<PAGE> 1
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, 1998
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
BEC ENERGY
(Exact name of registrant as specified in its charter)
Massachusetts 04-6830187
- ------------- ----------
(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: 1-888-423-2364
--------------
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 September 30, 1998
- ----- ---------------------------------
Common Shares, $1 par value 47,184,073 shares
<PAGE> 2
Part I - Financial Information
Item 1. Financial Statements
- -----------------------------
<TABLE>
BEC Energy
Consolidated Statements of Income
(Unaudited)
(in thousands, except per share amounts)
<CAPTION>
Three Months Nine Months
Ended September 30, Ended September 30,
1998 1997 1998 1997
-------- -------- ---------- ----------
<S> <C> <C> <C> <C>
Operating revenues $476,459 $520,414 $1,257,001 $1,370,104
-------- -------- ---------- ----------
Operating expenses:
Energy supply 191,197 202,991 522,262 607,150
Operations and maintenance 88,610 103,569 272,908 301,321
Depreciation and amortization 22,394 29,089 69,519 71,273
Demand side management and
renewable energy programs 10,102 7,463 27,144 21,560
Taxes - property and other 15,312 24,808 62,684 76,963
Income taxes 48,797 45,821 88,487 78,395
-------- -------- ---------- ----------
Total operating expenses 376,412 413,741 1,043,004 1,156,662
-------- -------- ---------- ----------
Operating income 100,047 106,673 213,997 213,442
Other income (expense), net (4,809) 1,697 (10,392) 3,508
-------- -------- ---------- ----------
Operating and other income 95,238 108,370 203,605 216,950
-------- -------- ---------- ----------
Interest charges:
Long-term debt 19,457 23,049 63,489 69,436
Other 701 4,174 8,420 12,129
Allowance for borrowed funds
used during construction (410) (271) (975) (949)
-------- -------- ---------- ----------
Total interest charges 19,748 26,952 70,934 80,616
-------- -------- ---------- ----------
Net income 75,490 81,418 132,671 136,334
Preferred dividends of subsidiary 1,486 2,919 7,275 10,230
-------- -------- ---------- ----------
Earnings available for common
shareholders $ 74,004 $ 78,499 $ 125,396 $ 126,104
======== ======== ========== ==========
Weighted average common shares
outstanding:
basic 47,691 48,515 48,239 48,515
====== ====== ====== ======
diluted 47,859 48,572 48,387 48,538
====== ====== ====== ======
Earnings per common share:
basic $1.55 $1.62 $2.60 $2.60
===== ===== ===== =====
diluted $1.55 $1.62 $2.59 $2.60
===== ===== ===== =====
Dividends declared per common
share $0.47 $0.47 $1.41 $1.41
===== ===== ===== =====
</TABLE>
The accompanying notes are an integral part of the consolidated financial
statements.
<PAGE> 3
<TABLE>
BEC Energy
Consolidated Balance Sheets
(Unaudited)
(in thousands)
<CAPTION>
September 30, December 31,
1998 1997
------------- ------------
<S> <C> <C>
Assets
- ------
Utility plant in service, at original cost $2,689,406 $4,451,134
Less: accumulated depreciation 903,432 1,712,903
---------- ----------
1,785,974 2,738,231
Generation-related regulatory asset, net 374,095 0
Nuclear fuel, net 60,049 67,935
Construction work in progress 43,812 33,292
---------- ----------
Net utility plant 2,263,930 2,839,458
Non-utility property 19,543 14,669
Nuclear decommissioning trust 168,990 151,634
Equity investments 80,975 35,455
Other investments 8,109 7,107
Current assets:
Cash and cash equivalents 146,845 4,140
Accounts receivable 255,752 207,093
Accrued unbilled revenues 21,736 30,048
Fuel, materials and supplies,
at average cost 17,198 60,834
Prepaid expenses and other 67,364 31,283
---------- ----------
Total current assets 508,895 333,398
---------- ----------
Other regulatory assets:
Power contracts 62,534 71,445
Income taxes, net 51,876 51,096
Redemption premiums 24,016 27,019
Postretirement benefits costs 21,804 22,441
Other 1,045 23,369
---------- ----------
Total regulatory assets 161,275 195,370
Other deferred debits 29,456 45,256
---------- ----------
Total assets $3,241,173 $3,622,347
========== ==========
</TABLE>
The accompanying notes are an integral part of the consolidated financial
statements.
<PAGE> 4
<TABLE>
BEC Energy
Consolidated Balance Sheets
(Unaudited)
(in thousands)
<CAPTION>
September 30, December 31,
1998 1997
------------- ------------
<S> <C> <C>
Capitalization and Liabilities
- ------------------------------
Common equity:
Common shares and premium $ 691,393 $ 744,652
Retained earnings 378,696 328,802
---------- ----------
Total common equity 1,070,089 1,073,454
---------- ----------
Cumulative preferred stock of subsidiary:
Nonmandatory redeemable series 43,000 83,000
Mandatory redeemable series 48,980 78,093
---------- ----------
Total preferred stock 91,980 161,093
---------- ----------
Long-term debt 955,638 1,057,076
---------- ----------
Total capitalization 2,117,707 2,291,623
---------- ----------
Current liabilities:
Long-term debt/preferred stock
due within one year 1,067 102,667
Notes payable 60,000 137,013
Accounts payable 103,888 87,015
Transition contract payable 31,223 0
Taxes payable 33,628 (630)
Accrued interest 12,198 24,289
Dividends payable 23,170 24,748
Other 154,089 128,691
---------- ----------
Total current liabilities 419,263 503,793
---------- ----------
Deferred credits:
Accumulated deferred income taxes 351,204 485,738
Accumulated deferred investment tax credits 46,714 60,736
Nuclear decommissioning liability 172,423 155,182
Power contracts 62,534 71,445
Other 71,328 53,830
---------- ----------
Total deferred credits 704,203 826,931
Commitments and contingencies __________ __________
Total capitalization and liabilities $3,241,173 $3,622,347
========== ==========
</TABLE>
The accompanying notes are an integral part of the consolidated financial
statements.
<PAGE> 5
<TABLE>
BEC Energy
Consolidated Statements of Cash Flows
(Unaudited)
(in thousands)
<CAPTION>
Nine Months Ended September 30,
1998 1997
--------- ---------
<S> <C> <C>
Operating activities:
Net income $ 132,671 $ 136,334
Adjustments to reconcile net income to net
cash provided by operating activities:
Depreciation and amortization 178,051 170,395
Deferred income taxes and investment
tax credits (149,710) (21,707)
Allowance for borrowed funds used during
construction (975) (949)
Net changes in:
Accounts receivable and accrued
unbilled revenues (40,347) 3,704
Fuel, materials and supplies 27,819 (172)
Transition contract and other
accounts payable 48,096 (45,242)
Other current assets and liabilities 9,906 27,841
Other, net 25,018 (4,590)
--------- ---------
Net cash provided by operating activities 230,529 265,614
--------- ---------
Investing activities:
Plant expenditures (excluding AFUDC) (67,443) (90,900)
Proceeds from sale of fossil assets 533,633 0
Nuclear fuel expenditures (11,141) (2,811)
Investments (62,876) (28,711)
--------- ---------
Net cash provided by (used in) investing
activities 392,173 (122,422)
--------- ---------
Financing activities:
Issuances/(repurchases)
Common shares (53,285) 144
Long-term debt 0 100,000
Redemptions:
Preferred stock (71,519) (44,000)
Long-term debt (201,600) (101,600)
Net change in notes payable (77,013) (17,164)
Dividends paid (76,580) (79,234)
--------- ---------
Net cash used in financing activities (479,997) (141,854)
--------- ---------
Net increase in cash and cash equivalents 142,705 1,338
Cash and cash equivalents at beginning of year 4,140 5,651
--------- ---------
Cash and cash equivalents at end of period $ 146,845 $ 6,989
========= =========
Supplemental disclosures of cash flow
information:
Cash paid during the period for:
Interest, net of amounts capitalized $ 79,660 $ 87,916
========= =========
Income taxes $ 182,258 $ 59,289
========= =========
</TABLE>
The accompanying notes are an integral part of the consolidated financial
statements.
<PAGE> 6
Notes to Unaudited Consolidated Financial Statement
- ---------------------------------------------------
A) Basis of Presentation
---------------------
Boston Edison Company (Boston Edison) received final approval of its
reorganization plan to form a holding company structure from the Securities
and Exchange Commission on May 20, 1998. Effective May 20 the holding
company, BEC Energy (BEC), was formed with Boston Edison as a wholly owned
subsidiary of BEC. Under the new holding company structure the owners of
Boston Edison's common stock became BEC common shareholders. Existing debt
and preferred stock of Boston Edison remained obligations of the regulated
utility business. Effective June 25, 1998, Boston Energy Technology Group
(BETG) ceased being a subsidiary of Boston Edison and became a wholly owned
subsidiary of BEC. The accompanying consolidated financial statements reflect
the results of operations and cash flows of Boston Edison prior to the
reorganization. The consolidated balance sheet at December 31, 1997 reflects
the financial position of Boston Edison which also included BETG.
The accompanying unaudited consolidated financial statements should be read in
conjunction with the Boston Edison 1997 Annual Report on Form 10-K and Form
10-Q for the period ended March 31, 1998 and the BEC Form 10-Q for the period
ended June 30, 1998. The financial information presented as of September 30
has been prepared from BEC's books and records without audit by independent
accountants. Financial information as of December 31 has been derived from
the audited financial statements of Boston Edison, but does not include all
disclosures required by generally accepted accounting principles (GAAP). In
the opinion of BEC'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.
Under the Boston Edison restructuring settlement agreement, which was approved
by the Massachusetts Department of Telecommunications and Energy (DTE),
approximately 75% of the net assets of Pilgrim Nuclear Power Station are
recoverable through a non-bypassable transition charge of the utility's
distribution business. The distribution business continues to be subject to
rate-regulation. The remaining 25% is collected under Pilgrim's wholesale
power contracts with other utilities and municipalities. Consistent with the
guidance from accounting authoritative bodies regarding any impaired portion
of utility plant assets identified for recovery in a legislative/rate order,
the 1998 consolidated balance sheet reflects a reclassification of the Pilgrim
net assets recoverable through the transition charge from utility plant to
regulatory asset. This Pilgrim regulatory asset, included in the generation-
related regulatory asset on the consolidated balance sheet at September 30,
1998, continues to be grouped with utility plant for financial statement
presentation. Refer to Note C of Item 8 in the Boston Edison 1997 Annual
Report on Form 10-K for more information on the accounting implications of the
electric utility industry restructuring and the utility's related settlement
agreement.
Finalization of the sale of Boston Edison's fossil generating assets to Sithe
Energies took place on May 15, 1998. Boston Edison received proceeds from the
sale of $655 million, including $121 million for a six-month transitional
<PAGE 7)
power purchase contract. The amount received above net book value on the sale
of these assets will be returned to Boston Edison's customers over the
settlement period. That amount is partially offset by certain costs
recoverable through the transition charge due to the support of standard offer
service provided by Boston Edison's fossil generating assets prior to the
fossil divestiture. The net deferred gain is included as a reduction to the
generation-related regulatory asset on the consolidated balance sheet at
September 30, 1998. In addition, Boston Edison received $19 million from
Sithe for inventory and other closing adjustments.
Under the terms of Boston Edison's settlement agreement, generation and
purchased power costs are recovered from customers. The settlement agreement
allows for the deferral of the difference between these costs and the amounts
billed to customers with a return for future recovery. The net
undercollection from the settlement recovery mechanisms at September 30, 1998
was more than offset by an overrecovery of approximately $36 million from the
fuel and purchased power clause and is included in other regulatory assets on
the consolidated balance sheet. The fuel and purchased power clause ceased on
March 1, 1998. The inclusion of the over recovered fuel and purchased power
clause costs as an offset to the settlement recovery mechanisms is consistent
with Boston Edison's proposal made to the DTE. Generation and purchased power
costs recoverable under the settlement agreement have been separately
reflected as energy supply expenses on the consolidated statements of income.
These costs include retail generation-related depreciation and amortization,
decommissioning and other operating costs recovered through the transition
charge. The corresponding 1997 expenses have been reclassified for
comparability.
The preparation of financial statements in conformity with GAAP requires BEC
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 three and nine-month periods ended
September 30, 1998 and 1997 are not indicative of the results which 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.
B) Nature of Operations
--------------------
Within the newly restructured electric utility industry, BEC has announced its
intention to focus its utility operations on the transmission and distribution
of energy. In April 1998, Boston Edison began soliciting expressions of
interest for the sale of Pilgrim Nuclear Power Station as part of the
previously announced strategy to exit the generation business. Final bids for
the purchase of Pilgrim were received on October 16, 1998. Boston Edison is
currently evaluating those bids and anticipates signing a purchase and sale
agreement by year-end 1998. Boston Edison provides standard offer service to
all customers of record as of the retail access date, March 1, 1998. Default
service is provided to customers who are not eligible for standard offer
service or who elect to not contract with a competitive energy supplier. As
<PAGE> 8
of September 30, 1998, 90% of customers are receiving standard offer service,
while 10% are receiving default service. No customers are receiving
generation service from competitive suppliers. Boston Edison delivers
electricity at retail to an area of 590 square miles, including the City of
Boston and 39 surrounding cities and towns. It also supplies electricity at
wholesale for resale to other utilities and municipal electric departments.
Boston Edison is required to continue to develop and implement electric demand
side management programs as well as to provide funding for renewable energy
projects pursuant to the Massachusetts electric industry restructuring
legislation enacted in November 1997. In addition, BEC conducts unregulated
activities through its unregulated subsidiaries. Refer to Note A of Item 8 in
the Boston Edison 1997 Annual Report on Form 10-K for information regarding
BEC's telecommunications joint venture.
C) Contingencies
-------------
1. Hazardous Waste
Boston Edison is an owner or operator of approximately 20 properties where oil
or hazardous materials were spilled or released. As such, Boston Edison is
required to clean up these remaining properties in accordance with a timetable
developed by the Massachusetts Department of Environmental Protection. There
are uncertainties associated with these costs due to the complexities of
cleanup technology, regulatory requirements and the particular characteristics
of the different sites. Boston Edison continues to evaluate the cleanup costs
of these sites. It also faces possible liability as a potentially responsible
party in the cleanup of five 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. Boston Edison is one
of many potentially responsible parties and currently expects to have only a
small percentage of the total potential liability for these sites. Through
September 30, 1998, BEC had approximately $6 million accrued on its
consolidated balance sheet related to these cleanup liabilities. Management
is unable to fully determine a range of reasonably possible cleanup costs in
excess of the accrued amount, however based on its assessments of the specific
site circumstances, it does not believe that it is probable that any such
additional costs will have a material impact on its 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.
2. Generating Unit Performance Program
Boston Edison's generating unit performance program ceased March 1, 1998.
Under this program the recovery of incremental purchased power costs resulting
from generating unit outages prior to March 1, 1998 are subject to regulatory
review. Proceedings relative to generating unit performance remain pending
before the DTE. Management is unable to fully determine a range of reasonably
possible disallowance costs in excess of amounts accrued, however based on its
assessments of the information currently available, it does not believe that
it is probable that any such additional costs will have a material impact on
its consolidated financial position. However, it is reasonably possible that
additional disallowance 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.
<PAGE> 9
3. Connecticut Yankee
Boston Edison is a 9.5% equity investor and power purchaser of Connecticut
Yankee Atomic Power Company (CYAPC). The investment in CYAPC at September 30,
1998 is approximately $10 million and is included in equity investments on the
consolidated balance sheet. In December 1996, the Board of Directors of
CYAPC, which owns and operates the Connecticut Yankee nuclear electric
generating unit, unanimously voted to retire the unit. The decision was based
on an economic analysis of the costs of operating the unit through 2007, the
period of the operating license, compared to the costs of closing the unit and
incurring replacement power costs for the same period.
In December 1996, CYAPC filed for rate relief at the Federal Energy Regulatory
Commission (FERC) seeking to recover certain post-operating costs, including
decommissioning. On August 31, 1998, the FERC Administrative Law Judge (ALJ)
released an initial decision regarding CYAPC's filing. This decision called
for the disallowance of the common equity return on the CYAPC investment
subsequent to the shutdown. The decision also stated that decommissioning
collections should continue to be based on a previously approved estimate,
with an adjustment for inflation, until a more reliable estimate is developed.
In October 1998, both CYAPC and Northeast Utilities, a 49% equity investor in
CYAPC, filed briefs on exceptions to the ALJ decision. If the initial
decision is upheld, CYAPC could be required to write off a portion of its
investment in the generating unit and refund a portion of the previously
collected return on investment. Management is currently unable to determine
the ultimate outcome of this proceeding, however, the estimate of the effect
of the ALJ's initial decision does not have a material impact on its
consolidated financial position or results of operations.
4. Industry and Corporate Restructuring Legal Proceedings/Referendum Campaign
The DTE order approving the Boston Edison settlement agreement and the DTE
order approving the formation of BEC as a holding company have been appealed
by certain parties to the Massachusetts Supreme Judicial Court. In addition,
along with other Massachusetts investor-owned utilities, Boston Edison has
been named as a defendant in a class action suit seeking to declare certain
provisions of the Massachusetts electric industry restructuring legislation
unconstitutional. Management is currently unable to determine the outcome of
these proceedings or the impact the proceedings may have on its consolidated
financial position or results of operations.
A referendum seeking repeal of the Massachusetts electric industry
restructuring legislation that was enacted in November 1997 was overwhelmingly
defeated by a better than 70% to 30% margin in a state-wide general election
held on November 3, 1998. This outcome allows the comprehensive framework
established for the restructuring of the electric industry to continue as
intended under the enacted legislation.
5. Regulatory Proceeding
In October 1997, the DTE opened a proceeding to investigate Boston Edison's
compliance with the 1993 order which permitted the formation of BETG and
authorized Boston Edison to invest up to $45 million in unregulated
activities. The DTE has scheduled hearings on this matter for the fourth
<PAGE> 10
quarter. Management is currently unable to determine the outcome of this
proceeding or the impact the proceeding may have on its consolidated financial
position or results of operations.
6. Plymouth Lawsuit
In October 1998, the town of Plymouth, Massachusetts, the site of Pilgrim
Nuclear Power Station, filed suit against Boston Edison. The town claims that
Boston Edison has wrongfully failed to execute an agreement with the town for
payments in addition to taxes due to the town under the recently enacted
Massachusetts electric industry restructuring legislation. Boston Edison has
disputed the town's claim and will vigorously defend itself. Management is
unable to determine the ultimate outcome of this action or the impact it may
have on its consolidated financial position or results of operations.
7. Litigation
In the normal course of its business BEC and its subsidiaries are also
involved in certain other legal matters. Management is unable to fully
determine a range of reasonably possible legal costs in excess of amounts
accrued, however based on the information currently available, it does not
believe that it is probable that any such additional costs will have a
material impact on its consolidated financial position. However, it is
reasonably possible that additional legal 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.
D) Income Taxes
The following table reconciles the statutory federal income tax rate to the
annual estimated effective income tax rate for 1998 and the actual effective
income tax rate for 1997.
<TABLE>
<CAPTION>
1998 1997
---- ----
<S> <C> <C>
Statutory tax rate 35.0% 35.0%
State income tax, net of federal income
tax benefit 5.1 4.5
Investment tax credit amortization (6.8) (3.3)
Other 0.8 0.1
---- ----
Effective tax rate 34.1% 36.3%
==== ====
</TABLE>
The estimate of the 1998 effective tax rate declined by 5% as a result of the
recognition in net income of the remaining unamortized investment tax credits
related to Boston Edison's fossil generating assets at the time of their sale.
This shareholder benefit is included in other expense, net in the consolidated
statement of income for the nine-month period ended September 30, 1998.
E) Financing Activity
------------------
On May 15, 1998, Boston Edison closed the sale of its fossil generating assets
and received total proceeds of $674 million in cash. $202 million of these
funds were used to retire short-term debt securities. BEC borrowed $60
million under its $225 million revolving credit agreement in the third
<PAGE> 11
quarter. The outstanding amount under the credit agreement is reflected as
notes payable on the September 30, 1998 consolidated balance sheet.
In June 1998, Boston Edison's $100 million 6.662% outstanding bank loan was
redeemed. Boston Edison also redeemed $2 million of mandatory and $2 million
of the optional 7.27% sinking fund series preferred stock in May 1998. In
March 1998, $100 million of 5.95% debentures matured.
In July 1998, Boston Edison redeemed the remaining $32 million 7.27% sinking
fund series preferred stock along with the $40 million 7.75% series preferred
stock.
As of September 30, 1998, BEC has repurchased 1.3 million shares under its
previously announced common share repurchase program.
F) Earnings Per Common Share
-------------------------
The following table summarizes the reconciling amounts between basic and
diluted earnings per share (EPS) computations.
<TABLE>
(in thousands, except per share amounts)
<CAPTION>
Three months Nine months
Ended September 30, Ended September 30,
1998 1997 1998 1997
------- ------- -------- --------
<S> <C> <C> <C> <C>
Net income $75,490 $81,418 $132,671 $136,334
Less: preferred dividends of
subsidiary 1,486 2,919 7,275 10,230
------- ------- -------- --------
Earnings available for common
shareholders $74,004 $78,499 $125,396 $126,104
Basic EPS $1.55 $1.62 $2.60 $2.60
Diluted EPS $1.55 $1.62 $2.59 $2.60
Weighted average common shares
outstanding for basic EPS 47,691 48,515 48,239 48,515
Effect of dilutive securities:
Weighted average potential common
shares related to share-based
compensation 168 57 148 23
Weighted average common shares
outstanding for diluted EPS 47,859 48,572 48,387 48,538
</TABLE>
G) Nuclear Decommissioning
-----------------------
An update of Pilgrim Nuclear Power Station's decommissioning cost study was
filed with the DTE in November 1998. The updated study includes an estimate
<PAGE> 12
of decommissioning and fuel storage costs of approximately $600 million in
1997 dollars.
Item 2. Management's Discussion and Analysis
- ---------------------------------------------
Results of Operations - Three Months Ended September 30, 1998 vs. Three Months
- ------------------------------------------------------------------------------
Ended September 30, 1997
- ------------------------
Earnings per common share for the three months ended September 30, 1998 were
$1.55 as compared to $1.62 for the same period in 1997. The decrease reflects
the effect of the mandated 10% retail rate reduction which became effective as
of March 1, 1998 under the Massachusetts Electric Utility Restructuring Law.
In addition, unregulated subsidiary losses were higher in 1998. These
negative impacts were partially offset by a decrease in operations and
maintenance expense resulting from the fossil divestiture in May 1998 along
with continued cost control efforts.
The results of operations for the quarter are not indicative of the results
which may be expected for the entire year due to the seasonality of kilowatt-
hour (kWh) sales and revenues. Refer to Note A to the Consolidated Financial
Statements.
Operating revenues
Operating revenues decreased 8.4% during the third quarter of 1998 as follows:
<TABLE>
<CAPTION>
(in thousands)
- ------------------------------------------------------
<S> <C>
Retail electric revenues $(37,519)
Wholesale revenues (818)
Short-term sales and other revenues (5,618)
- ------------------------------------------------------
Decrease in operating revenues $(43,955)
======================================================
</TABLE>
Retail electric revenues decreased due to the 10% retail rate reduction
effective for electricity usage as of March 1, 1998. The decrease from the
rate reduction was partially offset by a 6.1% increase in kWh sales for the
quarter. The increase in kWh sales was due to warmer summer temperatures and
continued strong economic conditions in the Boston area.
Operating expenses
Energy supply expense includes fuel and purchased power, retail generation-
related depreciation and amortization, decommissioning and other operating
costs recovered through the transition charge. Energy supply expense
decreased approximately $12 million. Total fuel and purchased power expenses
decreased approximately $18 million. This decrease reflects lower company
fuel costs and the timing effect of the fuel and purchased power and standard
offer cost collection mechanisms. Lower fuel costs in the third quarter
reflect the first full reporting period since the sale of Boston Edison's
fossil generating assets to Sithe Energies in May 1998. This decrease was
partially offset by higher purchased power costs that include a six-month
transitional power purchase contract with Sithe that began in May. Boston
Edison received $121 million from Sithe to enter into the transition contract.
The capacity portion of the Sithe purchased power costs is offset by the
<PAGE> 13
recognition of the payment from Sithe and, therefore, has no net effect on
earnings.
Operations and maintenance expense decreased $15 million. The decrease is
primarily due to the impact of the fossil divestiture.
The decrease in depreciation and amortization expense is due to an $8.7
million nonrecurring charge to depreciation expense in the third quarter of
1997 to reflect the removal of specific nuclear-related intangible assets from
the balance sheet. This was partially offset by an increase in the composite
distribution depreciation rate effective March 1, 1998 in accordance with the
settlement agreement.
The increase in demand side management (DSM) and renewable energy programs
reflects an increase in the required spending for DSM programs in 1998. In
addition, the renewable energy programs expense is the result of a new state
mandate for the funding of renewable energy that became effective March 1,
1998. Renewable energy expenses are collected through distribution revenues
and, therefore, have no net effect on earnings.
The decrease in property and other taxes is due to a decrease in municipal
property taxes as a result of the divestiture of the fossil generating
stations in May 1998.
Other income (expense), net
Other income in the third quarter of 1997 includes interest income from the
favorable outcome of an IRS appeal related to investment tax credits. Also
impacting the comparison of 1998 to 1997 are higher unregulated subsidiary
losses in 1998.
Interest charges
Interest charges on long-term debt decreased due to the maturing of $100
million of 5.95% debentures in March 1998 and the cessation of amortization of
the associated redemption premiums along with the redemption of a $100 million
6.662% bank loan in June 1998.
Interest charges on short-term debt decreased due to the redemption of Boston
Edison's outstanding short-term debt with the fossil divestiture proceeds.
Preferred stock dividends
Preferred stock dividends decreased as a result of the redemption of 40,000
shares of 7.27% series cumulative preferred stock in May 1998, the remaining
320,000 shares of the 7.27% series in July 1998 and 400,000 shares of 7.75%
series cumulative preferred stock in July 1998.
Results of Operations - Nine Months Ended September 30, 1998 vs. Nine Months
- ----------------------------------------------------------------------------
Ended September 30, 1997
- ------------------------
Earnings per common share for the nine months ended September 30, 1998 and
September 30, 1997 were $2.60. Earnings in 1998 were positively impacted by
decreases in operations and maintenance expense, municipal property taxes and
<PAGE> 14
interest expense resulting from the fossil divestiture in May 1998. Warmer
summer weather and the continued strong local economy also had a positive
impact on earnings. These positive impacts were offset by the rate reduction
mandated under Boston Edison's settlement agreement and an increase in
unregulated subsidiary losses.
The results of operations for the nine months ended September 30, 1998 are not
indicative of the results which may be expected for the entire year due to the
seasonality of kWh sales and revenues. Refer to Note A to the Consolidated
Financial Statements.
Operating revenues
Operating revenues decreased 8.3% during the first nine months of 1998 as
follows:
<TABLE>
<CAPTION>
(in thousands)
- --------------------------------------------------------
<S> <C>
Retail electric revenues $(107,512)
Wholesale revenues (3,545)
Short-term sales and other revenues (2,046)
- --------------------------------------------------------
Decrease in operating revenues $(113,103)
========================================================
</TABLE>
Retail electric revenues decreased partly due to the timing effect of fuel and
purchased power cost recovery. Prior to its cessation as of March 1, 1998,
the fuel clause charge was lower than the prior year as the 1997 charge
reflected the recovery of substantial prior period undercollections. Fuel
clause revenues were offset by fuel and purchased power expenses and,
therefore, had no net effect on earnings. Retail electric revenues also
reflect the impact of the mandated 10% retail rate reduction. The rate
reduction partially offset the impact of the 2.7% increase in kWh sales in
1998. Warmer than usual summer weather and the strong economic conditions in
1998 offset the negative impacts from the mild winter weather.
Operating expenses
Energy supply expense includes fuel and purchased power, retail generation-
related depreciation and amortization, decommissioning and other operating
costs recovered through the transition charge. Energy supply expense
decreased approximately $85 million. Total fuel and purchased power expenses
decreased approximately $93 million. The decrease in company fuel costs
resulting from the fossil divestiture in May 1998 was significantly offset by
an increase in purchased power subsequent to the divestiture. Purchased power
costs include the six-month transitional power purchase contract with Sithe
Energies that began in May. As the capacity portion of the Sithe purchased
power costs is offset by the recognition of the payment from Sithe, those
costs have no net effect on earnings. The timing effect of the fuel and
purchased power and standard offer cost collection mechanisms also contributed
to the decrease.
Operations and maintenance expense decreased approximately $28 million. The
decrease reflects lower employee benefits costs, lower nuclear spending and
the impact of the fossil divestiture. The comparison of 1998 and 1997 is also
positively impacted by the April 1997 Boston area storm.
<PAGE> 15
The decrease in depreciation and amortization expense is due to the $8.7
million nonrecurring charge in the third quarter of 1997 as discussed in the
results of operations for the third quarter. This was partially offset by the
increase in the composite distribution depreciation rate in accordance with
the settlement agreement.
As discussed in the results of operations for the third quarter, the increase
in DSM and renewable energy programs expense reflects an increase in the
required spending for DSM programs in 1998. In addition, the renewable energy
programs expense is the result of a new state mandate for the funding of
renewable energy that became effective March 1, 1998. Renewable energy
expenses are collected through distribution revenues and, therefore, have no
net effect on earnings.
The decrease in property and other taxes is due to the decrease in municipal
property taxes resulting from the fossil divestiture.
Other income (expense), net
The increase in other expense, net reflects certain costs related to the
fossil divestiture, net of the related tax benefits, including the recognition
of previously deferred investment tax credits associated with the fossil
generating stations. Also negatively impacting the comparison of 1998 to 1997
is the interest income from the favorable outcome of an IRS appeal related to
investment tax credits received in the third quarter of 1997. In addition,
unregulated subsidiary losses were higher in 1998 as BETG's telecommunications
joint venture with RCN began operations in the second quarter of 1997.
Interest charges
Interest charges on long-term debt decreased due to the maturing of $100
million of 5.70% debentures in March 1997, $100 million of 5.95% debentures in
March 1998 and the cessation of amortization of the associated redemption
premiums along with the redemption of a $100 million 6.662% bank loan in June
1998.
Interest charges on short-term debt decreased due to the redemption of Boston
Edison's outstanding short-term debt with proceeds from the fossil
divestiture.
Preferred stock dividends
Preferred stock dividends decreased as a result of Boston Edison's redemption
of 40,000 shares of 7.27% series cumulative preferred stock in May 1998 and
1997, the remaining 320,000 shares of the 7.27% series and 400,000 shares of
7.75% series cumulative preferred stock in July 1998 and 400,000 shares of
8.25% series in June 1997.
Electric Revenues
- -----------------
Effective March 1, 1998, the retail access date, Boston Edison's electric
delivery business provides its standard offer customers service at rates
designed to give 10% savings from rates previously in effect. These customers
will realize an additional 5% average savings, after an adjustment for
<PAGE> 16
inflation, by September 1, 1999. The cost of providing standard offer
service, which includes fuel and purchased power costs, is recovered from
customers on a fully reconciling basis. New retail customers in the Boston
Edison service territory and previously existing customers that are no longer
eligible for the standard offer due to choosing a competitive supplier are on
default service. The price of default service is based on the average
competitive market price for power. Refer also to the Electric Revenues
section of Item 7 of the Boston Edison 1997 Annual Report on Form 10-K.
As part of the restructuring settlement agreement, the annual performance
adjustment charge ceased and the cost recovery mechanism for Pilgrim Station
changed effective March 1, 1998. Approximately 25% of the operations and
capital costs, including a return on investment, continues to be collected
under wholesale contracts with other utilities and municipalities. Refer to
the Electric Revenues section of Item 7 of the Boston Edison 1997 Annual
Report on Form 10-K for a description of Pilgrim's new cost recovery
mechanism.
The rates of Boston Edison's distribution business will remain unchanged,
subject to a minimum and maximum return on average common equity (ROE) until
December 31, 2000. Refer to the Electric Revenues section of Item 7 of the
Boston Edison 1997 Annual Report on Form 10-K for detail regarding the minimum
and maximum ROE. Under the Boston Edison settlement agreement, the cost of
providing transmission service to distribution customers is recovered on a
fully reconciling basis.
Liquidity
- ---------
On June 25, 1998, BETG's outstanding line of credit of $35 million was paid in
full. On July 9, 1998, BEC established a $225 million revolving credit
agreement effective through July 2001. BEC borrowed $60 million under this
credit agreement in the third quarter in the form of short-term debt. These
funds are used to provide financing to the holding company for general
purposes, invest in its subsidiaries and fund the share repurchase program.
Boston Edison supplements internally generated funds as needed, primarily
through the issuance of short-term commercial paper and bank borrowings.
Boston Edison has authority from the Federal Energy Regulatory Commission to
issue up to $350 million of short-term debt in addition to a $200 million
revolving credit agreement and arrangements with several banks to provide
additional short-term credit on an uncommitted and as available basis. It
also has authority to issue up to $220 million of equity and long-term debt
securities under its approved long-term financing plan with the DTE which is
available through 1998. Proceeds from issuances under this plan are to be
used to refinance short and long-term securities and to fund capital
expenditures.
In April 1998, Boston Edison announced a common share repurchase program under
which it would repurchase up to four million of its common shares. BEC has
assumed this program since the reorganization to a holding company structure.
As of September 30, 1.3 million shares have been repurchased. Under this
program, shares are repurchased through open market, block or privately-
negotiated transactions, or a combination. The timing and actual number of
shares repurchased will be impacted by market conditions.
<PAGE> 17
Year 2000 Computer Issue
- ------------------------
The year 2000 issue is the result of computer programs that were written using
two digits rather than four to define an applicable year. If computer
programs with date-sensitive functions are not year 2000 compliant, they may
recognize a date using "00" as the year 1900 rather than the year 2000. This
could result in system failures or miscalculations causing disruptions of
operations, including, among other things, a temporary inability to process
transactions and engage in other normal business activities. BEC has a year
2000 program in place that is addressing the risk of non-compliant internal
business software, internal non-business software and embedded chip technology
and external noncompliance of third parties.
BEC's plan to address the year 2000 issue includes modification of certain
applications and replacement of systems that are not year 2000 compliant. The
cost associated with year 2000 compliance will be expensed as incurred. In
addition, a decision has been made to use this opportunity to upgrade some of
BEC's less efficient centralized business systems. Replacement costs
associated with these systems will be capitalized and amortized over future
periods. Management estimates that it will expend approximately $30 million
on these system modifications and upgrades. For each system designated as
"critical" (defined as being necessary to safely provide a reliable flow of
electricity), BEC's year 2000 program requires system testing and a
contingency plan to be developed.
As part of the year 2000 program, significant suppliers, service providers and
other vendors were contacted to determine year 2000 readiness. Many third
parties have noted that they are already year 2000 compliant or in the process
of becoming compliant. In addition to the risk faced from its dependence on
other third party suppliers, BEC has a risk that power will not be available
from the New England Power Pool (NEPOOL) for purchase and distribution to
Boston Edison's customers. Should NEPOOL fail to resolve its year 2000 issues
as planned, there would be an adverse impact to Boston Edison. To mitigate
this risk, efforts are being coordinated with NEPOOL to establish inter-
utility testing guidelines to determine year 2000 readiness. Boston Edison is
also a participant in the NEPOOL/ISO New England Year 2000 Joint Oversight
Committee which has been given responsibility for the operational reliability
of NEPOOL.
The year 2000 program remains on schedule with anticipated completion in the
third quarter of 1999. However, management believes it is not possible to
determine with complete certainty that all potential year 2000 problems have
been identified or will be corrected due to the complexity and pervasiveness
of the issue. In the event that compliance is not completed as anticipated,
it is reasonably possible that the year 2000 issue could have an adverse
effect on operations.
New Accounting Standards
- ------------------------
In 1997, the Financial Accounting Standards Board (FASB) issued Statement of
Financial Accounting Standards No. 131, Disclosures about Segments of an
Enterprise and Related Information (SFAS 131) which is effective in 1998.
This statement requires the reporting of certain additional information about
operating segments as applicable within an enterprise. SFAS 131 disclosure is
<PAGE> 18
not required for interim reporting in the initial year of application. BEC
will include the selected financial information and disclosures as required in
its 1998 Annual Report on Form 10-K and its future interim reports on Form 10-
Q as appropriate.
In June 1998, the FASB issued SFAS 133, Accounting for Derivative Instruments
and Hedging Activities which is effective in 2000. This statement requires
the recognition of all derivative instruments as either assets or liabilities
in the statement of financial position and the measurement of those
instruments at fair value. BEC does not expect this statement to have a
material impact on its consolidated financial position or results of
operations.
The Accounting Standards Executive Committee of the American Institute of
Certified Public Accountants issued Statement of Position 98-1, Accounting for
the Costs of Computer Software Developed or Obtained for Internal Use (SOP
98-1) in March 1998. SOP 98-1, effective in 1999, provides specific guidance
on whether to capitalize or expense costs within its scope. BEC does not
expect this SOP to have a material impact on its consolidated financial
position or results of operations.
Energy Marketing Joint Venture
- ------------------------------
In August 1998, BEC and Williams Energy Services Company (WESCO), a subsidiary
of The Williams Companies, entered into an agreement to sell BETG's 50%
interest in their joint venture, EnergyVision, to WESCO. This transaction did
not have a material impact on BEC's consolidated financial position or results
of operations.
Safe Harbor Cautionary Statement
- --------------------------------
BEC 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, 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. Refer also to the
safe harbor cautionary statements included in the Boston Edison 1997 Annual
Report on Form 10-K.
The preceding sections include certain forward-looking statements about
environmental and legal issues and year 2000.
The impacts of various environmental and legal issues 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 estimated cleanup liabilities. The
impacts of changes in available information and circumstances regarding legal
issues could affect the estimated litigation costs.
The timing and total costs related to the year 2000 plan could differ from
current expectations. Factors that may cause such differences include the
<PAGE> 19
ability to locate and correct all relevant computer codes and the availability
of personnel trained in this area. In addition, BEC cannot predict the nature
or impact on operations of third party noncompliance.
<PAGE> 20
Part II - Other Information
Item 5. Other Information
- --------------------------
Under recent changes to the Federal proxy rules, if a stockholder who wishes
to present a proposal at the 1999 Annual Meeting that will not be included in
the proxy statement fails to notify management by February 15, 1999, then the
proxies that management solicits for the 1999 Annual Meeting will include
discretionary authority to vote on the stockholder's proposal, if it is
properly brought before the meeting.
Paul A. La Camera, age 55, was elected as a Class II Trustee of BEC Energy and
member of the Audit, Finance and Risk Management Committee of the Board of
Trustees of BEC Energy, effective July 1, 1998. La Camera has been President
and General Manager of WCVB-TV Channel 5 since 1997. From 1994 to 1997 he was
Vice President and General Manager of the station.
Item 6. Exhibits and Reports on Form 8-K
- -----------------------------------------
a) Exhibits filed herewith:
Exhibit 15 - Letter Re Unaudited Interim Financial Information
15.1 - Report of Independent Accountants
Exhibit 27 - Financial Data Schedule
27.1 - Schedule UT
Exhibit 99 - Additional Exhibits
99.1 - Letter of Independent Accountants
Form S-3 Registration Statement filed by BEC Energy
on July 2, 1998 (File No. 33-59693); Form S-8
Registration Statements filed by BEC Energy on
June 17, 1998 (File Nos. 33-58457, 33-59662 and
33-59682) and June 29, 1998 (File No. 333-30975-99)
b) No Form 8-K was filed during the third quarter of 1998.
<PAGE> 21
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.
BEC ENERGY
------------
(Registrant)
Date: November 16, 1998 /s/ Robert J. Weafer, Jr.
------------------------------
Robert J. Weafer, Jr.
Vice President-Finance,
Controller, Assistant
Treasurer and Assistant
Clerk
<PAGE> 22
Exhibit 15.1
Report of Independent Accountants
To the Shareholders and Trustees
of BEC Energy
We have reviewed the accompanying consolidated balance sheet of BEC Energy
(BEC) as of September 30, 1998 and the related statements of income for the
three and nine-month periods ended September 30, 1998 and 1997 and cash flows
for the nine-month periods ended September 30, 1998 and 1997. These financial
statements are the responsibility of BEC'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 financial statements in order for them to
be in conformity with generally accepted accounting principles.
Boston, Massachusetts PricewaterhouseCoopers LLP
October 22, 1998
<PAGE> 23
Exhibit 99.1
Securities and Exchange Commission
450 Fifth Street, N.W.
Washington, D.C. 20549
Re: BEC Energy
Registration on
Forms S-3 and S-8
We are aware that our report dated October 22, 1998 on our review of the
interim financial information of BEC Energy (BEC) for the period ended
September 30, 1998 and included in this Form 10-Q is incorporated by reference
in BEC's registration statements on Form S-3 (File No. 33-59693) and on Form
S-8 (File Nos. 33-58457, 33-59662, 33-59682 and 333-30975-99). 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.
Boston, Massachusetts PricewaterhouseCoopers LLP
October 22, 1998
<TABLE> <S> <C>
<ARTICLE> UT
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 9-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-END> SEP-30-1998
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 2,263,930
<OTHER-PROPERTY-AND-INVEST> 277,617
<TOTAL-CURRENT-ASSETS> 508,895
<TOTAL-DEFERRED-CHARGES> 190,731
<OTHER-ASSETS> 0
<TOTAL-ASSETS> 3,241,173
<COMMON> 47,184
<CAPITAL-SURPLUS-PAID-IN> 644,209
<RETAINED-EARNINGS> 378,696
<TOTAL-COMMON-STOCKHOLDERS-EQ> 1,070,089
48,980
43,000
<LONG-TERM-DEBT-NET> 955,638
<SHORT-TERM-NOTES> 60,000
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 1,067
0
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 1,062,399
<TOT-CAPITALIZATION-AND-LIAB> 3,241,173
<GROSS-OPERATING-REVENUE> 1,257,001
<INCOME-TAX-EXPENSE> 88,487
<OTHER-OPERATING-EXPENSES> 954,517
<TOTAL-OPERATING-EXPENSES> 1,043,004
<OPERATING-INCOME-LOSS> 213,997
<OTHER-INCOME-NET> (10,392)
<INCOME-BEFORE-INTEREST-EXPEN> 203,605
<TOTAL-INTEREST-EXPENSE> 70,934
<NET-INCOME> 132,671
7,275
<EARNINGS-AVAILABLE-FOR-COMM> 125,396
<COMMON-STOCK-DIVIDENDS> 68,351
<TOTAL-INTEREST-ON-BONDS> 0
<CASH-FLOW-OPERATIONS> 230,529
<EPS-PRIMARY> 2.60
<EPS-DILUTED> 2.59
</TABLE>
