission projects.
Effective January 1, 2004, PSNH completed the purchase of the electric system
and retail franchise of CVEC, a subsidiary of Central Vermont Public Service
Corporation (CVPS), for $30.1 million. CVEC's 11,000 customers in western
New Hampshire have been added to PSNH's customer base of more than 460,000
customers. The purchase price included the book value of CVEC's plant assets
of approximately $9 million and an additional $21 million to terminate an
above-market wholesale power purchase agreement CVEC had with CVPS. CVEC is
expected to add approximately $1.1 million to PSNH's annual earnings.
REGIONAL TRANSMISSION ORGANIZATION
The FERC has required all transmission owning utilities, including PSNH, to
voluntarily form regional transmission organizations (RTOs) or to state why
this process has not begun.
On October 31, 2003, the New England Independent System Operator (ISO-NE),
along with NU (including PSNH), and six other New England transmission
companies filed a proposal with the FERC to create a RTO for New England.
The RTO is intended to strengthen the independent and efficient management of
the region's power system while ensuring that customers in New England
continue to have the most reliable system possible to realize the benefits of
a competitive wholesale energy market.
ISO-NE, as a RTO, will have a new independent governance structure and will
also become the transmission provider for New England by exercising
operational control over New England's transmission facilities pursuant to a
detailed contractual arrangement with the New England transmission owners.
Under this contractual arrangement, the RTO will have clear authority to
direct the transmission owners to operate their facilities in a manner that
preserves system reliability, including requiring transmission owners to
expand existing transmission lines or build new ones when needed for
reliability. Transmission owners will retain their rights over revenue
requirements, rates and rate designs. The filing requests that the FERC
approve the RTO arrangements for an effective date of March 1, 2004.
In a separate filing made on November 4, 2003, NU including PSNH, along with
six other New England transmission owners requested, consistent with the
FERC's pricing policy for RTOs and Order-2000-compliant independent system
operators, that the FERC approve a single return on equity (ROE) for regional
and local rates that would consist of a base ROE as well as incentive adders
of 50 basis points for joining a RTO and 100 basis points for constructing
new transmission facilities approved by the RTO. If the FERC approves the
request, then the transmission owners would receive a 13.3 percent ROE for
existing transmission facilities and a 14.3 percent ROE for new transmission
facilities. The outcome of this request and its impact on PSNH cannot be
determined at this time.
RESTRUCTURING AND RATE MATTERS
On August 26, 2003, NU's electric operating companies, including PSNH, filed
their first transmission rate case at the FERC since 1995. In the filing, NU
requested implementation of a formula rate that would allow recovery of
increasing transmission expenditures on a timelier basis and that the
changes, including a $23.7 million annual rate increase through 2004, take
effect on October 27, 2003. NU requested that the FERC maintain NU's
existing 11.75 percent ROE until a ROE for the New England RTO is
established by the FERC. On October 22, 2003, the FERC accepted this filing
implementing the proposed rates subject to refund effective on October 28,
2003. A final decision in the rate case is expected in 2004.
Increasing transmission rates are generally recovered from distribution
companies through FERC-approved transmission rates. Electric distribution
companies pass through higher transmission rates to retail customers as
approved by the NHPUC. PSNH requested a tracking mechanism from the NHPUC
when it filed its rate case on December 29, 2003, which will allow it to
recover changes in transmission expenses on a timely basis.
Transition Energy Service: In accordance with the "Agreement to Settle PSNH
Restructuring" (Restructuring Settlement) and state law, PSNH must file for
updated transition energy service (TS) rates annually. The TS rate recovers
PSNH's generation and purchased power costs, including a return on PSNH's
generation investment. During the February 1, 2004 through January 31, 2005
time period when current rates will be effective, PSNH will defer any
difference between its TS revenues and the actual costs incurred. On
December 19, 2003, the NHPUC approved a $0.0536 per kilowatt-hour (kWh) TS
rate effective February 1, 2004.
Delivery Rate Case: PSNH's delivery rates were fixed by the Restructuring
Settlement until February 1, 2004. Consistent with the requirements of the
Restructuring Settlement and state law, PSNH filed a delivery service rate
case and tariffs with the NHPUC on December 29, 2003 to increase electricity
delivery rates by approximately $21 million, or approximately 2.6 percent,
effective February 1, 2004. In addition, PSNH is requesting that recovery of
FERC-regulated transmission costs be adjusted annually through a tracking
mechanism. The NHPUC suspended the proposed rate increase until the
conclusion of the delivery rate case. Hearings are expected in August 2004,
and a decision is expected in the third quarter of 2004 with rates
retroactively applied to February 1, 2004.
SCRC Reconciliation Filings: On an annual basis, PSNH files with the NHPUC a
SCRC reconciliation filing for the preceding calendar year. This filing
includes the reconciliation of stranded cost revenues with stranded costs,
and TS revenues with TS costs. The NHPUC reviews the filing, including a
prudence review of PSNH's generation operations.
On May 1, 2003, PSNH filed with the NHPUC an SCRC reconciliation filing for
the period January 1, 2002, through December 31, 2002. This filing included
the reconciliation of stranded cost revenues with stranded costs and a net
proceeds calculation related to the sale of NAEC's share of Seabrook and the
subsequent transfer of those net proceeds to PSNH. Upon the completion of
discovery and technical sessions with the NHPUC staff and the New Hampshire
Office of the Consumer Advocate (OCA), PSNH, the NHPUC Staff and the OCA
entered into a stipulation and settlement agreement that was filed with the
NHPUC on September 15, 2003. An order from the NHPUC approving the
settlement agreement on October 24, 2003 did not have a material impact on
PSNH's net income or financial position.
The 2003 SCRC filing is expected to be filed on May 1, 2004. Management does
not expect the review of the 2003 SCRC filing to have a material effect on
PSNH's net income or financial position. The recovery of stranded costs is
expected to be a significant source of cash flow for PSNH through 2007.
On May 22, 2003, the NHPUC issued an order approving a settlement between PSNH,
owners of 14 small hydroelectric power producers, the NHPUC staff and the OCA
calling for the termination of PSNH's obligations to purchase power from the
hydroelectric units at above market prices. On May 30, 2003, under the terms
of this settlement, PSNH made lump sum payments to those owners amounting to
$20.4 million. The buyout payments were recorded as regulatory assets and will
be recovered, including a return, over the initial term of the obligations as
Part 2 stranded costs. PSNH is entitled to retain 20 percent of the estimated
savings from the buyouts. PSNH is expected to recover $21 million of the
purchase price of CVEC over the next three to four years.
For information regarding commitments and contingencies related to
restructuring and rate matters, see Note 7A, "Commitments and Contingencies -
Restructuring and Rate Matters," to the consolidated financial statements.
NUCLEAR GENERATION ASSET DIVESTITURES
Millstone: On March 31, 2001, PSNH sold its ownership interest in Millstone.
Vermont Yankee: On July 31, 2002, Vermont Yankee Nuclear Power Corporation
(VYNPC) consummated the sale of its nuclear generating unit. In November
2003, PSNH sold back to VYNPC its shares of stock for approximately $0.4
million. PSNH continues to purchase approximately 4 percent of the plant's
output under a new contract.
Nuclear Decommissioning and Plant Closure Costs: Although the purchasers of
PSNH's ownership shares of the Millstone and Vermont Yankee plants assumed
the obligation of decommissioning those plants, PSNH still has significant
decommissioning and plant closure cost obligations to the companies that own
the Yankee Atomic, Connecticut Yankee (CY) and Maine Yankee plants
(collectively Yankee Companies). Each plant has been shut down and is
undergoing decommissioning. The Yankee Companies collect decommissioning and
closure costs through wholesale FERC-approved rates charged under a power
purchase agreement with PSNH. PSNH in turn passes these costs on to its
customers through state regulatory commission-approved retail rates. A
portion of the decommissioning and closure costs have already been collected,
but a substantial portion related to the decommissioning of CY has not yet
been filed at and approved for collection by the FERC. The cost estimate for
CY that has not yet been approved for recovery by FERC at December 31, 2003
is $26.3 million.
PSNH cannot at this time predict the timing or outcome of the FERC proceeding
required for the collection of these remaining decommissioning and closure
costs or the Bechtel Power Corporation litigation referred to in Note 7E,
"Commitments and Contingencies - Nuclear Decommissioning and Plant Closure
Costs," to the consolidated financial statements. Although management
believes that these costs will ultimately be recovered from PSNH's customers,
there is a risk that the FERC may not allow these costs, the estimates of
which have increased significantly in 2003 and 2002, to be recovered in
wholesale rates. If FERC does not allow these costs to be recovered in
wholesale rates, PSNH would expect the state regulatory commissions to
disallow these costs in retail rates as well.
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 statements of
PSNH. Management communicates to and discusses with NU's Audit Committee of
the Board of Trustees all critical accounting policies and estimates. The
following are the 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 which control is
maintained and all variable interest entities for which PSNH is the primary
beneficiary, as defined. 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, and Maine Yankee Atomic
Power Company. PSNH does not control these companies and does not
consolidate them in its financial statements. PSNH accounts for the
investments in these companies using the equity method. Under the equity
method, PSNH records its ownership share of the earnings or losses at these
companies. Determining whether or not PSNH should apply the equity method of
accounting for an investee company requires management judgment.
The required adoption date of Financial Accounting Standards Board (FASB)
Interpretation No. (FIN) 46, "Consolidation of Variable Interest Entities"
was delayed from July 1, 2003 to December 31, 2003 for PSNH. However, PSNH
elected to adopt FIN 46 at the original adoption date. The adoption of FIN
46 had no impact on PSNH. In December 2003, the FASB issued a revised
version of FIN 46 (FIN 46R). FIN 46R is effective for PSNH for the first
quarter of 2004, but is not expected to have an impact on PSNH's consolidated
financial statements.
Revenue Recognition: PSNH retail revenues are based on rates approved by the
NHPUC. These regulated rates are applied to customers' use of energy to
calculate a bill. In general, rates can only be changed through formal
proceedings with the NHPUC.
PSNH utilizes regulatory commission-approved tracking mechanisms to track the
recovery of certain incurred costs. The tracking mechanisms allow for rates
to be changed periodically, with overcollections refunded to customers or
underrecollections collected from customers in future periods.
The determination of the energy sales to individual customers is based on the
reading of meters, which occurs on a systematic basis throughout the month.
Billed revenues are based on these meter readings. At the end of each month,
amounts of energy delivered to customers since the date of the last meter
reading are estimated, and an estimated amount of unbilled revenues is
recorded.
Wholesale transmission revenues are based on rates and formulas that are
approved by the FERC. Most of PSNH's wholesale transmission revenues are
collected through a combination of the New England Regional Network Service
(RNS) tariff and PSNH's Local Network Service (LNS) tariff. The RNS tariff,
which is administered by ISO-NE, recovers the revenue requirements associated
with transmission facilities that are deemed by the FERC to be Pool
Transmission Facilities. The LNS tariff which was accepted by the FERC on
October 22, 2003, provides for the recovery of PSNH's total transmission
revenue requirements, net of revenue credits received from various rate
components, including revenues received under the RNS rates.
The settlement of wholesale non-trading derivative contracts for the sale of
energy by PSNH that are not related to customers' needs are recorded in
operating expenses.
Unbilled Revenues: Unbilled revenues represent an estimate of electricity
delivered to customers that has not been billed. Unbilled revenues represent
assets on the balance sheet that become accounts receivable in the following
month as customers are billed.
The estimate of unbilled revenues is sensitive to numerous factors that can
significantly impact the amount of revenues recorded. Estimating the impact
of these factors is complex and requires management's judgment. The estimate
of unbilled revenues is important to PSNH's consolidated financial statements
as adjustments to that estimate could significantly impact operating revenues
and earnings. Two potential methods for estimating unbilled revenues are the
requirements and the cycle method.
PSNH estimates unbilled revenues monthly using the requirements method. The
requirements method utilizes the total monthly volume of electricity
delivered to the system and applies a delivery efficiency (DE) factor to
reduce the total monthly volume by an estimate of delivery losses in order to
calculate total estimated monthly sales to customers. The total estimated
monthly sales amount less total monthly billed sales amount results in a
monthly estimate of unbilled sales. Unbilled revenues are estimated by
applying an average rate to the estimate of unbilled sales.
Differences between the actual DE factor and the estimated DE factor can have
a significant impact on estimated unbilled revenue amounts.
In 2003, the unbilled sales estimates for PSNH were tested using the cycle
method. The cycle method uses the billed sales from each meter reading cycle
and an estimate of unbilled days in each month based on the meter reading
schedule. The cycle method is historically more accurate than the
requirements method when used in a mostly weather-neutral month. The cycle
method resulted in adjustments to the estimate of unbilled revenues that had
a positive after-tax earnings impact on PSNH of $3.3 million in 2003.
The testing of the requirements method with the cycle method will be done on
at least an annual basis using a weather-neutral month.
Derivative Accounting: Effective January 1, 2001, PSNH adopted Statement of
Financial Accounting Standards (SFAS) No. 133, as amended.
Many PSNH contracts for the purchase or sale of energy or energy-related
products are derivatives. The application of derivative accounting under
SFAS No. 133, as amended, is complex and requires management judgment in the
following respects: identification of derivatives and embedded derivatives,
election, and designation of the normal purchases and sales exception, and
determining the fair value of derivatives. All of these judgments, depending
upon their timing and effect, can have a significant impact on PSNH's
consolidated balance sheet.
In April 2003, the FASB issued SFAS No. 149, "Amendment of Statement 133 on
Derivative Instruments and Hedging Activities," which amended existing
derivative accounting guidance. This new statement incorporates
interpretations that were included in previous Derivative Implementation
Group guidance, clarifies certain conditions, and amends other existing
pronouncements. It was effective for contracts entered into or modified
after June 30, 2003. Management has determined that the adoption of SFAS No.
149 resulted in fair value accounting for certain PSNH contracts that are
subject to unplanned netting and do not meet the definition of capacity
contracts. These non-trading derivative contracts are recorded at fair value
at December 31, 2003 as derivative assets and liabilities with offsetting
amounts recorded as regulatory liabilities and assets because the contracts
are part of providing regulated electric service.
Emerging Issues Task Force (EITF) Issue No. 03-11 "Reporting Realized Gains
and Losses on Derivative Instruments That Are Subject to FASB Statement No.
133, and 'Not Held for Trading Purposes' as Defined in EITF Issue No. 02-3,"
was derived from EITF Issue No. 02-3, which requires net reporting in the
income statement of energy trading activities. Issue No. 03-11 addresses
income statement classification of revenues related to derivatives that
physically deliver and are not related to energy trading activities. Prior
to Issue No. 03-11, there was no specific accounting guidance that addressed
the classification in the income statement of PSNH's power supply contracts,
some of which are non-trading derivatives.
On July 31, 2003, the EITF reached a consensus in Issue No. 03-11 that
determining whether realized gains and losses on contracts that physically
deliver and are not held for trading purposes should be reported on a net
(sales and purchases both in expenses) or gross (sales in revenues and
purchases in expenses) basis is a matter of judgment that depends on the
relevant facts and circumstances. The EITF indicated that existing
accounting guidance should be considered and provided no new guidance in
Issue No. 03-11. In Issue No. 03-11, the EITF did not provide transition
guidance, which management could have interpreted as becoming applicable on
October 1, 2003 for revenues from that date forward. However, management
applied its conclusion on net or gross reporting to all periods presented to
enhance comparability.
Though previously reported on a gross basis, after reviewing the relevant
facts and circumstances, PSNH reported the settlement of all short-term sales
contracts that are part of procurement activities on a net basis in expenses.
PSNH applied this new classification to revenues for all years presented in
order to enhance comparability. These non-requirements sales that amounted
to $48.9 million for the first nine months of 2003 and $99.6 million and $207.2
million for the years ended December 31, 2002 and 2001, respectively, were
reflected as revenues in quarterly reporting but are now included in expenses.
PSNH holds financial transmission rights (FTR) contracts to mitigate the risk
associated with the congestion price differences associated with LMP in New
England. FTR contracts held by PSNH were recorded at a fair value of $0.1
million. Management believes the amount to be paid for the FTR contracts
best represents their fair value. If new markets for these contracts
develop, then there may be an impact on PSNH's consolidated financial
statements in future periods.
Regulatory Accounting: The accounting policies of PSNH historically reflect
the effects of the rate-making process in accordance with SFAS No. 71,
"Accounting for the Effects of Certain Types of Regulation." The generation,
transmission and distribution businesses of PSNH continue to be cost-of-
service rate regulated, and management believes the application of SFAS No.
71 to those businesses continues to be appropriate. Management must reaffirm
this conclusion at each balance sheet date. If, as a result of a change in
circumstances, it is determined that any portion of the company 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
their regulatory assets and liabilities. Such a write-off could have a
material impact on PSNH's consolidated financial statements.
The application of SFAS No. 71 results in recording regulatory assets and
liabilities. Regulatory assets represent the deferral of incurred costs that
are probable of future recovery in customer rates. In some cases, PSNH
records regulatory assets before approval for recovery has been received from
the NHPUC. Management must use judgment to conclude that costs deferred as
regulatory assets are probable of future recovery. Management bases its
conclusion on certain factors, including changes in the regulatory
environment, recent rate orders issued by the NHPUC and the status of any
potential new legislation. Regulatory liabilities represent revenues
received from customers to fund expected costs that have not yet been
incurred or probable future refunds to customers.
Management uses its best judgment when recording regulatory assets and
liabilities; however, the NHPUC can reach different conclusions about the
recovery of costs, and those conclusions could have a material impact on
PSNH's consolidated financial statements. Management believes it is probable
that PSNH will recover the regulatory assets that have been recorded.
Pension and Postretirement Benefits Other Than Pensions (PBOP): PSNH
participates in a uniform noncontributory defined benefit retirement plan
(Pension Plan) covering substantially all regular PSNH employees. PSNH also
participates in a postretirement benefit plan (PBOP Plan) to provide 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 resulting
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.
Results: Pre-tax periodic pension expense/income for the Pension Plan,
excluding settlements, curtailments and special termination benefits,
totaled $6.8 million in expense, $0.6 million in expense and $3.9 million in
income for the years ended December 31, 2003, 2002 and 2001, respectively.
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. Net SFAS No. 88 items totaled $1.3 million in expense
for the year ended December 31, 2001.
The pre-tax net PBOP Plan cost, excluding settlements, curtailments and
special termination benefits, totaled $6.2 million, $5.3 million and $4.3
million for the years ended December 31, 2003, 2002 and 2001, respectively.
Long-Term Rate of Return Assumptions: In developing the expected long-term
rate of return assumptions, PSNH evaluated input from actuaries, consultants
and economists, as well as long-term inflation assumptions and PSNH's
historical 20-year compounded return of approximately 11 percent. PSNH's
expected long-term rate of return on assets is based on certain target asset
allocation assumptions and expected long-term rates of return. The Pension
Plan's and PBOP Plan's target asset allocation assumptions and expected long-
term rates of return assumptions by asset category are as follows:
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At December 31,
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Pension Benefits Postretirement Benefits
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2003 2002 2003 2002
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Target Assumed Target Assumed Target Assumed Target Assumed
Asset Rate of Asset Rate of Asset Rate of Asset Rate of
Asset Category Allocation Return Allocation Return Allocation Return Allocation Return
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Equity securities:
United States 45.00% 9.25% 45.00% 9.75% 55.00% 9.25% 55.00% 9.75%
Non-United States 14.00% 9.25% 14.00% 9.75% 11.00% 9.25% - -
Emerging markets 3.00% 10.25% 3.00% 10.75% 2.00% 10.25% - -
Private 8.00% 14.25% 8.00% 14.75% - - - -
Debt Securities:
Fixed income 20.00% 5.50% 20.00% 6.25% 27.00% 5.50% 45.00% 6.25%
High yield fixed
income 5.00% 7.50% 5.00% 7.50% 5.00% 7.50% - -
Real estate 5.00% 7.50% 5.00% 7.50% - - - -
- -----------------------------------------------------------------------------------------------------------------
The actual asset allocations at December 31, 2003 and 2002 approximated these
target asset allocations. PSNH regularly reviews the actual asset
allocations and periodically rebalances the investments to the targeted asset
allocations when appropriate. For information regarding actual asset
allocations, see Note 5, "Pension Benefits and Postretirement Benefits Other
Than Pensions," to the consolidated financial statements.
PSNH reduced the long-term rate of return assumption 50 basis points from
9.25 percent to 8.75 percent in 2003 for the Pension Plan and PBOP Plan due
to lower expected market returns. PSNH believes that 8.75 percent is a
reasonable long-term rate of return on Pension Plan and PBOP Plan assets for
2003, and PSNH expects to use 8.75 percent in 2004. 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.
Actuarial Determination of Income and Expense: PSNH bases the actuarial
determination of Pension Plan and PBOP Plan income/expense on a market-
related valuation of assets, which reduces year-to-year volatility. This
market-related valuation calculation 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 valuation
calculation 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
Pension Plan and PBOP Plan assets.
At December 31, 2003, the Pension Plan had cumulative unrecognized investment
losses of $10.5 million, which will increase pension expense over the next
four years by reducing the expected return on Pension Plan assets. At
December 31, 2003, the Pension Plan also had cumulative unrecognized
actuarial losses of $26.8 million, which will increase pension expense over
the expected future working lifetime of active Pension Plan participants, or
approximately 13 years. The combined total of unrecognized investment and
actuarial losses at December 31, 2003 is $37.3 million. These losses impact
the determination of pension expense and the actuarially determined prepaid
pension amount recorded on the consolidated balance sheets but have no impact
on expected Pension Plan funding.
At December 31, 2003, the PBOP Plan had cumulative unrecognized investment
losses of $1.5 million, which will increase PBOP Plan cost over the next four
years by reducing the expected return on plan assets. At December 31, 2003,
the PBOP Plan also had cumulative unrecognized actuarial losses of $13.2
million, which will increase PBOP Plan expense over the expected future
working lifetime of active PBOP Plan participants, or approximately 13 years.
The combined total of unrecognized investment and actuarial losses at
December 31, 2003 is $14.7 million. These losses impact the determination of
PBOP Plan cost and the actuarially determined accrued PBOP Plan cost recorded
on the consolidated balance sheets.
Discount Rate: The discount rate that is utilized in determining future
pension and PBOP 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 Pension Plan's longer duration 25 basis points were
added to the benchmark. The discount rate determined on this basis has
decreased from 6.75 percent at December 31, 2002 to 6.25 percent at
December 31, 2003.
Expected Pension Expense: Due to the effect of the unrecognized actuarial
losses and based on an expected rate of return on Pension Plan assets of 8.75
percent, a discount rate of 6.25 percent and various other assumptions, PSNH
estimates that expected contributions to and pension expense for the Pension
Plan will be as follows (in millions):
- ----------------------------------------------------------
Expected
Year Contributions Pension Expense
- ----------------------------------------------------------
2004 $ - $10.6
2005 $ - $11.9
2006 $ - $11.9
- ----------------------------------------------------------
Future actual pension expense/income will depend on future investment
performance, changes in future discount rates and various other factors
related to the populations participating in the Pension Plan.
Sensitivity Analysis: The following represents the increase/(decrease) to
the Pension Plan's reported cost and increases to the PBOP Plan's reported
cost as a result of the change in the following assumptions by 50 basis
points (in millions):
- ---------------------------------------------------------------------
At December 31,
- ---------------------------------------------------------------------
Pension Plan Postretirement Plan
- ---------------------------------------------------------------------
Assumption Change 2003 2002 2003 2002
- ---------------------------------------------------------------------
Lower long-term
rate of return $ 1.1 $ 1.1 $0.2 $0.2
Lower discount
rate $ 1.9 $ 1.7 $0.2 $0.2
Lower compensation
increase $(1.0) $(0.8) N/A N/A
- ---------------------------------------------------------------------
Plan Assets: The value of the Pension Plan assets has increased from $163.5
million at December 31, 2002 to $191.9 million at December 31, 2003. The
investment performance returns, despite declining discount rates, have
decreased the underfunded status of the Pension Plan on a projected benefit
obligation (PBO) basis from $97.4 million at December 31, 2002 to $97.1
million at December 31, 2003. The PBO includes expectations of future
employee compensation increases. The accumulated benefit obligation (ABO) of
the Pension Plan was $51.7 million more than Pension Plan assets at
December 31, 2003 and $54.9 million more than Pension Plan assets at
December 31, 2002. The ABO is the obligation for employee service and
compensation provided through December 31, 2003. If the ABO for the entire
Pension Plan exceeds all Pension Plan assets at a future plan measurement date,
NU will record an additional minimum liability of which PSNH will be allocated
its proportionate share. PSNH has not made employer contributions since 1991.
The value of PBOP Plan assets has increased from $24.4 million at December 31,
2002 to $29.7 million at December 31, 2003. The investment performance
returns, despite declining discount rates, have decreased the underfunded
status of the PBOP Plan on an accumulated projected benefit obligation basis
from $39.3 million at December 31, 2002 to $37.1 million at December 31,
2003. PSNH has made a contribution each year equal to the PBOP Plan's
postretirement benefit cost, excluding curtailments, settlements and special
termination benefits.
Health Care Cost: The health care cost trend assumption used to project
increases in medical costs is 9 percent for 2003, decreasing one percentage
point per year to an ultimate rate of 5 percent in 2007. The effect of
increasing the health care cost trend by one percentage point would have
increased 2003 service and interest cost components of the PBOP Plan cost
by $0.1 million in 2003 and 2002.
Accounting for the Effect of Medicare Changes on PBOP: On December 8, 2003,
the President signed into law a bill that expands Medicare, primarily by
adding a prescription drug benefit and by adding a federal subsidy to
qualifying plan sponsors of retiree health care benefit plans. Management
believes that PSNH currently qualifies.
Specific authoritative accounting guidance on how to account for the effect
the Medicare federal subsidy has on PSNH's PBOP Plan has not been issued by
the FASB. FASB Staff Position (FSP) No. FAS 106-1, "Accounting and
Disclosure Requirements Related to the Medicare Prescription Drug,
Improvement and Modernization Act of 2003," required PSNH to make an election
for 2003 financial reporting. The election was to either defer the impact of
the subsidy until the FASB issues guidance or to reflect the impact of the
subsidy on December 31, 2003 reported amounts. PSNH chose to reflect the
impact on December 31, 2003 reported amounts.
Reflecting the impact of the Medicare change decreased the PBOP benefit
obligation by approximately $4.4 million and increased actuarial gains by
approximately $4.4 million with no impact on 2003 expenses, assets, or
liabilities. The $4.4 million actuarial gain will be amortized as a
reduction to PBOP expense over 13 years beginning in 2004. PBOP expense in
2004 will also reflect a lower interest cost due to the reduction in the
December 31, 2003 benefit obligation. Management estimates that the
reduction in PBOP expense in 2004 will be approximately $0.3 million.
When accounting guidance is issued by the FASB, it may require PSNH to change
the accounting described above and change the information included in this
annual report.
Income Taxes: Income tax expense is calculated each year in each of the
jurisdictions in which PSNH operates. 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 and expenses for tax and book accounting purposes. These
differences result in deferred tax assets and liabilities, which are included
in PSNH's consolidated balance sheets. Adjustments made to income taxes
could significantly affect PSNH's consolidated financial statements.
Management must also assess the likelihood that 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 and deferred tax
assets and liabilities.
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. The regulatory asset amounted to $44.2 million and $96.5 million at
December 31, 2003 and 2002, respectively. Regulatory agencies in certain
jurisdictions in which PSNH companies operate require the tax effect of
specific temporary differences to be "flowed through" to utility customers.
Flow through treatment means that deferred tax expense is not recorded on the
consolidated statements of income. Instead, the tax effect of the temporary
difference impacts both amounts for income tax expense currently included in
customers' rates and the company's net income. Flow through treatment can
result in effective income tax rates that are significantly different than
expected income tax rates. Recording deferred taxes on flow through items is
required by SFAS No. 109, and the offset to the deferred tax amounts is the
regulatory asset referred to above. A reconciliation from expected tax
expense at the statutory federal income tax rate to actual tax expense
recorded is included in Note 12, "Income Tax Expense," to the consolidated
financial statements.
The estimates that are made by management in order to record income tax
expense, accrued taxes and deferred taxes are compared each year to the
actual tax amounts filed on PSNH's income tax returns. The income tax
returns were filed in the fall of 2003 for the 2002 tax year. In the fourth
quarter, PSNH recorded differences between income tax expense, accrued taxes
and deferred taxes on its consolidated financial statements and the amounts
that were on its income tax returns. Recording these differences in income
tax expense resulted in a positive impact of approximately $2.1 million on
PSNH's 2003 earnings.
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 absent timely
rate relief for PSNH's assets.
Accounting for Environmental Reserves: Environmental reserves are accrued
using a probabilistic model approach when assessments indicate that it is
probable that a liability has been incurred and an amount can be reasonably
estimated. Adjustments made to environmental liabilities could have a
significant effect on earnings. The probabilistic model approach estimates
the liability based on the most likely action plan from a variety of
available remediation options, ranging from no action to remedies ranging
from establishing institutional controls to full site remediation and long-
term monitoring. The probabilistic model approach estimates the liabilities
associated with each possible action plan based on findings through various
phases of site assessments. These estimates are based on currently available
information from presently enacted state and federal environmental laws and
regulations and several cost estimates from outside engineering and
remediation contractors. These amounts also take into consideration prior
experience in remediating contaminated sites and data released by the United
States Environmental Protection Agency and other organizations.
These estimates are subjective in nature partly because there are usually
several different remediation options from which to choose when working on a
specific site. These estimates are subject to revisions in future periods
based on actual costs or new information concerning either the level of
contamination at the site or newly enacted laws and regulations. The amounts
recorded as environmental liabilities on the consolidated balance sheets
represent management's best estimate of the liability for environmental costs
based on current site information from site assessments and remediation
estimates. These liabilities are estimated on an undiscounted basis.
Under current rate-making policy, PSNH has a regulatory recovery mechanism in
place for environmental costs. Accordingly, regulatory assets have been
recorded for certain of PSNH's environmental liabilities. As of December 31,
2003 and 2002, $7.6 million and $4.9 million, respectively, have been
recorded as regulatory assets on the accompanying consolidated balance
sheets.
Asset Retirement Obligations: PSNH adopted SFAS No. 143, "Accounting for
Asset Retirement Obligations" on January 1, 2003. SFAS No. 143 requires that
legal obligations associated with the retirement of property, plant and
equipment be recorded as a liability on the balance sheet at fair value when
incurred and when a reasonable estimate of the fair value can be made. SFAS
No. 143 defines an asset retirement obligation (ARO) as a legal obligation
that is required to be settled due to an existing or enacted law, statute,
ordinance or a written or oral promise to remove an asset. AROs may stem
from environmental laws, state laws and regulations, easement agreements,
building codes, contracts, franchise grants and agreements, oral promises
made upon which third parties have relied, or the dismantlement, restoration,
or reclamation of properties.
Upon adoption of SFAS No. 143, certain removal obligations were identified
that management believes are AROs but either have not been incurred or are
not material. These removal obligations arise in the ordinary course of
business or have a low probability of occurring. The 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. There was no impact to PSNH's
earnings upon adoption of SFAS No. 143; however, if there are changes in
certain laws and regulations, orders, interpretations or contracts entered
into by PSNH there may be future AROs that need to be recorded.
Under SFAS No. 71, regulated utilities, including PSNH, currently recover
amounts in rates for future costs of removal of plant assets. Future
removals of assets do not represent legal obligations and are not AROs.
Historically, these amounts were included as a component of accumulated
depreciation until spent. At December 31, 2003 and 2002, these amounts
totaling $88 million and $67 million, respectively, were reclassified to
regulatory liabilities on the accompanying consolidated balance sheets.
In June 2003, the FASB issued a proposed FSP, "Applicability of SFAS No. 143,
'Accounting for Asset Retirement Obligations', to Legislative Requirements on
Property Owners to Remove and Dispose of Asbestos or Asbestos-Containing
Materials." In the FSP, the FASB staff concludes that current legislation
creates a legal obligation for the owner of a building to remove and dispose
of asbestos-containing materials. In the FSP, the FASB staff also concludes
that this legal obligation constitutes an ARO that should be recognized as a
liability under SFAS No. 143. This FSP changes a FASB staff interpretation
of SFAS No. 143 that an obligating event did not occur until a building
containing asbestos was demolished. In November 2003, the FASB indicated
that, based on the diverse views it received in comment letters on the
proposed FSP, it was considering a proposal for a FASB agenda project to
address this issue. If this FSP is adopted in its current form, then PSNH
would be required to record an ARO. Management has not estimated this
potential ARO at December 31, 2003.
Special Purpose Entities: During 2001 and 2002, to facilitate the issuance of
rate reduction bonds intended to finance certain stranded costs, PSNH
established two SPEs: PSNH Funding LLC and PSNH Funding LLC 2 (the funding
companies). The funding companies were created as part of a state-sponsored
securitization program. 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 PSNH's bankruptcy estate
if it ever became involved in a bankruptcy proceeding. The funding companies
and the securitization amounts are consolidated in the accompanying
consolidated financial statements.
For further information regarding the matters in this "Critical Accounting
Policies and Estimates" section see Note 1, "Summary of Significant
Accounting Policies," Note 5, "Pension Benefits and Postretirement Benefits
Other Than Pensions," Note 12, "Income Tax Expense," and Note 7B,
"Commitments and Contingencies - Environmental Matters," to the consolidated
financial statements.
OTHER MATTERS
Commitments and Contingencies: For further information regarding other
commitments and contingencies, see Note 7, "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,
2003 is summarized through 2008 and thereafter as follows:
- ------------------------------------------------------------------------------------------------------
(Millions of
Dollars) 2004 2005 2006 2007 2008 Thereafter
- ------------------------------------------------------------------------------------------------------
Notes payable
to banks (a) $ 10.0 $ - $ - $ - $ - $ -
Long-term
Debt(a) - - - - - 407.3 -
Capital
leases (b) (c) 0.5 0.5 0.3 0.2 0.2 -
Operating
leases (c) (d) 4.6 3.9 3.6 2.6 2.1 3.6
Long-term
contractual
arrangements (c) (d) 136.6 138.0 139.0 66.8 40.6 392.2
- ------------------------------------------------------------------------------------------------------
Totals $151.7 $142.4 $142.9 $69.6 $42.9 $803.1
- ------------------------------------------------------------------------------------------------------
(a) Included in PSNH's debt agreements are usual and customary positive,
negative and financial covenants. Non-compliance with certain covenants, for
example the timely payment of principal and interest, may constitute an event
of default, which could cause an acceleration of principal in the absence of
receipt by the company of a waiver or amendment. Such acceleration would
change the obligations outlined in the table of contractual obligations and
commercial commitments.
(b) The capital lease obligations include imputed interest of $0.7 million.
(c) PSNH has no provisions in its capital or operating lease agreements or
agreements related to its long-term contractual arrangements that could
trigger a change in terms and conditions, such as acceleration of payment
obligations.
(d) Amounts are not included on PSNH's consolidated balance sheets.
Rate reduction bond amounts are non-recourse to PSNH, have no required
payments over the next five years and are not included in this table.
Additionally, this table does not include notes payable to affiliated
companies totaling $48.9 million at December 31, 2003 and PSNH's expected
contribution to the PBOP Plan in 2004 of $7 million. For further information
regarding PSNH's contractual obligations and commercial commitments, see
Note 3, "Short-Term Debt," Note 9, "Leases," Note 7D, "Commitments and
Contingencies - Long-Term Contractual Arrangements," and Note 11, "Long-Term
Debt," 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, regulatory proceedings, 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 commodity markets, and
other presently unknown or unforeseen factors.
Website: Additional financial information is available through NU's website
at www.nu.com.
RESULTS OF OPERATIONS
The following table provides the variances in income statement line items for
the consolidated statements of income included in this annual report for the
past two years.
- ---------------------------------------------------------------------------------------------------
2003 over/(under) 2002 2002 over/(under) 2001
Income Statement Variances ---------------------- ------------------------
(Millions of Dollars) Amount Percent Amount Percent
- ---------------------------------------------------------------------------------------------------
Operating Revenues $ (59) (6)% $ (17) (2)%
Operating Expenses:
Fuel, purchased and net interchange power 112 39 (218) (43)
Other operation 16 13 3 2
Maintenance 1 1 8 14
Depreciation 2 6 1 3
Amortization of regulatory assets, net (158) (81) 158 (a)
Amortization of rate reduction bonds (3) (6) 16 59
Taxes other than income taxes (1) (2) (4) (11)
- ---------------------------------------------------------------------------------------------------
Total operating expenses (31) (4) (36) (4)
- ---------------------------------------------------------------------------------------------------
Operating Income (28) (18) 19 14
Interest expense, net (4) (8) (2) (4)
Other (loss)/income, net (4) (a) (38) (a)
- ---------------------------------------------------------------------------------------------------
Income before income tax expense (28) (27) (17) (14)
Income tax expense (11) (26) 2 4
- ---------------------------------------------------------------------------------------------------
Net Income $ (17) (27)% $ (19) (23)%
===================================================================================================
(a) Percent greater than 100.
OPERATING REVENUES
Operating revenues decreased $59 million in 2003 compared with the same
period of 2002 primarily due to lower regulated wholesale revenues resulting
from the impact of less owned generation since the sale of Seabrook ($114
million), partially offset by higher retail revenues ($56 million). Retail
revenues were higher primarily due to higher retail sales volumes ($37
million) and higher TS revenues. Retail kWh sales increased 4.7 percent for
the year 2003.
Operating revenues decreased $17 million in 2002 primarily due to lower
retail revenues. Retail revenues decreased $24 million primarily due to the
May 2001 rate decrease. Retail kWh sales were essentially flat with a 0.1
percent decrease.
FUEL, PURCHASED AND NET INTERCHANGE POWER
Fuel, purchased and net interchange power expense increased $112 million in
2003 primarily due to the absence of the 2002 gain on the sale of utility
plant resulting from the sale of Seabrook recorded on NAEC's books, which was
transferred to PSNH through the Seabrook Power Contracts ($167 million),
partially offset by lower fuel expense resulting from lower regulated
wholesale transactions.
Fuel, purchased and net interchange power expense decreased $218 million in
2002 primarily due to the gain on the sale of utility plant resulting from
the sale of Seabrook recorded on NAEC's books, which was transferred to PSNH
through the Seabrook Power Contracts ($167 million) and lower purchased power
from NAEC ($67 million).
OTHER OPERATION AND MAINTENANCE
Other operation and maintenance (O&M) expenses increased $17 million in 2003
primarily due to higher pension costs ($8 million) and higher conservation
and customer assistance programs expense ($8 million).
Other 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).
DEPRECIATION
Depreciation increased $2 million in 2003 primarily due to additions to
distribution, generation, and general plant assets.
Depreciation increased $1 million in 2002 primarily due to the construction
of the new corporate headquarters.
AMORTIZATION OF REGULATORY ASSETS, NET
Amortization of regulatory assets, net decreased $158 million in 2003
primarily due to the 2002 amortization of stranded costs upon the sale of
Seabrook ($167 million), partially offset by an increase in the recovery of
stranded costs ($4 million) resulting from the SCRC reconciliation of
stranded cost revenues against actual stranded costs.
Amortization of regulatory assets, net increased $158 million in 2002
primarily due to recovery of stranded costs associated with the sale of the
Seabrook Station.
AMORTIZATION OF RATE REDUCTION BONDS
Amortization of rate reduction bonds decreased $3 million in 2003 due to the
repayment of principle and associated reduction of securitized regulatory
assets.
Amortization of rate reduction bonds increased $16 million in 2002 due to the
issuance of rate reduction bonds in 2002 and April 2001.
TAXES OTHER THAN INCOME TAXES
Taxes other than income taxes decreased $1 million in 2003 primarily due to
lower property tax.
Taxes other than income taxes decreased $4 million in 2002 primarily due to
the discontinuance of New Hampshire franchise taxes in 2001.
INTEREST EXPENSE, NET
Interest expense, net decreased $4 million in 2003 due to lower interest on
rate reduction bonds due to lower debt levels ($1 million) and lower interest
rates.
Interest expense, net decreased $2 million in 2002 primarily due to the
December 2001 refinancing of long-term debt at lower rates.
OTHER (LOSS)/INCOME, NET
Other (loss)/income, net decreased $4 million in 2003 primarily due to
increased service fees associated with rate reduction bonds and lower gains
on the disposition of property in 2003.
Other (loss)/income, net decreased $38 million 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).
INCOME TAX EXPENSE
Income tax expense decreased $11 million in 2003 primarily as a result of
lower book taxable income as compared to 2002. For further information
regarding income tax expense, see Note 12, "Income Tax Expense," to the
consolidated financial statements.
Income tax expense increased $2 million in 2002 primarily as a result of
reduced investment tax credit amortization, partially offset by the tax
consequences of lower acquisition premium amortization.
COMPANY REPORT
- -------------------------------------------------------------------------------
Management is responsible for the preparation, integrity, and fair
presentation of the accompanying consolidated financial statements of Public
Service Company of New Hampshire and subsidiaries and other sections of this
annual report. These financial statements, which were audited by Deloitte &
Touche LLP, have been prepared in conformity with accounting principles
generally accepted in the United States of America using estimates and
judgments, where required, and giving consideration to materiality.
The company has endeavored to establish a control environment that encourages
the maintenance of high standards of conduct in all of its business
activities. Management is responsible for maintaining a system of internal
control over financial reporting that is designed to provide reasonable
assurance, at an appropriate cost-benefit relationship, to the company's
management and Board of Trustees of Northeast Utilities regarding the
preparation of reliable published financial statements. The system is
supported by an organization of trained management personnel, policies and
procedures, and a comprehensive program of internal audits. Through
established programs, the company regularly communicates to its management
employees their internal control responsibilities and obtains information
regarding compliance with policies prohibiting conflicts of interest and
policies segregating information between regulated and unregulated subsidiary
companies. The company has standards of business conduct for all employees,
as well as a code of ethics for senior financial officers.
The Audit Committee of the Board of Trustees of Northeast Utilities is
composed entirely of independent trustees and includes two members that the
Board of Trustees considers "audit committee financial experts." The Audit
Committee meets regularly with management, the internal auditors and the
independent auditors to review the activities of each and to discuss audit
matters, financial reporting matters, and the system of internal controls
over financial reporting. The Audit Committee also meets periodically with
the internal auditors and the independent auditors without management
present.
Because of inherent limitations in any system of internal controls, errors or
irregularities may occur and not be detected. The company believes, however,
that its system of internal controls over financial reporting and control
environment provide reasonable assurance that its assets are safeguarded from
loss or unauthorized use and that its financial records, which are the basis
for the preparation of all financial statements, are reliable. Additionally,
management believes that its disclosure controls and procedures are in place
and operating effectively. Disclosure controls and procedures are designed
to ensure that information included in reports such as this annual report is
recorded, processed, summarized, and reported within the time periods
required and that the information disclosed is accumulated and reviewed by
management for discussion and approval.
INDEPENDENT AUDITORS' REPORT
- -------------------------------------------------------------------------------
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) (the
"Company") as of December 31, 2003 and 2002, 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,
2003. 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 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
audits provide a reasonable basis for our opinion.
In our opinion, such 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, 2003 and 2002, and the results
of their operations and their cash flows for each of the three years in the
period ended December 31, 2003, in conformity with accounting principles
generally accepted in the United States of America.
As discussed in Note 1C to the consolidated financial statements, in 2003,
the Company adopted Emerging Issues Task Force Issue 03-11, Reporting
Realized Gains and Losses on Derivative Instruments that are Subject to FASB
Statement No. 133 and not "Held for Trading Purposes" as Defined in Issue No.
02-3, and retroactively, restated the 2002 and 2001 consolidated financial
statements.
/s/ DELOITTE & TOUCHE LLP
DELOITTE & TOUCHE LLP
Hartford, Connecticut
February 23, 2004
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
- -----------------------------------------------------------------------------------------
At December 31, 2003 2002
- -----------------------------------------------------------------------------------------
(Thousands of Dollars)
ASSETS
- ------
Current Assets:
Cash $ 2,737 $ 5,319
Special deposits 30,104 -
Receivables, net less provision for uncollectible
accounts of $1,590 in 2003 and $1,990 in 2002 67,121 68,204
Accounts receivable from affiliated companies 11,291 9,667
Unbilled revenues 39,220 32,004
Notes receivable from affiliated companies - 23,000
Fuel, materials and supplies, at average cost 54,533 49,182
Derivative assets 1,510 -
Prepayments and other 9,945 10,032
------------- -------------
216,461 197,408
------------- -------------
Property, Plant and Equipment:
Electric utility 1,517,513 1,431,774
Other 5,707 6,195
------------- -------------
1,523,220 1,437,969
Less: Accumulated depreciation 635,029 648,800
------------- -------------
888,191 789,169
Construction work in progress 37,401 50,547
------------- -------------
925,592 839,716
------------- -------------
Deferred Debits and Other Assets:
Regulatory assets 969,434 1,026,043
Other 60,324 92,280
------------- -------------
1,029,758 1,118,323
------------- -------------
Total Assets $ 2,171,811 $ 2,155,447
============= =============
The accompanying notes are an integral part of these consolidated financial
statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
- --------------------------------------------------------------------------------------------
At December 31, 2003 2002
- --------------------------------------------------------------------------------------------
(Thousands of Dollars)
LIABILITIES AND CAPITALIZATION
- ------------------------------
Current Liabilities:
Notes payable to banks $ 10,000 $ -
Notes payable to affiliated companies 48,900 -
Accounts payable 48,408 54,588
Accounts payable to affiliated companies 13,911 4,008
Accrued taxes 2,543 65,317
Accrued interest 10,894 11,333
Unremitted rate reduction bond collections 11,051 25,555
Derivative liabilities 1,414 -
Other 16,689 12,674
-------------- -------------
163,810 173,475
-------------- -------------
Rate Reduction Bonds 472,222 510,841
-------------- -------------
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes 338,930 359,910
Accumulated deferred investment tax credits 2,096 2,680
Deferred contractual obligations 64,237 56,165
Regulatory liabilities 272,081 254,064
Accrued pension 44,766 37,933
Other 26,124 31,264
-------------- -------------
748,234 742,016
-------------- -------------
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 2003 and 2002 - -
Capital surplus, paid in 156,555 126,937
Retained earnings 223,822 194,998
Accumulated other comprehensive loss (117) (105)
-------------- -------------
Common Stockholder's Equity 380,260 321,830
-------------- -------------
Total Capitalization 787,545 729,115
-------------- -------------
Commitments and Contingencies (Note 7)
Total Liabilities and Capitalization $ 2,171,811 $ 2,155,447
============== =============
The accompanying notes are an integral part of these consolidated financial
statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
- -----------------------------------------------------------------------------------------------------------
For the Years Ended December 31, 2003 2002 2001
- -----------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
Operating Revenues $ 888,186 $ 947,178 $ 964,415
----------- ----------- ------------
Operating Expenses:
Operation -
Fuel, purchased and net interchange power 400,518 288,427 506,397
Other 142,550 126,506 123,533
Maintenance 64,872 64,146 56,276
Depreciation 43,322 40,941 39,741
Amortization of regulatory assets, net 37,861 196,246 38,629
Amortization of rate reduction bonds 40,040 42,714 26,816
Taxes other than income taxes 33,407 34,226 38,375
----------- ----------- ------------
Total operating expenses 762,570 793,206 829,767
----------- ----------- ------------
Operating Income 125,616 153,972 134,648
Interest Expense:
Interest on long-term debt 15,408 16,752 29,308
Interest on rate reduction bonds 29,081 30,499 20,721
Other interest 727 1,874 915
----------- ----------- ------------
Interest expense, net 45,216 49,125 50,944
----------- ----------- ------------
Other (Loss)/Income, Net (5,003) (1,671) 36,643
----------- ----------- ------------
Income Before Income Tax Expense 75,397 103,176 120,347
Income Tax Expense 29,773 40,279 38,571
----------- ----------- ------------
Net Income $ 45,624 $ 62,897 $ 81,776
=========== =========== ============
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net Income $ 45,624 $ 62,897 $ 81,776
----------- ----------- ------------
Other comprehensive income/(loss), net of tax:
Unrealized gains/(losses) on securities 128 (620) (801)
Minimum supplemental executive retirement
pension liability adjustments (140) 109 -
----------- ----------- ------------
Other comprehensive loss, net of tax (12) (511) (801)
----------- ----------- ------------
Comprehensive Income $ 45,612 $ 62,386 $ 80,975
=========== =========== ============
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
- --------------------------------------------------------------------------------------------------------------------
Accumulated
Common Stock Capital Other
---------------- Surplus, Retained Comprehensive Total
Shares Amount Paid In Earnings Income/(Loss) (a)
- --------------------------------------------------------------------------------------------------------------------
(Thousands of Dollars, except share information)
Balance at January 1, 2001 1,000 $ 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 (612) (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 388 - 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 (87) (37,000) (37,000)
Allocation of benefits - ESOP (1,063) 682 (381)
Other comprehensive loss (511) (511)
----- ---- --------- -------- ------ --------
Balance at December 31, 2002 301 - 126,937 194,998 (105) 321,830
Net income for 2003 45,624 45,624
Cash dividends on common stock (16,800) (16,800)
Allocation of benefits - ESOP (382) (382)
Capital contribution from NU parent 30,000 30,000
Other comprehensive loss (12) (12)
----- ---- --------- -------- ------ --------
Balance at December 31, 2003 301 $ - $ 156,555 $223,822 $ (117) $380,260
===== ==== ========= ======== ====== ========
(a) The Federal Power Act, the Public Utility Holding Act of 1935 (the
1935 Act), and certain state statutes limit the payment of dividends by
the company to its retained earnings balance.
The Utility Group credit agreement also limits dividend payments subject
to the requirements that the company's total debt to total capitalization
ratio does not exceed 65 percent.
At December 31, 2003, retained earnings available for payment of dividends
is restricted to $84.0 million.
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
- ---------------------------------------------------------------------------------------------------------------
For the Years Ended December 31, 2003 2002 2001
- ---------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
Operating activities:
Net income $ 45,624 $ 62,897 $ 81,776
Adjustments to reconcile to net cash flows
provided by operating activities:
Depreciation 43,322 40,941 39,741
Deferred income taxes and investment tax credits, net (6,670) (79,866) 195,422
Amortization of regulatory assets, net 37,861 196,246 38,629
Amortization of rate reduction bonds 40,040 42,714 26,816
Amortization of recoverable energy costs 23,388 9,859 (21,234)
Regulatory recoveries 10,778 (34,315) (133,954)
Other sources of cash 23,723 23,708 113,626
Other uses of cash (52,769) (18,137) (42,060)
Changes in current assets and liabilities:
Receivables and unbilled revenues, net (7,757) 2,989 3,212
Fuel, materials and supplies (5,351) (7,135) (13,287)
Other current assets (excludes cash) 87 179 14,576
Accounts payable 3,723 7,583 (48,888)
Accrued taxes (62,774) 63,036 1,624
Other current liabilities (10,981) 14,253 15,716
---------- ---------- ----------
Net cash flows provided by operating activities 82,244 324,952 271,715
---------- ---------- ----------
Investing Activities:
Investments in plant (105,626) (108,729) (91,770)
NU system Money Pool borrowing/(lending) 71,900 (46,000) 23,000
Investments in nuclear decommissioning trusts - - (137)
Net proceeds from sale of utility plant - - 24,888
Buyout/buydown of IPP contracts (20,437) (5,152) (48,164)
CVEC acquisition special deposit (30,104) - -
Other investment activities 15,066 (8,269) (30,906)
---------- ---------- ----------
Net cash flows used in investing activities (69,201) (168,150) (123,089)
---------- ---------- ----------
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 (38,619) (46,540) (17,619)
Increase/(decrease) in short-term debt 10,000 (60,500) 60,500
Reacquisitions and retirements of long-term debt - - (287,485)
Reacquisitions and retirements of preferred stock - - (24,268)
Buydown of capital lease obligation - - (497,508)
Capital contribution from Northeast Utilities 30,000 - -
Cash dividends on preferred stock - - (1,286)
Cash dividends on common stock (16,800) (45,000) (27,000)
Other financing activities (206) (13,922) (21,448)
---------- ---------- ----------
Net cash flows used in financing activities (15,625) (152,962) (263,629)
---------- ---------- ----------
Net (decrease)/increase in cash (2,582) 3,840 (115,003)
Cash - beginning of year 5,319 1,479 116,482
---------- ---------- ----------
Cash - end of year $ 2,737 $ 5,319 $ 1,479
========== ========== ==========
Supplemental Cash Flow Information:
Cash paid during the year for:
Interest, net of amounts capitalized $ 45,639 $ 47,506 $ 47,369
========== ========== ==========
Income taxes $ 97,165 $ 56,458 $ 168,021
========== ========== ==========
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) is a wholly
owned subsidiary of Northeast Utilities (NU). 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). PSNH,
The Connecticut Light and Power Company (CL&P), and Western Massachusetts
Electric Company (WMECO), furnish franchised retail electric service in New
Hampshire, Connecticut and Massachusetts, respectively.
Several wholly owned subsidiaries of NU provide support services for NU's
companies, including PSNH. Northeast Utilities Service Company (NUSCO)
provides centralized accounting, administrative, engineering, financial,
information technology, legal, operational, planning, purchasing, and other
services to NU's companies.
B. PRESENTATION
The consolidated financial statements of PSNH and of its subsidiaries, as
applicable, include the accounts of all their respective subsidiaries.
Intercompany transactions have been eliminated in consolidation.
The preparation of financial statements in conformity with accounting
principles generally accepted in the United States of America requires
management to make estimates and assumptions that affect the reported amounts
of assets and liabilities and disclosure of contingencies 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. Reclassifications were made to cost of
removal, regulatory asset and liability amounts and special deposits on the
accompanying consolidated balance sheets and operating revenues and fuel,
purchased and net interchange power on the accompanying consolidated
statements of income. Reclassifications have also been made to the
accompanying consolidated statements of cash flows.
C. NEW ACCOUNTING STANDARDS
Derivative Accounting: Effective January 1, 2001, PSNH adopted Statement of
Financial Accounting Standards (SFAS) No. 133, "Accounting for Derivative
Instruments and Hedging Activities," as amended. In April 2003, the
Financial Accounting Standards Board (FASB) issued SFAS No. 149, "Amendment
of Statement 133 on Derivative Instruments and Hedging Activities," which
amends SFAS No. 133. This new statement incorporates interpretations that
were included in previous Derivative Implementation Group guidance, clarifies
certain conditions, and amends other existing pronouncements. It is
effective for contracts entered into or modified after June 30, 2003. The
adoption of SFAS No. 149 resulted in fair value accounting for certain PSNH
contracts that are subject to unplanned netting and do not meet the
definition of capacity contracts. These non-trading derivative contracts are
recorded at fair value at December 31, 2003, as derivative assets and
liabilities with offsetting amounts recorded as regulatory liabilities and
assets because the contracts are part of providing regulated electric or gas
service.
In August of 2003, the FASB ratified the consensus reached by its Emerging
Issues Task Force (EITF) in July 2003 on EITF Issue No. 03-11, "Reporting
Realized Gains and Losses on Derivative Instruments That Are Subject to FASB
Statement No. 133 and Not `Held for Trading Purposes' as Defined in Issue No.
02-3." Prior to Issue No. 03-11, no specific guidance existed to address the
classification in the income statement of derivative contracts that are not
held for trading purposes. The consensus states that determining whether
realized gains and losses on contracts that physically deliver and are not
held for trading purposes should be reported on a net or gross basis is a
matter of judgment that depends on the relevant facts and circumstances.
PSNH has derivative sales contracts, and though these contracts may result in
physical delivery, management has determined, based on the relevant facts and
circumstances, that because these transactions are part of PSNH's procurement
activities, inclusion in operating expenses better depicts these sales
activities. At December 31, 2003, settlements of these derivative contracts
that are not held for trading purposes, though previously reported on a gross
basis, are reported on a net basis in expenses. Sales amounting to $48.9
million for the first nine months of 2003 were reflected as revenues in
quarterly reporting but are now included in expenses.
In Issue No. 03-11, the EITF did not provide transition guidance, which
management could have interpreted as becoming applicable on October 1, 2003
for revenues from that date forward. However, management applied its
conclusion on net or gross reporting to all periods presented to enhance
comparability. Operating revenues and fuel, purchased and net interchange
power for the year ended December 31, 2003 reflect net reporting. The
adoption of net reporting had no effect on net income.
The impact on previously reported 2002 and 2001 amounts is as follows:
- ---------------------------------------------------------------------
For the Years Ended December 31,
- ---------------------------------------------------------------------
(Millions of Dollars) 2002 2001
- ---------------------------------------------------------------------
Operating Revenues:
As previously reported $1,046.8 $1,171.6
Impact of reclassifications (99.6) (207.2)
- ---------------------------------------------------------------------
As currently reported $ 947.2 $ 964.4
- ---------------------------------------------------------------------
Fuel, Purchased and Net
Interchange Power:
As previously reported $ 388.0 $ 713.6
Impact of reclassifications (99.6) (207.2)
- ---------------------------------------------------------------------
As currently reported $ 288.4 $ 506.4
- ---------------------------------------------------------------------
Employers' Disclosures about Pensions and Other Postretirement Benefits: In
December 2003, the FASB issued SFAS No. 132 (Revised 2003), "Employers'
Disclosures about Pensions and Other Postretirement Benefits," (SFAS No.
132R). This statement revises employers' disclosures about pension plans and
other postretirement benefit plans, requires additional disclosures about the
assets, obligations, cash flows, and the net periodic benefit cost of defined
benefit pension plans and other defined benefit postretirement plans and
requires companies to disclose various elements of pension and postretirement
benefit costs in interim period financial statements. The revisions in SFAS
No. 132R are effective for 2003, and PSNH included the disclosures required
by SFAS No. 132R in this annual report. For the required disclosures, see
Note 5, "Pension Benefits and Postretirement Benefits Other Than Pensions,"
to the consolidated financial statements.
Liabilities and Equity: In May 2003, the FASB issued SFAS No. 150,
"Accounting for Certain Financial Instruments with Characteristics of Both
Liabilities and Equity." SFAS No. 150 establishes standards on how to
classify and measure certain financial instruments with characteristics of
both liabilities and equity. SFAS No. 150 is effective for financial
instruments entered into or modified after May 31, 2003, and was otherwise
effective for PSNH for the third quarter of 2003. The adoption of SFAS No.
150 did not have an impact on PSNH's consolidated financial statements.
Consolidation of Variable Interest Entities: In December 2003, the FASB
issued a revised version of FASB Interpretation No. (FIN) 46 "Consolidation
of Variable Interest Entities," (FIN 46R). FIN 46R is effective for PSNH for
the first quarter of 2004 but is not expected to have an impact on PSNH's
consolidated financial statements.
D. GUARANTEES
At December 31, 2003, NU had outstanding guarantees to PSNH of $4.4 million.
PSNH has no guarantees outstanding at December 31, 2003.
E. REVENUES
PSNH retail revenues are based on rates approved by the NHPUC. These
regulated rates are applied to customers' use of energy to calculate a bill.
In general, rates can only be changed through formal proceedings with the
NHPUC.
NHPUC utilizes regulatory commission-approved tracking mechanisms to track
the recovery of certain incurred costs. The tracking mechanisms allow for
rates to be changed periodically, with overcollections refunded to customers
or underrecollections collected from customers in future periods.
Unbilled revenues represent an estimate of electricity delivered to customers
that has not been billed. Unbilled revenues represent assets on the balance
sheet that become accounts receivable in the following month as customers are
billed. Billed revenues are based on meter readings.
Unbilled revenues are estimated monthly using the requirements method. The
requirements method utilizes the total monthly volume of electricity or gas
delivered to the system and applies a delivery efficiency factor to reduce
the total monthly volume by an estimate of delivery losses in order to
calculate total estimated monthly sales to customers. The total estimated
monthly sales amount less total monthly billed sales amount results in a
monthly estimate of unbilled sales. Unbilled revenues are estimated by
applying an average rate to the estimate of unbilled sales.
In 2003, the unbilled sales estimates for PSNH were tested using the cycle
method. The cycle method uses the billed sales from each meter reading cycle
and an estimate of unbilled days in each month based on the meter reading
schedule. The cycle method is historically more accurate than the
requirements method when used in a mostly weather-neutral month. The cycle
method resulted in adjustments to the estimate of unbilled revenues that had
a positive after-tax earnings impact on PSNH of $3.3 million in 2003.
Wholesale transmission revenues are based on rates and formulas that are
approved by the FERC. Most of PSNH's wholesale transmission revenues are
collected through a combination of the New England Regional Network Service
(RNS) tariff and PSNH's Local Network Service (LNS) tariff. The RNS tariff,
which is administered by the New England Independent System Operator,
recovers the revenue requirements associated with transmission facilities
that are deemed by the FERC to be Pool Transmission Facilities. The LNS
tariff which was accepted by the FERC on October 22, 2003, provides for the
recovery of PSNH's total transmission revenue requirements, net of revenue
credits received from various rate components, including revenues received
under the RNS rates.
F. ACCOUNTING FOR ENERGY CONTRACTS
The accounting treatment for energy contracts entered into varies between
contracts and depends on the intended use of the particular contract and on
whether or not the contracts are derivatives.
Non-derivative contracts that are entered into for the normal purchase or
sale of energy to customers that will result in physical delivery are
recorded at the point of delivery under accrual accounting.
Derivative contracts that are entered into for the normal purchase and sale
of energy and meet the normal purchase and sale exception to derivative
accounting, as defined in SFAS No. 133 and amended by SFAS No. 149 (normal),
are also recorded at the point of delivery under accrual accounting.
Both non-derivative contracts and derivative contracts that are normal are
recorded in revenues when these contracts represent sales, and recorded in
fuel, purchased and net interchange power when these contracts represent
purchases, except for sales contracts that relate to procurement activities.
These contracts are recorded in fuel, purchased and net interchange power
when settled.
Derivative contracts that are not held for trading purposes and that do not
qualify as normal purchases and sales or hedges are non-trading derivative
contracts. These contracts are recorded on the consolidated balance sheets
at fair value, and since management believes that these costs will continue
to be recovered or refunded in rates, the changes in fair value are offset by
regulatory assets and liabilities.
For further information regarding these contracts and their accounting, see
Note 4, "Derivative Instruments and Risk Management Activities," to the
consolidated financial statements.
G. REGULATORY ACCOUNTING
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."
The transmission, distribution and generation businesses of PSNH continue to
be cost-of-service rate regulated. The state's electric utility industry
restructuring laws have been modified to delay the sale of PSNH's fossil and
hydroelectric generation assets until at least April of 2006. There has been
no regulatory action to the contrary, 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 on and recovery of these assets,
as well as all operating expenses, PSNH meets the criteria for the
application of SFAS No. 71. Stranded costs related to 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.
Management believes the application of SFAS No. 71 to the portions of the
aforementioned businesses continues to be appropriate. Management also
believes it is probable that PSNH will recover their investments in long-
lived assets, including regulatory assets. In addition, all material net
regulatory assets are earning an equity return, except for securitized
regulatory assets, which are not supported by equity.
The components of regulatory assets are as follows:
- ----------------------------------------------------------------
At December 31,
- ----------------------------------------------------------------
(Millions of Dollars) 2003 2002
- ----------------------------------------------------------------
Recoverable nuclear costs $ 33.3 $ 36.8
Securitized assets 465.3 505.4
Income taxes, net 44.2 96.5
Unrecovered contractual obligations 69.9 58.7
Recoverable energy costs 218.3 241.7
Other 138.4 87.0
- ----------------------------------------------------------------
Totals $969.4 $1,026.1
- ----------------------------------------------------------------
Recoverable Nuclear Costs: In March 2001, PSNH recorded a regulatory asset
in conjunction with the sale of the Millstone nuclear units (Millstone) with
an unamortized balance of $33.3 million and $36.8 million at December 31,
2003 and 2002, respectively, which is included in recoverable nuclear costs.
Securitized Assets: In April 2001, PSNH issued rate reduction certificates
in the amount of $525 million. PSNH used the majority of this amount to
buy down its power contract with North Atlantic Energy Corporation (NAEC).
The remaining balance is $427 million and $460 million at December 31, 2003
and 2002, respectively.
In January 2002, PSNH issued an additional $50 million in rate reduction
certificates and used the proceeds from this issuance to repay short-term
debt that was incurred to buy out a purchased-power contract in December 2001.
The remaining balance is $38 million and $46 million at December 31, 2003 and
2002, respectively.
Securitized assets are being recovered over the amortization period of their
associated rate reduction bonds. All outstanding rate reduction bonds of
PSNH are scheduled to fully amortize by May 1, 2013.
Income Taxes, Net: 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
NHPUC and SFAS No. 109. Differences in income taxes between SFAS No. 109 and
the rate-making treatment of the NHPUC are recorded as regulatory assets.
For further information regarding income taxes, see Note 1H, "Summary of
Significant Accounting Policies - Income Taxes," and Note 12, "Income Tax
Expense," to the consolidated financial statements.
Unrecovered Contractual Obligations: PSNH, under the terms of contracts with
the Yankee Companies, is responsible for their proportionate share of the
remaining costs of the units, including decommissioning. These amounts are
recorded as unrecovered contractual obligations and are 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.
In November 2003, the Connecticut Yankee Atomic Power Company (CYAPC)
prepared an updated estimate of the cost of decommissioning its nuclear unit.
PSNH's aggregate share of the estimated increased cost is $17.1 million.
PSNH recorded an additional $17.1 million in deferred contractual obligations
and a corresponding increase in the unrecovered contractual obligations
regulatory asset as a result of these increased costs.
Recoverable Energy Costs: 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, 2003 and 2002, PSNH had $162.2 million and $179.6 million,
respectively, of recoverable energy costs deferred under the FPPAC, including
previous deferrals of purchases from IPPs. Under the Restructuring
Settlement, the FPPAC deferrals are recovered as a Part 3 stranded cost
through a stranded cost recovery charge (SCRC). Also included in PSNH's
recoverable energy costs are costs associated with certain contractual
purchases from IPPs that had previously been included in the FPPAC. These
costs are treated as Part 3 stranded costs and amounted to $56.1 million and
$62.1 million at December 31, 2003 and 2002, respectively.
PSNH's recoverable energy costs are Part 3 stranded costs which are
nonsecuritized regulatory assets which must be recovered by a recovery end
date to be determined in accordance with the Restructuring Settlement or
which will be written off. Based on current projections, PSNH expects to
fully recover all of its Part 3 stranded costs by the recovery end date.
Regulatory Liabilities: PSNH maintained $272.1 million and $254.1 million of
regulatory liabilities at December 31, 2003 and 2002, respectively. These
amounts are comprised of the following:
- ----------------------------------------------------------------
At December 31,
- ----------------------------------------------------------------
(Millions of Dollars) 2003 2002
- ----------------------------------------------------------------
Cost of removal $ 88.0 $ 67.0
SCRC overcollections 160.4 166.2
Regulatory liabilities offsetting
derivative assets 1.5 -
Other regulatory liabilities 22.2 20.9
- ----------------------------------------------------------------
Totals $272.1 $254.1
- ----------------------------------------------------------------
Under SFAS No. 71, PSNH currently recovers amounts in rates for future costs
of removal of plant assets. Historically, these amounts were included as a
component of accumulated depreciation until spent. These amounts were
reclassified to regulatory liabilities on the accompanying consolidated
balance sheets.
The SCRC allows PSNH to recover its stranded costs.
The regulatory liabilities offsetting derivative assets relate to the fair
value of purchase and sales contracts used for market discovery of future
procurement activities that will benefit ratepayers in the future. PSNH also
has financial transmission rights (FTR) contracts which are derivative assets
offset by a regulatory liability.
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.
The tax effects of temporary differences that give rise to the net
accumulated deferred tax obligation are as follows:
- ----------------------------------------------------------------
At December 31,
- ----------------------------------------------------------------
(Millions of Dollars) 2003 2002
- ----------------------------------------------------------------
Deferred tax liabilities:
Accelerated depreciation and
other plant-related differences $117.6 $100.0
Regulatory amounts:
Securitized contract termination
costs and other 173.3 183.0
Deferrals of fuel and small
power producer costs 91.9 94.0
Income tax gross-up 17.8 38.0
Other 68.7 66.1
- ----------------------------------------------------------------
Total deferred tax liabilities 469.3 481.1
- ----------------------------------------------------------------
Deferred tax assets:
Regulatory deferrals 96.7 90.2
Employee benefits 21.0 18.7
Income tax gross-up 1.0 1.2
Other 11.7 11.1
- ----------------------------------------------------------------
Total deferred tax assets 130.4 121.2
- ----------------------------------------------------------------
Totals $338.9 $359.9
- ----------------------------------------------------------------
NU and its subsidiaries, including PSNH, file a consolidated federal income
tax return. Likewise NU and its subsidiaries, including PSNH, file state
income tax returns, with some filing in more than one state. NU and its
subsidiaries, including PSNH, are parties to a tax allocation agreement under
which each taxable subsidiary pays a quarterly estimate (or settlement) of no
more than it would have otherwise paid had it filed a stand-alone tax return.
Generally these quarterly estimated payments are settled to actual payments
within three months after filing the associated return. Subsidiaries
generating tax losses are similarly paid for their losses when utilized.
In 2000, NU requested from the Internal Revenue Service (IRS) a Private
Letter Ruling (PLR) regarding the treatment of unamortized investment tax
credits (ITC) and excess deferred income taxes (EDIT) related to generation
assets that have been sold. EDIT are temporary differences between book and
taxable income that were recorded when the federal statutory tax rate was
higher than it is now or when those differences were expected to be resolved.
The PLR addresses whether or not EDIT and ITC can be returned to customers,
which without a PLR management believes would represent a violation of
current tax law. The IRS declared a moratorium on issuing PLRs until final
regulations on the return of EDIT and ITC to regulated customers are issued
by the Treasury Department. Proposed regulations were issued in March 2003,
and a hearing took place in June 2003. The proposed new regulations would
allow the return of EDIT and ITC to regulated customers without violating the
tax law. Also, under the proposed regulations, a company could elect to
apply the regulation retroactively. The Treasury Department is currently
deliberating the comments received at the hearing. If final regulations
consistent with the proposed regulations are issued, then there could be an
impact on PSNH's financial statements.
I. DEPRECIATION
The provision for depreciation on utility assets is calculated using the
straight-line method based on the estimated remaining useful lives of
depreciable 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 it is 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. Cost of removal is now classified as a regulatory liability.
The depreciation rates for the several classes of electric utility plant-in-
service are equivalent to a composite rate of 3 percent in 2003, 2002 and
2001.
J. EQUITY INVESTMENTS AND JOINTLY OWNED ELECTRIC UTILITY PLANT
Regional Nuclear Companies: At December 31, 2003, PSNH owns common stock in
three regional nuclear companies (Yankee Companies). PSNH's ownership
interests in the Yankee Companies at December 31, 2003, which are accounted
for on the equity method are 5 percent of the CYAPC, 7 percent of the Yankee
Atomic Electric Company (YAEC) and 5 percent of the Maine Yankee Atomic Power
Company (MYAPC). Effective November 7, 2003, PSNH sold its collective 4.3
percent ownership interest in Vermont Yankee Nuclear Power Corporation
(VYNPC). PSNH's total equity investment in the Yankee Companies at
December 31, 2003 and 2002 is $4.6 million and $8 million respectively. Each
of the remaining Yankee Companies owns a single nuclear generating plant
which is being decommissioned.
K. ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION
The allowance for funds used during construction (AFUDC) is a non-cash item
that is included in the cost of utility plant and represents the cost of
borrowed and equity funds used to finance construction. The portion of AFUDC
attributable to borrowed funds is recorded as a reduction of other interest
expense, and the cost of equity funds is recorded as other income on the
consolidated statements of income:
- -----------------------------------------------------------
For the Years Ended December 31,
- -----------------------------------------------------------
(Millions of Dollars,
except percentages) 2003 2002 2001
- -----------------------------------------------------------
Borrowed funds $0.6 $1.0 $0.9
Equity funds 0.6 0.6 1.7
- -----------------------------------------------------------
Totals $1.2 $1.6 $2.6
- -----------------------------------------------------------
Average AFUDC rates 3.9% 4.7% 8.8%
- -----------------------------------------------------------
L. ASSET RETIREMENT OBLIGATIONS
In June 2001, the FASB issued 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 was effective on January 1, 2003,
for PSNH. Management has completed its review process for potential asset
retirement obligations (ARO) and has not identified any material AROs that
have been incurred. However, management identified certain removal obligations
that arise in the ordinary course of business or have a low probability of
occurring. 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. These
obligations are AROs that have not been incurred or are not material in nature.
A portion of PSNH's rates is intended to recover the cost of removal of
certain utility assets. The amounts recovered do not represent AROs. At
December 31, 2003 and 2002, cost of removal was approximately $88 million and
$67 million, respectively.
M. MATERIALS AND SUPPLIES
Materials and supplies include materials purchased primarily for
construction, operation and maintenance (O&M) purposes. Materials and
supplies are valued at the lower of average cost or market.
N. SPECIAL DEPOSITS
Special deposits represents $30.1 million in escrow that PSNH funded to
acquire Connecticut Valley Electric Company, Inc. on January 1, 2004.
O. OTHER (LOSS)/INCOME
The pre-tax components of PSNH's other (loss)/income items are as follows:
- ---------------------------------------------------------------------
For the Years Ended December 31,
- ---------------------------------------------------------------------
(Millions of Dollars) 2003 2002 2001
- ---------------------------------------------------------------------
Gain related to Millstone sale $ - $ - $25.9
Investment income 0.1 1.2 2.3
Charitable donations (0.4) (0.4) (0.7)
Other (4.7) (2.5) 9.1
- ---------------------------------------------------------------------
Totals $(5.0) $(1.7) $36.6
- ---------------------------------------------------------------------
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 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 and refunded
the remaining proceeds from the sale to PSNH through the Seabrook Power
Contracts. 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. On June 30, 2003, the SEC granted authorization allowing PSNH to
incur total short-term borrowings up to a maximum of $100 million through
June 30, 2006, with authorization for borrowings from the NU Money Pool
(Pool) granted through June 30, 2004.
PSNH is authorized by the NHPUC to incur short-term borrowings up to a
maximum of $100 million.
Credit Agreement: On November 10, 2003, PSNH, CL&P, WMECO and Yankee Gas
entered into a 364-day unsecured revolving credit facility for $300 million.
This facility replaces a similar credit facility that expired on November 11,
2003 and PSNH may draw up to $100 million under this facility. Unless
extended, the credit facility will expire on November 8, 2004. At December 31,
2003 and 2002, there were $10 million and no borrowings, respectively,
under these credit 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, 2003 was 2 percent.
Under the credit agreement, PSNH must comply with certain financial and non-
financial covenants as are customarily included in such agreements, including
but not limited to, consolidated debt ratios and interest coverage ratios.
The most restrictive financial covenant is the interest coverage ratio. PSNH
currently is and expects to remain in compliance with these covenants.
Pool: PSNH is a member of the 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, 2003 and 2002, PSNH had borrowings of $48.9
million and lendings of $23 million to the Pool, respectively. The interest
rate on borrowings from and lendings to the Pool at December 31, 2003 and
2002 was 1 percent and 1.2 percent, respectively.
4. DERIVATIVE INSTRUMENTS AND RISK MANAGEMENT ACTIVITIES
- -------------------------------------------------------------------------------
A. DERIVATIVE INSTRUMENTS
Effective January 1, 2001, PSNH adopted SFAS No. 133, as amended.
Derivatives that do not meet the definition of a cash flow hedge and cannot
be designated as being used for normal purchases or normal sales are also
recorded at fair value with changes in fair value included in earnings unless
recorded as a regulatory asset or liability. Derivative contracts that are
entered into as a normal purchase or sale and will result in physical
delivery, and are documented as such, are recorded under accrual accounting.
For information regarding accounting changes related to derivative
instruments, see Note 1C, "Summary of Significant Accounting Policies - New
Accounting Standards," to the consolidated financial statements.
In 2003, there were changes to interpretations of as well as an amendment to
SFAS No. 133, and the FASB continues to consider changes that could affect
the way PSNH records and discloses derivative and hedging activities.
PSNH has energy contracts that are subject to unplanned netting and do not
meet the definition of capacity contracts. These non-trading derivative
contracts were recorded at fair value at December 31, 2003 as derivative
assets of approximately $1.4 million and derivative liabilities with a fair
value of approximately $1.4 million with offsetting regulatory assets and
regulatory liabilities, respectively.
To mitigate the risk associated with certain supply contracts, PSNH purchased
FTRs. FTRs are derivatives that cannot qualify for the normal purchases and
sales exception. The fair value of these FTR non-trading derivatives at
December 31, 2003 was an asset of $0.1 million. PSNH had no non-trading
derivatives at December 31, 2002 that were required to be recorded at fair
value.
B. RISK MANAGEMENT ACTIVITIES
PSNH is subject to credit risk from certain long-term or high-volume supply
contracts with energy marketing companies. Credit risks and market risks at
PSNH are monitored regularly by a Risk Oversight Council operating outside of
the business units that create or actively manage these risk exposures to
ensure compliance with NU's stated risk management policies.
5. PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS
- -------------------------------------------------------------------------------
Pension Benefits: PSNH participates in a uniform noncontributory defined
benefit retirement plan (Pension 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) was $6.8 million of expense in 2003, $0.6 million of
expense in 2002, and $3.9 million of income in 2001. These amounts exclude
pension settlements, curtailments and net special termination expense of $1.3
million in 2001. PSNH uses a December 31 measurement date for the Pension
Plan. Pension expense/(income)attributable to earnings is as follows:
- -------------------------------------------------------------------------
For the Years Ended December 31,
- -------------------------------------------------------------------------
(Millions of Dollars) 2003 2002 2001
- -------------------------------------------------------------------------
Pension expense/(income) before
settlements, curtailments
and special termination benefits $ 6.8 $ 0.6 $(3.9)
Net pension expense/(income)
capitalized as utility plant (2.0) (0.2) (1.4)
- -------------------------------------------------------------------------
Net pension expense/(income)
before settlements, curtailments
and special termination
benefits 4.8 0.4 (2.5)
Settlements, curtailments and
special termination benefits
reflected in earnings - - 1.2
- -------------------------------------------------------------------------
Total pension expense/(income)
included in earnings $ 4.8 $ 0.4 $(1.3)
- -------------------------------------------------------------------------
Pension Settlements, Curtailments and Special Termination Benefits: There
were no settlements, curtailments or special termination benefits in 2002 and
2003.
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 5 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 which $1.2 million of costs were included in operating expenses,
$0.1 million was deferred as a regulatory liability and is expected to be
returned to customers.
Postretirement Benefits Other Than Pensions (PBOP): PSNH also provides
certain health care benefits, primarily medical and dental, and life
insurance benefits through a benefit plan to retired employees (PBOP Plan).
These benefits are available for employees retiring from PSNH 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. PSNH uses a December 31 measurement date for the PBOP Plan. PSNH
annually funds postretirement costs through external trusts with amounts that
have been rate-recovered and which also are tax deductible.
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.
Impact of New Medicare Changes on PBOP: On December 8, 2003, the President
signed into law a bill that expands Medicare, primarily by adding a
prescription drug benefit starting in 2006 for Medicare-eligible retirees as
well as a federal subsidy to plan sponsors of retiree health care benefit
plans who provide a prescription drug benefit at least actuarially equivalent
to the new Medicare benefit.
Based on the current PBOP Plan provisions, PSNH's actuaries believe that PSNH
will qualify for this federal subsidy because the actuarial value of PSNH's
PBOP Plan is estimated to be 60 percent greater than that of the standard
Medicare benefit. PSNH will directly benefit from the federal subsidy for
retirees who retired before 1993. For other retirees, management does not
believe that PSNH will benefit from the subsidy because PSNH's cost support
for these retirees is capped at a fixed dollar commitment.
The aggregate effect of recognizing the Medicare change is a decrease to the
PBOP benefit obligation of $4.4 million. This amount includes the present
value of the future government subsidy, which was estimated by discounting
the expected payments using the actuarial assumptions used to determine the
PBOP liability at December 31, 2003. Also included in the $4.4 million
estimate is a decrease in the assumed participation in NU's retiree health
plan from 95 percent to 85 percent for future retirees, which reflects the
expectation that the Medicare prescription benefit will produce insurer-
sponsored health plans that are more financially attractive to future
retirees. The per capita claims cost estimate was not changed. Management
reduced the PBOP benefit obligation as of December 31, 2003 by $4.4 million
and recorded this amount as an actuarial gain within unrecognized net
loss/(gain) in the tables that follow. The $4.4 million actuarial gain will
be amortized beginning in 2004 as a reduction to PBOP expense over the future
working lifetime of employees covered under the plan (approximately 13
years). PBOP expense in 2004 will also reflect a lower interest cost due to
the reduction in the December 31, 2003 benefit obligation.
Specific authoritative guidance on accounting for the effect of the Medicare
federal subsidy on PBOP plans and amounts is pending from the FASB. When
issued, that guidance could require PSNH to change the accounting described
above and change the information reported herein.
PBOP Settlements, Curtailments and Special Termination Benefits: There were
no settlements, curtailments or special termination benefits in 2002 and
2003. In 2001, PSNH recorded PBOP special termination benefits expense
totaling $0.2 million in connection with the VSP. This amount was recorded
as a regulatory asset and collected through regulated utility rates in 2002.
The following table represents information on the plans' benefit obligation,
fair value of plan assets, and the respective plans' funded status:
- ----------------------------------------------------------------------------------------------------------
At December 31,
- ----------------------------------------------------------------------------------------------------------
Pension Benefits Postretirement Benefits
- ----------------------------------------------------------------------------------------------------------
(Millions of Dollars) 2003 2002 2003 2002
- ----------------------------------------------------------------------------------------------------------
Change in benefit obligation
Benefit obligation at beginning of year $(260.9) $(227.9) $(63.7) $(65.4)
Service cost (6.4) (5.8) (1.1) (1.1)
Interest cost (17.3) (16.8) (4.5) (4.6)
Medicare impact - - 4.4 -
Plan amendment - (1.8) - 4.6
Transfers - (0.5) - -
Actuarial loss (17.3) (20.6) (8.5) (4.1)
Benefits paid - excluding lump sum payments 12.9 12.3 6.6 6.9
Benefits paid - lump sum payments - 0.2 - -
Curtailments and settlements - - - -
Special termination benefits - - - -
- ----------------------------------------------------------------------------------------------------------
Benefit obligation at end of year $(289.0) $(260.9) $(66.8) $(63.7)
- ----------------------------------------------------------------------------------------------------------
Change in plan assets
Fair value of plan assets at beginning of year $ 163.5 $ 196.6 $ 24.4 $ 28.4
Actual return on plan assets 41.3 (21.1) 5.7 (2.5)
Employer contribution - - 6.2 5.4
Plan asset transfer in - 0.5 - -
Benefits paid - excluding lump sum payments (12.9) (12.3) (6.6) (6.9)
Benefits paid - lump sum payments - (0.2) - -
- ----------------------------------------------------------------------------------------------------------
Fair value of plan assets at end of year $ 191.9 $ 163.5 $ 29.7 $ 24.4
- ----------------------------------------------------------------------------------------------------------
Funded status at December 31 $ (97.1) $ (97.4) $(37.1) $(39.3)
Unrecognized transition (asset)/obligation 2.0 2.3 22.4 24.8
Unrecognized prior service cost 13.0 14.5 - -
Unrecognized net loss/(gain) 37.3 42.7 14.7 14.4
- ----------------------------------------------------------------------------------------------------------
Prepaid/(accrued) benefit cost $ (44.8) $ (37.9) $ - $ (0.1)
- ----------------------------------------------------------------------------------------------------------
The accumulated benefit obligation for the Pension Plan was $243.6 million
and $218.4 million at December 31, 2003 and 2002, respectively. Plan assets
for the entire Pension Plan on an NU consolidated basis are approximately
$240 million more than the accumulated benefit obligation at December 31,
2003.
The following actuarial assumptions were used in calculating the plans' year
end funded status:
- -------------------------------------------------------------------------------
At December 31,
- -------------------------------------------------------------------------------
Balance Sheets Pension Benefits Postretirement Benefits
- -------------------------------------------------------------------------------
2003 2002 2003 2002
- -------------------------------------------------------------------------------
Discount rate 6.25% 6.75% 6.25% 6.75%
Compensation/progression rate 3.75% 4.00% N/A N/A
Health care cost trend rate N/A N/A 9.00% 10.00%
- -------------------------------------------------------------------------------
The components of net periodic (income)/expense are as follows:
- -----------------------------------------------------------------------------------------------------------------------
For the Years Ended December 31,
- -----------------------------------------------------------------------------------------------------------------------
Pension Benefits Postretirement Benefits
- -----------------------------------------------------------------------------------------------------------------------
(Millions of Dollars) 2003 2002 2001 2003 2002 2001
- -----------------------------------------------------------------------------------------------------------------------
Service cost $ 6.4 $ 5.8 $ 5.0 $ 1.1 $ 1.1 $ 1.1
Interest cost 17.3 16.8 15.8 4.5 4.6 4.3
Expected return on plan assets (18.2) (20.3) (20.9) (2.6) (2.9) (2.9)
Amortization of unrecognized net
transition (asset)/obligation 0.3 0.3 0.3 2.5 2.8 2.9
Amortization of prior service cost 1.5 1.4 1.3 - - -
Amortization of actuarial gain (0.5) (3.4) (5.4) - - -
Other amortization, net - - - 0.7 (0.3) (1.1)
- -----------------------------------------------------------------------------------------------------------------------
Net periodic (income)/expense - before
settlements, curtailments and special
termination benefits 6.8 0.6 (3.9) 6.2 5.3 4.3
- -----------------------------------------------------------------------------------------------------------------------
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 (income)/expense $ 6.8 $ 0.6 $ (2.6) $ 6.2 $ 5.3 $ 4.5
- -----------------------------------------------------------------------------------------------------------------------
For calculating pension and postretirement benefit income and expense
amounts, the following assumptions were used:
- -----------------------------------------------------------------------------------------
For the Years Ended December 31,
- -----------------------------------------------------------------------------------------
Statements of Income Pension Benefits Postretirement Benefits
- -----------------------------------------------------------------------------------------
2003 2002 2001 2003 2002 2001
- -----------------------------------------------------------------------------------------
Discount rate 6.75% 7.25% 7.50% 6.75% 7.25% 7.50%
Expected long-term rate of return 8.75% 9.25% 9.50% 8.75% 9.25% 9.50%
Compensation/progression rate 4.00% 4.25% 4.50% N/A N/A N/A
- -----------------------------------------------------------------------------------------
The following table represents the PBOP assumed health care cost trend rate
for the next year and the assumed ultimate trend rate:
- --------------------------------------------------------------------
Year Following December 31,
- ---------------------------------------------------------------------
2003 2002
- ---------------------------------------------------------------------
Health care cost trend rate
assumed for next year 8.00% 9.00%
Rate to which health care cost
trend rate is assumed to
decline (the ultimate trend rate) 5.00% 5.00%
Year that the rate reaches the
ultimate trend rate 2007 2007
- ---------------------------------------------------------------------
The annual per capita cost of covered health care benefits was assumed to
decrease by one percentage point each year through 2007.
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 $ 2.0 $(1.8)
- ---------------------------------------------------------------------
PSNH's investment strategy for its Pension Plan and PBOP Plan is to maximize
the long-term rate of return on those plans' assets within an acceptable
level of risk. The investment strategy establishes target allocations, which
are regularly reviewed and periodically rebalanced. PSNH's expected long-
term rates of return on Pension Plan assets and PBOP Plan assets are based on
these target asset allocation assumptions and related expected long-term
rates of return. In developing its expected long-term rate of return
assumptions for the Pension Plan and the PBOP Plan, PSNH also evaluated input
from actuaries, consultants and economists as well as long-term inflation
assumptions and PSNH's historical 20-year compounded return of approximately
11 percent. The Pension Plan's and PBOP Plan's target asset allocation
assumptions and expected long-term rate of return assumptions by asset
category are as follows:
- -----------------------------------------------------------------------------------------------------------------
At December 31,
- -----------------------------------------------------------------------------------------------------------------
Pension Benefits Postretirement Benefits
- -----------------------------------------------------------------------------------------------------------------
2003 2002 2003 2002
- -----------------------------------------------------------------------------------------------------------------
Target Assumed Target Assumed Target Assumed Target Assumed
Asset Rate of Asset Rate of Asset Rate of Asset Rate of
Asset Category Allocation Return Allocation Return Allocation Return Allocation Return
- -----------------------------------------------------------------------------------------------------------------
Equity securities:
United States 45.00% 9.25% 45.00% 9.75% 55.00% 9.25% 55.00% 9.75%
Non-United States 14.00% 9.25% 14.00% 9.75% 11.00% 9.25% - -
Emerging markets 3.00% 10.25% 3.00% 10.75% 2.00% 10.25% - -
Private 8.00% 14.25% 8.00% 14.75% - - - -
Debt Securities:
Fixed income 20.00% 5.50% 20.00% 6.25% 27.00% 5.50% 45.00% 6.25%
High yield fixed
income 5.00% 7.50% 5.00% 7.50% 5.00% 7.50% - -
Real estate 5.00% 7.50% 5.00% 7.50% - - - -
- -----------------------------------------------------------------------------------------------------------------
The actual asset allocations at December 31, 2003 and 2002, approximated
these target asset allocations. The plans' actual weighted-average asset
allocations by asset category are as follows:
- --------------------------------------------------------------------------
At December 31,
- --------------------------------------------------------------------------
Postretirement
Pension Benefits Benefits
- --------------------------------------------------------------------------
Asset Category 2003 2002 2003 2002
- --------------------------------------------------------------------------
Equity securities:
United States 47.00% 46.00% 59.00% 55.00%
Non-United States 18.00% 17.00% 12.00% -
Emerging markets 3.00% 3.00% 1.00% -
Private 3.00% 3.00% - -
Debt Securities:
Fixed income 19.00% 21.00% 25.00% 45.00%
High yield fixed
income 5.00% 5.00% 3.00% -
Real estate 5.00% 5.00% - -
- -------------------------------------------------------------------------
Total 100.00% 100.00% 100.00% 100.00%
- --------------------------------------------------------------------------
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.
PSNH does not expect to make any contributions to the Pension Plan in 2004
and expects to make $7 million in contributions to the PBOP Plan in 2004.
Postretirement health plan assets for non-union employees are subject to
federal income taxes.
6. NUCLEAR GENERATION ASSET DIVESTITURES
- -------------------------------------------------------------------------------
Seabrook: On November 1, 2002, NAEC consummated the sale of its 35.98
percent combined ownership interest in Seabrook to a subsidiary of FPL Group,
Inc. (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 and other
short-term debt, to return a portion of NAEC's equity to NU and was used to
pay approximately $93 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. On
November 7, 2003, PSNH sold its 4.3 percent ownership interest in VYNPC.
PSNH will continue to buy approximately 4 percent of the plant's output
through March 2012 at a range of fixed prices.
7. COMMITMENTS AND CONTINGENCIES
- -------------------------------------------------------------------------------
A. RESTRUCTURING AND RATE MATTERS
SCRC Reconciliation Filing: On an annual basis, PSNH files with the NHPUC an
SCRC reconciliation filing for the preceding calendar year. This filing
includes the reconciliation of stranded cost revenues with stranded costs,
and transition energy service (TS) revenues with TS costs. The NHPUC reviews
the filing, including a prudence review of PSNH's generation operations.
The 2003 SCRC filing is expected to be filed on May 1, 2004. Management does
not expect the review of the 2003 SCRC filing to have a material effect on
PSNH's net income or financial position.
B. ENVIRONMENTAL MATTERS
General: 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. These laws and regulations require the removal
or the remedy of the effect on the environment of the disposal or release of
certain specified hazardous substances at current and former operating sites.
As such, PSNH has an active environmental auditing and training program and
believes that it is substantially in compliance with all enacted laws and
regulations.
Environmental reserves are accrued using a probabilistic model approach when
assessments indicate that it is probable that a liability has been incurred
and an amount can be reasonably estimated. The probabilistic model approach
estimates the liability based on the most likely action plan from a variety
of available remediation options, ranging from no action to several different
remedies ranging from establishing institutional controls to full site
remediation and monitoring.
These estimates are subjective in nature as they take into consideration
several different remediation options at each specific site. The reliability
and precision of these estimates can be affected by several factors including
new information concerning either the level of contamination at the site,
recently enacted laws and regulations or a change in cost estimates due to
certain economic factors.
The amounts recorded as environmental liabilities on the consolidated balance
sheets represent management's best estimate of the liability for
environmental costs and takes into consideration site assessment and
remediation costs. Based on currently available information for estimated
site assessment and remediation costs at December 31, 2003 and 2002, PSNH had
$9.8 million and $10.8 million, respectively, recorded as environmental
reserves. A reconciliation of the total amount reserved at December 31, 2003
and 2002 is as follows:
- --------------------------------------------------------------------
(Millions of Dollars) For the Years Ended December 31,
- --------------------------------------------------------------------
2003 2002
- --------------------------------------------------------------------
Balance at beginning of year $10.8 $11.4
Additions and adjustments 0.8 1.1
Payments (1.8) (1.7)
- --------------------------------------------------------------------
Balance at end of year $ 9.8 $10.8
- --------------------------------------------------------------------
These liabilities are estimated on an undiscounted basis and do not assume
that any amounts are recoverable from insurance companies or other third
parties. The environmental reserve includes sites at different stages of
discovery and remediation and does not include any unasserted claims. At
December 31, 2003, there are two sites for which there are unasserted claims;
however, any related remediation costs are not probable or estimable at this
time. PSNH's environmental liability also takes into account recurring costs
of managing hazardous substances and pollutants, mandated expenditures to
remediate previously contaminated sites and any other infrequent and non-
recurring clean up costs.
PSNH currently has 15 sites included in the environmental reserve. Of those
15 sites, seven sites are in the remediation or long-term monitoring phase,
three sites have had site assessments completed and the remaining five sites
are in the preliminary stages of site assessment.
In addition, capital expenditures related to environmental matters are
expected to total approximately $84 million in aggregate for the years 2004
through 2008. Of the $84 million, $70 million relates to the proposed
conversion of a 50 megawatt oil and coal burning unit at Schiller Station to
a wood burning unit. The remainder primarily relates to other environmental
remediation programs including programs associated with PSNH's hydroelectric
generation assets.
MGP Sites: Manufactured gas plant (MGP) sites comprise the largest portion
of PSNH's environmental liability. MGPs are sites that manufactured gas from
coal and produced certain byproducts that may pose risk to human health and the
environment. At December 31, 2003 and 2002, $9.1 million and $8.7 million,
respectively, represent amounts for the site assessment and remediation of
MGPs. At December 31, 2003 and 2002, the two largest MGP sites comprise
approximately 87 percent and 94 percent, respectively, of the total MGP
environmental liability. PSNH currently has seven MGP sites included in its
environmental liability and one contingent MGP site of which management is
aware and for which costs are not probable or estimable at this time. Of the
seven MGP sites, three are currently undergoing remediation with the
remainder in the site assessment stage.
CERCLA Matters: The Comprehensive Environmental Response, Compensation and
Liability Act of 1980 (CERCLA) and its' amendments or state equivalents
impose joint and several strict liabilities, regardless of fault, upon
generators of hazardous substances resulting in removal and remediation costs
and environmental damages. Liabilities under these laws can be material and
in some instances may be imposed without regard to fault or for past acts
that may have been lawful at the time they occurred. PSNH has two superfund
sites under CERCLA for which it has been notified that it is a potentially
responsible party (PRP). For sites where there are other PRPs and PSNH is
not managing the site assessment and remediation, the liability accrued
represents PSNH's estimate of what it will need to pay to settle its
obligations with respect to the site.
It is possible that new information or future developments could require a
reassessment of the potential exposure to related environmental matters. As
this information becomes available management will continue to assess the
potential exposure and adjust the reserves as necessary.
Rate Recovery: PSNH has a rate recovery mechanism for environmental costs.
C. NUCLEAR INSURANCE CONTINGENCIES
In conjunction with the divestiture of Millstone in 2001 and Seabrook in
2002, PSNH terminated its 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, 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 its agreement, 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. The total cost of purchases
under contracts with VYNPC amounted to $7.5 million in 2003, $6.9 million in
2002 and $6.5 million in 2001.
Electricity Procurement Obligations: PSNH has entered into various
arrangements for the purchase of electricity. The total cost of purchases
under these arrangements amounted to $122.8 million in 2003, $121.2 million
in 2002, and $144.4 million in 2001. 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) 2004 2005 2006 2007 2008 Thereafter
- -------------------------------------------------------------------------------
VYNPC $ 7.4 $ 6.8 $ 7.1 $ 6.9 $ 7.0 $ 56.0
Electricity
Procurement
Contracts 121.3 123.6 124.8 53.6 27.6 240.2
Hydro-Quebec 7.9 7.6 7.1 6.3 6.0 96.0
- -------------------------------------------------------------------------------
Totals $136.6 $138.0 $139.0 $66.8 $40.6 $392.2
- -------------------------------------------------------------------------------
E. NUCLEAR DECOMMISSIONING AND PLANT CLOSURE COSTS
In conjunction with the Millstone and VYNPC nuclear generation asset
divestitures, the applicable liabilities and nuclear decommissioning trusts
were transferred to the purchasers, and the purchasers agreed to assume
responsibility for decommissioning their respective units.
PSNH still has significant decommissioning and plant closure cost obligations
to the Yankee Companies that own the Yankee Atomic, Connecticut Yankee (CY)
and Maine Yankee nuclear power plants. Each plant has been shut down and is
undergoing decommissioning. The Yankee Companies collect decommissioning and
closure costs through wholesale FERC-approved rates charged under power
purchase agreements to PSNH. PSNH in turn passes these costs on to its
customers through state regulatory commission-approved retail rates. A
portion of the decommissioning and closure costs have already been collected,
but a substantial portion related to the decommissioning of CY has not yet
been filed at and approved for collection by the FERC.
During 2002, PSNH was notified by CYAPC and YAEC that the estimated cost of
decommissioning these units and other closure costs increased over prior
estimates due to higher anticipated costs for spent fuel storage, security
and liability and property insurance. PSNH's share of this increase is $24.9
million. Following FERC rate cases by the Yankee Companies, PSNH expects to
recover the higher decommissioning costs from its retail customers.
In June 2003, CYAPC notified NU that it had terminated its contract with
Bechtel Power Corporation (Bechtel) for the decommissioning of the CY nuclear
power plant. CYAPC terminated the contract based on its determination that
Bechtel's decommissioning work has been incomplete and untimely and that
Bechtel refused to perform the remaining decommissioning work. Bechtel has
filed a counterclaim against CYAPC asserting a number of claims and seeking a
variety of remedies, including monetary and punitive damages and the
rescission of the contract. Bechtel has amended its complaint to add claims
for wrongful termination.
In November 2003, CYAPC prepared an updated estimate of the cost of
decommissioning its nuclear unit. PSNH's aggregate share of the estimated
increased cost primarily related to the termination of Bechtel, is $17.1
million.
CYAPC is seeking recovery of additional decommissioning costs and other
damages from Bechtel and, if necessary, its surety. In pursuing this
recovery through pending litigation, CYAPC is also exploring options to
structure an appropriate rate application to be filed with the FERC, with any
resulting adjustments being charged to the owners of the nuclear unit,
including PSNH. The timing, amount and outcome of these filings cannot be
predicted at this time.
PSNH cannot at this time predict the timing or outcome of the FERC proceeding
required for the collection of these remaining decommissioning and closure
costs. Although management believes that these costs will ultimately be
recovered from PSNH's customers, there is a risk that the FERC may not allow
these costs, the estimates of which have increased significantly in 2003 and
2002, to be recovered in wholesale rates. If FERC does not allow these costs
to be recovered in wholesale rates, PSNH would expect the state regulatory
commissions to disallow these costs in retail rates as well.
At December 31, 2003 and 2002, PSNH's remaining estimated obligations for
decommissioning and closure costs for the shut down units owned by CYAPC,
YAEC and MYAPC were $64.2 million and $56.2 million, respectively.
8. 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, 2003
- ---------------------------------------------------------------------
(Millions of Dollars) Carrying Amount Fair Value
- ---------------------------------------------------------------------
Long-term debt -
Other long-term debt $407.3 $425.6
Rate reduction bonds 472.2 517.3
- ---------------------------------------------------------------------
- ---------------------------------------------------------------------
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
- ---------------------------------------------------------------------
Other Financial Instruments: The carrying value of financial instruments
included in current assets and current liabilities, including investments in
securitizable assets, approximates their fair value.
9. 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 $0.5 million
in 2003, $0.4 million in 2002, and $0.7 million in 2001. Interest included
in capital lease rental payments was $0.3 million in 2003, 2002, and 2001.
Operating lease rental payments charged to expense were $1.8 million in 2003,
$2.6 million in 2002, and $3.9 million in 2001.
Future minimum rental payments excluding executory costs, such as property
taxes, state use taxes, insurance, and maintenance, under long-term
noncancelable leases, at December 31, 2003 are as follows:
- ---------------------------------------------------------------------
(Millions of Dollars) Capital Operating
Year Leases Leases
- ---------------------------------------------------------------------
2004 $0.5 $ 4.6
2005 0.5 3.9
2006 0.3 3.6
2007 0.2 2.6
2008 0.2 2.1
Thereafter - 3.6
- ---------------------------------------------------------------------
Future minimum lease payments $1.7 $20.4
Less amount representing interest 0.7
- ---------------------------------------------------------------------
Present value of future
minimum lease payments $1.0
- ---------------------------------------------------------------------
10. 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) 2002 Change 2003
- -----------------------------------------------------------------------
Unrealized
gains/(losses)
on securities $ - $ 0.1 $ 0.1
Minimum supplemental
executive retirement
pension liability
adjustments (0.1) (0.1) (0.2)
- -----------------------------------------------------------------------
Accumulated other
comprehensive
loss $(0.1) $ - $(0.1)
- -----------------------------------------------------------------------
- -----------------------------------------------------------------------
Current
December 31, Period December 31,
(Millions of Dollars) 2001 Change 2002
- -----------------------------------------------------------------------
Unrealized
gains/(losses)
on securities $ 0.6 $(0.6) $ -
Minimum supplemental
executive retirement
pension liability
adjustments (0.2) 0.1 (0.1)
- -----------------------------------------------------------------------
Accumulated other
comprehensive
income/(loss) $ 0.4 $(0.5) $(0.1)
- -----------------------------------------------------------------------
The changes in the components of other comprehensive income/(loss) are
reported net of the following income tax effects:
- -----------------------------------------------------------------------
(Millions of Dollars) 2003 2002 2001
- -----------------------------------------------------------------------
Unrealized
(losses)/gains
on securities $(0.1) $0.3 $0.4
Minimum supplemental
executive retirement
pension liability
adjustments - - -
- -----------------------------------------------------------------------
Accumulated other
comprehensive
(loss)/income $(0.1) $0.3 $0.4
- -----------------------------------------------------------------------
11. LONG-TERM DEBT
- -------------------------------------------------------------------------------
Details of long-term debt outstanding are as follows:
- -----------------------------------------------------------------------
At December 31, 2003 2002
- -----------------------------------------------------------------------
(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
2004 through 2008. 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 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 rate on the variable-rate pollution control
notes was 1 percent in 2003 and 1.4 percent in 2002.
12. INCOME TAX EXPENSE
- -------------------------------------------------------------------------------
The components of the federal and state income tax provisions were
charged/(credited) to operations as follows:
- ---------------------------------------------------------------------
For the Years
Ended December 31, 2003 2002 2001
- ---------------------------------------------------------------------
(Millions of Dollars)
Current income taxes:
Federal $27.9 $101.1 $(143.5)
State 8.5 19.0 (13.4)
- ---------------------------------------------------------------------
Total current 36.4 120.1 (156.9)
- ---------------------------------------------------------------------
Deferred income taxes, net:
Federal (3.8) (65.0) 197.3
State (2.3) (5.5) 13.5
- ---------------------------------------------------------------------
Total deferred (6.1) (70.5) 210.8
- ---------------------------------------------------------------------
Investment tax credits, net (0.5) (9.3) (15.3)
- ---------------------------------------------------------------------
Total income tax expense $29.8 $ 40.3 $ 38.6
- ---------------------------------------------------------------------
Deferred income taxes are comprised of the tax effects of temporary
differences as follows:
- ---------------------------------------------------------------------
For the Years
Ended December 31, 2003 2002 2001
- ---------------------------------------------------------------------
(Millions of Dollars)
Depreciation $12.2 $ 7.7 $ 1.9
Net regulatory deferral (8.2) (65.3) (5.4)
Regulatory disallowance - - 2.3
Contractual settlements - - 6.7
Contract termination costs,
net of amortization (9.7) (13.5) 196.6
Other (0.4) 0.6 8.7
- ---------------------------------------------------------------------
Deferred income taxes, net $(6.1) $(70.5) $210.8
- ---------------------------------------------------------------------
A reconciliation between income tax expense and the expected tax expense at
the statutory rate is as follows:
- ---------------------------------------------------------------------
For the Years
Ended December 31, 2003 2002 2001
- ---------------------------------------------------------------------
(Millions of Dollars)
Expected federal income tax $26.3 $36.1 $42.1
Tax effect of differences:
Depreciation 1.1 1.9 0.5
Amortization of
regulatory assets 1.8 1.2 5.1
Investment tax credit
amortization (0.5) (9.3) (15.3)
State income taxes,
net of federal benefit 4.1 8.8 0.1
Other, net (3.0) 1.6 6.1
- ---------------------------------------------------------------------
Total income tax expense $29.8 $40.3 $38.6
- ---------------------------------------------------------------------
13. SEGMENT INFORMATION
- -------------------------------------------------------------------------------
NU is organized between the Utility Group and NU Enterprises based on each
segments' regulatory environment or lack thereof. PSNH is included in the
utility group segment of NU and has no other reportable segments.
- -------------------------------------------------------------------------------
Consolidated Quarterly Financial Data (Unaudited)
- -------------------------------------------------------------------------------
(Thousands of Dollars) Quarter Ended (a)
- -------------------------------------------------------------------------------
2003 March 31, June 30, September 30, December 31,
- -------------------------------------------------------------------------------
Operating Revenues $230,768 $203,364 $235,972 $218,082
Operating Income $ 31,383 $ 29,668 $ 34,774 $ 29,791
Net Income $ 10,827 $ 11,054 $ 12,613 $ 11,130
- -------------------------------------------------------------------------------
2002
- -------------------------------------------------------------------------------
Operating Revenues $228,028 $230,382 $272,189 $216,579
Operating Income $ 30,750 $ 37,004 $ 40,929 $ 45,289
Net Income $ 11,729 $ 15,231 $ 19,482 $ 16,455
- -------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------------------------------
Selected Consolidated Financial Data (Unaudited)
- ----------------------------------------------------------------------------------------------------------------------------
(Thousands of Dollars) 2003 2002 2001 2000 1999
- ----------------------------------------------------------------------------------------------------------------------------
Operating Revenues (b) $ 888,186 $ 947,178 $ 964,415 $1,291,280 $1,160,572
Net Income/(Loss) 45,624 62,897 81,776 (146,666) 84,209
Cash Dividends on Common Stock 16,800 45,000 27,000 50,000 -
Gross Property, Plant and Equipment (c) 1,560,621 1,488,516 1,499,137 1,535,343 2,283,187
Total Assets (d) 2,171,811 2,155,447 2,094,514 2,082,296 2,622,433
Rate Reduction Bonds 472,222 510,841 507,381 - -
Long-Term Debt (e) 407,285 407,285 407,285 407,285 516,485
Preferred Stock Not Subject to Mandatory Redemption - - - 24,268 50,000
Obligations Under Seabrook Power Contracts and
Other Capital Leases (e) 986 1,192 110,275 629,230 726,153
- ----------------------------------------------------------------------------------------------------------------------------
(a) Certain reclassifications of prior years' data have been made to conform
with the current year's presentation. Operating revenue amounts have been
reclassified from those reported in 2002 and from those reported in the
first three quarters of 2003 on the reports on Form 10-Q because of the
adoption of EITF Issue No. 03-11. Quarterly operating revenues as
previously reported for 2003 and 2002 are as follows (thousands of
dollars):
-------------------------------------------------
Operating Revenues
-------------------------------------------------
Quarter Ended 2003 2002
-------------------------------------------------
March 31 $256,895 $242,381
June 30 220,264 248,914
September 30 241,829 324,818
December 31 N/A 230,625
-------------------------------------------------
(b) Operating revenue amounts have been reclassified from those reported in
2002 and 2001 related to the adoption of EITF Issue No. 03-11.
(c) Amount includes construction work in progress.
(d) Total assets were not adjusted for cost of removal prior to 2002.
(e) Includes portions due within one year.
- -----------------------------------------------------------------------------------------------------------------------------
Consolidated Statistics (Unaudited)
- -----------------------------------------------------------------------------------------------------------------------------
2003 2002 2001 2000 1999
- -----------------------------------------------------------------------------------------------------------------------------
Revenues: (Thousands)
Residential $351,622 $325,912 $323,642 $ 355,176 $ 356,970
Commercial 318,081 297,196 297,632 306,386 302,135
Industrial 159,560 150,582 175,575 195,058 188,622
Other Utilities 38,622 152,131 144,350 394,080 266,118
Streetlighting and Railroads 4,801 4,820 5,227 5,925 5,927
Non-franchised Sales - - - - 18,963
Miscellaneous 15,500 16,537 17,989 34,655 21,837
- -----------------------------------------------------------------------------------------------------------------------------
Total $888,186 $947,178 $964,415 $1,291,280 $1,160,572
- -----------------------------------------------------------------------------------------------------------------------------
Sales: (kWh - Millions)
Residential 2,944 2,765 2,592 2,474 2,447
Commercial 3,100 2,969 2,873 2,614 2,536
Industrial 1,684 1,646 1,926 2,026 1,952
Other Utilities 674 4,034 4,086 10,007 5,869
Streetlighting and Railroads 23 23 23 22 22
Non-franchised Sales - - - - 6
- -----------------------------------------------------------------------------------------------------------------------------
Total 8,425 11,437 11,500 17,143 12,832
- -----------------------------------------------------------------------------------------------------------------------------
Customers: (Average)
Residential 388,133 382,481 376,832 372,286 367,119
Commercial 63,324 61,775 59,538 58,279 57,203
Industrial 2,758 2,818 2,863 2,887 2,896
Other 554 540 517 485 476
- -----------------------------------------------------------------------------------------------------------------------------
Total 454,769 447,614 439,750 433,937 427,694
- -----------------------------------------------------------------------------------------------------------------------------
Average Annual Use Per
Residential Customer (kWh) 7,584 7,208 6,868 6,644 6,665
- -----------------------------------------------------------------------------------------------------------------------------
Average Annual Bill Per
Residential Customer $906.29 $849.10 $859.87 $954.08 $972.42
- -----------------------------------------------------------------------------------------------------------------------------
Average Revenue Per kWh:
Residential 11.95 cents 11.78 cents 12.52 cents 14.36 cents 14.59 cents
Commercial 10.26 10.01 10.36 11.72 11.91
Industrial 9.48 9.15 9.12 9.63 9.66
- -----------------------------------------------------------------------------------------------------------------------------
Employees 1,282 1,243 1,241 1,227 1,258
=============================================================================================================================