UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
[x] Quarterly report pursuant to Section 13 or 15(d) of the
Securities Exchange Act of 1934
For the quarterly period ended September 30, 2000
or
[ ] Transition report pursuant to Section 13 or 15(d) of the
Securities Exchange Act of 1934
For the transition period from __________ to __________
Commission file number 1-14768
NSTAR
(Exact name of registrant as specified in its charter)
Massachusetts 04-3466300
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
800 Boylston Street, Boston, Massachusetts 02199
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (617) 424-
2000
Indicate by check mark whether the registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the
Securities Exchange Act of 1934 during the preceding 12 months
(or for such shorter period that the registrant was required to
file such reports), and (2) has been subject to such filing
requirements for the past 90 days.
Yes X No
Indicate the number of shares outstanding of each of the issuer's
classes of common stock, as of the latest practicable date.
Class Outstanding at November 3, 2000
Common Shares, $1 par value 53,032,546 shares
Part I - Financial Information
Item 1. Financial Statements
NSTAR
Condensed Consolidated Statements of Income
(Unaudited)
(in thousands, except per share amounts)
Three Months Nine Months
Ended September 30, Ended September 30,
2000 1999 2000 1999
Operating revenues $709,519 $517,151 $2,004,975 $1,268,311
Operating expenses:
Fuel, purchased power and
cost of gas sold 325,000 213,223 999,013 510,920
Operations and 111,847 93,050 327,407 243,999
maintenance
Depreciation and 58,958 56,609 176,925 151,797
amortization
Demand side management
and 23,286 15,507 59,014 42,208
renewable energy
programs
Taxes - property and 20,123 17,228 66,868 57,176
other
Income taxes 43,147 36,512 92,234 74,791
Total operating 582,361 432,129 1,721,461 1,080,891
expenses
Operating income 127,158 85,022 283,514 187,420
Other income, net 325 17,012 8,195 13,643
Operating and other income 127,483 102,034 291,709 201,063
Interest charges:
Long term debt 24,235 19,693 79,817 58,594
Transition property
securitization 11,223 8,439 34,625 8,439
certificates
Other 26,541 6,091 43,686 11,324
Allowance for borrowed
funds used during (802) (449) (2,732) (1,368)
construction
Total interest 61,197 33,774 155,396 76,989
charges
Net income 66,286 68,260 136,313 124,074
Preferred stock dividends
of subsidiary 1,490 1,490 4,470 4,470
Earnings available for
common shareholders $ 64,796 $ 66,770 $ 131,843 $ 119,604
======== ======== ========== ==========
Weighted average common
shares outstanding:
Basic 53,690 50,674 55,510 47,811
====== ====== ====== ======
Diluted 53,850 50,922 55,677 47,963
====== ====== ====== ======
Earnings per common share:
Basic $1.21 $1.32 $2.38 $2.50
===== ===== ===== =====
Diluted $1.20 $1.31 $2.37 $2.49
===== ===== ===== =====
Dividends declared per
common share $0.50 $0.485 $1.50 $1.455
===== ====== ===== ======
The accompanying notes are an integral part of the condensed consolidated
financial statements.
NSTAR
Condensed Consolidated Statements of Comprehensive Income
(Unaudited)
(in thousands)
Three Months Nine Months
Ended September 30, Ended September 30,
2000 1999 2000 1999
Net income $ 66,286 $ 68,260 $136,313 $124,074
Other comprehensive
income, net:
Unrealized (loss)
gain on investments (11,147) (1,704) (56,382) 15,229
Comprehensive income $ 55,139 $ 66,556 $ 79,931 $139,303
======== ======== ======== ========
The accompanying notes are an integral part of the condensed consolidated
financial statements.
NSTAR
Condensed Consolidated Statements of Retained Earnings
(Unaudited)
(in thousands)
Three Months Nine Months
Ended September 30, Ended September 30,
2000 1999 2000 1999
Balance at the beginning of the $395,086 $365,995 $389,989 $360,509
period
Net income 66,286 68,260 136,313 124,074
Dividends declared:
Common shares (26,516) (29,570) (82,003) (74,139)
Preferred stock (1,490) (1,490) (4,470) (4,470)
Subtotal 433,366 403,195 439,829 405,974
Provision for preferred stock
redemption and issuance costs (60) (60) (180) (248)
Common share repurchase program (2,507) 68 (8,850) (2,523)
Balance at the end of the period $430,799 $403,203 $430,799 $403,203
======== ======== ======== ========
The accompanying notes are an integral part of the condensed consolidated
financial statements.
NSTAR
Condensed Consolidated Balance Sheets
(Unaudited)
(in thousands)
September 30, December 31,
2000 1999
Assets
Utility plant in service, at $3,971,713 $3,884,728
original cost
Less: accumulated depreciation 1,355,073 1,303,893
2,616,640 2,580,835
Construction work in progress 82,096 67,217
Net utility plant 2,698,736 2,648,052
Nonutility property 85,064 100,525
Goodwill 476,801 485,990
Equity investments 160,984 173,290
Other investments 101,221 69,942
Current assets:
Cash and cash equivalents 23,537 168,599
Restricted cash 141,998 147,941
Accounts receivable 430,694 392,702
Accrued unbilled revenues 67,090 34,013
Materials and supplies, at average 47,226 48,756
cost
Prepaid expenses and other 155,886 147,469
Total current assets 866,431 939,480
Regulatory assets 974,799 883,867
Other deferred debits 205,848 164,997
Total assets $5,569,884 $5,466,143
========== ==========
The accompanying notes are an integral part of the condensed consolidated
financial statements.
NSTAR
Condensed Consolidated Balance Sheets
(Unaudited)
(in thousands)
September 30, December 31,
2000 1999
Capitalization and Liabilities
Common equity:
Common shares, par value $1 per
share
(53,032,546 and 58,059,646 shares
issued
and outstanding) $ 53,033 $ 58,060
Premium on common shares 876,899 1,075,483
Retained earnings 430,799 389,989
Total common equity 1,360,731 1,523,532
Accumulated other comprehensive
(loss) income, net (36,267) 20,115
Cumulative preferred stock of
subsidiary:
Nonmandatory redeemable series 43,000 43,000
Mandatory redeemable series 49,459 49,279
Total preferred stock 92,459 92,279
Long-term debt 1,448,770 986,843
Transition property securitization
certificates 584,130 646,559
Total long-term debt 2,032,900 1,633,402
Total capitalization 3,449,823 3,269,328
Current liabilities:
Transition property securitization
certificates due within one year 64,363 50,922
Long-term debt due within one year 6,870 170,470
Notes payable 516,697 458,000
Accounts payable 179,314 193,937
Accrued interest 17,991 21,830
Dividends payable 27,986 29,871
Other 331,817 271,191
Total current liabilities 1,145,038 1,196,221
Deferred credits:
Accumulated deferred income taxes 627,202 608,587
Accumulated deferred investment tax
credits 39,874 41,946
Other 307,947 350,061
Total deferred credits 975,023 1,000,594
Commitments and contingencies
Total capitalization and $5,569,884 $5,466,143
liabilities ========== ==========
The accompanying notes are an integral part of the condensed consolidated
financial statements.
NSTAR
Condensed Consolidated Statements of Cash Flows
(Unaudited)
(in thousands)
Nine Months Ended September 30,
2000 1999
Operating activities:
Net income $ 136,313 $ 124,074
Adjustments to reconcile net income to
net cash provided by operating
activities:
Depreciation and amortization 176,925 152,104
Deferred income taxes and
investment tax credits 45,317 46,980
Allowance for borrowed funds used
during construction (2,732) (1,420)
Power contract buyout (8,494) (65,781)
Net changes in working capital (133,616) (90,188)
Other, net (127,252) (36,853)
Net cash provided by operating activities 86,461 128,916
Investing activities:
Plant expenditures (excluding AFUDC) (147,800) (94,914)
Costs of nuclear divestiture, net - (127,061)
Payment for acquisition, net of cash - (295,535)
acquired
Nuclear fuel expenditures (1,340) (16,117)
Investments (59,393) (77,219)
Net cash used in investing activities (208,533) (610,846)
Financing activities:
Proceeds from transition property - 725,000
securitization
Common share repurchases (212,039) (68,698)
Long-term debt redemptions (201,886) (225,376)
Transition property securitization
certificates redemptions (82,149) -
Long-term debt issue 500,000 -
Financing costs (1,145) -
Net change in notes payable 58,697 115,725
Dividends paid (84,468) (71,924)
Net cash (used in) provided by financing
activities (22,990) 474,727
Net decrease in cash and cash equivalents (145,062) (7,203)
Cash and cash equivalents at beginning of 168,599 89,126
year
Cash and cash equivalents at end of $ 23,537 $ 81,923
period ========= =========
Supplemental disclosures of cash flow
information:
Cash paid during the period for:
Interest, net of amounts capitalized $ 127,988 $ 80,580
========= =========
Income taxes $ 20,835 $ 16,722
========= =========
Supplemental noncash investing activity:
Number of common shares issued for 20,251
acquisition of COM/Energy =========
The accompanying notes are an integral part of the condensed consolidated
financial statements.
Notes to Unaudited Condensed Consolidated Financial Statements
The accompanying Notes should be read in conjunction with the
Notes to the Consolidated Financial Statements included in
NSTAR's 1999 Annual Report on Form 10-K.
A) Merger of BEC Energy and Commonwealth Energy System
On August 25, 1999, BEC Energy (BEC) and Commonwealth Energy
System (COM/Energy) completed a merger to create NSTAR, an energy
delivery company serving approximately 1.3 million customers in
Massachusetts including more than one million electric customers
in 81 communities and 240,000 gas customers in 51 communities.
NSTAR is an exempt public utility holding company under the
provisions of the Public Utility Holding Company Act of 1935.
NSTAR's utility subsidiaries are Boston Edison Company,
Commonwealth Electric Company, Cambridge Electric Light Company,
Canal Electric Company and Commonwealth Gas Company. NSTAR's
nonutility operations include telecommunications, district
heating and cooling operations and liquefied natural gas
services.
B) Basis of Presentation
The merger was accounted for as an acquisition of COM/Energy by
BEC using the purchase method of accounting. Under this method,
the accompanying unaudited condensed consolidated financial
statements of NSTAR for the three and nine-month periods ended
September 30, 2000 include the results of operations,
comprehensive income and cash flows of BEC and COM/Energy for the
entire period presented. However, the 1999 unaudited condensed
consolidated financial statements for the three and nine-month
periods reflect the results of operations, comprehensive income
and cash flows of BEC for the two and eight-month periods,
respectively, and NSTAR as of September 1.
The financial information presented as of September 30, 2000 and
for the periods ended September 30, 2000 and 1999 have been
prepared from NSTAR's books and records without audit by
independent accountants. Financial information as of
December 31, 1999 was derived from the audited consolidated
financial statements of NSTAR, but does not include all
disclosures required by generally accepted accounting principles
(GAAP). In the opinion of NSTAR's management, all adjustments
(which are of a normal recurring nature) necessary for a fair
presentation of the financial information for the periods
indicated have been included. Certain reclassifications have
been made to the prior year data to conform with the current
presentation.
The preparation of financial statements in conformity with GAAP
requires management of NSTAR and its subsidiaries to make
estimates and assumptions that affect the reported amounts of
assets and liabilities and disclosures of contingent assets and
liabilities at the date of the financial statements and the
reported amounts of revenues and expenses during the reporting
period. Actual results could differ from these estimates.
The results of operations for the periods ended September 30,
2000 and 1999 are not indicative of the results that may be
expected for an entire year. Kilowatt-hour sales and revenues
are typically higher in the winter and summer than in the spring
and fall as sales tend to vary with weather conditions. Gas
sales and revenues are typically higher in the winter months than
during other periods of the year.
C) Securitization
On July 27, 1999, a wholly owned special purpose subsidiary (SPS)
of Boston Edison, BEC Funding LLC (BEC Funding), closed the sale
of $725 million of notes to a special purpose trust created by
two Massachusetts state agencies. The trust then concurrently
closed the sale of $725 million of electric rate reduction
certificates to the public. The certificates are secured by a
portion of the transition charge assessed on Boston Edison's
retail customers as permitted under the Massachusetts Electric
Restructuring Act (the Restructuring Act) and authorized by the
Massachusetts Department of Telecommunications and Energy (MDTE).
These certificates are non-recourse to Boston Edison. Principal
redemptions will occur on a semi-annual basis over the life of
the certificates. Furthermore, Boston Edison is required to
transfer funds collected on a daily basis to its trustee and are
held in escrow. These funds are used to meet BEC Funding's semi-
annual principal and interest payments.
D) Contingencies
1. Environmental Matters
The utility subsidiaries of NSTAR are involved in approximately
30 properties where oil or hazardous materials were spilled or
released. As such, the companies are required to clean up these
remaining properties in accordance with specific state
regulations. There are uncertainties associated with these costs
due to the complexities of cleanup technology, regulatory
requirements and the particular characteristics of the different
sites. NSTAR subsidiaries also face possible liability as a
potentially responsible party in the cleanup of six multi-party
hazardous waste sites in Massachusetts and other states where it
is alleged to have generated, transported or disposed of
hazardous waste at the sites. NSTAR generally expects to have
only a small percentage of the total potential liability for
these sites. Approximately $7 million is included as a liability
on the September 30, 2000 and December 31, 1999 Condensed
Consolidated Balance Sheets related to the non-recoverable
portion of these cleanup liabilities. Management is unable to
fully determine a range of reasonably possible cleanup costs in
excess of the accrued amount. Based on its assessments of the
specific site circumstances, management does not believe that it
is probable that any such additional costs will have a material
impact on NSTAR's consolidated financial position. However, it
is reasonably possible that additional provisions for cleanup
costs that may result from a change in estimates could have a
material impact on the results of a reporting period in the near
term.
Commonwealth Gas is participating in the assessment of a number
of former manufactured gas plant (MGP) sites and alleged MGP
waste disposal locations to determine if and to what extent such
sites have been contaminated and whether Commonwealth Gas may be
responsible for remedial action. The MDTE has to date approved
recovery of costs associated with MGP sites. As of September 30,
2000 and December 31, 1999, Commonwealth Gas has recorded a
liability and corresponding regulatory asset amounting to $2.2
million as an estimate for site cleanup costs for several MGP
sites for which Commonwealth Gas was previously cited as a
potentially responsible party.
Estimates related to environmental remediation costs are reviewed
and adjusted periodically as further investigation and assignment
of responsibility occurs. NSTAR is unable to estimate its
ultimate liability for future environmental remediation costs.
However, in view of NSTAR's current assessment of its
environmental responsibilities, existing legal requirements and
regulatory policies, management does not believe that these
matters will have a material adverse effect on NSTAR's results of
operations, cash flows or financial position.
2. Generating Unit Performance Programs
The MDTE's generating unit performance programs ceased March 1,
1998. Under these programs, the recovery of incremental
purchased power costs resulting from generating unit outages
occurring through the retail access date was subject to review by
the MDTE. Comprehensive settlements relative to generating unit
performance, including the review of replacement power costs
associated with the shutdown of the Connecticut Yankee nuclear
electric generating unit, were approved by the MDTE on August 1,
2000. The approved MDTE settlements did not have a material
impact on NSTAR's consolidated financial position, results of
operations or cash flows.
3. Industry and Corporate Restructuring Legal Proceedings
The MDTE order approving the Boston Edison electric restructuring
settlement agreement was appealed by certain parties to the
Massachusetts Supreme Judicial Court (SJC). One settlement
agreement appeal remains pending. However, to date there has
been no briefing, hearing or other action taken with respect to
this proceeding. Management is currently unable to determine the
outcome of this proceeding. However, if an unfavorable outcome
were to occur, there could be a material adverse impact on
business operations, the consolidated financial position, cash
flows or results of operations for a reporting period.
4. Regulatory Proceedings
Under applicable restructuring plans or settlements approved by
the MDTE, each NSTAR retail electric subsidiary must, on an
annual basis, file proposed adjustments to their rates for the
upcoming year along with a proposed reconciliation of prior year
revenues and costs for their standard offer, default service,
transmission and transition charges. Each retail electric
subsidiary made such a filing with the MDTE in the Fall of 1999,
as to which the MDTE subsequently approved proposed rate
adjustments effective January 1, 2000, and conducted further
hearings for the purpose of reconciliation of prior year's costs
and revenues related to each company's transition and
transmission charges and the charges for standard offer and
default service. In each such proceeding, intervenors have
contested certain cost allocations and other related issues. The
MDTE has not yet rendered a final decision. In November 2000,
each retail electric subsidiary made a similar filing containing
proposed rate adjustments for 2001 and included a reconciliation
of costs and revenues through 1999. No action has yet been taken
by the MDTE concerning such filings.
As part of the accounting for the transition charge, a final
reconciliation was performed to the 1998 and 1999 transition
charge true-up filings. Management is unable to determine the
outcome of the MDTE proceedings. However, if an unfavorable
outcome were to occur, there would be a material adverse impact
on NSTAR's consolidated financial position, results of operations
and cash flows in the near term.
In addition to the annual rate filings referenced above, the
NSTAR retail electric subsidiaries have also made separate
filings with the MDTE concerning charges for standard offer and
default service. The NSTAR electric companies have filed with
the MDTE a request for approval to increase their standard offer
service rates based on a fuel adjustment formula based on the
prices of natural gas and oil contained in their standard offer
tariffs. The adjustments would increase standard offer service
rates as follows: Boston Edison - from 4.5 cents per kWh to 5.081
cents per kWh; Cambridge Electric and Commonwealth Electric -
from 3.8 cents per kWh to 4.45 cents per kWh. The MDTE continues
to consider the request for effect in future months. If the
request is approved, the companies expect to make further monthly
filings to adjust customer billings based on changes in the costs
of natural gas and oil. The NSTAR Electric companies have also
made filings with the MDTE to increase the price for default
service to market-based levels. On October 19, 2000 the MDTE
approved the companies' request to increase the price of
generation service for default service to 6.280 cents per kWh
effective December 1, 2000. On November 9, 2000 the NSTAR
electric companies filed a request with the MDTE to increase the
price for default service to 6.993 cents per kWh for the period
January 1, 2001 through June 30, 2001. These and future prices
for default service are based upon market solicitations for power
supply for default service purposes consistent with provisions of
the Electric Restructuring Act and MDTE orders.
The Massachusetts Attorney General has contested cost allocations
related to Boston Edison's wholesale customers since 1998.
Management is unable to determine the outcome of the MDTE
proceedings. However, if an unfavorable outcome were to occur,
there would be a material adverse impact on Boston Edison's
consolidated financial position, results of operations and cash
flows in the near term.
In October 1997, the MDTE opened a proceeding to investigate
Boston Edison's compliance with a 1993 order that permitted the
formation of Boston Energy Technology Group (BETG) and authorized
Boston Edison to invest up to $45 million in unregulated
activities. The hearing was completed during the first quarter
of 1999. Management is currently unable to determine the timing
of and the outcome of this proceeding. However, if an
unfavorable outcome were to occur, there could be a material
adverse impact on business operations, the consolidated financial
position, cash flows and results of operations for a reporting
period.
5. Rate Plan
In July 1999, the MDTE approved a rate plan filed by the utility
subsidiaries of BEC and COM/Energy in connection with the merger.
A group of four intervenors and the Massachusetts Attorney
General filed two separate appeals of the MDTE's rate plan order
with the SJC in August 1999. While management anticipates that
the MDTE's decision to approve the rate plan will be upheld by
the SJC, it is unable to determine the timing or ultimate outcome
of these appeals.
6. Natural Gas Industry Restructuring and Rates
In late 1998, the MDTE issued an order establishing rules and
regulations governing the unbundling of gas service to all
customers in Massachusetts. Prior to this, only commercial and
industrial customers were able to obtain competitive gas supply
service from a source other than the local distribution company
(LDC). These regulations are similar to those adopted by the
MDTE governing electric restructuring. Among the important
provisions are: setting the LDC as the default service provider,
certification of competitive suppliers/marketers, extension of
the MDTE's consumer protection rules to residential customers
taking competitive service, requirement for LDCs to provide
suppliers/marketers with customer usage data, and requirement for
suppliers/marketers to disclose service terms to potential
customers. In addition, the MDTE has standardized the
eligibility requirements for low-income rates for all LDCs that
are identical to previously established requirements for electric
customers. In February 1999, the MDTE issued an order requiring
the mandatory assignment of LDC upstream pipeline capacity and
downstream peaking capacity to customers who elect a competitive
gas supply. In January 2000, the MDTE approved the Model Terms
and Conditions submitted by the LDCs that provided the framework
for implementing the regulations. In October 2000, the MDTE
approved compliance Terms and Conditions submitted by
Commonwealth Gas and the LDCs that implement the unbundling of
gas services to all customers. With the issuance of these orders
and regulations, the MDTE has moved the process for customer
choice to commence November 1, 2000. It is not expected that
many additional customers (in particular residential customers)
will elect to take competitive gas supply service on November 1,
but more migration from LDC service to competitive service is
expected by November 1, 2001.
7. Other Matters
In the normal course of its business NSTAR and its subsidiaries
are also involved in certain other legal and regulatory matters.
Management is unable to fully determine a range of reasonably
possible costs in excess of amounts accrued. Based on the
information currently available, management does not believe that
it is probable that any such additional costs will have a
material impact on NSTAR's consolidated financial position.
However, it is reasonably possible that additional legal and
regulatory costs that may result from a change in estimates could
have a material impact on the results of a reporting period in
the near term.
E) Income Taxes
The following table reconciles the statutory federal income tax
rate to the annual estimated effective income tax rate for 2000
and the actual effective income tax rate for the year ended
December 31, 1999.
2000 1999
Statutory tax rate 35.0% 35.0%
State income tax, net of federal income tax 5.6 5.5
benefit
Investment tax credit amortization (0.9) (11.3)
Goodwill amortization 1.8 0.4
Other 0.7 (0.5)
Effective tax rate 42.2% 29.1%
===== =====
The effective tax rate for 1999 reflects $20.8 million of
investment tax credits recognized as a result of generation asset
divestiture in July 1999. Excluding the impact of these credits,
the corresponding estimated effective tax rate for the same
period in 1999 was 39.1%.
F) Earnings Per Common Share
The following table illustrates the reconciliation between basic
and diluted earnings per share (EPS) computations.
(in thousands, except per share amounts)
Three Months Nine Months
Ended September 30, Ended September 30,
2000 1999 2000 1999
Earnings available for
common shareholders $64,796 $66,770 $131,843 $119,604
Basic EPS $1.21 $1.32 $2.38 $2.50
Diluted EPS $1.20 $1.31 $2.37 $2.49
Weighted average common
shares outstanding for
basic EPS 53,690 50,674 55,510 47,811
Effect of dilutive
securities:
Weighted average dilutive
potential common shares
related to share-based
compensation 160 248 167 152
Weighted average common
shares outstanding for
diluted EPS 53,850 50,922 55,677 47,963
G) Segment and Related Information
For the purpose of providing segment information, NSTAR's
principal operating segments, or its traditional core businesses,
are the electric and natural gas utilities that provide energy
delivery services in numerous cities and towns in Massachusetts.
NSTAR subsidiaries also supply electricity at wholesale for
resale to other utilities. The unregulated operating segments
engage in non-utility business activities. Such activities
include telecommunications, district heating and cooling
operations, and liquefied natural gas services.
The accounting policies used to develop segment information
correspond to those described in Note B, "Basis of Presentation."
NSTAR evaluates performance based on earnings from operations
before income taxes and nonrecurring gains and losses.
Financial data for the operating segments are as follows:
(in thousands)
Unregulated
Utility Operations Nonutility Consolidated
Electric Gas Operations Total
Three months ended September
30, 2000
Operating revenues $ 608,391 $ 47,641 $ 53,487 $ 709,519
Segment net income $ 83,207 $ (3,726) $ (13,195) (a) $ 66,286
(loss)
1999
Operating revenues $ 498,074 $ 13,336 $ 5,741 $ 517,151
Segment net income $ 82,556 $ (1,691) $ (12,605) (a) $ 68,260
(loss)
Nine months ended September 30,
2000
Operating revenues $1,666,384 $ 242,050 $ 96,541 $2,004,975
Segment net income $ 144,768 $ 14,879 $ (23,334) (a) $ 136,313
(loss)
1999
Operating revenues $1,248,413 $ 13,336 $ 6,562 $1,268,311
Segment net income $ 148,492 $ (1,691) $ (22,727) (a) $ 124,074
(loss)
Total assets
September 30, 2000 $4,626,861 $ 453,298 $ 489,725 $5,569,884
December 31, 1999 $4,656,735 $ 459,887 $ 351,521 $5,468,143
(a)Net income of nonutility operations for periods ended in 2000
and 1999 reflects pre-tax charges of $5 million and $11
million, respectively related to the reduction of the
carrying value of certain property, plant and equipment.
H) RCN Joint Venture
NSTAR Communications, Inc. (NSTAR COM), an indirect subsidiary of
NSTAR, is a participant in a telecommunications venture with RCN
Telecom Services, Inc. of Massachusetts (RCN), a subsidiary of
RCN Corporation. NSTAR accounts for its Class A Equity
investment in the joint venture using the equity method of
accounting. As part of the joint venture agreement, NSTAR has
the option to exchange portions of its joint venture interest for
shares of RCN common stock at specified periods. During 1998,
NSTAR exercised its option to convert a portion of its interest.
In the first quarter of 1999, NSTAR received 1.1 million shares
of RCN Corporation common stock in exchange for a portion of its
joint venture interest that had a net book value of $7.8 million.
In May 1999, NSTAR COM notified RCN of its intention to exercise
its option to convert an additional portion of its joint venture
interest that had a net book value of $72.3 million at that time.
In March 2000, NSTAR COM received approximately 3 million shares
of RCN Corporation common stock associated with this second
exchange. In connection with these two exchanges, as of the date
of each respective conversion, NSTAR COM recorded a deferred gain
for the difference between the net book value of its equity
investment in the joint venture and the fair value of the shares
received. In accordance with Generally Accepted Accounting
Principles (GAAP), this gain must be deferred until such time
that NSTAR sells off its holdings of RCN Corporation shares.
The RCN Corporation shares received are included in other
investments on the September 30, 2000 Condensed Consolidated
Balance Sheets at their fair value of approximately $85 million.
This fair value may increase or decrease, at any time, as a
result of changes in the market price of RCN Corporation common
shares. The unrealized gain or loss due to the changes in fair
value on these shares during each period is reflected, net of
associated income taxes, as comprehensive (loss) income on the
Condensed Consolidated Statements of Comprehensive Income for the
three and nine months ended September 30, 2000 and 1999. The
cumulative increase or decrease in fair value of these shares as
of September 30, 2000 and December 31, 1999 is reflected as
accumulated other comprehensive income, net on the Condensed
Consolidated Balance Sheets.
In addition, on April 6, 2000, NSTAR COM issued its third notice
to exchange substantially all of its remaining interest in the
joint venture with a net book value as of September 30, 2000 of
approximately $129 million in the joint venture into common stock
of RCN Corporation. The number of RCN Corporation shares
associated with this third notice is expected to be finalized by
December 31, 2000.
On October 18, 2000, NSTAR COM and RCN signed an agreement in
principal to amend the Joint Venture Agreement. Among other
items, this proposal would settle the number of shares to be
exchanged associated with the third conversion of NSTAR COM's
Class A Equity. This amendment also offers NSTAR COM the option
to continue to invest in the joint venture through a new "Class B
Preferred Equity" with a fixed return guaranteed by RCN
Corporation and changes the calculation of the joint venture
profit and loss sharing ratio and investment interest
percentages. This Class B Equity has no voting rights and no
sharing of profits or losses.
NSTAR COM anticipates that all definitive documents to complete
these amendments to the Joint Venture Agreement will be executed
by December 31, 2000.
Item 2. Management's Discussion and Analysis
NSTAR was created through the merger of BEC Energy (BEC) and
Commonwealth Energy System (COM/Energy) on August 25, 1999 as an
exempt public utility holding company. NSTAR's utility
subsidiaries are Boston Edison Company (Boston Edison),
Commonwealth Electric Company (ComElectric), Cambridge Electric
Light Company (Cambridge Electric), Canal Electric Company (Canal
Electric) and Commonwealth Gas Company (ComGas). Effective
November 1, 2000, NSTAR's three retail electric companies began
to operate under NSTAR Electric brand name and Commonwealth Gas
began to operate under NSTAR Gas brand name. Although the
companies will continue to maintain their separate identities,
they will proceed on a "doing business as" basis rather than
through formal corporate consolidation.
The electric and natural gas industries have continued to change
in response to legislative, regulatory and marketplace demands
for improved customer service at lower prices. These demands
have resulted in an increasing trend in the industry to seek
competitive advantages and other benefits through business
combinations. NSTAR was created to operate in this new
marketplace by combining the resources of its utility
subsidiaries and concentrating its activities in the transmission
and distribution of energy. This is illustrated by the sale of
BEC's and COM/Energy's generating facilities during 1999 and
1998.
Merger of BEC Energy and Commonwealth Energy System
An integral part of the merger is the rate plan that was filed by
the retail utility subsidiaries of BEC and COM/Energy that was
approved by the Massachusetts Department of Telecommunications
and Energy (MDTE) on July 27, 1999. Significant elements of the
rate plan include a four-year distribution rate freeze, recovery
of the acquisition premium (Goodwill) over 40 years and recovery
of transaction and integration costs (costs to achieve) over 10
years. Refer to the "Retail Electric Rates" section of this
discussion for more information.
The merger was accounted for by NSTAR as an acquisition of
COM/Energy by BEC under the purchase method of accounting.
Goodwill amounted to approximately $486 million, resulting in an
annual amortization of goodwill of approximately $12.2 million.
Costs to achieve are being amortized based on the filed estimate
of $111 million over 10 years. NSTAR's retail utility
subsidiaries will reconcile the ultimate costs to achieve with
that estimate and any difference is expected to be recovered over
the remainder of the amortization period. To date, a majority of
costs to achieve the merger were for severance costs associated
with a voluntary separation program (VSP) in which approximately
700 employees elected to participate. The VSP was completed by
the end of August 2000. These amounts are expected to be offset
by ongoing future cost savings from streamlined operations and
avoidance of costs that would have otherwise been incurred by BEC
and COM/Energy.
In July 1999, the MDTE approved a rate plan filed by the utility
subsidiaries of BEC and COM/Energy in connection with the merger.
A group of four intervenors and the Massachusetts Attorney
General filed two separate appeals of the MDTE's rate plan order
with the SJC in August 1999. While management anticipates that
the MDTE's decision to approve the rate plan will be upheld by
the SJC, it is unable to determine the ultimate outcome of these
appeals.
Generating Asset Divestiture
To complete its divestiture of generating assets, Boston Edison
sold Pilgrim Nuclear Generating Station (Pilgrim) in July 1999
for $81 million to Entergy Nuclear Generating Company. As part
of the sale, Boston Edison transferred approximately $228 million
in decommissioning funds to Entergy. Entergy, by contract,
assumed all future liability related to the ultimate
decommissioning of the plant. The difference between the total
proceeds from the sale and the net book value of the Pilgrim
assets plus the net amount to fully fund the decommissioning
trust is included in regulatory assets on the accompanying
Condensed Consolidated Balance Sheets as such amounts are
collected from customers.
Securitization of Boston Edison's Transition Charge
On July 27, 1999, BEC Funding LLC, a wholly owned special-purpose
subsidiary of Boston Edison, closed the sale of $725 million of
notes to a special purpose trust created by two Massachusetts
state agencies. The trust then concurrently closed the sale of
$725 million of electric rate reduction certificates as a public
offering. The certificates are secured by a portion of the
transition charge assessed on Boston Edison's retail customers as
permitted under the Massachusetts Electric Restructuring Act and
authorized by the MDTE. These certificates are non-recourse to
Boston Edison.
Retail Electric Rates
As a result of the Electric Restructuring Act, the regulated
retail electric subsidiaries of NSTAR currently provide their
standard offer customers service at inflation adjusted rates that
are 15% lower than rates in effect prior to March 1, 1998, the
retail access date.
All distribution customers must pay a transition charge as a
component of their rate. The purpose of the transition charge is
to allow for the collection of generation-related costs that
would not be collected in the competitive energy supply market.
The plant and regulatory asset balances that will be recovered
through the transition charge until 2009 were approved by the
MDTE.
The Electric Restructuring Act requires electric distribution
companies to obtain and resell power to customers that choose not
to buy energy from a competitive energy supplier. This is
through either "standard offer service" or "default service."
Standard offer service will be available to eligible customers
through 2004 at prices approved by the MDTE set at levels so as
to guarantee mandatory rate reductions provided by the Electric
Restructuring Act. New retail customers in the NSTAR electric
service territories and previously existing customers that are no
longer eligible for the standard offer service and have not
chosen to receive service from a competitive supplier, are on
"default service." The price of default service is intended to
reflect the average competitive market price for power. The
NSTAR electric subsidiaries have actively solicited proposals to
transfer all of the unit output entitlements in their existing
power purchase contracts and in exchange to procure power
supplies for their standard offer service obligations through
2004. The companies have entered into six-month and shorter term
agreements to meet standard offer service obligations and
continue to evaluate further proposals. In November 2000 the
companies entered into power purchase agreements to meet their
default service supply obligations for the period January through
June of 2001. The companies expect to continue periodic market
solicitations for default service power supply consistent with
provisions of the Electric Restructuring Act and MDTE orders.
The cost of providing standard offer and default service, which
includes purchased power costs, is recovered from customers on a
fully reconciling basis.
NSTAR's cost to provide default service as well as standard offer
service is in excess of the price it is currently allowed to
bill. As a result, NSTAR has recorded, at September 30, 2000, a
deferred asset of approximately $225.2 million that is reflected
as a component of Regulatory assets on the accompanying Condensed
Consolidated Balance Sheet.
Under its restructuring settlement agreement, Boston Edison's
distribution business is subject to a minimum and maximum return
on average common equity (ROE). The ROE is subject to a floor of
6% and a ceiling of 11.75%. If the ROE is below 6%, Boston
Edison is authorized to add a surcharge to distribution rates in
order to achieve the 6% floor. If the ROE is above 11%, it is
required to adjust distribution rates by an amount necessary to
reduce the calculated ROE between 11% and 12.5% by 50%, and a
return above 12.5% by 100%. No adjustment is made if the ROE is
between 6% and 11%. This rate mechanism expires on December 31,
2000.
Under applicable restructuring plans or settlements approved by
the MDTE, each NSTAR retail electric subsidiary must, on an
annual basis, file proposed adjustments to their rates for the
upcoming year along with a proposed reconciliation of prior year
revenues and costs for their standard offer, default service,
transmission and transition charges. Each retail electric
subsidiary made such a filing with the MDTE in the Fall of 1999,
as to which the MDTE subsequently approved proposed rate
adjustments effective January 1, 2000, and conducted further
hearings for the purpose of reconciliation of prior year's costs
and revenues related to each company's transition and
transmission charges and the charges for standard offer and
default service. In each such proceeding, certain cost
allocations and other related issues have been contested;
however, the MDTE has not yet rendered a final decision. In
November 2000, each retail electric subsidiary has made a similar
filing containing proposed rate adjustments for 2001, including a
reconciliation of costs and revenues through 1999. No action has
yet been taken by the MDTE concerning such filings. Management
is unable to determine the outcome of the MDTE proceedings.
However, if an unfavorable outcome were to occur, there would be
a material adverse impact on NSTAR's consolidated financial
position, results of operations and cash flows in the near term.
In addition to the annual rate filings referenced above, the
NSTAR retail electric subsidiaries have also made separate
filings with the MDTE concerning charges for standard offer and
default service. The NSTAR electric companies have filed with
the MDTE a request for approval to increase their standard offer
service rates based on a fuel adjustment formula based on the
prices of natural gas and oil contained in their standard offer
tariffs. The adjustments would increase standard offer service
rates as follows: Boston Edison - from 4.5 cents per kWh to 5.081
cents per kWh; Cambridge Electric and Commonwealth Electric -
from 3.8 cents per kWh to 4.45 cents per kWh. The MDTE continues
to consider the request for effect in future months. If the
request is approved, the companies expect to make further monthly
filings to adjust customer billings based on changes in the costs
of natural gas and oil. The NSTAR Electric companies have also
made filings with the MDTE to increase the price for default
service to market-based levels. On October 19, 2000 the MDTE
approved the companies' request to increase the price of
generation service for default service to 6.280 cents per kWh
effective December 1, 2000. On November 9, 2000 the NSTAR
electric companies filed a request with the MDTE to increase the
price for default service to 6.993 cents per kWh for the period
January 1, 2001 through June 30, 2001. These and future prices
for default service are based upon market solicitations for power
supply for default service purposes consistent with provisions of
the Electric Restructuring Act and MDTE orders.
In October 1997, the MDTE opened a proceeding to investigate
Boston Edison's compliance with a 1993 order that permitted the
formation of Boston Energy Technology Group (BETG) and authorized
Boston Edison to invest up to $45 million in unregulated
activities. Hearings were completed during the first quarter of
1999. Management is currently unable to determine the outcome of
this proceeding. However, if an unfavorable outcome were to
occur, there could be a material adverse impact on business
operations, the consolidated financial position, cash flows or
results of operations for a reporting period.
Natural Gas Industry Restructuring and Rates
In late 1998, the MDTE issued an order establishing rules and
regulations governing the unbundling of gas service to all
customers in Massachusetts. Prior to this, only commercial and
industrial customers were able to obtain competitive gas supply
service from a source other than the local distribution company
(LDC). These regulations are similar to those adopted by the
MDTE governing electric restructuring. Among the important
provisions are: setting the LDC as the default service provider,
certification of competitive suppliers/marketers, extension of
the MDTE's consumer protection rules to residential customers
taking competitive service, requirement for LDCs to provide
suppliers/marketers with customer usage data, and requirement for
suppliers/marketers to disclose service terms to potential
customers. In addition, the MDTE has standardized the
eligibility requirements for low-income rates for all LDCs that
are identical to previously established requirements for electric
customers. In February 1999, the MDTE issued an order requiring
the mandatory assignment of LDC upstream pipeline capacity and
downstream peaking capacity to customers who elect a competitive
gas supply. In January 2000, the MDTE approved the Model Terms
and Conditions submitted by the LDCs that provided the framework
for implementing the regulations. In October 2000, the MDTE
approved compliance Terms and Conditions submitted by
Commonwealth Gas and the LDCs that implement the unbundling of
gas services to all customers. With the issuance of these orders
and regulations, the MDTE has moved the process for customer
choice to commence November 1, 2000. It is not expected that
many additional customers (in particular residential customers)
will elect to take competitive gas supply service on November 1,
but more migration from LDC service to competitive service is
expected by November 1, 2001.
Results of Operations - Three Months Ended September 30, 2000 vs.
Three Months
Ended September 30, 1999
Due to the application of purchase method accounting, the results
for 2000 reflect the combined performance of BEC Energy and
COM/Energy, as NSTAR. Results for the corresponding period in
1999 reflect two months of BEC Energy and one month of NSTAR.
As further described below, earnings per common share were as
follows:
Earnings per Common Share Three Months Ended September 30,
2000 1999 % Change
Basic $1.21 $1.32 (8.3%)
Diluted $1.20 $1.31 (8.4%)
Earnings per common share reflect the impact of a higher level of
common shares outstanding resulting from the merger. The results
of operations for the quarter are not indicative of the results
that may be expected for the entire year due to the seasonality
of electric and gas sales and revenues. Refer to Note B to the
Unaudited Condensed Consolidated Financial Statements.
Operating revenues
Operating revenues increased 37.2% during the third quarter of
2000 as follows:
(in thousands)
Retail electric revenues $ 139,939
Wholesale electric revenues (9,300)
Other revenues 28,525
Gas revenues 33,204
Increase in operating revenues $ 192,368
=========
Retail electric revenues were $591.9 million in 2000 compared to
$452 million in 1999, an increase of $139.9 million or 31%. The
change in retail revenues reflects an increase of $119 million
representing the addition of revenues from the former COM/Energy
retail electric subsidiaries, the recognition of incentive
revenue entitlements for successfully lowering certain transition
charges and the offsetting impact of a 2.1% decline in retail
kilowatt-hour (kWh) sales. The decrease in retail kWh sales is
the result of a cooler summer period than in 1999. The weather
impact was partially mitigated by a strong local economy and
customer growth. In addition, NSTAR's retail subsidiaries
increased their standard offer rates in January 2000. The
revenues charged for standard offer service are fully reconciled
to the costs incurred and have no impact on net income.
Wholesale electric revenues were $8.7 million in 2000 compared to
$18 million in 1999, a decrease of $9.3 million or 52%. This
decrease in wholesale revenues primarily reflects a decrease in
contract sales due to the sale of Pilgrim station in July 1999.
Other revenues were $62.3 million in 2000 compared to $33.8
million in 1999, an increase of $28.5 million or 84%. This
increase primarily reflects an additional $33 million for the non-
utility operations of COM/Energy, higher transmission revenues
related to a FERC-approved settlement for transmission contract
customers during 1999, an approximate 18% increase in average
transmission rates effective September 1, 1999, partially offset
by a lower provision for transmission refunds during 2000.
Gas revenues were $46.5 million in 2000 compared to $13.3 million
in 1999 representing revenues from Commonwealth Gas. This
increase is directly related to the addition of COM/Energy
merger.
Retail Electric Sales and Revenues
Retail kWh sales increased 35.7% in the quarter ended September
30, 2000. This increase includes an increase of 38.3%
representing the former COM/Energy subsidiaries. Without the
impact of the merger, kWh sales for 2000 would have declined 2.6%
from 1999. This decrease in retail kWh sales is primarily due to
weather conditions that reduced the need for air conditioning
despite continued improvement in regional economic conditions.
The commercial sector represents approximately 50% of electric
operating revenues.
Gas Sales
Firm gas sales for the quarter ended September 30, 2000 increased
nearly 63% over the prior year primarily related to the merger
and further impacted by the cooler than normal summer
temperatures and increased number of Commonwealth Gas customers.
The increase in gas sales also reflects the impact of converted
heating source from fuel oil to gas.
Operating expenses
Fuel, purchased power and cost of gas sold was $325 million in
2000 compared to $213.2 million in 1999, an increase of $111.8
million or 52%. The increase reflects additional expense from
the COM/Energy subsidiaries. Purchased power expense increased
$90.9 million due to the sale of Pilgrim in July 1999 and a
significant increase in the wholesale power market. NSTAR
adjusts its electric rates to collect the costs related to fuel
and purchased power from customers on a fully reconciling basis.
Fuel and purchased power expenses reflect a reduction of $95
million in 2000 and $71 million in 1999 related to these rate
recovery mechanisms. Due to the rate adjustment mechanisms,
changes in the amount of fuel and purchased power expense have no
impact on earnings. Further contributing to the reduction in
expense was the absence in the current period of fuel expense
related to Pilgrim of $.7 million in 1999.
Operations and maintenance expense was $111.8 million in 2000
compared to $93.1 million in 1999, an increase of $18.7 million
or 20%. This increase reflects the expense from the COM/Energy
subsidiaries. This increase was partially offset by the absence
of nuclear production expenses as a result of the sale of Pilgrim
in July 1999 that, for the three-months ended September 1999,
amounted to $1.9 million. Further offsetting this increase were
decreases in operations and maintenance expense resulting from
the merger and other cost control measures implemented by NSTAR.
As a result of the merger of BEC Energy and COM/Energy,
operations and maintenance cost savings have been realized due to
lower staffing levels, timing and classification of expenses,
maintenance on substation equipment and permanent savings in
employee pensions and benefits.
Depreciation and amortization expense was $58.9 million in 2000
compared to $56.6 million in 1999, an increase of $2.3 million or
4%. The increase reflects approximately $4 million resulting
from the amortization of goodwill and costs to achieve related to
the merger. These increases were partially offset by decreases
resulting from the Pilgrim divestiture.
Demand side management (DSM) and renewable energy programs
expense was $23.3 million in 2000 compared to $15.5 million in
1999, an increase of $7.8 million or 50% primarily due to $8.1
million from the COM/Energy subsidiaries. These costs are
collected from customers on a fully reconciling basis.
Therefore, the increase has no impact on earnings.
Property and other taxes were $20.1 million in 2000 compared to
$17.2 million in 1999, an increase of $2.9 million or 17%. The
increase is due to $7 million from the COM/Energy subsidiaries
partially offset by lower municipal property taxes of $3.4
million resulting from the sale of Pilgrim.
Income taxes from operations were $43.1 million in 2000 compared
to $36.5 million in 1999, a increase of $6.6 million or 18%
reflecting higher pre-tax operating income in 2000 resulting from
the addition of the COM/Energy subsidiaries and an increase in
the effective tax rate. Refer to Note E "Income Taxes" enclosed
herewith for further details.
Other income (expense), net
Other income, net was $0.3 million in 2000 compared to $17
million in 1999, a net decrease in income of $16.7 million or 98%
primarily due to the absence in 2000 of $20.8 million related to
the recognition of previously deferred investment tax credits
associated with the Pilgrim unit offset by a one-time charge
associated with the carrying value as a district energy
investment.
Interest charges
Interest on long-term debt and transition property securitization
certificates was $35.5 million in 2000 compared to $28.1 million
in 1999, an increase of $7.4 million or 26%. The increase
reflects $2.7 million of interest related to transition property
securitization certificates, $9 million of interest related to
NSTAR's $300 million 8% bonds issued in February 2000 and $5.1
million of interest from the COM/Energy subsidiaries. These
increases were partially offset by approximately $4.5 million of
debt interest related to retirements of $100 million of 6.05%
debentures during the third quarter of 2000.
Interest on other debt increased $20.5 million and reflects the
addition of the COM/Energy subsidiaries.
Results of Operations - Nine Months Ended September 30, 2000 vs.
Nine Months Ended September 30, 1999
Due to the application of purchase method accounting, the results
for 2000 reflect the combined performance of BEC Energy and
COM/Energy, as NSTAR. Results for the corresponding period in
1999 reflect eight months of BEC Energy and one month of NSTAR.
As further described below, earnings per common share were as
follows:
Earnings per Common Share Nine Months Ended September 30,
2000 1999 % Change
Basic $2.38 $2.50 (4.8%)
Diluted $2.37 $2.49 (4.8%)
Earnings per common share reflect the impact of a higher level of
common shares outstanding resulting from the merger. The results
of operations for the first nine months of 2000 are not
indicative of the results that may be expected for the entire
year due to the seasonality of electric and gas sales and
revenues. Refer to Note B to the Unaudited Condensed
Consolidated Financial Statements.
Operating revenues
Operating revenues increased 72% during the first nine months of
2000 as follows:
(in thousands)
Retail electric revenues $ 440,288
Wholesale electric revenues (34,451)
Other revenues 107,870
Gas revenues 222,957
Increase in operating revenues $ 736,664
=========
Retail electric revenues were $1,544.5 million in 2000 compared
to $1,104.2 million in 1999, an increase of $440.3 million or
40%. The change in retail revenues reflects an increase of $368
million representing the addition of revenues from the former
COM/Energy retail electric subsidiaries, the recognition of
incentive revenue entitlements for successfully lowering certain
transition charges and the impact of a 2.8% increase in retail
kilowatt-hour (kWh) sales. The increase in retail kWh sales is
the result of a strong local economy as indicated by an
improvement in the overall Massachusetts unemployment rate to
2.2% and customer growth. In addition, NSTAR's retail electric
subsidiaries increased their standard offer rates in January
2000. The revenues charged for standard offer service are fully
reconciled to the costs incurred and have no impact on net
income.
Wholesale electric revenues were $57.5 million in 2000 compared
to $92 million in 1999, a decrease of $34.5 million or 38%. This
decrease in wholesale revenues primarily reflects a decrease in
contract sales due to the sale of Pilgrim in July 1999.
Other revenues were $166.6 million in 2000 compared to $58.7
million in 1999, an increase of $107.9 million or 184%. This
increase primarily reflects approximately $82 million in
additional revenue from the non-utility operations of COM/Energy
and higher transmission revenues related to refunds to wholesale
customers resulting from a FERC-approved settlement for
transmission contract customers during 1999 in average
transmission rates effective September 1, 1999.
Gas revenues were $236.3 million in 2000 compared to $13.3
million in 1999 that represented revenues from Commonwealth Gas.
Retail Electric Sales and Revenues
Retail kWh sales increased 34.2% in 2000. This increase includes
an increase of 32.1% representing the former COM/Energy
subsidiaries. Without the impact of the merger, kWh sales for
the first nine months of 2000 would have increased 2.8% from
1999. This increase in retail kWh sales is primarily due to the
strong economic conditions and customer growth offset in part by
heating degree days being 4% more than in 1999. Cooling degree
days 35% less than 1999. The commercial sector represents
approximately 50% of electric operating revenues. This sector
has also been positively impacted by improved economic
conditions.
Gas Sales and Revenue
Commonwealth Gas generates revenues primarily through the sale
and transportation of natural gas. Gas sales are divided into
two categories; firm, whereby ComGas must supply gas or gas
transportation services to customers on demand; and
interruptible, whereby Commonwealth Gas may, generally during
colder months, temporarily discontinue service to high volume
commercial and industrial customers. Sales of gas to
interruptible customers do not materially affect Commonwealth
Gas' operating income because substantially all margin on such
sales offsets the revenue requirement of customers.
Commonwealth Gas' tariffs include a seasonal Cost of Gas
Adjustment Clause (CGAC) and a Local Distribution Adjustment
Clause (LDAC) that provide for the recovery, from firm customers
or default service customers, of certain costs previously
recovered through base rates. The CGAC provides for rates that
must be approved semi-annually by the MDTE. The LDAC provides
for rates that require annual approval.
Gas sales increased primarily due to colder first quarter
temperatures and continued customer growth. On a year-to-date
basis, heating degree days were 4.3% more than the same period in
1999. The number of Commonwealth Gas customers increased 1.6%
over 1999 including the addition of two major customers that
converted heating source from fuel oil to gas. The increase in
gas sales also reflects the impact of higher oil prices as
customers switched to lower cost heating sources.
Operating expenses
Fuel, purchased power and cost of gas sold was $999 million in
2000 compared to $510.9 million in 1999, an increase of $488.1
million or 96%. The increase primarily reflects the additional
expense from the COM/Energy subsidiaries. Fuel and purchased
power expense was $870.8 million in 2000 compared to $503.7
million in 1999, an increase of $367.1 million or 73% reflecting
the expense from the COM/Energy subsidiaries and $194.6 million
for the increase in purchased power due to the sale of Pilgrim in
1999 and an overall increase in the whole power market. NSTAR
adjusts its electric rates to collect the costs related to fuel
and purchased power from customers on a fully reconciling basis.
Fuel and purchased power expenses reflect a reduction of $143.8
million in 2000 and $34.2 million in 1999 related to these rate
recovery mechanisms. Due to the rate adjustment mechanisms,
changes in the amount of fuel and purchased power expense have no
impact on earnings. Further contributing to the reduction in
expense was the absence in the current period of fuel expense
related to Pilgrim that was $9.4 million in 1999. The cost of
gas sold was $128.2 million in 2000 compared to $7.2 million in
1999, an increase of $121 million.
As a result of the merger of BEC Energy and COM/Energy,
operations and maintenance cost savings have been realized due to
lower staffing levels, timing and classification of expenses,
maintenance on substation equipment and permanent savings in
employee pensions and benefits.
Operations and maintenance expense was $327.4 million in 2000
compared to $244 million in 1999, an increase of $83.4 million or
34%. This increase reflects the expense from the COM/Energy
subsidiaries that were partially offset by the absence of $36.2
million for nuclear production expenses as a result of the sale
of Pilgrim.
Depreciation and amortization expense was $176.9 million in 2000
compared to $151.8 million in 1999, an increase of $25.1 million
or 17%. The increase reflects approximately $15.5 million
resulting from the amortization of goodwill and costs to achieve
related to the merger and approximately $9.5 million related to
other expenses for the COM/Energy subsidiaries. These increases
were partially offset by decreases resulting from the Pilgrim
divestiture.
Demand side management (DSM) and renewable energy programs
expense was $59 million in 2000 compared to $42.2 million in
1999, an increase of $16.8 million or 40% primarily due to $16.4
million from the COM/Energy subsidiaries. In accordance with
legislative and regulatory directives, these costs are collected
from customers on a fully reconciling basis. Therefore, the
increase has no impact on earnings.
Property and other taxes were $66.9 million in 2000 compared to
$57.2 million in 1999, an increase of $9.7 million or 17%. The
increase is primarily due to the COM/Energy subsidiaries
partially offset by lower municipal property taxes of $7.4
million resulting from the Pilgrim divestiture.
Income taxes from operations were $92.2 million in 2000 compared
to $74.8 million in 1999, an increase of $17.4 million or 23%
reflecting higher pre-tax operating income in 2000.
Other income net
Other income, net was $8.2 million in 2000 compared to $13.6
million in 1999, a net decrease in income of $5.4 million or 40%
due primarily to the absence in 2000 of $20.8 million related to
the 1999 recognition of previously deferred investment tax
credits associated with the Pilgrim unit that was sold in 1999
and fossil generating plants sold in 1998. Somewhat offsetting
this decline in 2000 was income of $4.5 million from a third
party related to the Pilgrim contract buyout, $6.6 million
representing joint venture income from a subsidiary minority
interest, $1.3 million in interest income supporting a
construction financing loan on the Summit office complex,
miscellaneous income that includes a $3.6 million net gain
related to the sale of land and $5.9 million related to income
realized on funds held by Energy Investment Services. These
positive factors were offset by $7.4 million in expense primarily
for income taxes paid on non-operating income, $5.6 million in
operating losses associated with NSTAR COM's investment in the
RCN joint venture, $6.7 million related to a one-time charge
associated with the carrying value of a district energy
investment and $2.5 million related to miscellaneous non-
operating expenses.
Interest charges
Interest on long-term debt and transition property securitization
certificates was $114.4 million in 2000 compared to $67 million
in 1999, an increase of $47.4 million or 71%. The increase
reflects $26.1 million of interest related to transition property
securitization certificates, $15 million related to the $300
million 8% bonds issued in February 2000 and $20.9 million of
interest from the COM/Energy subsidiaries. These increases were
partially offset by approximately $14.9 million in reductions
related to the following retirements: $19 million of 7.8%
debentures, $66 million of 9.875% debentures, $91 million of
9.375% debentures during the third quarter of 1999, $65 million
of 6.8% debentures, $34 million of 9.875% debentures during the
first half of 2000 and $100 million of 6.05% debentures during
the third quarter of 2000.
Interest on other debt increased $32.4 million and reflected the
addition of the COM/Energy subsidiaries.
RCN Joint Venture and Investment Conversion
NSTAR Communications, Inc. (NSTAR COM), an indirect subsidiary of
NSTAR, is a participant in a telecommunications venture with RCN
Telecom Services, Inc. of Massachusetts (RCN), a subsidiary of
RCN Corporation. NSTAR accounts for its Class A Equity
investment in the joint venture using the equity method of
accounting. As part of the joint venture agreement, NSTAR has
the option to exchange portions of its joint venture interest for
shares of RCN common stock at specified periods. During 1998,
NSTAR exercised its option to convert a portion of its interest.
In the first quarter of 1999, NSTAR received 1.1 million shares
of RCN Corporation common stock in exchange for a portion of its
joint venture interest that had a net book value of $7.8 million.
In May 1999, NSTAR COM notified RCN of its intention to exercise
its option to convert an additional portion of its joint venture
interest that had a net book value of $72.3 million at that time.
In March 2000, NSTAR COM received approximately 3 million shares
of RCN Corporation common stock associated with this second
exchange. In connection with these two exchanges, as of the date
of each respective conversion, NSTAR COM recorded a deferred gain
for the difference between the net book value of its equity
investment in the joint venture and the fair value of the shares
received. In accordance with Generally Accepted Accounting
Principles ("GAAP"), this gain must be deferred until such time
that NSTAR sells off its holdings of RCN Corporation shares.
The RCN Corporation shares received are included in other
investments on the September 30, 2000 Condensed Consolidated
Balance Sheets at their fair value of approximately $85 million.
This fair value may increase or decrease, at any time, as a
result of changes in the market price of RCN Corporation common
shares. The unrealized gain or loss due to the changes in fair
value on these shares during each period is reflected, net of
associated income taxes, as comprehensive (loss) income on the
Condensed Consolidated Statements of Comprehensive Income for the
three and nine months ended September 30, 2000 and 1999. The
cumulative increase or decrease in fair value of these shares as
of September 30, 2000 and December 31, 1999 is reflected as
accumulated other comprehensive income, net on the Condensed
Consolidated Balance Sheets.
In addition, on April 6, 2000, NSTAR COM issued its third notice
to exchange substantially all of its remaining interest in the
joint venture with a net book value as of September 30, 2000 of
approximately $129 million in the joint venture into common stock
of RCN Corporation. The number of RCN Corporation shares
associated with this third notice is expected to be finalized by
December 31, 2000.
On October 18, 2000, NSTAR COM and RCN signed an agreement in
principal to amend the Joint Venture Agreement. Among other
items this proposal would settled the number of shares to be
exchanged associated with the third conversion of NSTAR COM's
Class A Equity. This amendment also offers NSTAR COM the option
to continue to invest in the joint venture through a new "Class B
Preferred Equity" with a fixed return guaranteed by RCN
Corporation and changes the calculation of the joint venture
profit and loss sharing ratio and investment interest
percentages. This Class B Equity has no voting rights and no
sharing of profits or losses.
NSTAR COM anticipates that all definitive documents to complete
these amendments to the Joint Venture Agreement will be executed
by December 31, 2000.
Liquidity
NSTAR and its subsidiaries supplement internally generated funds
as needed, primarily through the issuance of short-term
commercial paper and bank borrowings.
In February 2000, NSTAR issued $300 million of long-term debt of
its $500 million shelf registration statements filed with the
SEC. Proceeds from this issue were used to pay down on its short-
term borrowings. On October 6, 2000, NSTAR closed on the sale of
$200 million, 8% notes, due February 2010, the remaining portion
of its shelf registration. Pursuant to the Financial Accounting
Standards Board (FASB) and Statement of Financial Accounting
Standards No. 6, "Classification of Short-Term Obligations
Expected To Be Refinanced", NSTAR has reflect on the accompanying
financial statements at September 30, 2000 this $200 million
paydown of its short-term debt balance and a similar increase in
long-term debt. This new debt issuance forms a single series
with the notes issued in February 2000. These increases in long-
term debt were partially offset in 2000 by $199 million in
reductions, including $100 million in August, related to Boston
Edison debenture retirements.
NSTAR has a $450 million revolving credit agreement with a group
of banks effective through November 2002. As of September 30,
2000, there was no amount outstanding under this credit
agreement. The purpose of this agreement is to provide financing
for general corporate purposes, to fund the common share
repurchase program and for other corporate purposes.
Boston Edison has authority from the Federal Energy Regulatory
Commission (FERC) to issue up to $350 million of short-term debt.
Boston Edison has a $200 million revolving credit agreement with
a group of banks effective through December 2000, that serve as
backup to Boston Edison's $200 million commercial paper program.
In addition, the former subsidiaries of COM/Energy have $170
million available under several lines of credit. Approximately
$146 million was outstanding under these lines of credit as of
September 30, 2000.
Boston Edison's Financing Application with the MDTE was approved
in October 2000 for authorization to issue from time to time up
to $500 million of debt securities. Proceeds from such issuances
covered under this approved financing will be used for repayment
or refinancing of certain outstanding equity securities, long-
term indebtedness, and for other corporate purposes.
In April 1998, BEC Energy announced a common share repurchase
program under which it would repurchase up to four million of its
common shares. NSTAR assumed this program effective as of the
merger date. In October 1999, this program was completed by
NSTAR. Four million shares were repurchased at a total cost of
approximately $157 million. NSTAR subsequently announced a
second common share repurchase program of $300 million that was
completed in September 2000 with the repurchase of approximately
7.2 million shares.
In July 1999, BEC Funding LLC, a wholly owned special-purpose
subsidiary (SPS) of Boston Edison, closed the sale of $725
million of notes to a special purpose trust created by two
Massachusetts state agencies. The trust then concurrently closed
the sale of $725 million of electric rate reduction certificates
to the public. The certificates held by BEC Funding are secured
by a portion of the transition charge assessed to Boston Edison's
retail customers as permitted under the Massachusetts Electric
Restructuring Act and authorized by the MDTE. The certificates
were issued in five separate classes with variable payment
periods ranging from approximately one to ten years and bearing
fixed interest rates ranging from 5.99% to 7.03%. The
certificates are non-recourse to Boston Edison. Net proceeds
($719 million received by Boston Edison from BEC Funding) were
utilized to finance a portion of the stranded costs that are
being collected from customers under Boston Edison's
restructuring settlement agreement. Boston Edison will collect a
portion of the transition charge on behalf of BEC Funding and
remit the proceeds to the SPS. Boston Edison used a portion of
the proceeds received from the financing to fund a portion of the
nuclear decommissioning fund transferred to Entergy Nuclear
Generating Company as part of the sale of the Pilgrim generating
station. Boston Edison used the remaining proceeds to reduce its
capitalization and for general corporate purposes.
NSTAR's goal is to maintain a capital structure that preserves an
appropriate balance between debt and equity. Management believes
its liquidity and capital resources are sufficient to meet its
current and projected requirements.
New Accounting Principles
In June 1998, FASB issued Statement of Financial Accounting
Standards No. 133, "Accounting for Derivative Instruments and
Hedging Activities" and as amended by Statement of Accounting
Standards No. 138, collectively referred as, (SFAS 133). SFAS
133 establishes accounting and reporting standards requiring that
every derivative instrument (including certain derivative
instruments embedded in other contracts possibly including fixed-
price fuel supply and power contracts) be recorded on the
Consolidated Balance Sheets as either an asset or liability
measured at its fair value. SFAS 133, as amended by SFAS 137,
"Accounting for Derivative Instruments and Hedging Activities-
Deferral of the Effective Date of FASB Statement No 133", is
effective for fiscal years beginning after June 15, 2000 (January
1, 2001 for calendar year companies). Initial application shall
be as of the beginning of an entity's fiscal quarter.
NSTAR will adopt SFAS 133 as of January 1, 2001. The impact of
this adoption is currently being assessed by the management of
NSTAR. NSTAR has formed an implementation team consisting of
responsible key individuals from various operational areas of the
organization. The primary role of this team is to inventory and
discuss potential contractual arrangements for FAS 133
application.
Consolidation of Facilities
In completion of its corporate facilities consolidation, NSTAR is
constructing a 370,000 square foot office building (the Summit)
sited on 33 acres in the Boston suburb of Westwood. This site is
centrally located in NSTAR's new service territory and provides
immediate access to Interstate Routes 93 and 95. The building
will house central corporate offices including finance, human
resources, sales, engineering, information technology, and
customer care. NSTAR expects to consolidate more than a third of
its workforce into the building during the third quarter of 2001.
Safe harbor cautionary statement
NSTAR occasionally makes forward-looking statements such as
forecasts and projections of expected future performance or
statements of its plans and objectives. These forward-looking
statements may be contained in filings with the Securities and
Exchange Commission (SEC), press releases and oral statements.
Actual results could potentially differ materially from these
statements. Therefore, no assurances can be given that the
outcomes stated in such forward-looking statements and estimates
will be achieved.
The preceding sections include certain forward-looking statements
about operating results, environmental and legal issues.
The impacts of continued cost control procedures on operating
results could differ from current expectations. The effects of
changes in economic conditions, tax rates, interest rates,
technology and the prices and availability of operating supplies
could materially affect the projected operating results.
The timing and total costs related to the year 2000 plan could
differ from current expectations. Factors that may cause such
differences include the ability to locate and correct all
relevant computer codes and the availability of personnel trained
in this area. In addition, NSTAR cannot predict the nature or
impact on operations of third party noncompliance.
The impacts of various environmental, legal issues, and
regulatory matters could differ from current expectations. New
regulations or changes to existing regulations could impose
additional operating requirements or liabilities other than
expected. The effects of changes in specific hazardous waste
site conditions and cleanup technology could affect the estimated
cleanup liabilities. The impacts of changes in available
information and circumstances regarding legal issues could affect
the estimated litigation costs.
Part II - Other Information
Item 3. Quantitative and Qualitative Disclosures about Market
Risk
There have been no material changes since year-end.
Item 4. Submission of Matters to a Vote of Security Holders
None
Item 5. Other Information
The following additional information is furnished in connection
with the Registration Statement on Form S-3 of the Registrant
(File No. 33-57840), filed with the Securities and Exchange
Commission on February 3, 1993.
Ratio of earnings to fixed charges and ratio of earnings to fixed
charges and preferred stock dividend requirements.
Twelve months ended September 30, 2000:
Ratio of earnings to fixed charges 2.05
Ratio of earnings to fixed charges and
preferred stock dividend requirements 1.97
Item 6. Exhibits and Reports on Form 8-K
a) Exhibits filed herewith and incorporated by reference:
Exhibit 4 - Instruments Defining the Rights of
Security Holders, Including Indentures
Management agrees to furnish to the
Securities and Exchange Commission, upon
request, a copy of any agreements or
instruments defining the rights of
holders of any long-term debt whose
authorization does not exceed 10% of
total assets.
Exhibit 10 - Material Contracts
10.1 Waiver and Employment Agreement among
Commonwealth Energy System and certain
of its Subsidiaries, Deborah A.
McLaughlin and NSTAR, dated September
21, 2000 (Filed Herewith)
10.2 Change in Control Agreement between
James J. Judge and NSTAR, dated August
28, 2000 (Filed Herewith)
10.3 Change in Control Agreement between
Deborah A. McLaughlin and NSTAR, dated
September 21, 2000 (Filed Herewith)
10.4 NSTAR Trustees' Deferred Plan (Restated
Effective August 25, 1999), dated
October 20, 2000 (Filed Herewith)
10.5 Master Trust Agreement between NSTAR and
State Street Bank and Trust Company
(Rabbi Trust), dated August 25, 1999
(Filed Herewith)
Exhibit 12 - Computation of Ratio of Earnings to
Fixed Charges
12.1 - Computation of ratio of earnings to
fixed charges for the twelve months
ended September 30, 2000.
12.2 - Computation of ratio of earnings to
fixed charges and preferred stock
dividend requirements for the twelve
months ended September 30, 2000.
Exhibit 15 - Letter Re Unaudited Interim Financial
Information
15.1 - Letter of Independent Accountants
Form S-4 Registration Statement filed by
NSTAR on May 12, 1999 (File No. 333-
78285); Post-effective Amendment to Form
S-4 on Form S-3 filed by NSTAR on August
19, 1999 (File No. 333-78285); Post-
effective Amendment to Form S-4 on Form
S-8 filed by NSTAR on August 19, 1999
(File No. 333-78285); Form S-8
Registration Statement filed by NSTAR on
August 19, 1999 (File No. 333-85559);
and Form S-3 Registration Statement
filed by NSTAR on January 12, 2000 (File
No. 333-94735).
Exhibit 27 - Financial Data Schedule
27.1 - Schedule UT
Exhibit 99 - Additional Exhibits
99.1 - Report of Independent Accountants
b) No Form 8-K was filed during the third quarter of 2000.
Signature
Pursuant to the requirements of the Securities Exchange Act of
1934, the registrant has duly caused this report to be signed on its behalf
by the undersigned thereunto duly authorized.
NSTAR
(Registrant)
Date: November 13, 2000 /s/ R. J. Weafer Jr.
Robert J. Weafer Jr.
Vice President, Controller
and Chief Accounting
Officer
Exhibit 12.1
NSTAR
Computation of Ratio of Earnings to Fixed Charges
Twelve Months Ended September 30, 2000
(in thousands)
Net income from continuing operations $158,701
Income taxes 77,584
Fixed charges - (including securitization 225,135
certificates)
Total $461,420
========
Interest expense $208,135
Interest component of rentals 17,000
Total $225,135
========
Ratio of earnings to fixed charges and preferred 2.05
stock dividends requirements ========
Exhibit 12.2
NSTAR
Computation of Ratio of Earnings to Fixed Charges
And Preferred Stock Dividend Requirements
Twelve Months Ended September 30, 2000
(in thousands)
Net income from continuing operations $158,701
Income taxes 77,584
Fixed charges - (including securitization 225,135
certificates)
Total $461,420
========
Interest expense $208,135
Interest component of rentals 17,000
Subtotal $225,135
========
Preferred stock dividend requirements 8,873
Total $234,008
========
Ratio of earnings to fixed charges 1.97
========
Exhibit 15.1
Securities and Exchange Commission
450 Fifth Street, N.W.
Washington, D.C. 20549
Re: NSTAR
Registration on
Forms S-4, S-8, and
S-3.
We are aware that our report dated November 13, 2000 on our
review of the condensed consolidated interim financial
information of NSTAR as of and for the period ended September 30,
2000 and included in NSTAR's quarterly report on Form 10-Q for
the quarter then ended is incorporated by reference in NSTAR's
registration statement on Form S-4 and related amendments (File
No.
333-78285), Form S-8 (File No. 333-85559) and Form S-3 (File No.
333-94735). Pursuant to Rule 436(c) under the Securities Act of
1933, this report should not be considered a part of the
registration statements prepared or certified by us within the
meaning of Sections 7 and 11 of that Act.
PricewaterhouseCoopers LLP
Boston, Massachusetts
November 13, 2000
Exhibit 99.1
Report of Independent Accountants
To the Board of Trustees and Shareholders:
We have reviewed the accompanying condensed consolidated balance
sheet of NSTAR and its subsidiaries as of September 30, 2000 and
the related condensed consolidated statements of income,
comprehensive income and retained earnings for each of the three-
month and nine-month periods ended September 30, 2000 and
September 30, 1999 and the condensed consolidated statement of
cash flows for the nine-month periods ended September 30, 2000
and September 30, 1999. These financial statements are the
responsibility of the Company's management.
We conducted our review in accordance with standards established
by the American Institute of Certified Public Accountants. A
review of interim financial information consists principally of
applying analytical procedures to financial data and making
inquiries of persons responsible for financial and accounting
matters. It is substantially less in scope than an audit
conducted in accordance with generally accepted auditing
standards, the objective of which is the expression of an opinion
regarding the financial statements taken as a whole.
Accordingly, we do not express such an opinion.
Based on our review, we are not aware of any material
modifications that should be made to the accompanying condensed
consolidated interim financial statements for them to be in
conformity with accounting principles generally accepted in the
United States of America.
We previously audited in accordance with auditing standards
generally accepted in the United States of America, the
consolidated balance sheet as of December 31, 1999, and the
related consolidated statements of income, comprehensive income,
retained earnings and cash flows for the year then ended (not
presented herein), and in our report dated January 26, 2000 we
expressed an unqualified opinion on those consolidated financial
statements. In our opinion, the information set forth in the
accompanying condensed consolidated balance sheet as of December
31, 1999, is fairly stated in all material respects in relation
to the consolidated balance sheet from which it has been derived.
PricewaterhouseCoopers LLP
Boston, Massachusetts
November 13, 2000