5
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 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...March 31, 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..................1-1401...................
.......................PECO Energy Company.......................
(Exact name of registrant as specified in its charter)
..........Pennsylvania................ 23-0970240................
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
....2301 Market Street, Philadelphia, PA..........19103..........
(Address of principal executive offices) (Zip Code)
........................(215)841-4000............................
(Registrant's telephone number, including area code)
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:
The Company had 222,546,562 shares of common stock outstanding on
March 31, 1998.
<PAGE>
<TABLE>
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
(Millions of Dollars)
<CAPTION>
3 Months Ended
March 31,
----------------------
1998 1997
--------- ---------
OPERATING REVENUES
<S> <C> <C>
Electric $ 995.3 $ 970.5
Gas 177.8 192.9
--------- --------
TOTAL OPERATING REVENUES 1,173.1 1,163.4
--------- --------
OPERATING EXPENSES
Fuel and Energy Interchange 369.7 334.0
Operating and Maintenance 282.0 301.9
Depreciation 154.7 142.5
Taxes Other Than Income Taxes 82.1 83.0
--------- --------
TOTAL OPERATING EXPENSES 888.5 861.4
--------- --------
OPERATING INCOME 284.6 302.0
--------- --------
OTHER INCOME AND DEDUCTIONS
Interest Expense (87.2) (92.8)
Company Obligated Mandatorily Redeemable
Preferred Securities of a Partnership (7.7) (6.7)
Allowance for Funds Used During Construction 2.8 4.6
Other, Net (10.2) (2.4)
--------- --------
TOTAL OTHER INCOME AND DEDUCTIONS (102.3) (97.3)
--------- --------
INCOME BEFORE INCOME TAXES 182.3 204.7
--------- --------
INCOME TAXES 68.7 91.7
--------- --------
NET INCOME 113.6 113.0
PREFERRED STOCK DIVIDENDS 3.3 4.5
--------- --------
EARNINGS APPLICABLE TO COMMON STOCK $ 110.3 $ 108.5
========= ========
AVERAGE SHARES OF COMMON STOCK
OUTSTANDING (Millions) 222.5 222.5
BASIC AND DILUTIVE EARNINGS PER AVERAGE
COMMON SHARE (Dollars) $ 0.50 $ 0.49
DIVIDENDS PER AVERAGE COMMON SHARE (Dollars) $ 0.25 $ 0.45
BOOK VALUE PER COMMON SHARE (Dollars) $ 12.49 $ 20.92
See Notes to Condensed Consolidated Financial Statements.
</TABLE>
<PAGE>
<TABLE>
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Millions of Dollars)
<CAPTION>
March 31, December 31,
1998 1997
------------ ------------
(Unaudited)
ASSETS
UTILITY PLANT
<S> <C> <C>
Electric - Transmission & Distribution $ 3,644.9 $ 3,617.7
Electric - Generation 1,423.8 1,434.9
Gas 1,085.8 1,071.8
Common 309.4 302.7
---------- ----------
6,463.9 6,427.1
Less Accumulated Provision for Depreciation 2,737.5 2,690.8
---------- ----------
3,726.4 3,736.3
Nuclear Fuel, net 176.8 147.4
Construction Work in Progress 644.2 611.2
Leased Property, net 167.9 175.9
---------- ----------
4,715.3 4,670.8
---------- ----------
CURRENT ASSETS
Cash and Temporary Cash Investments 55.0 33.4
Accounts Receivable, net
Customer 156.0 173.3
Other 132.4 140.0
Inventories, at average cost
Fossil Fuel 64.5 84.9
Materials and Supplies 93.6 90.9
Deferred Generation Costs Recoverable in Current Rates 312.9 424.5
Deferred Energy Costs - Gas 16.7 35.7
Other 137.6 20.1
---------- ----------
968.7 1,002.8
---------- ----------
DEFERRED DEBITS AND OTHER ASSETS
Competitive Transition Charge 5,274.6 5,274.6
Recoverable Deferred Income Taxes 594.9 590.3
Deferred Non-Pension Postretirement Benefits Costs 95.8 97.4
Investments 516.0 515.8
Loss on Reacquired Debt 82.1 83.9
Other 110.2 121.0
---------- ----------
6,673.6 6,683.0
---------- ----------
TOTAL $ 12,357.6 $ 12,356.6
========== ==========
See Notes to Condensed Consolidated Financial Statements.
(continued on next page)
</TABLE>
<PAGE>
<TABLE>
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Millions of Dollars)
(continued)
<CAPTION>
Three Months Ended
March 31,
1998 1997
------------ ------------
(Unaudited)
CAPITALIZATION AND LIABILITIES
CAPITALIZATION
Common Shareholders' Equity
<S> <C> <C>
Common Stock (No Par) $ 3,517.7 $ 3,517.7
Other Paid-In Capital 1.2 1.2
Retained Deficit (740.6) (792.2)
Preferred and Preference Stock
Without Mandatory Redemption 137.5 137.5
With Mandatory Redemption 92.7 92.7
Company Obligated Mandatorily Redeemable
Preferred Securities of a Partnership 352.1 352.1
Long-Term Debt 3,597.4 3,853.1
---------- ----------
6,958.0 7,162.1
---------- ----------
CURRENT LIABILITIES
Notes Payable, Bank 384.5 401.5
Long-Term Debt Due Within One Year 498.0 247.1
Capital Lease Obligations Due Within One Year 77.1 55.8
Accounts Payable 233.4 306.9
Taxes Accrued 117.9 66.4
Interest Accrued 83.2 77.9
Dividends Payable 16.1 17.0
Deferred Income Taxes 130.8 185.7
Other 275.6 260.4
---------- ----------
1,816.6 1,618.7
---------- ----------
DEFERRED CREDITS AND OTHER LIABILITIES
Capital Lease Obligations 90.8 120.1
Deferred Income Taxes 2,321.8 2,297.1
Unamortized Investment Tax Credits 313.6 318.1
Pension Obligation 211.6 211.6
Non-Pension Postretirement Benefits Obligation 333.4 324.8
Other 311.8 304.1
---------- ----------
3,583.0 3,575.8
---------- ----------
COMMITMENTS AND CONTINGENCIES (NOTE 6)
TOTAL $ 12,357.6 $ 12,356.6
========== ==========
See Notes to Condensed Consolidated Financial Statements.
</TABLE>
<PAGE>
<TABLE>
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
(Millions of Dollars)
<CAPTION>
3 Months Ended
March 31,
---------------------------------
1998 1997
---------- ----------
CASH FLOWS FROM OPERATING ACTIVITIES
<S> <C> <C>
NET INCOME $ 113.6 $ 113.0
Adjustments to Reconcile Net Income to Net Cash
Provided by Operating Activities:
Depreciation and Amortization 170.9 149.9
Deferred Income Taxes (6.8) (4.7)
Deferred Energy Costs 19.0 6.4
Changes in Working Capital:
Accounts Receivable 24.9 (13.6)
Inventories 17.7 33.4
Accounts Payable (73.5) (86.7)
Other Current Assets and Liabilities (45.5) 5.5
Other Items Affecting Operations 11.7 18.0
---------- ---------
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES 232.0 221.2
---------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES
Investment in Plant (116.5) (101.4)
Increase in Investments (11.1) (33.1)
---------- ---------
NET CASH FLOWS USED BY INVESTING ACTIVITIES (127.6) (134.5)
---------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES
Change in Short-Term Debt (17.0) 15.0
Retirement of Long-Term Debt (5.5) -
Loss on Reacquired Debt 1.8 5.9
Dividends on Preferred and Common Stock (58.9) (104.7)
Change in Dividends Payable (0.9) 7.4
Other Items Affecting Financing (2.3) 0.2
---------- ---------
NET CASH FLOWS USED BY FINANCING ACTIVITIES (82.8) (76.2)
---------- ---------
INCREASE IN CASH AND CASH EQUIVALENTS 21.6 10.5
---------- ---------
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 33.4 29.2
---------- ---------
CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 55.0 $ 39.7
========== =========
See Notes to Condensed Consolidated Financial Statements.
</TABLE>
<PAGE>
15
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
1. BASIS OF PRESENTATION
The accompanying condensed consolidated financial statements as of
March 31, 1998 and for the three months then ended are unaudited, but include
all adjustments that PECO Energy Company (Company) considers necessary for a
fair presentation of such financial statements. All adjustments are of a normal,
recurring nature. The year-end condensed consolidated balance sheet data were
derived from audited financial statements but do not include all disclosures
required by generally accepted accounting principles. Certain prior-year amounts
have been reclassified for comparative purposes. These notes should be read in
conjunction with the Notes to Consolidated Financial Statements in the Company's
1997 Annual Report to Shareholders, which are incorporated by reference in the
Company's Annual Report on Form 10-K for the year ended December 31, 1997 (1997
Form 10-K).
2. RATE MATTERS
As previously reported in the 1997 Form 10-K, the Company filed
complaints in federal and state courts relating to the orders of the
Pennsylvania Public Utility Commission (PUC) issued in December 1997, and
January and February 1998, deregulating the Company's electric generation
operations (PUC Restructuring Order). In addition, numerous other parties have
filed appeals and cross appeals of the PUC Restructuring Order. Most of these
parties, including the Company, have entered into settlement discussions. The
Company cannot predict the outcome of such discussions or appeals. At December
31, 1997, the Company discontinued the use of regulatory accounting in its
financial statements for its electric generation operations.
3. RESTART OF SALEM GENERATING STATION (SALEM) Public Service Electric and
Gas Company (PSE&G), the operator of Salem Units No. 1 and No. 2, which are
42.59% owned by the Company, removed the units from service in the second
quarter of 1995. Unit No. 2 returned to commercial operation in the third
quarter of 1997 and Unit No. 1 returned to commercial operation on April 17,
1998.
For the three months ended March 31, 1998 and 1997, the Company
recorded in the accompanying Statements of Income as Fuel and Energy Interchange
$16 and $29 million, respectively, of replacement power costs and recorded as
Operating and Maintenance $8 and $13 million, respectively, of maintenance costs
relating to the shutdown of Salem. For the year ending December 31, 1998, the
Company expects to incur and expense approximately $35 million of costs related
to the shutdown.
4. SALES OF ACCOUNTS RECEIVABLE
The Company is party to an agreement with a financial institution,
under which it can sell or finance with limited recourse an undivided interest,
adjusted daily, in up to $425 million of designated accounts receivable until
November 2000. At March 31, 1998, the Company had sold a $425 million interest
in accounts receivable, consisting of a $296 million interest in accounts
receivable which the Company accounts for as a sale under Statement of Financial
Accounting Standards (SFAS) No. 125, "Accounting for Transfers and Servicing of
Financial Assets and Extinguishment of Liabilities," and a $129 million interest
in special agreement accounts receivable which were accounted for as a long-term
note payable. The Company retains the servicing responsibility for these
receivables. The agreement requires the Company to maintain its $425 million
interest, which if not met, requires the Company to deposit cash in order to
satisfy such requirements. The Company was required to deposit $37 million of
cash, which is restricted from the Company's use, under the terms of the
agreement at March 31, 1998. At March 31, 1998, the average annual
service-charge rate, computed on a daily basis on the portion of the accounts
receivable sold but not yet collected, was 5.59%.
5. STOCK REPURCHASE
During 1997, the Company's Board of Directors authorized the repurchase
of up to 25 million shares of its common stock from time to time through
open-market, privately negotiated and/or other types of transactions in
conformity with the rules of the Securities and Exchange Commission.
Pursuant to these authorizations, the Company has entered into forward
purchase agreements to be settled from time to time, at the Company's election,
on either a physical, net share or net cash basis. The amount at which these
agreements can be settled is dependent principally upon the market price of the
Company's common stock as compared to the forward purchase price per share and
the number of shares to be settled. If these agreements had been settled on a
net share basis at March 31, 1998, based on the closing price of the Company's
common stock on that date, the Company would have received approximately 476,000
shares of Company common stock.
6. COMMITMENTS AND CONTINGENCIES
For information regarding the Company's capital commitments, nuclear
insurance, nuclear decommissioning and spent fuel storage, energy commitments,
environmental issues, telecommunications and litigation, see note 5 of Notes to
Consolidated Financial Statements for the year ended December 31, 1997.
As previously reported, the Company has identified 27 sites where
former manufactured gas plant (MGP) activities have or may have resulted in
actual site contamination. As of March 31, 1998, the Company had accrued $63
million for environmental investigation and remediation costs, including $35
million for MGP investigation and remediation that currently can be reasonably
estimated. The Company cannot predict whether it will incur other significant
liabilities for additional investigation and remediation costs at these or
additional sites identified by the Company, environmental agencies or others, or
whether all such costs will be recoverable from third parties.
The Company periodically reviews its investments to determine that they
are properly valued in its financial statements. Due to the changes in the
electric deregulation environment throughout the United States, the Company is
specifically evaluating its investment in EnergyOne. As of March 31, 1998, the
Company had a net investment of $10 million in EnergyOne.
7. ACCOUNTING MATTERS
In February 1998, the Financial Accounting Standards Board (FASB)
issued SFAS No. 132, "Employers' Disclosures about Pensions and Other
Postretirement Benefits," to revise and standardize employers' disclosures about
pension and other postretirement benefit plans required by SFAS No. 87,
"Employers' Accounting for Pensions," SFAS No. 88, "Employers' Accounting for
Settlements and Curtailments of Defined Benefit Pension Plans and for
Termination Benefits," and SFAS No. 106, "Employers' Accounting for
Postretirement Benefits Other Than Pensions," but does not change the
measurement or recognition of those plans. The new standard is effective for
fiscal years beginning after December 15, 1997. The Company will adopt SFAS No.
132 in 1998. Adoption of SFAS No. 132 will not affect the Company's financial
condition or results of operations.
8. SUBSEQUENT FINANCINGS
On April 6, 1998, PECO Energy Capital Trust III (Trust) issued $78
million of Trust Receipts, each representing a 7.38% Company Obligated
Mandatorily Redeemable Preferred Securities of a Partnership (COMRPS), Series D,
representing limited partnership interests. The sole assets of the Trust are
7.38% COMRPS, Series D, issued by PECO Energy Capital, L.P., a Delaware limited
partnership of which a wholly owned subsidiary of the Company is the sole
general partner. The COMPRS, Series D are supported by a series of the Company's
deferrable interest subordinated debentures. Each holder of the Trust Receipts
is entitled to withdraw the corresponding number of 7.38% COMRPS, Series D, from
the Trust in exchange for the Trust Receipts so held. Proceeds from the issuance
will be used by the Company in connection with its redemption, on May 15, 1998,
of $78 million aggregate liquidation value of the Company's outstanding Trust
Receipts, each representing a 8.72% COMRPS, Series B, of PECO Energy Capital,
L.P.
<PAGE>
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
GENERAL
The Electricity Generation Customer Choice and Competition Act
(Competition Act) was enacted in December 1996 providing for the restructuring
of the electric utility industry in Pennsylvania, including retail competition
for generation beginning in 1999. Pursuant to the Competition Act, in April
1997, the Company filed with the Pennsylvania Public Utility Commission (PUC) a
comprehensive restructuring plan detailing its proposal to implement full
customer choice of electric generation supplier. The Company's restructuring
plan identified $7.5 billion of retail electric generation-related stranded
costs. In December 1997, the PUC entered an Opinion and Order, revised in
January and February 1998 (PUC Restructuring Order), which deregulates the
Company's electric generation operations and authorizes the Company to recover
stranded costs of $4.9 billion on a discounted basis, or $5.3 billion on a book
value basis, over 8-1/2 years beginning in 1999. The Company has filed appeals
of the PUC Restructuring Order with federal and state courts. The Company is in
settlement discussions related to its and other appeals of the PUC Restructuring
Order. For additional information concerning the PUC Restructuring Order, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations" in the Company's Annual Report to Shareholders for the year 1997;
the Company's Annual Report on Form 10-K for the year ended December 31, 1997
(1997 Form 10-K) under "PART I. ITEM 1. BUSINESS-Deregulation and Rate Matters";
and "PART II. ITEM 5. OTHER INFORMATION" of this Quarterly Report on Form 10-Q
(Report).
At December 31, 1997, the Company discontinued the use of regulatory
accounting in its financial statements for its electric generation operations
resulting in an extraordinary charge against income of $3.1 billion ($1.8
billion net of income taxes) to reflect the amount of electric
generation-related assets that will not be recovered from customers either prior
to the commencement of competition or under the PUC Restructuring Order. For
additional discussion on the discontinuance of the use of regulatory accounting
for the Company's electric generation operations, see note 4 of Notes to
Consolidated Financial Statements for the year ended December 31, 1997.
Although the Company cannot predict the ultimate effect of the PUC
Restructuring Order and competition for electric generation services, the
Company believes that its future financial condition and results of operations
will be adversely affected.
On January 26, 1998, the Company's Board of Directors reduced the
quarterly common stock dividend from $0.45 per share to $0.25 per share,
effective with the dividend payable on March 31, 1998. The Board of Directors
concluded that, given the impact of the PUC Restructuring Order, the dividend
reduction was necessary to provide the Company with the financial flexibility
needed to meet the demands of competition.
The Company is continuing its cost management efforts through a
Competitive Cost Review (CCR). The objective of this review is to achieve a best
in class cost structure while maintaining high quality service through an
in-depth analysis and assessment of all Company expenses, capital expenditures,
programs, processes and personnel. CCR's goal is to enable the Company to be a
low cost energy provider while not compromising its service quality,
reliability, safety or overall performance levels.
The Company's Local Distribution Company (LDC), a business unit of the
Company, provides customers with electric transmission and distribution
services, gas services and other energy products and services. On March 31,
1998, the LDC announced a workforce reduction of approximately 700 employees and
150 contractors to take place over the next twelve to eighteen months in order
to improve productivity and efficiency and to implement new processes and
technology.
On April 8, 1998, the Board of Directors authorized the implementation
of a retirement incentive program and an enhanced severance benefit program to
achieve targeted workforce reductions. The retirement incentive program will
allow employees age 50 and older, who have been designated as excess or who are
in job classifications facing reduction, to retire from the Company. The
enhanced severance benefit program will provide non-retiring excess employees
with less than ten years of service, severance benefits of two weeks pay per
year of service. Non-retiring excess employees with more than ten years of
service will receive severance benefits of three weeks pay per year of service.
The Company cannot currently predict the magnitude of the impact of the
CCR, the LDC workforce reduction, the retirement incentive program and the
enhanced severance benefit program on its future financial condition and results
of operations.
RESULTS OF OPERATIONS
EARNINGS
Basic and dilutive earnings per average common share for the three
months ended March 31, 1998 were $0.50 per share compared to $0.49 per share in
1997. Earnings for the first quarter of 1998 improved due to an increase in
wholesale electric revenues net of fuel and energy interchange, lower operating
and maintenance expense, and lower income tax expense. The earnings increase was
partially offset by lower total revenues net of fuel and energy interchange, due
to milder weather conditions and the effects of lower margins on retail electric
sales, and increased depreciation expense.
OPERATING REVENUES
Electric revenues increased 3% for the three months ended March 31,
1998 compared to 1997 primarily due to higher wholesale electric sales. The
increase was partially offset by milder weather conditions in 1998 compared to
1997 and lower average rates as a result of the customer choice pilot program.
Gas revenues decreased 8% for the three months ended March 31, 1998
compared to 1997 primarily due to a decrease in sales volume as a result of
milder weather conditions.
FUEL AND ENERGY INTERCHANGE
Fuel and energy interchange expense increased 11% for the three months
ended March 31, 1998 compared to 1997 primarily due to additional interchange
purchases needed for increased wholesale electric sales.
OPERATING AND MAINTENANCE
Operating and maintenance expense decreased 7% for the three months
ended March 31, 1998 compared to 1997. The decrease was primarily due to lower
electric transmission and distribution system expenses and lower uncollectible
accounts expenses. The decrease was partially offset by an increase in other
administrative and general expenses.
DEPRECIATION EXPENSE
Depreciation expense increased 9% for the three months ended March 31,
1998 compared to 1997 primarily due to the amortization of Deferred Generation
Costs Recoverable in Current Rates during 1998, preceding the Company's
transition to market-based pricing of electric generation in 1999.
OTHER INCOME AND DEDUCTIONS
Other income and deductions excluding interest charges decreased
substantially for the three months ended March 31, 1998 compared to 1997. The
decrease was primarily due to increased losses from investments in subsidiaries.
INTEREST CHARGES
Interest charges decreased 6% for the three months ended March 31, 1998
compared to 1997 primarily as a result of lower amortization expense due to the
write-off of electric generation-related debt discounts at December 31, 1997 and
the Company's ongoing program to reduce and refinance higher-cost, long-term
debt. These decreases were partially offset by higher average short-term debt
balances compared to 1997 and the replacement of $62 million of preferred stock
with Company Obligated Mandatorily Redeemable Preferred Securities of a
Partnership (COMRPS) in the third quarter of 1997.
INCOME TAXES
Total income taxes decreased 25% for the three months ended March 31,
1998 compared to 1997. The decrease was primarily due to full normalization of
deferred taxes associated with generation plant and lower pre-tax income.
PREFERRED STOCK DIVIDENDS
Preferred stock dividends decreased 27% for the three months ended March
31, 1998 compared to 1997 primarily due to the replacement of $62 million of
preferred stock with COMRPS in the third quarter of 1997.
DISCUSSION OF LIQUIDITY AND CAPITAL RESOURCES
Total construction expenditures, primarily for utility plant, are
estimated to be $600 million for 1998. The estimated expenditures include
approximately $150 million for new ventures, principally through the
Telecommunications Group. Due to the expected adverse impact of the PUC
Restructuring Order and competition for electric generating services on its
future capital resources, the Company is currently evaluating its capital
commitments for 1999 and beyond. Certain facilities under construction and to be
constructed may require permits and licenses which the Company has no assurance
will be granted.
At March 31, 1998, the Company and its subsidiaries had outstanding
$385 million of notes payable, including $297 million of commercial paper. At
March 31, 1998, the Company had formal and informal lines of bank credit
aggregating $100 million. At March 31, 1998, the Company and its subsidiaries
had no short-term investments.
As a result of the extraordinary charge to earnings in December 1997,
the Company did not meet the earnings test under the Mortgage required for the
issuance of additional bonds against property additions for the twelve months
ended March 31, 1998. In addition, the Company does not expect to meet the
earnings test under the Mortgage for any twelve-month period ending prior to
December 31, 1998. At March 31, 1998, the Company was entitled to issue
approximately $3.6 billion of mortgage bonds without regard to the earnings and
property additions tests against previously retired mortgage bonds.
As a result of the extraordinary charge to earnings in December 1997,
the Company did not meet the earnings test of the Company's Amended and Restated
Articles of Incorporation (Articles), required for the issuance of additional
preferred stock without an affirmative vote of the holders of two-thirds of all
preferred shares outstanding, for the twelve months ended March 31, 1998. In
addition, the Company does not expect to meet the earnings test under the
Articles for any twelve-month period ending prior to December 31, 1998.
For the three months ended March 31, 1998, the Company's Ratio of
Earnings to Fixed Charges (SEC Method) (Exhibit 12-1) and Ratio of Earnings to
Combined Fixed Charges and Preferred Stock Dividends (SEC Method) (Exhibit 12-2)
were 3.12 times and 2.94 times, respectively, compared to 3.24 times and 2.97
times, respectively, for the corresponding period in 1997.
See the 1997 Form 10-K under "PART I. ITEM 1. BUSINESS-Capital
Requirements and Financing Activities," for a discussion of the ratio methods.
As previously disclosed, the Company's Board of Directors authorized
the repurchase of up to 25 million shares of its common stock from time to time
through open market, privately negotiated and/or other types of transactions in
conformity with the rules of the Securities and Exchange Commission (SEC).
The Company has entered into forward purchase agreements to be settled
from time to time, at the Company's election, on either a physical, net share or
net cash basis. The amount at which these agreements can be settled is dependent
principally upon the market price of the Company's common stock as compared to
the forward purchase price per share and the number of shares to be settled. If
these agreements had been settled on a net share basis at March 31, 1998, based
on the closing price of the Company's Common Stock on that date, the Company
would have received approximately 476,000 shares of Company common stock.
On April 6, 1998, PECO Energy Capital Trust III (Trust) issued $78
million of Trust Receipts, each representing a 7.38% COMRPS, Series D,
representing limited partnership interests. The sole assets of the Trust are
7.38% COMRPS, Series D, issued by PECO Energy Capital, L.P., a Delaware limited
partnership of which a wholly owned subsidiary of the Company is the sole
general partner. The COMPRS, Series D are supported by a series of the Company's
deferrable interest subordinated debentures. Each holder of the Trust Receipts
is entitled to withdraw the corresponding number of 7.38% COMRPS, Series D, from
the Trust in exchange for the Trust Receipts so held. Proceeds from the issuance
will be used by the Company in connection with its redemption, on May 15, 1998,
of $78 million aggregate liquidation value of the Company's outstanding Trust
Receipts, each representing a 8.72% COMRPS, Series B, of PECO Energy Capital,
L.P.
FORWARD-LOOKING STATEMENTS
Except for the historical information contained herein, certain of the
matters discussed in this Report are forward-looking statements which are
subject to risks and uncertainties. The factors that could cause actual results
to differ materially include those discussed herein as well as those listed in
notes 2, 3 and 6 of Notes to Condensed Consolidated Financial Statements and
other factors discussed in the Company's filings with the SEC. Readers are
cautioned not to place undue reliance on these forward-looking statements, which
speak only as of the date of this Report. The Company undertakes no obligation
to publicly release any revision to these forward-looking statements to reflect
events or circumstances after the date of this Report.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK
None.
<PAGE>
PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
On March 10, 1998, the Grays Ferry Cogeneration Partnership sued the
Company in the United States District Court for the Eastern District of
Pennsylvania (Eastern District Court) to enjoin the Company's termination of the
power purchase agreements relating to the Grays Ferry Cogeneration Project
(Project). In addition to specific enforcement of the agreements, the plaintiff
claimed damages in excess of $200 million. The Company claimed that, as a result
of the elimination of the Energy Cost Adjustment through statutory and
regulatory changes and the resulting inability of the Company to recover these
costs from customers, the contract contingency had been triggered and the
agreements were no longer in effect. On March 19, 1998, the Eastern District
Court dismissed the suit for lack of subject-matter jurisdiction. On April 9,
1998, the plaintiff filed an action asserting similar claims in the Court of
Common Pleas in Philadelphia County against the Company and the PUC. In a
separate action, on March 18, 1998, The Chase Manhattan Bank, the lender for the
Project, filed an action in the Eastern District Court against the Company
alleging breach of the letter agreement relating to the Project's credit. The
Company cannot predict the outcome of these matters.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
On April 8, 1998, the Company held its 1998 Annual Meeting of
Shareholders.
The following Class II directors of the Company were re-elected for
terms expiring in 2001:
Votes For Votes Withheld
Susan W. Catherwood 180,415,786 4,931,865
G. Fred DiBona, Jr. 180,197,956 5,149,695
R. Keith Elliott 180,300,452 5,047,199
John M. Palms 180,437,426 4,910,225
Joseph F. Paquette, Jr. 180,337,084 5,010,567
The incumbent Class I directors, with terms expiring in 2000, are Richard
H. Glanton, Rosemarie B. Greco, Corbin A. McNeill, Jr. and Robert Subin. The
incumbent Class III directors, with terms expiring in 1999, are Daniel L.
Cooper, M. Walter D'Alessio, Kinnaird R. McKee and Ronald Rubin.
Other items voted on by holders of common stock at the Annual Meeting
were as follows:
(1) The appointment of the firm of Coopers & Lybrand L.L.P.,
independent certified public accountants, as auditors of the
Company for 1998, was approved with 181,224,591 common shares
(81.43% of common shares outstanding) voting for; 2,483,519
common shares (1.12% of common shares outstanding) voting
against; and 1,639,541 common shares (0.74% of common shares
outstanding) abstaining;
(2) A shareholder proposal requiring lawyers deriving compensation
from a law firm providing legal services to the Company not be
selected for the slate of endorsed candidates for director was
defeated with 22,338,397 common shares (10.04% of common
shares outstanding) voting for; 134,437,011 common shares
(60.41% of common shares outstanding) voting against;
7,716,446 common shares (3.47% of common shares outstanding)
abstaining; and 20,855,797 common shares (9.37% of common
shares outstanding) broker non-votes; and
(3) A shareholder proposal requesting the Company to establish a
firm policy to refuse to use mixed-oxide fuel in the Company's
nuclear reactors was defeated with 9,467,258 common shares
(4.25% of common shares outstanding) voting for; 142,219,309
common shares (63.91% of common shares outstanding) voting
against; 12,805,379 common shares (5.75% of common shares
outstanding) abstaining; and 20,855,705 common shares (9.37%
of common shares outstanding) broker non-votes.
ITEM 5. OTHER INFORMATION
As previously reported in the 1997 Form 10-K, the Company filed
complaints in federal and state courts relating to the PUC Restructuring Order.
In addition, numerous other parties have filed appeals and cross appeals of the
PUC Restructuring Order. Most of these parties, including the Company, have
entered into settlement discussions. The Company cannot predict the outcome of
such discussions or appeals.
As previously reported in the 1997 Form 10-K, the Company had requested
that the Nuclear Regulatory Commission (NRC) extend the deferral period for the
installation of large capacity passive strainers at Unit No. 2 at Limerick
Generating Station (Limerick) until its scheduled refueling outage in April
1999. By letter dated March 6, 1998, the NRC approved the Company's request.
As previously reported in the 1997 Form 10-K, the Company planned to
remove from service Unit No. 3 at Peach Bottom Atomic Power Station (Peach
Bottom) to perform permanent repairs of cracks in several recirculation system
jet pump pipes within the reactor vessel. In March 1998, the Company made the
repairs.
Salem Generating Station Units No. 1 and No. 2 were taken out of service by
Public Service Electric and Gas Company in the second quarter of 1995. Unit No.
2 returned to commercial operation in the third quarter of 1997. Unit No. 1
returned to commercial operation on April 17, 1998.
The Company is continuing its cost management efforts through a CCR.
The objective of this review is to achieve a best in class cost structure while
maintaining high quality service through an in-depth analysis and assessment of
all Company expenses, capital expenditures, programs, processes and personnel.
CCR's goal is to enable the Company to be a low cost energy provider while not
compromising its service quality, reliability, safety or overall performance
levels.
The Company's LDC, a business unit of the Company, provides customers
with electric transmission and distribution services, gas services and other
energy products and services. On March 31, 1998, the LDC announced a workforce
reduction of approximately 700 employees and 150 contractors to take place over
the next twelve to eighteen months in order to improve productivity and
efficiency and to implement new processes and technology.
On April 8, 1998, the Board of Directors authorized the implementation
of a retirement incentive program and an enhanced severance benefit program to
achieve targeted workforce reductions. The retirement incentive program will
allow employees age 50 and older, who have been designated as excess or who are
in job classifications facing reduction, to retire from the Company. The
enhanced severance benefit program will provide non-retiring excess employees
with less than ten years of service, severance benefits of two weeks pay per
year of service. Non-retiring excess employees with more than ten years of
service will receive severance benefits of three weeks pay per year of service.
The Company cannot currently predict the magnitude of the impact of the
CCR, the LDC workforce reduction, the retirement incentive program and the
enhanced severance benefit program on its future financial condition and results
of operations.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits:
12-1 - Statement regarding computation of ratio of
earnings to fixed charges.
12-2 - Statement regarding computation of ratio of
earnings to combined fixed charges and preferred
stock dividends.
27 - Financial Data Schedule.
(b) Reports on Form 8-K filed during the reporting period:
Report, dated January 9, 1998, reporting information under "ITEM 5.
OTHER EVENTS" regarding the Company's filing of a Petition for
Rehearing, Reconsideration, Clarification, and Amendment to
the Pennsylvania Public Utility Commission's Opinion and Order
in the Company's restructuring proceeding.
Report, dated January 15, 1998, reporting information under "ITEM 5.
OTHER EVENTS" regarding the Pennsylvania Public Utility
Commission's response to the Company's filing of a Petition
for Rehearing, Reconsideration, Clarification, and Amendment
to the Opinion and Order in the Company's Restructuring
Proceeding.
Report, dated January 22, 1998, reporting information under "ITEM 5.
OTHER EVENTS" regarding the Company's filing of complaints
appealing the Pennsylvania Public Utility Commission's
decision in its restructuring proceeding.
Report, dated January 23, 1998, reporting information under "ITEM 5.
OTHER EVENTS" regarding the Company's filing of complaints
appealing the Pennsylvania Public Utility Commission's
decision in its restructuring proceeding.
Report, dated January 26, 1998, reporting information under "ITEM 5.
OTHER EVENTS" regarding the Company's decision to reduce the
Company's quarterly common stock dividend and reporting 1997
financial results.
Reports on Form 8-K filed subsequent to the reporting period:
None
<PAGE>
Signatures
Pursuant to 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.
PECO ENERGY COMPANY
/s/ Michael J. Egan
--------------------------
Michael J. Egan
Senior Vice President and
Chief Financial Officer
(Principal Financial and
Accounting Officer)
Date: April 27, 1998
<PAGE>
EXHIBIT 12-1
<TABLE>
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
SEC METHOD
($000)
<CAPTION>
3 MONTHS
ENDED 03/31/98
--------
<S> <C>
NET INCOME $113,554
ADD BACK:
- - INCOME TAXES:
OPERATING INCOME 73,838
NON-OPERATING INCOME (5,105)
--------
NET TAXES 68,733
- - FIXED CHARGES:
INTEREST APPLICABLE TO DEBT 83,691
ANNUAL RENTALS 2,101
--------
TOTAL FIXED CHARGES 85,792
ADJUSTED EARNINGS INCLUDING AFUDC $268,079
========
RATIO OF EARNINGS TO FIXED CHARGES 3.12
====
</TABLE>
EXHIBIT 12-2
<TABLE>
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
COMPUTATION OF RATIO OF EARNINGS TO COMBINED FIXED CHARGES
AND PREFERRED STOCK DIVIDEND REQUIREMENTS
SEC METHOD
($000)
<CAPTION>
3 MONTHS
ENDED
03/31/98
--------
<S> <C>
NET INCOME $113,554
ADD BACK:
- - INCOME TAXES:
OPERATING INCOME 73,838
NON-OPERATING INCOME (5,105)
-------
NET TAXES 68,733
- - FIXED CHARGES:
INTEREST APPLICABLE TO DEBT 83,691
ANNUAL RENTALS 2,101
-------
TOTAL FIXED CHARGES 85,792
EARNINGS REQUIRED FOR PREFERRED DIVIDENDS:
DIVIDENDS ON PREFERRED STOCK 3,277
ADJUSTMENT TO PREFERRED DIVIDENDS* 1,984
-------
5,261
FIXED CHARGES AND PREFERRED DIVIDENDS $91,053
=======
EARNINGS BEFORE INCOME TAXES AND
FIXED CHARGES $268,079
========
RATIO OF EARNINGS TO COMBINED FIXED CHARGES
AND PREFERRED STOCK DIVIDEND REQUIREMENTS 2.94
====
<FN>
* ADDITIONAL CHARGE EQUIVALENT TO EARNINGS REQUIRED
TO ADJUST DIVIDENDS ON PREFERRED STOCK TO A PRE-TAX BASIS
</FN>
</TABLE>
<TABLE> <S> <C>
<ARTICLE> UT
<MULTIPLIER> 1,000,000
<S> <C>
<PERIOD-TYPE> 3-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-END> MAR-31-1998
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 4715
<OTHER-PROPERTY-AND-INVEST> 516
<TOTAL-CURRENT-ASSETS> 969
<TOTAL-DEFERRED-CHARGES> 5965
<OTHER-ASSETS> 192
<TOTAL-ASSETS> 12358
<COMMON> 3518
<CAPITAL-SURPLUS-PAID-IN> 1
<RETAINED-EARNINGS> (741)
<TOTAL-COMMON-STOCKHOLDERS-EQ> 2778
93
138
<LONG-TERM-DEBT-NET> 3597
<SHORT-TERM-NOTES> 385
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 297
<LONG-TERM-DEBT-CURRENT-PORT> 498
0
<CAPITAL-LEASE-OBLIGATIONS> 91
<LEASES-CURRENT> 77
<OTHER-ITEMS-CAPITAL-AND-LIAB> 4702
<TOT-CAPITALIZATION-AND-LIAB> 12358
<GROSS-OPERATING-REVENUE> 1173
<INCOME-TAX-EXPENSE> 69
<OTHER-OPERATING-EXPENSES> 889
<TOTAL-OPERATING-EXPENSES> 957
<OPERATING-INCOME-LOSS> 216
<OTHER-INCOME-NET> (7)
<INCOME-BEFORE-INTEREST-EXPEN> 209
<TOTAL-INTEREST-EXPENSE> 95
<NET-INCOME> 114
3
<EARNINGS-AVAILABLE-FOR-COMM> 110
<COMMON-STOCK-DIVIDENDS> 56
<TOTAL-INTEREST-ON-BONDS> 87
<CASH-FLOW-OPERATIONS> 232
<EPS-PRIMARY> 0.50
<EPS-DILUTED> 0.50
</TABLE>
