SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
Quarterly Report Under Section 13 or 15(d)
of the Securities Exchange Act of 1934
For Quarter Ended March 31, 1999
--------------
Commission file number 1-1072
------
Potomac Electric Power Company
- ----------------------------------------------------------------
(Exact name of registrant as specified in its charter)
District of Columbia and Virginia 53-0127880
- ----------------------------------------------------------------
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
1900 Pennsylvania Avenue, N.W., Washington, D.C. 20068
- ----------------------------------------------------------------
(Address of principal executive office) (Zip Code)
(202) 872-2000
- ----------------------------------------------------------------
(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
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 March 31, 1999
- -------------------------- ---------------------------------
Common Stock, $1 par value 118,527,287
TABLE OF CONTENTS
PART I - Financial Information Page
Item 1. - Consolidated Financial Statements
Consolidated Statements of Earnings and Retained Income.. 2
Consolidated Balance Sheets.............................. 3
Consolidated Statements of Cash Flows.................... 4
Notes to Consolidated Financial Statements............... 5
(1) SMECO Agreement.................................... 6
(2) Comprehensive Income............................... 6
(3) Income Taxes....................................... 7
(4) Capitalization and Fair Value of Financial
Instruments...................................... 10
(5) Commitments and Contingencies...................... 16
(6) Segment Information................................ 17
Report of Independent Accountants on Review of Interim
Financial Information.................................. 19
Item 2. - Management's Discussion and Analysis of Consolidated
Results of Operations and Financial Condition
General.................................................. 20
Forward Looking Statements............................... 21
Utility
Results of Operations.................................. 22
Year 2000 Readiness Disclosure....................... 24
Capital Resources and Liquidity........................ 27
Nonutility Subsidiary
Results of Operations.................................. 29
Year 2000 Readiness Disclosure....................... 34
Capital Resources and Liquidity........................ 34
PART II - Other Information
Item 1. - Legal Proceedings................................ 35
Item 4. - Submission of Matters to a Vote
of Security Holders...................................... 35
Item 5. - Other Information
Other Financing Arrangements............................. 36
Base Rate Proceedings.................................... 36
Restructuring of the Bulk Power Market................... 37
Competition.............................................. 38
Peak Load, Sales, Conservation, and Construction and
Generating Capacity.................................... 39
Selected Nonutility Subsidiary Financial Information..... 42
Statistical Data......................................... 44
Item 6. - Exhibits and Reports on Form 8-K................. 45
Signatures................................................. 47
Computation of Ratios - Parent Company Only................ 48
Computation of Ratios - Consolidated....................... 49
Independent Accountants Awareness Letter................... 50
1
<TABLE>
Part I FINANCIAL INFORMATION
- ------ ---------------------
Item 1 CONSOLIDATED FINANCIAL STATEMENTS
- ------ ---------------------------------
POTOMAC ELECTRIC POWER COMPANY
Consolidated Statements of Earnings and Retained Income
(Unaudited)
-------------------------------------------------------
<CAPTION>
Three Months Ended Twelve Months Ended
March 31, March 31,
------------------ --------------------
1999 1998 1999 1998
-------- -------- --------- ---------
(In Millions, except Per Share Data)
<S> <C> <C> <C> <C>
Revenue
Sales of electricity $ 389.9 $ 366.3 $ 1,896.3 $ 1,796.5
Other electric revenue 4.7 3.5 14.5 9.7
-------- -------- --------- ---------
Total Operating Revenue 394.6 369.8 1,910.8 1,806.2
Interchange deliveries 34.4 10.6 201.7 48.6
-------- -------- --------- ---------
Total Revenue 429.0 380.4 2,112.5 1,854.8
-------- -------- --------- ---------
Operating Expenses
Fuel 81.1 82.0 379.3 323.1
Purchased energy 63.2 40.4 292.6 189.9
Capacity purchase payments 53.5 40.0 169.3 154.9
Other operation 53.3 56.0 235.0 224.5
Maintenance 23.3 20.0 94.8 94.1
-------- -------- --------- ---------
Total Operation and Maintenance 274.4 238.4 1,171.0 986.5
Depreciation and amortization 61.2 58.8 242.2 233.3
Income taxes 5.0 1.5 134.0 113.9
Other taxes 44.1 45.8 202.6 202.1
-------- -------- --------- ---------
Total Operating Expenses 384.7 344.5 1,749.8 1,535.8
-------- -------- --------- ---------
Operating Income 44.3 35.9 362.7 319.0
-------- -------- --------- ---------
Other Income (Loss)
Nonutility Subsidiary
Income 55.8 36.1 163.2 121.4
Expenses, including interest
and income taxes (51.3) (29.8) (149.9) (111.5)
-------- -------- --------- ---------
Net earnings from nonutility
subsidiary 4.5 6.3 13.3 9.9
Allowance for other funds used during
construction and capital cost recovery factor 0.2 0.3 1.3 5.3
Contract termination fee 23.2 - 23.2 -
Write-off of merger costs - - - (52.5)
Other, net (8.3) 0.8 (5.9) 24.2
-------- -------- --------- ---------
Total Other Income (Loss) 19.6 7.4 31.9 (13.1)
-------- -------- --------- ---------
Income Before Utility Interest Charges 63.9 43.3 394.6 305.9
-------- -------- --------- ---------
Utility Interest Charges
Long-term debt 34.2 34.4 136.7 135.3
Distributions on preferred securities of
subsidiary company 2.3 - 8.0 -
Other 2.3 2.5 8.9 11.5
Allowance for borrowed funds used during
construction and capital cost recovery factor (0.9) (1.1) (3.8) (7.3)
-------- -------- --------- ---------
Net Utility Interest Charges 37.9 35.8 149.8 139.5
-------- -------- --------- ---------
Net Income 26.0 7.5 244.8 166.4
Dividends on preferred stock 2.0 4.1 9.3 16.6
Redemption premium on preferred stock - - 6.6 -
-------- -------- --------- ---------
Earnings for Common Stock 24.0 3.4 228.9 149.8
Retained Income at Beginning of Period 747.3 734.3 690.2 730.2
Dividends on Common Stock (49.2) (49.1) (196.7) (196.6)
Subsidiary Marketable Securities, Net
Unrealized (Loss) Gain, Net of Tax (0.2) 1.6 (0.5) 6.8
-------- -------- --------- ---------
Retained Income at End of Period $ 721.9 $ 690.2 $ 721.9 $ 690.2
======== ======== ========= =========
Basic Average Common Shares
Outstanding 118.5 118.5 118.5 118.5
Basic Earnings Per Common Share $0.20 $0.03 $1.93 $1.26
Diluted Average Common Shares
Outstanding 118.5 118.5 124.2 124.3
Diluted Earnings Per Common Share $0.20 $0.03 $1.89 $1.26
Cash Dividends Per Common Share $0.415 $0.415 $1.66 $1.66
Book Value Per Share $15.62 $15.35
Dividend Payout Ratio 86.0% 131.7%
Effective Federal Income Tax Rate 32.2% 27.4%
2
</TABLE>
<TABLE>
POTOMAC ELECTRIC POWER COMPANY
Consolidated Balance Sheets
(Unaudited at March 31, 1999 and 1998)
--------------------------------------
<CAPTION>
March 31, December 31, March 31,
ASSETS 1999 1998 1998
------ ---------- ------------ ----------
(Millions of Dollars)
<S> <C> <C> <C>
Property and Plant - at original cost
Electric plant in service $ 6,560.9 $ 6,539.9 $ 6,401.8
Construction work in progress 84.6 73.2 98.0
Electric plant held for future use 2.2 4.3 4.2
Nonoperating property 42.5 40.4 22.8
---------- ------------ ----------
6,690.2 6,657.8 6,526.8
Accumulated depreciation (2,173.2) (2,136.6) (2,046.4)
---------- ------------ ----------
Net Property and Plant 4,517.0 4,521.2 4,480.4
---------- ------------ ----------
Current Assets
Cash and cash equivalents 82.8 6.4 6.1
Customer accounts receivable, less allowance
for uncollectible accounts of $2.2, $2.4 and $2.2 109.8 114.9 115.8
Other accounts receivable, less allowance for
uncollectible accounts of $.3 39.5 44.8 35.1
Accrued unbilled revenue 68.5 65.6 63.6
Prepaid taxes 17.9 34.7 16.8
Other prepaid expenses 7.3 3.3 4.9
Material and supplies - at average cost
Fuel 52.6 53.3 56.2
Construction and maintenance 69.6 68.7 69.4
---------- ------------ ----------
Total Current Assets 448.0 391.7 367.9
---------- ------------ ----------
Deferred Charges
Income taxes recoverable through future rates, net 230.8 232.5 236.7
Conservation costs, net 187.3 197.5 217.1
Unamortized debt reacquisition costs 49.2 49.9 52.0
Other 203.4 175.6 158.6
---------- ------------ ----------
Total Deferred Charges 670.7 655.5 664.4
---------- ------------ ----------
Nonutility Subsidiary Assets
Cash and cash equivalents 8.3 79.6 4.5
Marketable securities 232.2 231.1 265.2
Investment in finance leases 395.6 399.2 461.5
Operating lease equipment, net of accumulated
depreciation of $125.9, $120.1 and $123.5 116.8 122.6 147.4
Receivables, less allowance for uncollectible
accounts of $4.8, $5.0 and $6.0 55.3 55.6 39.6
Other investments 124.0 120.6 171.3
Other assets 20.2 23.1 13.4
Deferred income taxes 43.6 25.6 51.0
---------- ------------ ----------
Total Nonutility Subsidiary Assets 996.0 1,057.4 1,153.9
---------- ------------ ----------
Total Assets $ 6,631.7 $ 6,625.8 $ 6,666.6
========== ============ ==========
CAPITALIZATION AND LIABILITIES
- ------------------------------
Capitalization
Common stock $ 118.5 $ 118.5 $ 118.5
Other common equity 1,733.5 1,758.9 1,700.6
Serial preferred stock 100.0 100.0 125.0
Redeemable serial preferred stock 50.0 50.0 141.0
Company obligated mandatorily redeemable preferred
securities of subsidiary trust which holds solely
parent junior subordinated debentures 125.0 125.0 -
Long-term debt 1,963.8 1,859.0 1,902.2
---------- ------------ ----------
Total Capitalization 4,090.8 4,011.4 3,987.3
---------- ------------ ----------
Other Non-Current Liabilities
Capital lease obligations 156.9 157.6 159.7
---------- ------------ ----------
Current Liabilities
Long-term debt and preferred stock redemption 207.6 45.2 1.0
Short-term debt - 191.7 225.0
Accounts payable and accrued expenses 187.7 193.2 174.2
Capital lease obligations due within one year 20.8 20.8 20.8
Other 94.1 95.8 89.1
---------- ------------ ----------
Total Current Liabilities 510.2 546.7 510.1
---------- ------------ ----------
Deferred Credits
Income taxes 1,052.8 1,049.2 1,033.5
Investment tax credits 52.7 53.7 56.4
Other 23.6 24.6 19.5
---------- ------------ ----------
Total Deferred Credits 1,129.1 1,127.5 1,109.4
---------- ------------ ----------
Nonutility Subsidiary Liabilities
Long-term debt 654.9 716.9 702.3
Short-term notes payable 10.0 - 113.2
Other 79.8 65.7 84.6
---------- ------------ ----------
Total Nonutility Subsidiary Liabilities 744.7 782.6 900.1
---------- ------------ ----------
Total Capitalization and Liabilities $ 6,631.7 $ 6,625.8 $ 6,666.6
========== ============ ==========
3
</TABLE>
<TABLE>
POTOMAC ELECTRIC POWER COMPANY
Consolidated Statements of Cash Flows
(Unaudited)
-------------------------------------
<CAPTION>
Three Months Ended Twelve Months Ended
March 31, March 31,
--------------------- -------------------
1999 1998 1999 1998
------- ------- ------- -------
(Millions of Dollars)
<S> <C> <C> <C> <C>
Operating Activities
Income from utility operations $ 21.5 $ 1.2 $ 231.5 $ 156.5
Adjustments to reconcile income to net
cash from operating activities:
Depreciation and amortization 61.2 58.8 242.2 233.3
Deferred income taxes and investment tax credits 5.4 6.2 22.3 54.5
Deferred conservation costs (2.2) (7.0) (19.5) (33.9)
Allowance for funds used during construction
and capital cost recovery factor (1.1) (1.4) (5.1) (12.6)
Changes in materials and supplies (0.2) 2.0 3.4 17.7
Changes in accounts receivable and accrued unbilled revenue 7.7 3.5 (3.2) (2.0)
Changes in contract termination fee receivable (23.4) - (23.4) -
Changes in accounts payable 6.8 (16.0) 10.2 11.5
Changes in other current assets and liabilities (2.6) 19.7 3.5 18.4
Changes in deferred merger costs - - - 33.6
Net other operating activities (6.8) (11.9) (23.8) (61.3)
Nonutility subsidiary:
Net earnings 4.5 6.3 13.3 9.9
Deferred income taxes (17.9) (52.1) 7.7 (94.1)
Changes in other assets and net other operating activities 30.4 24.8 7.3 61.9
------- ------- ------- -------
Net Cash From Operating Activities 83.3 34.1 466.4 393.4
------- ------- ------- -------
Investing Activities
Total investment in property and plant (40.8) (38.3) (214.2) (227.4)
Allowance for funds used during construction
and capital cost recovery factor 1.1 1.4 5.1 12.6
------- ------- ------- -------
Net investment in property and plant (39.7) (36.9) (209.1) (214.8)
Nonutility subsidiary:
Purchase of marketable securities (9.2) (0.5) (9.7) (12.5)
Proceeds from sale or redemption of marketable securities 7.6 40.3 43.9 69.8
Proceeds from sale of assets - 11.0 94.9 45.2
Purchase of other investments (6.5) (12.6) (18.9) (17.3)
Proceeds from sale or distribution of other investments 0.7 2.7 32.4 16.7
Net proceeds from promissory notes - - - 34.1
Net proceeds from liquidation of partnership 8.4 - 8.4 -
Net gain upon liquidation of partnership (9.5) - (9.5) -
------- ------- ------- -------
Net Cash (Used By) From Investing Activities (48.2) 4.0 (67.6) (78.8)
------- ------- ------- -------
Financing Activities
Dividends on common stock (49.2) (49.1) (196.7) (196.6)
Dividends on preferred stock (2.0) (4.1) (9.3) (16.6)
Redemption of preferred stock - (0.1) (123.6) (1.6)
Issuance of mandatorily redeemable preferred securities - - 125.0 -
Issuance of long-term debt 266.6 - 266.6 182.3
Reacquisition and retirement of long-term debt (0.2) (51.1) (0.2) (201.1)
Short-term debt, net (191.7) 93.6 (225.0) 51.5
Other financing activities (1.5) (0.1) (4.5) (1.5)
Nonutility subsidiary:
Issuance of long-term debt 36.1 10.7 245.6 50.7
Repayment of long-term debt (98.1) (138.8) (293.0) (337.8)
Short-term debt, net 10.0 105.5 (103.2) 112.2
------- ------- ------- -------
Net Cash Used By Financing Activities (30.0) (33.5) (318.3) (358.5)
------- ------- ------- -------
Net Increase (Decrease) in Cash and Cash Equivalents 5.1 4.6 80.5 (43.9)
Cash and Cash Equivalents at Beginning of Period 86.0 6.0 10.6 54.5
------- ------- ------- -------
Cash and Cash Equivalents at End of Period $ 91.1 $ 10.6 $ 91.1 $ 10.6
======= ======= ======= =======
Cash paid for interest (net of capitalized interest of $.2,
$.2, $.6 and $.5) and income taxes
Interest (including nonutility subsidiary interest of
$21.2, $27.4, $52.2 and $67.5) $ 63.1 $ 67.2 $ 194.5 $ 196.7
Income taxes (including nonutility subsidiary) $ (7.2) $ - $ 61.6 $ 10.7
4
</TABLE>
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
- ------------------------------------------
Organization
- ------------
Potomac Electric Power Company (the Company) is engaged in
the generation, transmission, distribution and sale of electric
energy in the Washington, D.C. metropolitan area. The Company's
retail service territory includes all of the District of Columbia
and major portions of Montgomery and Prince George's counties in
suburban Maryland. In addition, the Company supplies
electricity, at wholesale, under a full-requirements agreement
with Southern Maryland Electric Cooperative, Inc. (SMECO). The
Company also delivers economy energy to the Pennsylvania-New
Jersey-Maryland Interconnection LLC (PJM) of which the Company is
a member. PJM is composed of more than 100 electric utilities,
independent power producers, power marketers, cooperatives and
municipals which operate on a fully integrated basis.
Potomac Capital Investment Corporation (PCI), a wholly owned
subsidiary of the Company, was formed in 1983. PCI's principal
new business activity has been the development and expansion of
operating businesses in the competitive markets for energy and
telecommunications products and services. PCI continues to
manage a substantial portfolio of financial investments including
securities, direct finance and leveraged leases, real estate and
structured finance transactions.
Potomac Electric Power Company Trust I (Trust), a Delaware
statutory business trust and a wholly owned subsidiary of the
Company, was established in April 1998. The Trust exists for the
exclusive purposes of (i) issuing Trust securities representing
undivided beneficial interests in the assets of the Trust, (ii)
investing the gross proceeds from the sale of the Trust
Securities in Junior Subordinated Deferrable Interest Debentures
issued by the Company, and (iii) engaging only in other
activities as necessary or incidental to the foregoing.
Basis of Presentation
- ---------------------
The information furnished in the accompanying Consolidated
Statements of Earnings and Retained Income, Consolidated Balance
Sheets and Consolidated Statements of Cash Flows reflects all
adjustments (which consist only of normal recurring accruals)
which are, in the opinion of management, necessary for a fair
presentation of the results of operations for the interim
periods. The accompanying consolidated financial statements and
notes thereto should be read in conjunction with the consolidated
financial statements and notes included in the Company's 1998
Annual Report to the Securities and Exchange Commission on Form
10-K.
5
Certain prior year amounts have been reclassified to conform
to the current year presentation.
(1) SMECO Agreement
---------------
As discussed in Item 7. Management's Discussion and Analysis
of Financial Condition and Results of Operations of the Company's
1998 Form 10-K, the new full-requirements agreement was accepted
by the Federal Energy Regulatory Commission (FERC) on February 9,
1999, without change or modification, and became effective on
January 1, 1999. Accordingly, during the first quarter of 1999,
the Company recorded pre-tax income of $23.2 million. This
amount is classified as "other deferred charges" on the Company's
Consolidated Balance Sheet as of March 31, 1999. In accordance
with Accounting Principles Board Opinion No. 21 "Interest on
Receivables and Payables," the amount owed by SMECO requires the
imputation of interest and therefore the Company is amortizing
the $2.8 million difference between the present value of the
termination payment and its face amount ($26 million) through
December 31, 2000 using the effective interest method at a 6%
interest rate. The 6% interest rate approximates the rate the
Company could earn on a two year treasury instrument. The
Company recorded $.2 million in interest income during the first
quarter of 1999 related to the amortization of the $2.8 million
difference.
(2) Comprehensive Income
--------------------
The Company's components of comprehensive income are net
income, and unrealized gains and losses on marketable securities.
Comprehensive income totaled $25.8 million and $244.3 million for
the three and twelve months ended March 31, 1999, compared to
$9.1 million and $173.2 million in the corresponding periods
ended March 31, 1998.
6
<TABLE>
(2) INCOME TAXES
- ----------------
Provision for Income Taxes
- --------------------------
<CAPTION>
Three Months Ended Twelve Months Ended
March 31, March 31,
----------------------- -----------------------
1999 1998 1999 1998
-------- -------- -------- --------
(Millions of Dollars)
<S> <C> <C> <C> <C>
Utility current tax expense
Federal $ 7.5 $ (3.5) $ 106.8 $ 35.2
State and local 1.1 (1.1) 14.3 4.4
-------- -------- -------- --------
Total utility current tax expense 8.6 (4.6) 121.1 39.6
-------- -------- -------- --------
Utility deferred tax expense
Federal 5.4 5.5 22.3 50.4
State and local 0.9 1.6 3.7 7.7
Investment tax credits (1.0) (0.9) (3.7) (3.6)
-------- -------- -------- --------
Total utility deferred tax expense 5.3 6.2 22.3 54.5
-------- -------- -------- --------
Total utility income tax expense 13.9 1.6 143.4 94.1
-------- -------- -------- --------
Nonutility subsidiary current tax expense
Federal 8.1 14.3 9.2 37.5
Nonutility subsidiary deferred tax expense
Federal (9.0) (14.7) (18.4) (56.8)
-------- -------- -------- --------
Total nonutility subsidiary income tax expense (0.9) (0.4) (9.2) (19.3)
-------- -------- -------- --------
Total consolidated income tax expense 13.0 1.2 134.2 74.8
Income taxes included in other income 8.0 (0.3) 0.2 (39.1)
-------- -------- -------- --------
Income taxes included in utility operating expenses $ 5.0 $ 1.5 $ 134.0 $ 113.9
======== ======== ======== ========
7
</TABLE>
<TABLE>
Reconciliation of Consolidated Income Tax Expense
- -------------------------------------------------
<CAPTION>
Three Months Ended Twelve Months Ended
March 31, March 31,
----------------------- -----------------------
1999 1998 1999 1998
-------- -------- -------- --------
(Millions of Dollars)
<S> <C> <C> <C> <C>
Income before income taxes $ 39.0 $ 8.7 $ 379.0 $ 241.2
======== ======== ======== ========
Utility income tax at federal
statutory rate $ 12.4 $ 1.0 $ 131.2 $ 87.7
Increases (decreases) resulting from
Depreciation 2.8 2.8 10.9 11.1
Removal costs (1.4) (1.3) (6.1) (5.8)
Allowance for funds used during
construction 0.2 0.2 0.5 0.9
Other (0.4) (0.5) (0.8) (3.8)
State income taxes, net of federal effect 1.3 0.3 11.7 7.9
Tax credits (1.0) (0.9) (4.0) (3.9)
-------- -------- -------- --------
Total utility income tax expense 13.9 1.6 143.4 94.1
-------- -------- -------- --------
Nonutility subsidiary income tax at federal
statutory rate 1.3 2.0 1.5 (3.3)
Decreases resulting from
Dividends received deduction (1.0) (1.2) (4.2) (5.1)
Reversal of previously accrued deferred taxes - - (1.0) -
Other (1.2) (1.2) (5.5) (10.9)
-------- -------- -------- --------
Total nonutility subsidiary income tax credit (0.9) (0.4) (9.2) (19.3)
-------- -------- -------- --------
Total consolidated income tax expense 13.0 1.2 134.2 74.8
Income taxes, included in other income 8.0 (0.3) 0.2 (39.1)
-------- -------- -------- --------
Income taxes included in utility operating expenses $ 5.0 $ 1.5 $ 134.0 $ 113.9
======== ======== ======== ========
8
</TABLE>
<TABLE>
Components of Consolidated Deferred Tax Liabilities (Assets)
- ------------------------------------------------------------
<CAPTION>
Mar. 31, Dec. 31, Mar. 31,
1999 1998 1998
-------- -------- --------
(Millions of Dollars)
<S> <C> <C> <C>
Utility deferred tax liabilities (assets)
Depreciation and other book to tax
basis differences $ 897.8 $ 891.6 $ 877.3
Rapid amortization of certified pollution
control facilities 26.8 27.2 25.4
Deferred taxes on amounts to be collected
through future rates 87.4 88.0 89.6
Property taxes 13.0 12.9 13.6
Deferred fuel (8.5) (9.7) (6.1)
Prepayment premium on debt retirement 18.6 18.9 19.7
Deferred investment tax credit (20.0) (20.3) (21.4)
Contributions in aid of construction (32.5) (32.0) (30.2)
Contributions to pension plan 22.1 22.1 18.2
Conservation costs (demand side management) 50.4 49.4 47.1
Other 17.4 19.7 19.3
-------- -------- --------
Total utility deferred tax liabilities, net 1,072.5 1,067.8 1,052.5
Current portion of utility deferred tax liabilities
(included in Other Current Liabilities) 19.7 18.6 19.0
-------- -------- --------
Total utility deferred tax liabilities, net - non-current $1,052.8 $1,049.2 $1,033.5
======== ======== ========
Nonutility subsidiary deferred tax liabilities (assets)
Finance leases $ 123.8 $ 134.3 $ 112.9
Operating leases 5.6 5.0 23.9
Alternative minimum tax (43.6) (43.6) (97.1)
Assets with a tax basis greater than book basis (46.5) (46.0) (38.9)
Other (82.9) (75.3) (51.8)
-------- -------- --------
Total nonutility subsidiary deferred tax liabilities
(assets), net $ (43.6) $ (25.6) $ (51.0)
======== ======== ========
9
</TABLE>
(4) Capitalization and Fair Value of Financial Instruments
------------------------------------------------------
Common Equity
- -------------
At March 31, 1999, 118,527,287 shares of the Company's $1
par value Common Stock were outstanding. A total of 200 million
shares is authorized. As of March 31, 1999, 2,324,721 shares
were reserved for issuance under the Shareholder Dividend
Reinvestment Plan; 1,221,624 shares were reserved for issuance
under the Employee Savings Plans; and 2,769,412 and 3,392,500
shares were reserved for conversion of the 7% and 5% Convertible
Debentures, respectively.
Serial Preferred, Redeemable Serial Preferred and Preference
- ------------------------------------------------------------
Stock, Company Obligated Mandatorily Redeemable Preferred
---------------------------------------------------------
Securities and Long-Term Debt
-----------------------------
On June 1, 1998, the Company redeemed 60,000 shares of
Serial Preferred Stock, $3.37 series of 1987, at $50 per share
for sinking fund purposes. The Company also redeemed in
accordance with their terms, all of the 779,696 shares remaining
after the sinking fund redemption of Serial Preferred Stock,
$3.37 series of 1987, at $51.13 per share; all of the 500,000
shares of Serial Preferred Stock, $3.82 series of 1969, at $51.00
per share; and all of the 1,000,000 shares of Serial Preferred
Stock, $3.89 series of 1991, at $53.89 per share. The redemption
totaled $123.7 million and includes $6.6 million in premiums.
At March 31, 1999, the Company had outstanding 3,000,000
shares of its $50 par value Serial Preferred Stock, including the
Redeemable Serial Preferred Stock. A total of 8,750,000 shares
is authorized. At March 31, 1999, the aggregate annual dividend
requirements on the Serial Preferred Stock and the Redeemable
Serial Preferred Stock were approximately $4.7 million and $3.4
million, respectively. Also, the Company has a total of
8,800,000 shares of cumulative, $25 par value, Preference Stock
authorized and unissued.
At March 31, 1999, the Company had outstanding one million
shares of its Serial Preferred Stock, Auction Series A. The
annual dividend rate is 4.625% ($2.3125) for the period March 1,
1999, through May 31, 1999. For the period December 1, 1998,
through February 28, 1999, the annual dividend rate was 4.2%
($2.10). The average rate at which dividends were paid during
the twelve months ended March 31, 1999, was 4.15% ($2.08).
10
At March 31, 1999, the Company had outstanding one million
shares of Redeemable Serial Preferred Stock, $3.40 (6.80%) Series
of 1992, on which the sinking fund requirement commences
September 1, 2002. The sinking fund requirement in 2002 and 2003
with respect to this series is $2.5 million.
In May 1998, the Trust, of which the Company owns all of the
common securities, issued $125 million of 7-3/8% Trust Originated
Preferred Securities (TOPrS). The proceeds from the sale of the
TOPrS and from the common securities of the Trust to the Company
were used by the Trust to purchase from the Company $128.9
million of 7-3/8% Junior Subordinated Deferrable Interest
Debentures, due June 1, 2038. The sole assets of the Trust are
the Subordinated Debentures. The Trust will use interest
payments received on the Subordinated Debentures to make
quarterly cash distributions on the TOPrS. Proceeds from the
sale of the Subordinated Debentures to the Trust were used by the
Company to redeem three series of serial preferred stock on June
1, 1998.
Additionally, as discussed in Item 7. Management's
Discussion and Analysis of Financial Condition and Results of
Operations - Subsequent Events - "Sale of First Mortgage Bonds,"
of the Company's 1998 Form 10-K, on March 17, 1999, the Company
sold $270 million of 6% First Mortgage Bonds maturing April 1,
2004.
At March 31, 1999, the aggregate annual interest requirement
on the Company's long-term debt and Company obligated mandatorily
redeemable preferred securities of subsidiary trust, including
debt due within one year, was $155 million; and the aggregate
amounts of long-term debt maturities are zero in 2000, $165
million in 2001, $190 million in 2002 and $90 million in 2003.
At March 31, 1999, long-term debt due within one year consisted
of $45 million of 4-1/2% First Mortgage Bonds, $100 million of 9%
First Mortgage Bonds and $62.6 million of 7% Convertible
Debentures.
11
The estimated fair values of the Company's financial
instruments at March 31, 1999, net of amounts due within one
year, are summarized below:
Carrying Fair
Amount Value
---------- ----------
(Millions of Dollars)
Utility
Capitalization and Liabilities
Serial preferred stock $ 100.0 $ 95.4
======== ========
Redeemable serial preferred stock $ 50.0 $ 53.6
======== ========
Company obligated mandatorily
redeemable preferred securities
of subsidiary trust which holds
solely parent junior subordinated
debentures $ 125.0 $ 128.1
======== ========
Long-term debt
First mortgage bonds (net of
unamortized premium and
discount of $16.5) $1,575.3 $1,616.6
Medium-term notes (net of
unamortized discount of $1.7) 281.4 292.6
Convertible debentures (net of
unamortized discount of $7.9) 107.1 110.1
-------- --------
Total long-term debt $1,963.8 $2,019.3
======== ========
Nonutility Subsidiary
Assets
Marketable securities (primarily
mandatorily redeemable preferred
stock) $ 232.2 $ 232.2
======== ========
Notes receivable $ 25.2 $ 22.1
======== ========
Liabilities
Long-term debt $ 654.9 $ 663.3
======== ========
The following methods and assumptions were used to estimate,
at March 31, 1999, the fair value of each class of financial
instrument shown above for which it is practicable to estimate
that value.
12
The fair values of the Company's Serial preferred stock,
Redeemable serial preferred stock and TOPrS were based on quoted
market prices or discounted cash flows using current rates of
preferred stock with similar terms.
The fair values of the Company's Long-term debt, which
includes First mortgage bonds, Medium-term notes and Convertible
debentures, excluding amounts due within one year, were based on
current market price, or for issues with no market price
available, were based on discounted cash flows using current
rates for similar issues with similar terms and remaining
maturities.
The fair value of PCI's Marketable securities was based on
quoted market prices.
The fair value of PCI's Notes receivable was based on
discounted future cash flows using current rates and similar
terms.
The fair value of PCI's Long-term debt, including non-
recourse debt, was based on current rates offered to similar
companies for debt with similar remaining maturities.
The carrying amounts of all other financial instruments
approximate fair value.
13
<TABLE>
Calculations of Earnings Per Share
- ----------------------------------
Reconciliations of the numerator and denominator for basic and diluted
earnings per common share are shown below.
<CAPTION>
Three Months Ended Twelve Months Ended
March 31, March 31,
------------------ ---------------------
1999 1998 1999 1998
----- ----- ------ ------
(Millions except Per Share Data)
<S> <C> <C> <C> <C>
Income (Numerator):
Earnings applicable to common stock $24.0 $3.4 $228.9 $149.8
Add: Interest paid or accrued on
Convertible Debentures,
net of related taxes - <F1> - <F1> 6.3 6.4
----- ----- ------ ------
Earnings applicable to common stock,
assuming conversion of convertible
securities $24.0 $3.4 $235.2 $156.2
===== ===== ====== ======
Shares (Denominator):
Average shares outstanding for
computation of basic earnings
per common share 118.5 118.5 118.5 118.5
===== ===== ====== ======
Average shares outstanding for
diluted computation:
Average shares outstanding 118.5 118.5 118.5 118.5
Additional shares resulting from:
Conversion of 7% Convertible
Debentures - <F1> - <F1> 2.3 2.4
Conversion of 5% Convertible
Debentures - <F1> - <F1> 3.4 3.4
----- ----- ------ ------
Average shares outstanding for
computation of diluted
earnings per common share 118.5 118.5 124.2 124.3
===== ===== ====== ======
Basic earnings per common share $0.20 $0.03 $1.93 $1.26
Diluted earnings per common share $0.20 $0.03 $1.89 $1.26
<FN>
<F1> These amounts are not reflected in the computation of diluted EPS because the effects
are antidilutive and would increase diluted EPS.
</FN>
14
</TABLE>
Nonutility Subsidiary Long-Term Debt
- ------------------------------------
Long-term debt at March 31, 1999, consisted primarily of
unsecured borrowings from institutional lenders. The interest
rates of such borrowings ranged from 5% to 10.1%. The weighted
average effective interest rate was 7.21% at March 31, 1999,
7.35% at December 31, 1998, and 7.41% at March 31, 1998. Annual
aggregate principal repayments on these borrowings are $73
million in 1999, $147.5 million in 2000, $88.5 million in 2001,
$93 million in 2002, $134.5 million in 2003 and $100.2 million
thereafter. Also included in long-term debt is $18.2 million of
non-recourse debt which is due in monthly installments with final
maturities in 2002 and 2011.
Nonutility Subsidiary Contractual Maturities
- --------------------------------------------
At March 31, 1999, the contractual maturities for
mandatorily redeemable preferred stock are $7.7 million within
one year, $93.8 million from one to five years, $97.7 million
from five to 10 years and $20.4 million for over 10 years.
15
(5) Commitments and Contingencies
-----------------------------
Competition
- -----------
For additional information refer to Item 7. Management's
Discussion and Analysis of Financial Condition and Results of
Operations of the Company's 1998 Form 10-K and Item 5. "Other
Information," herein.
Proposed Sale of Generating Assets
- ----------------------------------
On February 3, 1999, the Company filed an Agreement of
Stipulation and Settlement (the Agreement) concerning the
Company's Maryland stranded cost adjudication proceeding, an
element of the transition to electricity competition in Maryland.
Under the Agreement, if approved by the Maryland Public Service
Commission (the Maryland Commission) and if all other conditions
to the Agreement are satisfied, the Company will sell all of its
plants, facilities and equipment used in the generation of
electricity and its other rate-based assets that are not required
for the provision of electric transmission and distribution
services located both in Maryland and elsewhere (collectively,
the "generation assets"). The net book value of these assets at
March 31, 1999 is approximately $1.9 billion.
On March 16, 1999, the Company filed an application with the
District of Columbia Public Service Commission (D.C. Commission)
requesting its approval of the sale of the Company's generation
assets (see the disclosure related to this filing located in Item
5. "Other Information" in the "Competition - District of
Columbia" section, herein). Additionally, on April 2, 1999, the
Maryland General Assembly approved legislation enabling
competition and customer choice, including legislation that
modifies the taxation of Maryland utilities and it was signed by
the Governor of Maryland (see the disclosure related to this
filing located in Item 5. "Other Information" in the "Competition
- - Maryland" section, herein). The Agreement remains contingent
upon the approval of the Maryland Commission and the D.C.
Commission.
16
Environmental Contingencies
- ---------------------------
For a discussion of the Company's Environmental
Contingencies, in addition to the updated information disclosed
below, refer to Item 8. Financial Statements and Supplementary
Data, of the Company's 1998 Form 10-K.
On February 24, 1999, the Circuit Court for Baltimore City
declared the Maryland NOx Budget Proposal to be invalid and
remanded it to the Department of Environment.
The Company's generating stations operate under National
Pollutant Discharge Eliminating System (NPDES) permits. A NPDES
renewal application submitted in July 1993 for the Benning
station is pending. NPDES permits were issued for the Potomac
River station in February 1994, the Morgantown station in
February 1995, the Dickerson station in August 1996 and the Chalk
Point station in September 1996. An NPDES renewal application
was submitted for the Potomac River station in August 1998. At
this time resolution of the renewal application is pending.
Office Space Lease
- ------------------
The Company's current lease for office space expires in
March 2002. PCI is in the process of constructing and financing
a new 10-story facility at a cost of $92 million, which includes
329,000 square feet of office space for 1,200 of the Company's
employees. The Company will lease the office space through PCI.
The new building is scheduled to be completed in mid-2001.
(6) Segment Information
-------------------
The Company has identified the utility and nonutility
business operations as its two segments. The factors used to
identify these segments are that the Company organizes its
business around differences in products, services, and regulatory
environments and that the operating results for each segment are
regularly reviewed by the Company's chief operating decision-
maker in order to make decisions about resources and assess
performance.
Revenues for the utility segment are derived from the
generation, transmission, distribution and sale of electric
energy. The nonutility segment, which primarily consists of the
operations of the Company's wholly owned subsidiary, PCI, derives
its revenue from investment programs, energy-related businesses
and telecommunication services.
17
The following table presents information about the Company's
reportable segments for the three months ended March 31, 1999 and
March 31, 1998 and the year ended December 31, 1998. There are
no differences in the Company's basis of segmentation or in the
basis of measurement of segment profit or loss as outlined in
Item 8. Financial Statements and Supplementary Data of the
Company's 1998 Form 10-K.
Segment
Utility Nonutility Total
------- ---------- ---------
March 31, 1999
Revenues $ 429.0 $ 55.8 $ 484.8
Net Income 21.5 4.5 26.0
Net Income Before
Income Taxes 35.4 3.6 39.0
Income Tax Expense
(Credit) 13.9 (.9) 13.0
December 31, 1998
Revenues $2,063.9 $143.5 $2,207.4
Net Income 211.2 15.1 226.3
Net Income Before
Income Taxes 342.2 6.4 348.6
Income Tax Expense
(Credit) 131.0 (8.7) 122.3
March 31, 1998
Revenues $ 380.4 $ 36.1 $ 416.5
Net Income 1.2 6.3 7.5
Net Income Before
Income Taxes 2.8 5.9 8.7
Income Tax Expense
(Credit) 1.6 (.4) 1.2
The Company's revenues are earned primarily within the
United States and there were no material transactions between the
Company's segments.
* * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * *
This Quarterly Report on Form 10-Q, including the report of
PricewaterhouseCoopers LLP (on page 19) will automatically be
incorporated by reference in the Prospectuses constituting parts
of the Company's Registration Statements on Forms S-3 (Numbers
33-58810, 33-61379, 333-33495 and 333-66127) and Forms S-8
(Numbers 33-36798, 33-53685 and 33-54197), filed under the
Securities Act of 1933. Such report of PricewaterhouseCoopers
LLP, however, is not a "report" or "part of the Registration
Statement" within the meaning of Sections 7 and 11 of the
Securities Act of 1933 and the liability provisions of Section
11(a) of such Act do not apply.
18
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors
and Shareholders of
Potomac Electric Power Company
We have reviewed the accompanying consolidated balance sheets of
Potomac Electric Power Company and consolidated subsidiaries (the
Company) at March 31, 1999 and 1998, and the related consolidated
statements of earnings and retained income for the three and
twelve month periods then ended and the consolidated statements
of cash flows for the three and twelve month periods then ended.
These financial statements are the responsibility of the
Company's management.
We conducted our review in accordance with standards established
by the American Institute of Certified Public Accountants. A
review of interim financial information consists principally of
applying analytical procedures to financial data and making
inquiries of persons responsible for financial and accounting
matters. It is substantially less in scope than an audit
conducted in accordance with generally accepted auditing
standards, the objective of which is the expression of an opinion
regarding the financial statements taken as a whole.
Accordingly, we do not express such an opinion.
Based on our review, we are not aware of any material
modifications that should be made to the accompanying financial
information for it to be in conformity with generally accepted
accounting principles.
We have previously audited, in accordance with generally accepted
auditing standards, the consolidated balance sheet as of December
31, 1998, and the related consolidated statements of earnings and
consolidated statement of cash flows for the year then ended (not
presented herein); and in our report dated January 25, 1999, we
expressed an unqualified opinion on those consolidated financial
statements. In our opinion, the information set forth in the
accompanying consolidated balance sheet information as of
December 31, 1998, is fairly stated, in all material respects, in
relation to the consolidated balance sheet from which it has been
derived.
/s/ PricewaterhouseCoopers LLP
PricewaterhouseCoopers LLP
Washington, D.C.
May 11, 1999
19
Part I FINANCIAL INFORMATION
- ------ ---------------------
Item 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF CONSOLIDATED
- ------ ----------------------------------------------------
RESULTS OF OPERATIONS AND FINANCIAL CONDITION
---------------------------------------------
GENERAL
- -------
As an investor-owned electric utility, the Company is
capital intensive, with a gross investment in property and plant
of approximately $3 for each $1 of annual total revenue. The
costs associated with property and plant investment amounted to
45% and 46% of the Company's total revenue at March 31, 1999 and
December 31, 1998, respectively. Additionally, fuel and
purchased energy, capacity purchase payments and other operating
expenses were 55% and 54% of total revenue at March 31, 1999 and
December 31, 1998, respectively.
Potomac Capital Investment Corporation (PCI) conducts
nonutility investment programs and businesses with the objective
of supplementing current utility earnings and building long-term
shareholder value. Potomac Electric Power Company Turst I
(Trust) was established in April 1998 for the purposes of issuing
Trust Securities representing undivided beneficial interests in
the assets of the Trust, and investing the gross proceeds from
the sale of the Trust Securities in Junior Subordinated
Debentures of the Company.
The Company has two segments, consisting of its utility and
nonutility operations. The utility segment derives its revenue
from the generation, transmission, distribution and sale of
electric energy, while the nonutility segment, which primarily
consists of the operations of PCI, derives its revenue from
investment programs, energy-related businesses, and
telecommunication services. See the discussion in Note (6) of
the Notes to Consolidated Financial Statements - Segment
Information, for additional information.
As discussed in Note (5) of the Notes to the Consolidated
Financial Statements, Commitments and Contingencies - "Proposed
Sale of Generating Assets" on February 3, 1999, the Company
together with several other parties filed an Agreement of
Stipulation and Settlement concerning the Company's Maryland
stranded cost adjudication proceeding and the Company's intention
to sell its generating assets. Additionally, as discussed in
Note (1) of the Notes to the Consolidated Financial Statements,
"SMECO Agreement," the Company's new full-requirements power
supply agreement with the Southern Maryland Electric Cooperative
(SMECO) was accepted by the Federal Energy Regulatory Commission
(FERC) on February 9, 1999, without change or modification and
became effective on January 1, 1999.
20
FORWARD LOOKING STATEMENTS
- --------------------------
This Management's Discussion and Analysis of Consolidated
Results of Operations and Financial Condition contains forward
looking statements, as defined by the Private Securities
Litigation Act of 1995, with regard to matters that could have an
impact on the future operations, financial results or financial
condition of the Company. These statements are based on the
current expectations, estimates or projections of management and
are not guarantees of future performance. Actual results may
differ materially from those anticipated by the forward looking
statements, depending on the occurrence or nonoccurrence of
future events or conditions that are difficult to predict and
generally are beyond the control of the Company. All such
forward looking statements relating to the following matters are
qualified by the cautionary statements below and contained
elsewhere herein.
Growth in Demand, Sales and Capacity to Fulfill Demand
- ------------------------------------------------------
The actual growth in demand for and sales of electricity
within the Company's service territory may vary from the
statements made concerning the anticipated growth in demand and
sales, depending upon a number of factors, including weather
conditions, the competitive environment, general economic
conditions and the demographics of the Company's service
territory. Future construction expenditures (including the need
to construct additional generation capacity) may vary from the
projections, depending on the accuracy of management's
expectations regarding growth in demand for and sales of
electricity, regulatory developments including potential changes
in environmental regulations, and the evolution of the
competitive marketplace for electricity.
Competition
- -----------
Increased competition will have an impact on future results
of operations, which may be adverse, and will depend, among other
factors, upon governmental policies and regulatory actions,
including those of the FERC and the Maryland and District of
Columbia public service commissions, future economic conditions
and the influence exerted by emerging market forces over the
structure of the electric industry.
21
Year 2000 Readiness Disclosure
- ------------------------------
The Company has implemented a four-pronged approach to
address compliance with the Year 2000 processing requirements of
its computer systems. The phases being addressed are: Corporate
Applications Readiness, which includes all large core business
systems; Embedded Systems, which include all operating and
control systems; End-User Computing Systems, which are all
systems which are not considered core business systems but
contain date calculations; and Business Partners' Systems and
Vendor Supply-Chain Verification, which is intended to monitor
suppliers' readiness for Year 2000 processing. A database has
been developed to identify and track the progress of work on each
phase. The target date for completion of these phases is mid-
1999. The cost or consequences of a material incomplete or
untimely resolution of the Year 2000 problem could adversely
affect future operations, financial results or financial
condition of the Company.
UTILITY
- -------
RESULTS OF OPERATIONS
- ---------------------
Total Revenue
- -------------
Total revenue increased for the three and twelve months
ended March 31, 1999, as compared to the corresponding periods in
1998. The increases in revenue from sales of electricity for the
periods ending March 31, 1999, resulted primarily from increases
in kilowatt-hour sales of 4.7% and 3.9% over the corresponding
periods in 1998. Although temperatures in the first quarter, as
measured in heating degree days, were 15% colder than the
corresponding period in 1998, they were still 3% warmer than the
20-year average. Summer temperatures in the twelve months ended
March 31, 1999, as measured in cooling degree hours, were 15%
hotter than the corresponding period ended March 31, 1998, yet
remained approximately 7% cooler than the 20-year average. The
increase in base rate revenue in the three months ended March 31,
1999, compared to the corresponding period in 1998, reflects the
effects of a $19 million increase in Maryland base rates
(pursuant to a December 1998 settlement agreement) and a $9
million increase in the District of Columbia Demand Side
Management (DSM) surcharge tariff effective September 1998. In
addition, the increase in base rate revenue in the twelve months
ended March 31, 1999, reflects the effects of a $24 million
increase in Maryland base rates pursuant to a November 1997
settlement agreement.
22
Interchange deliveries increased for the three and twelve
months ended March 31, 1999, as compared to the corresponding
periods in 1998. The increases for the periods reflect changes
in levels and prices of energy delivered to the Pennsylvania-New
Jersey-Maryland Interconnection LLC (PJM) and increases in the
levels of bilateral energy transactions under the Company's
wholesale power sales tariff.
The Company receives point-to-point transmission service
revenue, pursuant to open access transmission tariffs. Such
revenues are classified as "Other electric revenue," and totaled
$1.2 million and $4.9 million for the three and twelve months
ended March 31, 1999, and $.2 million and $1 million for the
corresponding periods in 1998. The benefits derived from
interchange deliveries, capacity sales in the District of
Columbia and revenue under the open access transmission tariff
are passed through to the Company's customers through fuel
adjustment clauses.
Recent rate orders received by the Company provided for
changes in annual base rate revenue as shown in the table below:
Rate
Increase
(Decrease) % Effective
Regulatory Jurisdiction ($000) Change Date
- ----------------------- ---------- ------- ---------------
Maryland $19,000 2.0 % December 1998
Federal - Wholesale (2,500) (1.8) January 1998
Maryland 24,000 2.6 November 1997
See Part II, Item 5, Base Rate Proceedings, for additional
information.
As discussed in Note (1) of the Notes to the Consolidated
Financial Statements, "SMECO Agreement," the Company has a new
full-requirements agreement with SMECO, effective January 1,
1999.
Operating Expenses
- ------------------
Fuel expense increased for the twelve months ended March 31,
1999, as compared to the corresponding period in 1998, primarily
due to an increase of 19.6% in net generation; partially offset
by a decrease in the system average unit cost of fuel discussed
below. Fuel expense in the three month periods ended March 31,
1999 and 1998 remained relatively unchanged. The increases in
purchased energy for the three and twelve months ended March 31,
1999, reflect changes in levels and prices of energy purchased
from PJM and other utilities and power marketers.
23
The unit fuel costs for the comparative periods ended March
31, were as follows:
Three Twelve
Months Ended Months Ended
March 31, March 31,
------------ ------------
1999 1998 1999 1998
----- ----- ----- -----
System Average
Fuel Cost per MBTU $1.64 $1.79 $1.69 $1.83
System average unit fuel cost decreased for the three and
twelve months ended March 31, 1999, as compared to the
corresponding periods in 1998, primarily due to decreases in the
costs of coal, residual oil and natural gas.
For the twelve month periods ended March 31, 1999 and 1998,
the Company obtained 84% and 89%, respectively, of its system
generation from coal based upon percentage of Btus. The
Company's major cycling and certain peaking units can burn either
natural gas or oil, adding flexibility in selecting the most
cost-effective fuel mix.
Capacity purchase payments increased for the three and
twelve months ended March 31, 1999, as compared to the
corresponding periods in 1998. These increases reflect
contractual escalations under existing purchase capacity
contracts with FirstEnergy and Panda-Brandywine (Panda).
Operating expenses other than fuel, purchased energy and
capacity purchase payments increased for the three and twelve
months ended March 31, 1999, as compared to the corresponding
periods in 1998, primarily due to increases in other operation
and maintenance expenses associated with winter storm damages and
Year 2000 remediation costs, partially offset by reduced labor
and benefits costs; increases in depreciation and amortization
expense associated with additional investment in property and
plant; and increases in income taxes resulting from increased
taxable income. Also, increases in the twelve months ended March
31, 1999, reflect nonrecurring charges of $8.2 million for
operating costs associated with the Company's Targeted Severance
Plan.
Year 2000 Readiness Disclosure
------------------------------
For a discussion of the Company's Year 2000 Readiness
Disclosure refer to Part II., Item 7., "Management's Discussion
and Analysis of Financial Condition and Results of Operations" of
the Company's 1998 Form 10-K.
24
As of March 31, 1999, approximately 99% of the changes
required to the 110 corporate IT systems have been made and
regression tested. The Company's mainframe computer system has
been partitioned so that a portion is isolated from the
production environment and used for Year 2000 full-cycle, or
"time machine," testing. A total of 85% of corporate IT systems
have been tested in the time machine. Among the major
applications successfully tested are the Customer Information,
Accounts Payable, Materials Management, and Construction
Management systems. End-user computing testing in the time
machine began in January 1999. A parallel LAN (local area
network) Year 2000 testing facility has been established. All
standard LAN office automation, operating systems and business
applications supported by Computer Services have been tested
successfully. The LAN test lab is currently available for
business units to test their applications.
Year 2000 upgrades to the distributed control systems of
Potomac River Units 1, 2, 3, 4 and 5 and Chalk Point Units 1, 2,
3 and 4 have been completed and tested. Remediation efforts are
in process at other plants and areas of the electric system. A
total of 97% of mission-critical substation, system protection
and distribution controls are Year 2000 ready as of March 31,
1999. The Energy Management System (EMS) is critical to the
operation of the electric system. Factory acceptance testing for
the Year 2000 mitigation software has successfully been completed
and the new software will be installed, tested, and operational
by June 1, 1999. In total, 85% of EMS/Substation Control and
Data Acquisition facilities are now Year 2000 ready. In addition
to including Year 2000 remediation and testing as part of
regularly scheduled plant outages, special Year 2000 outages have
been scheduled in the winter of 1998-99 and spring of 1999. The
target date for completion of Year 2000 readiness activities for
all critical plant-related components is June 30, 1999. This
target date may be impacted by the integration testing plans and
scheduled generation/electric systems outage decisions inherent
in embedded systems processing. As of March 31, 1999 based upon
the Company's evaluation to date, it appears that all identified
Year 2000 impacted processing components can be upgraded,
modified or otherwise made Year 2000 ready within acceptable time
frames.
The United States Department of Energy requested that the
North American Electric Reliability Council (NERC) prepare a
comprehensive report outlining the efforts of electric power
supply and delivery systems to prepare for Year 2000. NERC
collected data from utilities on a voluntary basis and issued
reports in September 1998, January 1999, and April 1999. In the
last update provided to NERC, the Company reported 100%
completion for both the inventory and assessment phases of Year
2000, and 93% completion in the remediation phase.
25
As of March 31, 1999, major challenges related to the
Company's Year 2000 readiness remain in three primary areas:
1) maintaining sufficient resources to complete Year 2000 tasks;
2) evaluating full-scale integrated testing requirements for many
embedded systems as planned outages, vendor recommendations and
economic decisions are taken into account; and 3) completing
viable business continuity planning for the variety of scenarios
which might occur.
There are two potential areas of resource constraints.
First, there is a risk of insufficient technically and
functionally knowledgeable people to remediate and test systems.
This situation is exacerbated by the relatively compact
remediation and testing schedule for April - June, especially the
timetable for plant outages. However, operating areas continue
to give increased attention to Year 2000 efforts to mitigate any
potential problems.
Second, the availability of vendor resources to both assist
in remediation and testing efforts, and produce in volume any
required component (e.g. chip upgrades) remains a concern. Thus
far, the Company appears to be in good position with respect to
securing commitments from various vendors.
Integration testing also presents a challenge because of
scheduling constraints and admonitions from some vendors
regarding the risks of testing. A careful evaluation of testing
options and vendor testing documentation is being made on a
component-by-component basis in order to determine the most
appropriate method for obtaining Year 2000 readiness.
Contingency and business continuation planning are in
various stages of development. These tasks have taken on a more
important role as the assessment process has been completed and
remediation efforts are well under way. It is important that
these activities be completed as soon as possible so that timely
decisions can be made regarding resource requirements, and public
confidence can be maintained in the Company's ability to provide
electric service. The Task Force is monitoring these efforts.
The Company's business continuity planning process includes
a review of emergency coordination interfaces with the community.
For example, a key facet of business continuity is the Company's
interface with various emergency management agencies. The
Company is participating with the Metropolitan Washington Council
of Governments (COG), which is looking at public safety issues on
a regional basis using existing regional public safety and
emergency management organizations. The Company presented a
planning status report to the Council of Governments in November
1998 and follow-up presentations at COG's March 1999 Year 2000
forum. The Company is also actively participating with emergency
management agencies in Year 2000 planning and drills. In
December 1998, the Company participated with the Montgomery
26
County Office of Emergency Preparedness in a countywide drill, as
well as in a PJM Interconnection drill. In January 1999, the
Company participated in a Maryland Emergency Management Agency
drill. The Company also participated successfully in the nation-
wide NERC-sponsored drill on April 9, 1999.
The final business continuity plan is on schedule to be
completed by June 30, 1999.
The Company agrees with NERC's January 1999 report to the
United States Department of Energy regarding the various Year
2000 scenarios that could occur. NERC has divided these into
"more probable scenario types," such as loss or unavailability of
a portion of generation, loss of a portion of system monitoring
and control functions, loss of voice communications, loss of a
portion of load, or uncharacteristic load; and "credible worst-
case scenarios," such as loss of a portion of transmission
facilities, underfrequency load shedding, and loss of intra- or
interregional communications. The Company's Business Continuity
Planning Team will be evaluating scenarios such as these and
developing appropriate response plans.
The cost or consequences of a material incomplete or
untimely resolution of the Year 2000 problem could adversely
affect future operations, financial results or financial
condition of the Company.
The cost of expected modifications will be approximately $12
million, and will be charged to expense as incurred. This
estimate may change as additional evaluations are completed and
remediation and testing progresses. Through March 31, 1999, $8.1
million has been charged to expense; the remaining costs will be
expensed in 1999. Approximately $1.1 million, or 9% and
approximately $5.9 million, or 49% of the total expected cost,
were expensed in the three and twelve months ended March 31,
1999, respectively.
CAPITAL RESOURCES AND LIQUIDITY
- -------------------------------
The Company's investment in property and plant, at original
cost before accumulated depreciation, was $6.7 billion at March
31, 1999, an increase of $32.4 million from the investment at
December 31, 1998, and an increase of $163.4 million from the
investment at March 31, 1998. Cash invested in property and
plant construction, excluding Allowance for Funds Used During
Construction and Capital Cost Recovery Factor, amounted to $39.7
million for the three months ended March 31, 1999, and $209.1
million for the twelve months then ended.
27
At March 31, 1999, the Company's capital structure,
excluding short-term debt, long-term debt due within one Year and
nonutility subsidiary debt, consisted of 48% long-term debt, 2.4%
serial preferred stock, 1.2% redeemable serial preferred stock,
3.1% Company obligated redeemable preferred securities of
subsidiary trust and 45.3% common equity.
Cash from utility operations, after dividends, was $15.1
million for the three months ended March 31, 1999, and $232.1
million for the twelve months then ended as compared with $1.9
million and $202.5 million, respectively, for the corresponding
periods ended March 31, 1998.
The Company's current annual dividend on common stock is
$1.66 per share. The dividend rate is determined by the
Company's Board of Directors and takes into consideration, among
other factors, current and possible future developments which may
affect the Company's income and cash flow levels. The Company
has no current plans to change the dividend; however, there can
be no assurance that the $1.66 dividend rate will be in effect in
the future.
In May 1998, the Trust issued $125 million of 7-3/8% Trust
Originated Preferred Securities.
In June 1998, the Company redeemed three series of serial
preferred stock. The redemption totaled $123.7 million and
includes $6.6 million in premiums.
The Company had no outstanding utility short-term debt at
March 31, 1999, compared to $191.7 million and $225 million
outstanding at December 31, 1998 and March 31, 1998,
respectively.
In August 1998, the Company filed for a 5.3% decrease in the
Maryland fuel rate, which became effective beginning the billing
month of September 1998, subject to refund. Also, in October
1998, the Company filed for an additional 6.3% decrease in the
Maryland fuel rate, which became effective beginning the billing
month of November 1998, subject to refund.
As discussed in Note (4) of the Notes to Consolidated
Financial Statements, "Capitalization and Fair Value of Financial
Instruments," on March 17, 1999, the Company sold $270 million of
6% First Mortgage Bonds maturing April 1, 2004.
28
NONUTILITY SUBSIDIARY
- ---------------------
RESULTS OF OPERATIONS
- ---------------------
Over the past few years, the focus of PCI and its
subsidiaries has expanded from financial investments in aircraft,
leases and securities to that of a provider of energy,
telecommunications and related products and services in the
Northern Virginia/Washington, D.C./Baltimore metropolitan area.
PCI is seeking to expand its focus by installing and employing
leading-edge technologies; by attempting to realize significant
economies of scale from multi-product marketing and the use of
common facilities and support services, wherever appropriate; and
by endeavoring to deliver high-quality, convenient and reliable
services at competitive prices.
PCI's businesses consist of four separate components:
Telecommunications Services, Energy Services, Utility Industry
Services and Financial Investments.
PCI expanded its customer service and product offerings
through its strategic partnerships and with acquisitions of
certain energy businesses.
Telecommunications Services
- ---------------------------
In December 1997, wholly owned affiliates of PCI and RCN
Corporation entered into a 50/50 joint venture to create
Starpower Communications, LLC (Starpower). In 1998, Starpower
became the first company to begin offering a complete single-
source package of local and long-distance telephone and Internet
services to customers in the Washington, D. C. metropolitan area.
With planned initial investments of $150 million from each
partner over a three year period (1998-2000), Starpower has begun
building a 6,000 mile fiber optic network to serve homes and
businesses in a geographic area that ultimately is expected to
extend from Northern Virginia to Baltimore. High population
density areas have been targeted for the initial build-out of the
fiber optics system, and Starpower has begun supplying cable
television to residential customers in portions of the District
of Columbia and will begin doing so in Maryland during 1999. As
of March 31, 1999, Starpower has been granted local regulatory
approvals to provide cable television services to over 300,000
potential customer households. Starpower provides 140 plus
channels of cable television service through an advanced fiber-
optic network that is operational in portions of the District of
Columbia and Maryland and continues to be expanded. Starpower
provides video programming to local residents as well as local
phone, long-distance, dial-up and high speed Internet access. As
of March 31, 1999, Starpower's subscriber base has grown to in
29
excess of 250,000. PCI's portion of Starpower's pre-tax loss for
1998 was $10.6 million. For the three months ended March 31,
1999 the pre-tax loss was $3.5 million. PCI expects that the
joint venture will continue to incur losses in 1999 and 2000 as
it develops and expands its network and customer base. As of
March 31, 1999, PCI has invested $25.5 million of its total $150
million commitment to Starpower.
During the first quarter of 1998, RCN acquired Erol's
Internet. The majority of Erol's customers (approximately
197,000 out of a total 316,000 in February 1998) are located in
Starpower's target market. These customer accounts, as well as
certain associated network assets and related liabilities, were
acquired by Starpower from RCN. Starpower has agreed to pay
$51.9 million ($78.6 million in assets, primarily goodwill, net
of $26.7 million of unearned revenue) through a ratable reduction
to RCN's committed future capital contributions. As a result of
this transaction, Starpower is amortizing the acquisition premium
principally over a three to five Year period commencing February
1998.
The success of Starpower will depend upon the ability of
Starpower to achieve its commercial objectives and is subject to
a number of uncertainties and risks, including the pace of entry
into new markets; the time and expense required for building out
the planned network; success in marketing services; the intensity
of competition; the effect of regulatory developments; and the
possible development of alternative technologies. Statements
concerning the activities of Starpower that constitute forward-
looking statements are subject to the foregoing risks and
uncertainties.
Energy Services
- ---------------
In September 1998, a wholly owned subsidiary of PCI
purchased the net assets and operations of Gaslantic Corporation
(Gaslantic), a Maryland-based natural gas retail marketing and
advisory services company doing business principally in the mid-
Atlantic region. Gaslantic focuses on providing advisory
services to commercial, industrial and institutional end-users
regarding the management of the risks and costs of natural gas
procurement, and on making retail sales of natural gas to such
customers. It recommends purchasing strategies, negotiates
supply and pipeline transportation agreements, and, if requested,
purchases natural gas on behalf of its clients. Gaslantic is a
fee-based adviser and retail marketer rather than a gas trader.
Typical of gas marketing operations, Gaslantic's purchase of
energy to fulfill client contract requirements is a high-volume
and relatively low-margin business. Through December 31, 1998,
revenues recorded related to this business since its acquisition
in September 1998, totaled $13.3 million. As of March 31, 1999,
Year-to-date revenues totaled $17.3 million. With the
30
acquisition of Gaslantic, PCI added fuel supply management and
retail sales of natural gas to its inventory of integrated energy
products and services, which also includes energy use
assessments, facilities operation and management, performance-
based energy efficiency contracting, and the sale of electricity
in markets open to retail competition.
During 1998, a wholly owned energy services subsidiary of
PCI received authority to market and broker electric energy and
capacity. Thereafter, the subsidiary became a licensed
electricity supplier in the Commonwealth of Pennsylvania and
began retail marketing of electricity in late 1998. Through its
initial marketing efforts, the subsidiary has reached agreements
to supply aggregate load of approximately 40 megawatts to
residential and business customers in Pennsylvania. The
estimated annual revenues from these supply contracts are $5.9
million. The subsidiary has secured firm commitments from non-
affiliated third-party suppliers for the delivery of energy and
capacity sufficient to meet the full requirements of its
Pennsylvania customers. Both the sales commitments to the
Pennsylvania customers and the third-party purchase agreements
are at fixed prices which do not vary with future changes in
market conditions.
On January 25, 1999, a wholly owned unregulated subsidiary
of PCI signed a contract with SMECO to supply SMECO's full
requirements for power (approximately 600 MW of peak load) during
the four-Year period starting January 1, 2001. The PCI
subsidiary has secured a firm commitment from a third party
sufficient to serve SMECO's full requirements. Both the sales
commitment to SMECO and the third-party purchase agreement are at
fixed prices which do not vary with future changes in market
conditions.
In late 1998, a wholly owned subsidiary of PCI acquired the
net assets and operations of MET Electrical Testing, Inc. (MET
Testing). MET Testing is an electrical testing and engineering
company based in Columbia, Maryland, with specialized experience
in testing, inspecting, repairing, upgrading and maintaining
industrial and commercial-type electrical installations and
equipment. MET Testing's business is primarily in the mid-
Atlantic states, with clients that include major corporations,
healthcare facilities, property managers and government agencies.
PCI currently plans to use MET Testing as a platform to build
additional commercial services such as the operation and
maintenance of commercial energy equipment. For the three months
ended March 31, 1999, Met Testing's revenues were $1.3 million.
31
The commercial success of PCI in these markets is subject to
a number of risks, including regulatory developments and the pace
of deregulation; success in marketing services; the intensity of
competition; and the ability to secure electric supply to fulfill
sales commitments at favorable prices. Statements concerning the
activities of PCI in these markets that constitute forward-
looking statements are subject to the foregoing risks and
uncertainties.
Utility Industry Services
- -------------------------
A wholly owned subsidiary of PCI continues to own and
operate W. A. Chester, a utility contractor specializing in
underground transmission and cable distribution systems, and, in
partnership with Columbia Energy Group, a natural gas pipeline,
liquefied natural gas (LNG) storage and terminal facility, both
of which are providing services to the utility industry and other
customers.
Financial Investments
- ---------------------
PCI manages a portfolio of financial investments, including
securities, electric power plant and aircraft leases, real estate
and structured finance transactions. Its remaining aircraft
portfolio, with a net book value of $304 million and $313.7
million at March 31, 1999 and December 31, 1998, respectively, is
being managed with the objective of identifying future
opportunities for its sale or other disposition on economic
terms. PCI will continue to make new financial investments that
contribute to current and future earnings.
Consolidated Results
- --------------------
PCI's earnings for the three and twelve months ended March
31, 1999 were $4.5 million ($.04 per share) and $13.3 million
($.11 per share), respectively, compared with $6.3 million ($.05
per share) and $9.9 million ($.08 per share) for the same period
ended March 31, 1998. The decrease in earnings for the three
months ended March 31, 1999, from the corresponding period in
1998, was primarily the result of the timing of investment
transactions. The increase in earnings for the twelve months
ended March 31, 1999, from the corresponding period in 1998, was
primarily due to an increase in after-tax gains from the sale of
real estate and aircraft.
Currently, PCI generates income primarily from its leasing
activities and securities investments. Income from leasing
activity, which includes rental income, gains on asset sales,
interest income and fees, totaled $16.7 million and $68.3 million
for the three and twelve months ended March 31, 1999,
32
respectively, compared to $21.7 million and $76.2 million for the
corresponding periods in 1998. The decrease for the three-month
period ended March 31, 1999 over the corresponding period in 1998
was primarily due to lower rental income earned as a result of
aircraft dispositions and the gain on the sale of a B-747
aircraft sold during the first quarter of 1998. The decrease for
the twelve-month period ended March 31, 1999, over the
corresponding period in 1998, was also primarily due to reduced
rental income from the disposition of aircraft. PCI's marketable
securities portfolio contributed pre-tax income of $3.9 million
and $18.5 million for the three and twelve months ended March 31,
1999, respectively, compared to $4.6 million and $21.5 million
for the same periods in 1998. These results include a net
realized loss of $.2 million and a net realized gain of $2
million for the three and twelve months ended March 31, 1999,
compared to a net realized gain of zero and $1.6 million for the
three and twelve months ended March 31, 1998, respectively.
Securities income decreased for the three and twelve months ended
March 31, 1999 due to a decrease in dividend income as a result
of the reduction in the preferred stock portfolio.
Revenue from Utility Industry Services totaled $4.7 million
and $16.5 million for the three and twelve months ended March 31,
1999, respectively, compared to $2.7 million and $13.5 million
for the corresponding periods in 1998. The increase in revenue
for both periods reflects a general increase in business by its
operating interests.
Revenue from Energy Services totaled $22.3 million and $47.9
million for the three and twelve months ended March 31, 1999,
respectively, compared to $2.4 million and $8.8 million for the
corresponding periods in 1998. The increase in revenue was
primarily the result of increased energy services contracting and
the acquisition of Gaslantic and MET Electrical Testing during
1998.
Other income increased by $3.5 million and $10.6 million for
the three and twelve months ended March 31, 1999, respectively,
compared to the same periods in 1998. The increases are
primarily the result of a $9.5 million pre-tax gain on the
liquidation of PCI's interests in a partnership during the first
quarter of 1999, offset by PCI's equity losses from Starpower and
Metricom and the first quarter 1998 gain on sale of real estate.
Increases for the twelve month period ended March 31, 1999, over
the corresponding period in 1998, were also due to an increase in
revenue of $6 million resulting from the sale of real estate
during the period.
Expenses before income taxes, which include interest,
depreciation, and operating and other, totaled $52.2 million and
$159.1 million for the three and twelve months ended March 31,
1999, respectively, compared to $30.2 million and $130.8 million
for the same periods in 1998. The increases during the three and
33
twelve months ended March 31, 1999, compared to the same periods
in 1998, were primarily due to an increase in expenses of
approximately $21.6 million and $51.2 million, respectively,
related to one of PCI's operating subsidiaries. Expenses before
income taxes for the three and twelve months ended March 31, 1999
were partially offset by reductions in interest expense as a
result of reduced debt outstanding, as proceeds from sales of
aircraft and marketable securities were used to pay down debt.
PCI had income tax credits of $.9 million and $9.2 million
for the three and twelve months ended March 31, 1999,
respectively, compared to $.4 million and $19.3 million for the
corresponding periods in 1998. The increase in the income tax
credit for the three months ended March 31, 1999 was primarily
the result of lower earnings over the three-month period. As a
result of joint venture operations and other activity, including
the finalization in 1998 of the Internal Revenue Service's
examinations through the 1995 tax Year, PCI's obligation for
previously accrued deferred taxes was reduced, resulting in both
a decrease in the income tax credit for the twelve months ended
March 31, 1999 and a net reduction in income tax expense. The
decrease in the income tax credit for the twelve months ended
March 31, 1999 also partially resulted from higher earnings over
the twelve-month period ended March 31, 1998.
Year 2000 Readiness Disclosure
------------------------------
For a discussion of PCI's Year 2000 Readiness Disclosure
refer to Item 7. Management's Discussion and Analysis of
Financial Condition and Results of Operations of the Company's
1998 Form 10-K.
CAPITAL RESOURCES AND LIQUIDITY
- -------------------------------
PCI has a $232.2 million securities portfolio, consisting
primarily of fixed-rate electric utility preferred stocks.
During 1999, PCI increased the cost basis of its marketable
securities portfolio by $1.6 million, primarily as the result of
security purchases of $9.2 million, offset by calls and
acceptance of tender offers of approximately $7.6 million.
PCI had short-term debt outstanding of $10 million at March
31, 1999, compared to $113.2 million at March 31, 1998. During
1999, PCI issued $36.1 million in long-term debt, including non-
recourse debt, and debt repayments totaled $98.1 million. At
March 31, 1999, PCI had $467 million available under its Medium-
Term Note Program and $400 million of unused bank credit lines.
34
Part II OTHER INFORMATION
- ------- -----------------
Item 1. LEGAL PROCEEDINGS
- ------- -----------------
Refer to Note (5) of the Notes to Consolidated Financial
Statements, Commitments and Contingencies. Also, refer to the
discussion of Environmental Matters under Item 1. Business and
Item 3. Legal Proceedings of the Company's 1998 Form 10-K.
Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
- ------- ---------------------------------------------------
(a) Annual meeting of shareholders held April 28, 1999.
(b) (1) Directors who were elected at the annual meeting:
For Term Expiring in 2000:
Terence C. Golden Votes cast for: 106,252,155
Votes withheld: 2,224,233
For Term Expiring in 2002:
Roger R. Blunt, Sr. Votes cast for: 105,585,036
Votes withheld: 2,891,352
Edmund B. Cronin, Jr. Votes cast for: 106,151,240
Votes withheld: 2,325,147
Judith A. McHale Votes cast for: 106,046,771
Votes withheld: 2,429,616
A. Thomas Young Votes cast for: 106,179,043
Votes withheld: 2,297,345
(2) Directors whose terms of office continued after the
annual meeting:
John M. Derrick, Jr. Peter F. O'Malley
David O. Maxwell Louis A. Simpson
Floretta D. McKenzie Dennis R. Wraase
Edward F. Mitchell
(c) The following shareholder proposal was introduced:
(1) "RESOLVED: That the shareholders of Pepco recommend
that the Board of Directors take the necessary steps to
reinstate the election of directors ANNUALLY, instead of the
staggered system which was recently adopted."
35
The following statement has been supplied by the
shareholder submitting this proposal:
"REASONS: Until recently, directors of PEPCO were
elected annually by all shareholders."
"The great majority of New York Stock Exchange
listed corporations elect all their directors each Year."
"This insures that ALL directors will be more
accountable to ALL shareholders each Year and to a certain
extent prevents the self-perpetuation of the Board."
"Last Year the owners of 28,275,236 shares,
representing approximately 32.9% of shares voting, voted FOR
this proposal."
The shareholder proposal was defeated. There were
63,661,538 votes cast against the proposal, 22,521,399 votes cast
in support of the proposal, 3,222,737 votes abstaining and
19,070,714 broker nonvotes.
Item 5. OTHER INFORMATION
- ------- -----------------
OTHER FINANCING ARRANGEMENTS - Credit Agreements
- ------------------------------------------------
The Company and PCI satisfy their short-term financing
requirements through the sale of commercial promissory notes.
The Company and PCI maintain minimum 100 percent lines of credit
back-up, in the amounts of $230 million and $400 million,
respectively, for their outstanding commercial promissory notes.
These lines of credit were unused during 1999 and 1998.
BASE RATE PROCEEDINGS
- ---------------------
Maryland
- --------
In November 1998, pursuant to a settlement agreement, the
Maryland Public Service Commission authorized a $19 million, or
2%, increase in base rate revenue. Also, see the discussion of
Rates under Item 1. Business of the Company's 1998 Form 10-K.
36
District of Columbia
- --------------------
In July 1995, the District of Columbia Public Service
Commission authorized rates that are based on a 9.09% rate of
return on average rate base, including an 11.1% return on common
stock equity and a capital structure that excludes short-term
debt.
Federal - Interchange and Purchased Energy
- ------------------------------------------
The Company participates in wholesale capacity, energy and
transmission purchases and sales transactions, the savings from
which are passed along to customers. Presently, all transmission
service in PJM is administered by the PJM Office of the
Interconnection. In addition to interchange with PJM, the
Company is actively participating in the bilateral energy sales
marketplace; numerous utilities and marketers have executed
service agreements allowing them to arrange purchases under the
Company's wholesale power sales tariff, and the Company has
executed service agreements allowing it to purchase energy under
other market participants' power sales tariffs. The Company's
power sales tariff also allows for the sale of generating
capacity on a short-term basis. Presently, the Company has
agreements for installed capacity sales through December 31,
1999, totaling 150 megawatts. Revenues from capacity and
bilateral energy transactions totaled approximately $5.1 million
and $61.8 million for the three and twelve months ended March 31,
1999, respectively, and $3.6 million and $8.9 million for the
corresponding periods in 1998, and are included as components of
interchange deliveries.
The Company continues to purchase energy from FirstEnergy
under the Company's 1987 long-term capacity purchase agreement
with FirstEnergy and Allegheny Energy, Inc. (AEI). The Company
is purchasing energy from the Panda facility, pursuant to a
25-Year power purchase agreement for 230 megawatts of capacity
supplied by a gas-fueled combined-cycle cogenerator. The Company
also purchases energy from the Northeast Maryland Waste Disposal
Authority under an avoided cost-based purchase agreement.
RESTRUCTURING OF THE BULK POWER MARKET
- --------------------------------------
See the discussion of the Restructuring of the Bulk Power
Market under Item 1. Business of the Company's 1998 Form 10-K.
37
COMPETITION
- -----------
For additional information refer to the discussion included
under Item 3. Legal Proceedings of the Company's 1998 Form
10-K.
Maryland
- --------
On April 2, 1999, the Maryland General Assembly approved
legislation that enables competition and customer choice in
Maryland and legislation that modifies the taxation of Maryland
utilities. The legislation calls for customer choice to be
phased in for residential customers over a three-year period
starting in July 2000 (the Company's proposed settlement which is
pending approval by the Maryland Commission would provide choice
to all customers on July 1, 2000). Commercial, industrial,
governmental, and institutional customers all will have choice
starting in 2001. Other features of the legislation include a
residential customer rate reduction of 3 to 7.5 percent for
customers who remain with their incumbent utility (the Company is
not subject to this provision if, as expected, the Maryland
Commission concludes that the proposed settlement involving the
divestiture of generating assets is equally protective of
customers); a $34 million Universal Service Fund, to be paid by
ratepayers of all utilities operating in Maryland, to ensure
service for low-income customers; and disclosure by all energy
suppliers of their fuel sources to promote more consumers
choosing renewable energy sources. The Governor of Maryland has
signed the legislation. All stranded costs, if any, will be
recovered by a nonbypassable wires charge.
District of Columbia
- --------------------
For additional information refer to Item 7. Management's
Discussion and Analysis of Financial Condition and Results of
Operations - "Subsequent Events" - in the Company's 1998 Form
10-K.
Request for Approval of Proposed Sale of Generating Assets
- ----------------------------------------------------------
On March 16, 1999, the Company filed an application with the
D.C. Commission requesting its approval of the Company's sale of
its generating assets, irrespective of whether the D.C.
Commission orders retail electric competition in the District of
Columbia.
38
PEAK LOAD, SALES, CONSERVATION, AND CONSTRUCTION
- ------------------------------------------------
AND GENERATING CAPACITY
-----------------------
Peak Load and Sales Data
- ------------------------
Kilowatt-hour sales increased 4.7% and 3.9% for the three
and twelve months ended March 31, 1999, compared to sales in the
corresponding periods of 1998. Although temperatures in the
first quarter, as measured in heating degree days, were 15%
colder than the corresponding period in 1998, they were still 3%
warmer than the 20-Year average. Summer temperatures in the
twelve months ended March 31, 1999, as measured in cooling degree
hours, were 15% hotter than the corresponding period ended March
31, 1998, yet remained approximately 7% cooler than the 20-Year
average. Assuming future weather conditions approximate
historical averages, the Company expects its compound annual
growth in retail kilowatt-hour sales to be approximately 2% over
the next decade.
On June 26, 1998, the Company established an all-time summer
peak demand of 5,807 megawatts. This compares with the 1997
summer peak demand of 5,689 megawatts, and the prior all-time
summer peak demand of 5,769 megawatts, which occurred in July
1991. The Company's present generation capability, excluding
short-term capacity transactions, is 6,806 megawatts. At the
time of the 1998 summer peak demand, the Company's energy use
management programs had the capability of reducing system demand
by an additional 242 megawatts. Based on average weather
conditions, the Company estimates that its retail peak demand
will grow at a compound annual rate of approximately 2%,
reflecting anticipated service area growth trends. The 1998-1999
winter season peak demand of 4,631 megawatts was 7.6% below the
all-time winter peak demand of 5,010 megawatts which was
established in January 1994.
Conservation
- ------------
In September 1998, the Company received permission from the
Maryland Public Service Commission to decrease the DSM surcharge
effective with bills rendered on and after September 21, 1998,
which will reduce annual revenue by approximately $3 million.
The reduction in the surcharge rate reflects a decline in the
costs and scale of Maryland DSM programs. The Company invested
approximately $1.4 million and $11.7 million in Maryland DSM
programs for the three and twelve months ended March 31, 1999,
respectively, and $5.1 million and $23.6 million for
corresponding periods in 1998. The surcharge mechanism includes
a provision for the recovery of program cost amortization and
permits the Company to earn a return on its conservation
39
investment while receiving compensation for lost revenue. The
surcharge tariff is revised each Year. Beginning with the 1998
surcharge update, the program cost amortization period was
successively reduced to reflect the following: 1998 program
costs will be amortized over four Years; 1999 program costs will
be amortized over three Years; 2000 program costs will be
amortized over two Years; and 2001 and subsequent program costs
will be amortized over one Year. In addition, the performance
bonus provision of the surcharge relative to future energy saving
goals will no longer apply.
On March 19, 1999, the Company filed an agreement on behalf
of the Maryland Conservation Collaborative requesting the
approval of the Maryland Commission to discontinue operation of
the Company's High Efficiency Air Conditioner and Heat Pump
Rebate Program. The agreement also requested the Maryland
Commission's approval to initiate a program through which the
Company would reimburse the Maryland Weatherization Assistance
Program for the installation of conservation measures in the
residences of low income customers in the Company's Maryland
service territory. Reimbursements would be capped at $500,000
annually. These actions would further reduce the Company's
conservation expenditures in Maryland. The Maryland Commission
approved the agreement on April 7, 1999.
Investment in District of Columbia DSM programs totaled
approximately $.4 million and $4.7 million for the three and
twelve months ended March 31, 1999, respectively, and $.8 million
and $5.2 million for the corresponding periods in 1998. These
DSM costs are amortized over ten Years with an accrued return on
unamortized costs. The ECRR surcharge includes both a
conservation expenditure component and a component for recovering
certain costs associated with complying with the CAA amendments
of 1990; the conservation component is scheduled to be updated
annually on June 1 of each Year, while the CAA component is
updated quarterly. In June 1997, the Company filed an
Application for Authority with the District of Columbia
Commission to update the ECRR surcharge tariff to recover actual
DSM expenditures incurred during the period January 1995 through
December 1996. In a June 1998 filing, the Company requested that
recovery of Year 1997 DSM expenditures also be reflected within
the ECRR. On September 3, 1998, the Commission approved the
Company's June 1997 request for recovery of the January 1995
through December 1996 DSM expenditures, increasing annual revenue
by approximately $9 million. On October 30, 1998, the Company
updated its June 1998 request for 1997 DSM expenditures to
incorporate provisions of the Commission's September 3, 1998,
decision, which would increase annual revenue by approximately $3
million. A proposal by the Company to eliminate DSM programs
operated within the District of Columbia was filed with the
Commission in March 1998, and as of May 10, 1999, a decision is
pending.
40
Construction and Generating Capacity
- ------------------------------------
The Company incurred construction expenditures, excluding
AFUDC and CCRF, of $39.7 million for the three months ended March
31, 1999 ($13.1 million related to Generation). These
expenditures are projected to total $865 million ($389 million
related to Generation) for the five-Year period 1999 through
2003, which includes approximately $132 million of estimated CAA
expenditures. In 1999, construction expenditures are projected
to total $185 million ($79 million related to Generation) which
includes $22 million of estimated CAA expenditures. The Company
plans to finance its construction program primarily through funds
provided by operations.
The Company's present generation resource mix consist of
4,815 megawatts of steam generating capacity and 1,227 megawatts
from 31 combustion turbine units owned by the Company, including
166 megawatts of capacity from the Company's 9.72% undivided
interest in the Conemaugh Generating Station located in western
Pennsylvania.
The Company has a purchase agreement with SMECO, through
2015, for 84 megawatts of capacity supplied by a combustion
turbine installed and owned by SMECO at the Company's Chalk Point
Generating Station. The Company is responsible for all costs
associated with operating and maintaining the facility. The
capacity payment to SMECO is approximately $5.5 million per Year.
The Company continues to purchase 450 megawatts of capacity
and associated energy from FirstEnergy under a 1987 long-term
capacity purchase agreement with FirstEnergy and AEI. The
Company also has a 25-Year capacity purchase agreement with Panda
for 230 megawatts of capacity from a gas-fueled combined-cycle
cogenerator in Prince George's County, Maryland. In addition,
the Company continues to purchase capacity and associated energy
from a 50-megawatt municipally financed resource recovery
facility in Montgomery County, Maryland. The capacity expense
under these agreements, including an allocation of a portion of
FirstEnergy's fixed operating and maintenance costs, was $52.2
million and $163.4 million for the three and twelve months ended
March 31, 1999, respectively, compared to $38.6 million and
$149.3 million for the three and twelve months ended March 31,
1998, respectively.
The Company projects that existing contracts for nonutility
generation and the emerging wholesale market for generation
resources will provide adequate reserve margins to meet
customers' needs beyond the Year 2000.
41
SELECTED NONUTILITY SUBSIDIARY FINANCIAL INFORMATION
- ----------------------------------------------------
The Company's wholly owned subsidiary, PCI, was formed in
late 1983 to provide a vehicle to conduct the Company's ongoing
nonutility investment programs and operating businesses. The
principal assets of PCI are portfolios of securities and
equipment leases, and to a lesser extent real estate and other
investments. The $232.2 million securities portfolio, consisting
primarily of fixed rate electric utility preferred stocks,
provides PCI with significant liquidity and flexibility to
participate in additional investment opportunities. Subsidiary
equity totaled $247.7 million at March 31, 1999; $243.4 million
at December 31, 1998; and $234.9 million at March 31, 1998.
42
<TABLE>
Potomac Capital Investment Corporation
Consolidated Statements of Earnings:
- --------------------------------------
<CAPTION>
Three Twelve
Months Ended Months Ended
March 31, March 31,
------------------ -------------------
1999 1998 1999 1998
------ ------ ------- -------
(Millions of Dollars except Per Share Amounts)
<S> <C> <C> <C> <C>
Income
Energy services $ 22.3 $ 2.4 $ 47.9 $ 8.8
Leasing activities 16.7 21.7 68.3 76.2
Utility industry services 4.7 2.7 16.5 13.5
Marketable securities 3.9 4.6 18.5 21.5
Other (primarily gains on the sale
or liquidation of assets) 8.2 4.7 12.0 1.4
------ -------- ------- -------
55.8 36.1 163.2 121.4
------ -------- ------- -------
Expenses
Interest 12.8 15.4 53.6 65.3
Operating and other 33.7 8.0 83.1 33.1
Depreciation 5.7 6.8 22.4 32.4
Income tax credit (0.9) (0.4) (9.2) (19.3)
------ -------- ------- -------
51.3 29.8 149.9 111.5
------ -------- ------- -------
Net earnings from
nonutility subsidiary $ 4.5 $ 6.3 $ 13.3 $ 9.9
====== ====== ======= =======
Per share contribution to
earnings of the Company $ .04 $ .05 $ .11 $ .08
===== ===== ===== =====
43
</TABLE>
<TABLE>
STATISTICAL DATA
- ----------------
<CAPTION>
Three Months Ended Twelve Months Ended
March 31, March 31,
------------------------- -----------------------------
1999 1998 % Change 1999 1998 % Change
------ ------ -------- -------- -------- --------
<S> <C> <C> <C> <C> <C> <C>
Revenue from Sales
------------------
of Electricity
--------------
(Millions of Dollars)
Residential $123.6 $114.0 8.4 $ 577.4 $ 525.8 9.8
General Service 215.6 205.6 4.9 1,112.9 1,070.8 3.9
Large Power Service <F1> 7.1 7.0 1.4 35.1 35.1 -
Street Lighting 3.5 3.6 (2.8) 13.1 13.3 (1.5)
Rapid Transit 7.0 6.8 2.9 29.8 29.2 2.1
Wholesale 33.1 29.3 13.0 128.0 122.3 4.7
------- ------ -------- --------
System $389.9 $366.3 6.4 $1,896.3 $1,796.5 5.6
====== ====== ======== ========
Energy Sales
------------
(Millions of KWH)
Residential 1,824 1,707 6.9 6,875 6,542 5.1
General Service 3,682 3,551 3.7 15,722 15,203 3.4
Large Power Service <F1> 165 167 (1.2) 684 689 (0.7)
Street Lighting 46 46 - 163 166 (1.8)
Rapid Transit 104 101 3.0 425 413 2.9
Wholesale 738 692 6.6 2,724 2,570 6.0
------ ------ -------- --------
System 6,559 6,264 4.7 26,593 25,583 3.9
====== ====== ======== ========
Average System Revenue
----------------------
per KWH (cents per KWH) 5.94 5.85 1.5 7.13 7.02 1.6
-----------------------
System Peak Demand <F2>
------------------
(Thousands of KW)
Summer - - 5,807 5,689
Winter - - 4,631 4,076
Net Generation
--------------
(Millions of KWH) 5,353 4,709 22,359 18,698
Fuel Mix (% of Btu)
-------------------
Coal (%) 87 90 84 89
Oil (%) 12 9 13 7
Gas (%) 1 1 3 4
Fuel Cost per MBtu
------------------
System Average $1.64 $1.79 $1.69 $1.83
Weather Data
------------
Heating Degree Days 2,121 1,851 3,639 3,853
20 Year Average 2,196 3,977
Cooling Degree Hours - 71 10,086 8,883
20 Year Average 13 10,981
Heating Degree Days - The daily difference in degrees by which the
mean temperature is below 65 degrees Fahrenheit (dry bulb).
Cooling Degree Hours - The daily sum of the differences, by hours, by which
the temperature (effective temperature) for each hour exceeds 71 degrees
Fahrenheit (effective temperature).
<FN>
<F1> Large Power Service customers are served at a voltage of 66KV
or higher.
<F2> At March 31, 1999, the net generation capability, excluding
short-term capacity transactions, was 6,806 MW.
</FN>
44
</TABLE>
Item 6 EXHIBITS AND REPORTS ON FORM 8-K
- ------ --------------------------------
(a) Exhibits
Exhibit 12 - Computation of ratios - filed
herewith.
Exhibit 15 - Letter re unaudited interim
financial information - filed
herewith.
Exhibit 27 - Financial data schedule - filed
herewith.
(b) Reports on Form 8-K
A Current Report on Form 8-K was filed by the
Company on January 4, 1999, summarizing the
Company's new full service power supply require-
ments contract with the Southern Maryland Electric
Cooperative, Inc., the Company's principal
wholesale customer. The item reported on such
Form 8-K was Item 5. (Other Events).
A Current Report on Form 8-K was filed by the
Company on January 29, 1999, providing detailed
information and audited consolidated financial
statements. The item reported on such Form 8-K
was Item 7. (Financial Statements, Pro-Forma
Financial Information and Exhibits).
A Current Report on Form 8-K was filed by the
Company on February 1, 1999, summarizing the
Company's filing of stranded costs and unbundled
rates for retail competition, submitted in
compliance with orders previously issued by the
District of Columbia Public Service Commission.
The item reported on such Form 8-K was Item 5.
(Other Events).
A Current Report on Form 8-K was filed by the
Company on February 3, 1999, summarizing the
Company's Agreement of Stipulation and Settlement
concerning the Company's Maryland stranded cost
adjudication proceeding and the Company's proposal
to sell its generating assets. The item reported
on such Form 8-K was Item 5. (Other Events).
45
A Current Report on Form 8-K was filed by the
Company on March 16, 1999, summarizing the
application the Company filed with the D.C.
Commission on March 15, 1999 requesting approval
of the Company's plan to sell its generating
assets. The item reported on such Form 8-K was
Item 5. (Other Events).
46
SIGNATURES
----------
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.
Potomac Electric Power Company
------------------------------
Registrant
By /s/ D. R. Wraase
------------------------------
(D. R. Wraase)
Executive Vice President and
Chief Financial Officer
May 11, 1999
- ------------
DATE
47
<TABLE>
Exhibit 12 Statements Re. Computation of Ratios
- ---------- ------------------------------------
The computations of the coverage of fixed charges before income taxes, and
the coverage of combined fixed charges and preferred dividends for the twelve
months ended March 31, 1999, and for each of the preceding five years, on the
basis of parent company operations only, are as follows.
<CAPTION>
Twelve
Months For the Year Ended December 31,
Ended -----------------------------------------------
Mar. 31,
1999 1998 1997 1996 1995 1994
-------- ------- ------- ------- ------- -------
(Millions of Dollars)
<S> <C> <C> <C> <C> <C> <C>
Net income $231.5 $211.2 $164.7 $220.1 $218.8 $208.1
Taxes based on income 143.4 131.0 97.5 135.0 129.4 116.6
-------- ------- ------- ------- ------- -------
Income before taxes 374.9 342.2 262.2 355.1 348.2 324.7
-------- ------- ------- ------- ------- -------
Fixed charges:
Interest charges 153.6 151.8 146.7 146.9 146.6 139.2
Interest factor in rentals 23.8 23.8 23.6 23.6 23.4 6.3
-------- ------- ------- ------- ------- -------
Total fixed charges 177.4 175.6 170.3 170.5 170.0 145.5
-------- ------- ------- ------- ------- -------
Income before income taxes and fixed charges $552.3 $517.8 $432.5 $525.6 $518.2 $470.2
======== ======= ======= ======= ======= =======
Coverage of fixed charges 3.11 2.95 2.54 3.08 3.05 3.23
==== ==== ==== ==== ==== ====
Preferred dividend requirements $15.9 $18.0 $16.5 $16.6 $16.9 $16.5
-------- ------- ------- ------- ------- -------
Ratio of pre-tax income to net income 1.62 1.62 1.59 1.61 1.59 1.56
-------- ------- ------- ------- ------- -------
Preferred dividend factor $25.8 $29.2 $26.2 $26.7 $26.9 $25.7
-------- ------- ------- ------- ------- -------
Total fixed charges and preferred dividends $203.2 $204.8 $196.5 $197.2 $196.9 $171.2
======== ======= ======= ======= ======= =======
Coverage of combined fixed charges
and preferred dividends 2.72 2.53 2.20 2.66 2.63 2.75
==== ==== ==== ==== ==== ====
48
</TABLE>
<TABLE>
Exhibit 12 Statements Re. Computation of Ratios
- ---------- ------------------------------------
The computations of the coverage of fixed charges before income taxes, and
the coverage of combined fixed charges and preferred dividends for the twelve
months ended March 31, 1999, and for each of the preceding five years, on a
consolidated basis, are as follows.
<CAPTION>
Twelve
Months For the Year Ended December 31,
Ended -----------------------------------------------
Mar. 31,
1999 1998 1997 1996 1995 1994
-------- ------- ------- ------- ------- -------
(Millions of Dollars)
<S> <C> <C> <C> <C> <C> <C>
Net income $244.8 $226.3 $181.8 $237.0 $94.4 $227.2
Taxes based on income 134.2 122.3 65.6 80.4 43.7 94.0
-------- ------- ------- ------- ------- -------
Income before taxes 379.0 348.6 247.4 317.4 138.1 321.2
-------- ------- ------- ------- ------- -------
Fixed charges:
Interest charges 207.9 208.6 216.1 231.1 238.7 224.5
Interest factor in rentals 24.0 24.0 23.7 23.9 26.7 9.9
-------- ------- ------- ------- ------- -------
Total fixed charges 231.9 232.6 239.8 255.0 265.4 234.4
-------- ------- ------- ------- ------- -------
Nonutility subsidiary capitalized interest (0.6) (0.6) (0.5) (0.7) (0.5) (0.5)
-------- ------- ------- ------- ------- -------
Income before income taxes and fixed charges $610.3 $580.6 $486.7 $571.7 $403.0 $555.1
======== ======= ======= ======= ======= =======
Coverage of fixed charges 2.63 2.50 2.03 2.24 1.52 2.37
==== ==== ==== ==== ==== ====
Preferred dividend requirements $15.9 $18.0 $16.5 $16.6 $16.9 $16.5
-------- ------- ------- ------- ------- -------
Ratio of pre-tax income to net income 1.55 1.54 1.36 1.34 1.46 1.41
-------- ------- ------- ------- ------- -------
Preferred dividend factor $24.7 $27.7 $22.4 $22.2 $24.7 $23.3
-------- ------- ------- ------- ------- -------
Total fixed charges and preferred dividends $256.6 $260.3 $262.2 $277.2 $290.1 $257.7
======== ======= ======= ======= ======= =======
Coverage of combined fixed charges
and preferred dividends 2.38 2.23 1.86 2.06 1.39 2.15
==== ==== ==== ==== ==== ====
49
</TABLE>
Exhibit 15
May 11, 1999
Securities and Exchange Commission
450 Fifth Street, N.W.
Washington, D.C. 20549
Ladies and Gentlemen:
We are aware that Potomac Electric Power Company has incorporated
by reference our report dated May 11, 1999, (issued pursuant to
the provisions of Statement on Auditing Standards No. 71) in the
Prospectuses constituting parts of the Registration Statements on
Forms S-8 (Numbers 33-36798, 33-53685, 33-54197, 333-56683 and
333-57221) filed on September 12, 1990, May 18, 1994, June 17,
1994, June 12, 1998 and June 19, 1998, respectively, and on Forms
S-3 (Numbers 33-58810, 33-61379 and 333-33495) filed on February
26, 1993, July 28, 1995 and August 13, 1997, respectively. We
are also aware of our responsibilities under the Securities Act
of 1933.
Very truly yours,
/s/ PricewaterhouseCoopers LLP
PricewaterhouseCoopers LLP
Washington, D.C.
50
<TABLE> <S> <C>
<ARTICLE> UT
<CIK> 0000079732
<NAME> POTOMAC ELECTRIC POWER COMPANY
<SUBSIDIARY>
<NUMBER> 1
<NAME> POTOMAC CAPITAL INVESTMENT CORPORATION
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 3-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-START> JAN-01-1999
<PERIOD-END> MAR-31-1999
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 4,475,000
<OTHER-PROPERTY-AND-INVEST> 0
<TOTAL-CURRENT-ASSETS> 448,000
<TOTAL-DEFERRED-CHARGES> 670,700
<OTHER-ASSETS> 1,038,000
<TOTAL-ASSETS> 6,631,700
<COMMON> 118,500
<CAPITAL-SURPLUS-PAID-IN> 1,011,600
<RETAINED-EARNINGS> 721,900
<TOTAL-COMMON-STOCKHOLDERS-EQ> 1,852,000
50,000
100,000
<LONG-TERM-DEBT-NET> 1,963,800
<SHORT-TERM-NOTES> 0
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 207,600
0
<CAPITAL-LEASE-OBLIGATIONS> 156,900
<LEASES-CURRENT> 20,800
<OTHER-ITEMS-CAPITAL-AND-LIAB> 2,280,600<F1>
<TOT-CAPITALIZATION-AND-LIAB> 6,631,700
<GROSS-OPERATING-REVENUE> 429,000
<INCOME-TAX-EXPENSE> 5,000
<OTHER-OPERATING-EXPENSES> 379,700
<TOTAL-OPERATING-EXPENSES> 384,700
<OPERATING-INCOME-LOSS> 44,300
<OTHER-INCOME-NET> 19,600
<INCOME-BEFORE-INTEREST-EXPEN> 63,900
<TOTAL-INTEREST-EXPENSE> 37,900
<NET-INCOME> 26,000
2,000
<EARNINGS-AVAILABLE-FOR-COMM> 24,000
<COMMON-STOCK-DIVIDENDS> 49,200
<TOTAL-INTEREST-ON-BONDS> 155,000<F2>
<CASH-FLOW-OPERATIONS> 83,300
<EPS-PRIMARY> $0.20<F3>
<EPS-DILUTED> $0.20
<FN>
<F1>Includes mandatorily redeemable preferred securities of subsidiary trust.
<F2>Total annualized interest costs for all utility long-term debt and
mandatorily redeemable preferred securities of subsidiary trust outstanding
at March 31, 1999.
<F3>Basic earnings per share for the three months ended March 31, 1999 were
$0.20. Diluted earnings per share for the three months ended March 31, 1999
were $0.20.
</FN>
</TABLE>
