<PAGE>
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
[Mark one]
/X/ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 1999
-------------------------
OR
/_/ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
Commission file number 1-1405
Delmarva Power & Light Company
------------------------------
(Exact name of registrant as specified in its charter)
Delaware and Virginia 51-0084283
--------------------------- ---------------------
(States of incorporation) (I.R.S. Employer
Identification No.)
800 King Street, P.O. Box 231, Wilmington, Delaware 19899
- --------------------------------------------------- ----------
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code 302-429-3114
------------
Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
the preceding 12 months (or for such shorter period that the registrant was
required to file such reports), and (2) has been subject to such filing
requirements for the past 90 days.
Yes X No ____
-----
Indicate the number of shares outstanding of each of the issuer's classes of
common stock, as of the latest practicable date.
All 1,000 issued and outstanding shares of Delmarva Power & Light Company common
stock, $2.25 per share par value, are owned by Conectiv
<PAGE>
DELMARVA POWER & LIGHT COMPANY
------------------------------
Table of Contents
-----------------
<TABLE>
<CAPTION>
Page No.
--------
<S> <C>
Part I. Financial Information:
Consolidated Statements of Income for the three and
six months ended June 30, 1999 and 1998.............. 1
Consolidated Balance Sheets as of June 30, 1999
and December 31, 1998................................ 2-3
Consolidated Statements of Cash Flows for the
six months ended June 30, 1999 and 1998.............. 4
Notes to Consolidated Financial Statements........... 5-9
Management's Discussion and Analysis of Financial
Condition and Results of Operations.................. 10-19
Part II. Other Information and Signature........................... 20-21
</TABLE>
i
<PAGE>
Part I. FINANCIAL INFORMATION
DELMARVA POWER & LIGHT COMPANY
------------------------------
CONSOLIDATED STATEMENTS OF INCOME
(Dollars in Thousands)
(Unaudited)
<TABLE>
<CAPTION>
Three Months Ended Six Months Ended
June 30, June 30,
--------------------------- ------------------------
1999 1998 1999 1998
---------- ---------- ---------- ----------
<S> <C> <C> <C> <C>
OPERATING REVENUES
Electric $ 309,334 $ 287,176 $ 630,232 $ 565,552
Gas 131,391 72,850 422,382 188,593
Other services 10,077 2,352 17,895 24,343
---------- ---------- ---------- ----------
450,802 362,378 1,070,509 778,488
---------- ---------- ---------- ----------
OPERATING EXPENSES
Electric fuel and purchased energy 137,219 121,262 291,454 238,138
Gas purchased 119,199 62,543 390,812 161,171
Other services' cost of sales 7,470 665 15,529 16,039
Purchased electric capacity 12,359 9,290 21,832 18,102
Employee separation and other merger-related costs - (14,277) - 26,061
Operation and maintenance 68,469 62,618 126,459 142,437
Depreciation 32,865 32,979 65,667 66,710
Taxes other than income taxes 11,675 8,961 20,000 18,404
---------- ---------- ---------- ----------
389,256 284,041 931,753 687,062
---------- ---------- ---------- ----------
OPERATING INCOME 61,546 78,337 138,756 91,426
---------- ---------- ---------- ----------
OTHER INCOME
Allowance for equity funds used
during construction 245 608 835 915
Other income 65 (1,657) 2,787 (799)
---------- ---------- ---------- ----------
310 (1,049) 3,622 116
---------- ---------- ---------- ----------
INTEREST EXPENSE
Interest charges 19,822 21,178 40,342 41,996
Allowance for borrowed funds used during
construction and capitalized interest (260) (360) (752) (1,082)
---------- ---------- ---------- ----------
19,562 20,818 39,590 40,914
---------- ---------- ---------- ----------
DIVIDENDS ON PREFERRED SECURITIES
OF A SUBSIDIARY TRUST 1,422 1,422 2,844 2,844
---------- ---------- ---------- ----------
INCOME BEFORE INCOME TAXES 40,872 55,048 99,944 47,784
INCOME TAXES 16,279 21,973 39,737 19,565
---------- ---------- ---------- ----------
NET INCOME 24,593 33,075 60,207 28,219
DIVIDENDS ON PREFERRED STOCK 919 1,086 1,992 2,172
---------- ---------- ---------- ----------
EARNINGS APPLICABLE TO COMMON STOCK $ 23,674 $ 31,989 $ 58,215 $ 26,047
========== ========== ========== ==========
</TABLE>
See accompanying Notes to Consolidated Financial Statements.
-1-
<PAGE>
DELMARVA POWER & LIGHT COMPANY
------------------------------
CONSOLIDATED BALANCE SHEETS
(Dollars in Thousands)
(Unaudited)
<TABLE>
<CAPTION>
June 30, December 31,
1999 1998
------------ --------------
<S> <C> <C>
ASSETS
------
Current Assets
Cash and cash equivalents $ 8,856 $ 1,761
Accounts receivable 234,216 273,531
Accounts receivable from associated companies 3,199 2,325
Inventories, at average cost
Fuel (coal, oil and gas) 31,709 44,212
Materials and supplies 40,153 39,323
Prepayments 6,730 10,735
Deferred income taxes, net 14,095 13,061
------------ --------------
338,958 384,948
------------ --------------
Investments
Funds held by trustee 66,519 60,208
Notes receivable 757 -
Other investments 1,032 1,103
------------ --------------
68,308 61,311
------------ --------------
Property, Plant and Equipment
Electric utility plant 3,095,287 3,049,099
Gas utility plant 254,262 249,383
Common utility plant 152,204 158,109
------------ --------------
3,501,753 3,456,591
Less: Accumulated depreciation 1,554,098 1,492,182
------------ --------------
Net utility plant in service 1,947,655 1,964,409
Utility construction work-in-progress 131,730 138,496
Leased nuclear fuel, at amortized cost 25,196 28,325
Nonutility property, net 3,700 4,560
Goodwill, net 70,929 71,914
------------ --------------
2,179,210 2,207,704
------------ --------------
Deferred Charges and Other Assets
Prepaid employee benefits costs 108,923 94,354
Unamortized debt expense 11,789 12,140
Deferred debt refinancing costs 14,919 16,180
Deferred recoverable income taxes 82,022 82,211
Other 44,383 46,003
------------ --------------
262,036 250,888
------------ --------------
Total Assets $ 2,848,512 $ 2,904,851
============ ==============
</TABLE>
See accompanying Notes to Consolidated Financial Statements.
-2-
<PAGE>
DELMARVA POWER & LIGHT COMPANY
------------------------------
CONSOLIDATED BALANCE SHEETS
(Dollars in Thousands)
(Unaudited)
<TABLE>
<CAPTION>
June 30, December 31,
1999 1998
------------- --------------
<S> <C> <C>
CAPITALIZATION AND LIABILITIES
------------------------------
Current Liabilities
Short-term debt $ 12,000 $ 21,700
Long-term debt due within one year 1,545 31,287
Variable rate demand bonds 71,500 71,500
Accounts payable 132,303 177,859
Taxes accrued 19,779 16,257
Interest accrued 18,965 20,604
Dividends payable 22,118 23,615
Current capital lease obligation 12,487 12,481
Deferred energy costs 9,812 413
Accrued employee separation and
other merger-related costs 669 2,509
Other 22,391 27,586
------------- --------------
323,569 405,811
------------- --------------
Deferred Credits and Other Liabilities
Deferred income taxes, net 466,992 461,800
Deferred investment tax credits 36,103 37,382
Long-term capital lease obligation 13,828 17,003
Other 33,719 19,747
------------- --------------
550,642 535,932
------------- --------------
Capitalization
Common stock, $2.25 par value; shares authorized:
1,000,000 ; shares outstanding: 1,000 2 2
Additional paid-in capital 528,893 528,893
Retained earnings 335,148 322,599
------------- --------------
Total common stockholder's equity 864,043 851,494
Cumulative preferred stock 89,703 89,703
DPL obligated mandatorily redeemable preferred
securities of subsidiary trust holding solely DPL
debentures 70,000 70,000
Long-term debt 950,555 951,911
------------- --------------
1,974,301 1,963,108
------------- --------------
Total Capitalization and Liabilities $ 2,848,512 $ 2,904,851
============= ==============
</TABLE>
See accompanying Notes to Consolidated Financial Statements.
-3-
<PAGE>
DELMARVA POWER & LIGHT COMPANY
------------------------------
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in Thousands)
(Unaudited)
<TABLE>
<CAPTION>
Six Months Ended
June 30,
-----------------------------------
1999 1998
-------------- --------------
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 60,207 $ 28,219
Adjustments to reconcile net income to
net cash provided by operating activities:
Depreciation and amortization 70,829 70,900
Allowance for equity funds used during construction (835) (915)
Deferred income taxes, net 4,347 (6,010)
Investment tax credit adjustments, net (1,280) (1,280)
Net change in:
Accounts receivable 39,173 (14,361)
Inventories 11,673 14,692
Accounts payable (45,556) (11,785)
Other current assets and liabilities (1) 8,254 45,922
Other, net 3,735 3,262
-------------- --------------
Net cash provided by operating activities 150,547 128,644
-------------- --------------
CASH FLOWS FROM INVESTING ACTIVITIES
Acquisition of businesses, net of cash acquired - (8,970)
Capital expenditures (46,065) (45,554)
Net cash of nonutility subsidiaries transferred to Conectiv - (18,138)
Deposits to nuclear decommissioning trust funds (2,128) (2,120)
Other, net (55) 150
-------------- --------------
Net cash used by investing activities (48,248) (74,632)
-------------- --------------
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid (47,298) (47,413)
Preferred dividends paid (1,856) (2,265)
Long-term debt issued - 33,000
Common stock issued - 63
Long-term debt redeemed (31,187) (26,029)
Common stock purchased - (1,983)
Principal portion of capital lease payments (5,162) (4,190)
Net change in short-term debt (9,700) (17,979)
Cost of issuances and refinancings (1) (259)
-------------- --------------
Net cash used by financing activities (95,204) (67,055)
-------------- --------------
Net change in cash and cash equivalents 7,095 (13,043)
Cash and cash equivalents at beginning of period 1,761 35,339
-------------- --------------
Cash and cash equivalents at end of period $ 8,856 $ 22,296
============== ==============
</TABLE>
(1) Other than debt and deferred income taxes classified as current.
See accompanying Notes to Consolidated Financial Statements.
-4-
<PAGE>
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
------------------------------------------------------
1. Financial Statement Presentation
--------------------------------
The consolidated financial statements include the accounts of Delmarva Power &
Light Company (DPL) and its wholly-owned subsidiaries. On March 1, 1998, DPL
transferred its former nonutility subsidiaries to Conectiv in conjunction with
the Merger discussed in Note 4 to DPL's 1998 Consolidated Financial Statements
included in DPL's 1998 Report on Form 10-K. As a result of the transfer, the
Consolidated Statement of Income for the three months ended June 30, 1999, and
1998, and the six months ended June 30, 1999, do not include any operating
results for the former DPL nonutility subsidiaries. The Consolidated Statement
of Income for the six months ended June 30, 1998, includes the former nonutility
subsidiaries' operating results for the two months ended February 28, 1998. As
of March 1, 1998, DPL's only significant remaining wholly-owned subsidiary was
Delmarva Power Financing I.
Certain reclassifications, not affecting net income, have been made to conform
amounts previously reported to the current presentation. The financial
statements reflect all adjustments necessary in the opinion of DPL's management
for a fair presentation of interim results. In accordance with regulations of
the Securities and Exchange Commission (SEC), disclosures which would
substantially duplicate the disclosures in DPL's 1998 Report on Form 10-K have
been omitted. Accordingly, DPL's consolidated condensed interim financial
statements contained herein should be read in conjunction with DPL's 1998 Report
on Form 10-K and Part II of this Report on Form 10-Q for additional relevant
information.
2. Employee Separation and Other Merger-Related Costs
--------------------------------------------------
In 1998, enhanced retirement offers and other employee separation programs were
utilized to reduce DPL's workforce. The costs for separated DPL employees and
other Merger-related costs expensed in the first six months of 1998 were $26.0
million before taxes, reducing net income by $15.8 million. The $26.0 million
charge to expense was net of a $42.3 million gain from curtailments and
settlements of pension and other postretirement benefits, based on actual
settlements through June 30, 1998. For the three months ended June 30, 1998,
gains on settlements of pension obligations ($13.3 million) and revised cost
estimates ($1.0 million) caused pre-tax expenses to decrease by $14.3 million
($8.6 million after taxes).
3. Debt
----
In May 1999, DPL repaid at maturity $30.0 million of 7.50% Medium Term Notes.
In June 1999, DPL repaid $1.2 million of 6.95% Amortizing First Mortgage Bonds.
4. Rate Matters
------------
The following information updates the disclosures previously reported in Note 6,
"Rate Matters," to DPL's Consolidated 1998 Financial Statements included in
DPL's 1998 Report on Form 10-K.
Delaware Electric Utility Restructuring Legislation
As previously reported, the Governor of Delaware signed the Electric Utility
Restructuring Act of 1999 (the Delaware Act) on March 31, 1999. The Delaware
Act phases-in customer choice of electricity suppliers during the period from
October 1999 to October 2000. Assuming that a 7.5% rate reduction, as required
by the Delaware Act, had been effective as of January 1, 1998, management
estimates that the impact on revenue of DPL would have been to decrease revenue
during the fiscal year ended December 31, 1998 by approximately $17 million.
Under the Delaware Act, after the 7.5% rate reduction is implemented in October
1999, customer rates are held constant for 3 to 4 years, depending on customer
rate class.
The Delaware Act makes DPL the provider of default service to customers who do
not choose an alternative supplier for a period of 3 or 4 years for non-
residential and residential customers, respectively. Thereafter, the Delaware
Public Service Commission (DPSC) may conduct a bidding process to select
-5-
<PAGE>
the default supplier for such customers. The DPSC also has the authority under
the Delaware Act to order DPL to divest its generating assets, as a last resort,
to remedy any adverse effects of electricity supply market power. The DPSC also
is authorized to establish licensing standards for electricity suppliers. Unless
DPL asks the DPSC to make these functions competitive earlier, and the DPSC so
orders, metering functions will be performed by DPL for 3 or 4 years after they
may choose their electricity suppliers, for non-residential customers and
residential customers, respectively.
Among other matters, unbundled rates to be charged by DPL during the "rate
freeze" periods prescribed by the Delaware Act have been agreed upon by a number
of the participants in the restructuring proceeding contemplated by the Delaware
Act. Included within the agreement on unbundled rates, which is subject to DPSC
approval, DPL would recover $16 million (Delaware retail basis) of stranded
costs, and electric rates would not be changed in the event DPL sells or
transfers generating assets.
Implementation of the Delaware Act is being overseen by the DPSC in several
separate but related proceedings. The DPSC is expected to issue orders in these
proceedings by August 31, 1999.
Maryland Electric Utility Restructuring Legislation
On April 2, 1999, the Maryland General Assembly passed the Electric Customer
Choice and Competition Act of 1999 (the Maryland Act). On April 8, 1999, the
Governor of Maryland signed the Maryland Act. The major elements of the
Maryland Act include the following:
(A) Phase-in of retail choice beginning in July 2000, with full choice for all
customers by July 2003;
(B) Rate reductions of 3% to 7.5% for residential customers, with rates then
held constant for four years;
(C) The deregulation of generating assets sold to a non-affiliate or transferred
to an affiliate prior to January 1, 2001;
(D) Recovery of stranded costs and other costs associated with the transition to
retail choice through a method to be determined by the Maryland Public Service
Commission (MPSC);
(E) Imposition by the MPSC of an environmental surcharge on each kilowatt-hour
distributed in Maryland;
(F) The creation of a statewide fund for low-income assistance.
On May 5, 1999, DPL filed a proposed settlement, which was supplemented on
August 4, 1999 to include an additional party, with the MPSC in DPL's pending
restructuring proceeding. The proposed settlement is with most parties to the
proceeding, including the MPSC Staff and the Office of People's Counsel.
Included in the proposed settlement are the following provisions: (i) effective
July 1, 2000, all of DPL's Maryland-retail customers will be eligible to select
an alternative electricity supplier; (ii) for a period of at least 3 years
thereafter, DPL will remain the supplier of "standard offer service" for
customers who do not select an alternative electricity supplier; (iii) agreed-
upon unbundled rates (including nuclear decommissioning costs and funding for
low income energy assistance programs at an estimated level of between $2 and $3
million per year); (iv) the deregulation of DPL's generating facilities, such
that electric rates would not be changed in the event DPL sells or transfers
generating assets; (v) authorization to transfer DPL generating assets to one or
more affiliates at net book value; (vi) the recovery of an estimated $8 million
(Maryland retail basis) in stranded costs from non-residential customers; (vii)
a 7.5% reduction in residential rates effective July 1, 2000 (representing a
revenue reduction of approximately $12.5 million, on an annualized basis,
assuming fiscal year 1998 sales and revenue levels); and (viii) effective July
1, 2000, "rate freezes" for 4 years for residential customers and 3 years for
non-residential customers, subject to certain adjustments. In addition, under
the proposed settlement, effective July 1, 2000, DPL customers with loads in
excess of 300 kilowatts (kW) may elect to have meters installed and read by an
alternative supplier. Prior to that date, another MPSC proceeding will be
initiated to determine the level of and recovery mechanism for, any DPL stranded
metering costs. Other DPL customers will be eligible for competitive metering on
April 1, 2002, as set forth in the Maryland Act.
The MPSC is expected to issue an order with respect to the proposed settlement
by October 1, 1999.
-6-
<PAGE>
Virginia Electric Utility Industry Restructuring Legislation
The Virginia Electric Utility Restructuring Act, signed into law on March 29,
1999, phases-in retail electric competition beginning January 1, 2002.
Asset Impairments and Charges to Earnings
Management has made a preliminary estimate of the amount of stranded costs not
expected to be recovered through regulated electricity delivery rates after the
restructuring of the electric utility industry in Delaware and Maryland. Based
on the expected Delaware and Maryland restructuring orders, management expects
that, in the third and/or fourth quarters of 1999, DPL's electricity supply
business in Delaware and Maryland will no longer be subject to the requirements
of Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for
the Effects of Certain Types of Regulation." As a result, DPL expects to apply
the requirements of SFAS No. 101 "Regulated Enterprises--Accounting for the
Discontinuation of Application of FASB Statement No. 71," and record an
extraordinary charge to earnings. As discussed below, the portion of the
expected extraordinary charge related to the impairment of assets is determined
in accordance with SFAS No. 121, "Accounting for the Impairment of Long-Lived
Assets and for Long-Lived Assets To Be Disposed Of."
To estimate the impairment of electric generating plants of DPL in accordance
with SFAS No. 121, the book value of each generating plant is first compared to
the estimated future net operating cash flows of each generating plant. Any
electric generating plant with undiscounted future net cash flows less than book
value is considered impaired, and the plant's net future cash flows are
discounted. The amount by which the book value of the impaired electric
generating plants exceeds their discounted cash flows (or other estimate of fair
value) is the estimated impairment amount.
DPL has purchased power contracts expected to be uneconomic when customer choice
begins, and the stranded cost amount associated with these arrangements is
estimated to be the net present value of the contracts' costs less the
forecasted revenues from sales of the related purchased power.
The total amount that could be charged to earnings, on a consolidated basis,
includes (a) the impairment amount for the electric generating plants of DPL,
(b) the stranded cost amount for DPL's purchased power contracts, and (c)
regulatory assets of DPL related to its electric generation business. The
charge to earnings is reduced by the estimated cost recovery through regulated
electricity delivery rates. Based on this methodology (giving effect to
estimated cost recoveries), management currently estimates that the electric
utility industry restructuring will result in an extraordinary after-tax charge
to earnings during the third and/or fourth quarter of 1999 of approximately $300
million to $425 million.
Expected Sales of Electric Generating Plants
On May 11, 1999, Conectiv announced strategic and financial initiatives that
included the intention to solicit bids for the sale of over 2,000 megawatts (MW)
of DPL's and Atlantic City Electric Company's (ACE's) nuclear and non-strategic
baseload fossil electric generating plants. Conectiv intends to retain certain
electric generating plants which are strategic to Conectiv's energy business. In
June and July 1999, Conectiv distributed offering memoranda for the proposed
sale of fossil and jointly-owned nuclear electric generating plants. Assuming
the auction process goes as planned, the divestiture of the electric generating
plants is expected to be completed by mid-2000. A summary of DPL's electric
generating plants which have been offered for sale are shown in the table on the
following page.
-7-
<PAGE>
<TABLE>
<CAPTION>
DPL Generating Units
----------------------
MW of Net Book
Capacity Value (a)
--------- ---------
<S> <C> <C>
Fossil Units:
Wholly-owned 954.0 $284.7
Jointly-owned 126.8 32.3
Jointly-owned
nuclear units 331.0 245.5
------- ------
1,411.8 $562.5
======= ======
</TABLE>
(a) Net book value is as of December 31, 1998, and is stated in millions of
dollars.
The net book value of some of the electric generating units offered for sale is
expected to be written down in 1999 due to the impairment resulting from
deregulation of DPL's electricity supply business. Since an impaired electric
generating unit is written down to its estimated fair market value net of
estimated selling costs, the sale of an impaired electric generating plant is
not expected to result in a significant gain or loss. Some of the electric
generating plants which are not impaired may be sold at a gain. Under generally
accepted accounting principles, the write-down of impaired assets is not reduced
by expected future gains on sales of assets which are not impaired by electric
utility industry restructuring; the gain on the sale of an asset is recognized
when the sale occurs.
DPL's agreements with some participants in restructuring proceedings being
conducted by the DPSC and MPSC provide that electric rates will not be changed
in the event DPL sells or transfers assets. Accordingly, subject to DPSC and
MPSC approval of these agreements, the Delaware and Maryland portions of any
gains, or losses, realized on the sale of DPL electric generating plants would
affect future earnings. There can be no assurances, however, that DPL will elect
or be able to sell any such electric generating plants, or that any gains will
be realized from such sales of electric generating plants.
5. Contingencies
-------------
Environmental Matters
- ---------------------
DPL is subject to regulation with respect to the environmental effect of its
operations, including air and water quality control, solid and hazardous waste
disposal, and limitation on land use by various federal, regional, state, and
local authorities. Costs may be incurred to clean up facilities found to be
contaminated due to past disposal practices. Federal and state statutes
authorize governmental agencies to compel responsible parties to clean up
certain abandoned or uncontrolled hazardous waste sites. DPL is currently a
potentially responsible party at three federal superfund sites. At one of these
sites, DPL has resolved its liability for clean up costs through a de minimis
settlement with the government. At this site, DPL may be liable for a claim by
the state or federal government for natural resource damages. DPL also is
alleged to be a third-party contributor at three other federal superfund sites.
DPL also has two former coal gasification sites in Delaware and one former coal
gasification site in Maryland, each of which is a state superfund site. Also,
in August 1998, the Delaware Department of Natural Resources and Environmental
Control notified DPL that it is a potentially responsible party liable for
clean-up of the Wilmington Public Works Yard as a former owner of the property.
There is $2 million included in DPL's current liabilities as of December 31,
1998, and June 30, 1999, for clean-up and other potential costs related to these
sites. DPL does not expect such future costs to have a material effect on DPL's
financial position or results of operations.
Nuclear Insurance
- -----------------
In conjunction with DPL's ownership interests in the Peach Bottom Atomic Power
Station (Peach Bottom) and Salem Nuclear Generating Station (Salem), DPL could
be assessed for a portion of any third-party claims associated with an incident
at any commercial nuclear power plant in the United States. Under the
provisions of the Price Anderson Act, if third-party claims relating to such an
incident exceed $200 million
-8-
<PAGE>
(the amount of primary insurance), DPL could be assessed up to $26.3 million on
an aggregate basis for such third-party claims. In addition, Congress could
impose a revenue-raising measure on the nuclear industry to pay such claims.
The co-owners of Peach Bottom and Salem maintain property insurance coverage of
approximately $2.8 billion for each unit for loss or damage to the units,
including coverage for decontamination expense and premature decommissioning.
In addition, DPL is a member of an industry mutual insurance company, which
provides replacement power cost coverage in the event of a major accidental
outage at a nuclear power plant. Under these coverages, DPL is subject to
potential retrospective loss experience assessments of up to $4.0 million on an
aggregate basis.
6. Supplemental Cash Flow Information
----------------------------------
<TABLE>
<CAPTION>
Six Months Ended
June 30,
-------------------
Cash paid for 1999 1998
-------- --------
<S> <C> <C>
(Dollars in thousands)
Interest, net of amounts capitalized $39,527 $40,444
Income taxes, net of refunds $36,316 $17,120
</TABLE>
7. Segments
--------
Conectiv's organizational structure and management reporting information is
aligned with Conectiv's business segments, irrespective of the subsidiary, or
subsidiaries, through which a business is conducted. Businesses are managed
based on lines of business, not legal entity. Business segment information is
not produced, or reported, on a subsidiary by subsidiary basis. Thus, as a
Conectiv subsidiary, no business segment information (as defined by SFAS No.
131, "Disclosures about Segments of an Enterprise and Related Information") is
available for DPL on a stand-alone basis.
8. Accounting for Energy Trading and Risk Management Activities
------------------------------------------------------------
In June 1999, the Financial Accounting Standards Board (FASB) issued SFAS No.
137, "Accounting for Derivative Instruments and Hedging Activities--Deferral of
the Effective Date of FASB Statement No. 133," which delays the required
implementation date for SFAS No. 133, "Accounting for Derivative Instruments and
Hedging Activities," until all fiscal quarters of all fiscal years beginning
after June 15, 2000. Reporting entities may elect to adopt SFAS No. 133 prior
to the required implementation date. SFAS No. 133 establishes accounting and
reporting standards for derivative instruments and for hedging activities. It
requires that all derivatives be recognized as assets or liabilities in the
balance sheet and be measured at fair value. Under specified conditions, a
derivative may be designated as a hedge. The change in the fair value of
derivatives which are not designated as hedges is recognized in earnings. For
derivatives designated as hedges of changes in the fair value of an asset or
liability, or as a hedge of exposure to variable cash flows of a forecasted
transaction, earnings are affected to the extent the hedge does not match
offsetting changes in the hedged item. DPL currently cannot determine the
effect that SFAS No. 133 will have on its financial statements.
On January 1, 1999, DPL adopted Emerging Issues Task Force (EITF) consensus 98-
10, "Accounting for Contracts Involved in Energy Trading and Risk Management
Activities" under which contracts entered into in connection with energy trading
activities are marked to market, with gains and losses (unrealized and realized)
included in earnings. Implementation of EITF 98-10 did not have a material
impact on net income.
-9-
<PAGE>
MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
------------------------------------------------
Earnings Summary
- ----------------
DPL's earnings applicable to common stock were $23.7 million and $32.0 million
for the three months ended June 30, 1999, and 1998, respectively. After
excluding from second quarter 1998 earnings an $8.6 million non-recurring gain
primarily for settling pension obligations to separated employees, the variance
in second quarter earnings was minimal. For the regulated utility business,
additional gross margin from higher retail electric sales was offset by the
impact of lower resale sales. The non-regulated electric and gas businesses,
including bulk Merchant sales and competitive retail sales, earned a higher
amount of gross margin on increased sales volume, which was offset by higher
operation and maintenance expenses.
DPL's earnings applicable to common stock were $58.2 million for the six months
ended June 30, 1999, compared to $26.0 million for the six months ended June 30,
1998. Earnings for last year's six-month period were reduced by an after-tax
charge of $15.8 million for DPL employee separation costs and other Merger-
related costs and a $3.5 million operating loss for the nonutility subsidiaries
which were transferred to Conectiv on March 1, 1998. After excluding these two
items from last year's six-month period earnings, the current six-month period
earnings increased by $12.9 million compared to the same period last year
primarily due to (a) higher regulated retail electric and gas sales, which
increased mainly due to colder winter weather than last year, (b) a higher
amount of gross margin from non-regulated electric and gas sales mainly due to
sales volume, and (c) lower utility operating and maintenance expenses, which
decreased mainly due to prior year Merger-related employee separations.
Electric Utility Industry Restructuring
- ---------------------------------------
Revenue Reductions and Earnings Impact
As previously reported, provisions for customer rate reductions included in
electric utility industry restructuring legislation become effective when
customer choice begins in October 1999 in Delaware, and in July 2000 in
Maryland. Without reflecting other factors, the initial reduction in DPL's
annual electric utility revenues due to the restructuring legislation rate
reductions is estimated to be approximately $30 million in total (on an
annualized basis, assuming fiscal year 1998 sales and revenues).
DPL's future earnings will also be affected by its ability to achieve cost
reductions and streamline operations. A productivity improvement and cost
reduction program was announced in May 1999 which seeks to reduce costs over the
next 12 to 18 months. Depreciation costs for generating assets will also
decrease due to a lower book value after impairment write-downs. Also, certain
costs which had previously been deferred under SFAS No. 71 will now be charged
to expense in the period incurred.
Delaware Electric Utility Restructuring Legislation
As previously reported, the Governor of Delaware signed the Electric Utility
Restructuring Act of 1999 (the Delaware Act) on March 31, 1999. The Delaware Act
phases-in customer choice of electricity suppliers during the period from
October 1999 to October 2000. Assuming that a 7.5% rate reduction, as required
by the Delaware Act, had been effective as of January 1, 1998, management
estimates that the impact on revenue of DPL would have been to decrease revenue
during the fiscal year ended December 31, 1998 by approximately $17 million.
Under the Delaware Act, after the 7.5% rate reduction is implemented in October
1999, customer rates are held constant for 3 to 4 years, depending on customer
rate class.
-10-
<PAGE>
The Delaware Act makes DPL the provider of default service to customers who do
not choose an alternative supplier for a period of 3 or 4 years for non-
residential and residential customers, respectively. Thereafter, the DPSC may
conduct a bidding process to select the default supplier for such customers.
The DPSC also has the authority under the Delaware Act to order DPL to divest
its generating assets, as a last resort, to remedy any adverse effects of
electricity supply market power. The DPSC also is authorized to establish
licensing standards for electricity suppliers. Unless DPL asks the DPSC to make
these functions competitive earlier, and the DPSC so orders, metering functions
will be performed by DPL for 3 or 4 years after they may choose their
electricity suppliers, for non-residential customers and residential customers,
respectively.
Among other matters, unbundled rates to be charged by DPL during the "rate
freeze" periods prescribed by the Delaware Act have been agreed upon by a number
of the participants in the restructuring proceeding contemplated by the Delaware
Act. Included within the agreement on unbundled rates, which is subject to DPSC
approval, DPL would recover $16 million (Delaware retail basis) of stranded
costs, and electric rates would not be changed in the event DPL sells or
transfers generating assets.
Implementation of the Delaware Act is being overseen by the DPSC in several
separate but related proceedings. The DPSC is expected to issue orders in these
proceedings by August 31, 1999.
Maryland Electric Utility Restructuring Legislation
On April 2, 1999, the Maryland General Assembly passed the Electric Customer
Choice and Competition Act of 1999 (the Maryland Act). On April 8, 1999, the
Governor of Maryland signed the Maryland Act. The major elements of the
Maryland Act include the following:
(A) Phase-in of retail choice beginning in July 2000, with full choice for all
customers by July 2003;
(B) Rate reductions of 3% to 7.5% for residential customers, with rates then
held constant for four years;
(C) The deregulation of generating assets sold to a non-affiliate or transferred
to an affiliate prior to January 1, 2001;
(D) Recovery of stranded costs and other costs associated with the transition to
retail choice through a method to be determined by the MPSC;
(E) Imposition by the MPSC of an environmental surcharge on each kilowatt-hour
distributed in Maryland;
(F) The creation of a statewide fund for low-income assistance.
On May 5, 1999, DPL filed a proposed settlement, which was supplemented on
August 4, 1999 to include an additional party, with the MPSC in DPL's pending
restructuring proceeding. The proposed settlement is with most parties to the
proceeding, including the MPSC Staff and the Office of People's Counsel.
Included in the proposed settlement are the following provisions: (i) effective
July 1, 2000, all of DPL's Maryland-retail customers will be eligible to select
an alternative electricity supplier; (ii) for a period of at least 3 years
thereafter, DPL will remain the supplier of "standard offer service" for
customers who do not select an alternative electricity supplier; (iii) agreed-
upon unbundled rates (including nuclear decommissioning costs and funding for
low income energy assistance programs at an estimated level of between $2 and $3
million per year); (iv) the deregulation of DPL's generating facilities, such
that electric rates would not be changed in the event DPL sells or transfers
generating assets; (v) authorization to transfer DPL generating assets to one or
more affiliates at net book value; (vi) the recovery of an estimated $8 million
(Maryland retail basis) in stranded costs from non-residential customers; (vii)
a 7.5% reduction in residential rates effective July 1, 2000 (representing a
revenue reduction of approximately $12.5 million, on an annualized basis,
assuming fiscal year 1998 sales and revenue levels); and (viii) effective July
1, 2000, "rate freezes" for 4 years for residential customers and 3 years for
non-residential customers, subject to certain adjustments. In addition, under
the proposed settlement, effective July 1, 2000, DPL customers with loads in
excess of 300 kW may elect to have meters installed and read by an alternative
supplier. Prior to that date, another MPSC proceeding will be initiated to
determine the level of and recovery mechanism for, any DPL stranded metering
costs. Other DPL customers will be eligible for competitive metering on April 1,
2002, as set forth in the Maryland Act.
-11-
<PAGE>
The MPSC is expected to issue an order with respect to the proposed settlement
by October 1, 1999.
Virginia Electric Utility Industry Restructuring Legislation
The Virginia Electric Utility Restructuring Act, signed into law on March 29,
1999, phases-in retail electric competition beginning January 1, 2002.
Asset Impairments and Charges to Earnings
Management has made a preliminary estimate of the amount of stranded costs not
expected to be recovered through regulated electricity delivery rates after the
restructuring of the electric utility industry in Delaware and Maryland. Based
on the expected Delaware and Maryland restructuring orders, management expects
that, in the third and/or fourth quarters of 1999, DPL's electricity supply
business in Delaware and Maryland will no longer be subject to the requirements
of SFAS No. 71, "Accounting for the Effects of Certain Types of Regulation." As
a result, DPL expects to apply the requirements of SFAS No. 101, "Regulated
Enterprises--Accounting for the Discontinuation of Application of FASB Statement
No. 71," and record an extraordinary charge to earnings. As discussed below, the
portion of the expected extraordinary charge related to the impairment of assets
is determined in accordance with SFAS No. 121, "Accounting for the Impairment of
Long-Lived Assets and for Long-Lived Assets To Be Disposed Of."
To estimate the impairment of electric generating plants of DPL in accordance
with SFAS No. 121, the book value of each generating plant is first compared to
the estimated future net operating cash flows of each generating plant. Any
electric generating plant with undiscounted future net cash flows less than book
value is considered impaired, and the plant's net future cash flows are
discounted. The amount by which the book value of the impaired electric
generating plants exceeds their discounted cash flows (or other estimate of fair
value) is the estimated impairment amount.
DPL has purchased power contracts expected to be uneconomic when customer choice
begins, and the stranded cost amount associated with these arrangements is
estimated to be the net present value of the contracts' costs less the
forecasted revenues from sales of the related purchased power.
The total amount that could be charged to earnings, on a consolidated basis,
includes (a) the impairment amount for the electric generating plants of DPL,
(b) the stranded cost amount for DPL's purchased power contracts, and (c)
regulatory assets of DPL related to its electric generation business. The
charge to earnings is reduced by the estimated cost recovery through regulated
electricity delivery rates. Based on this methodology (giving effect to
estimated cost recoveries), management currently estimates that the electric
utility industry restructuring will result in an extraordinary after-tax charge
to earnings during the third and/or fourth quarter of 1999 of approximately $300
million to $425 million.
Expected Sales of Electric Generating Plants
On May 11, 1999, Conectiv announced strategic and financial initiatives that
included the intention to solicit bids for the sale of over 2,000 MW of DPL's
and ACE's nuclear and non-strategic baseload fossil electric generating plants.
Conectiv intends to retain certain electric generating plants which are
strategic to Conectiv's energy business. In June and July 1999, Conectiv
distributed offering memoranda for the proposed sale of fossil and jointly-owned
nuclear electric generating plants. Assuming the auction process goes as
planned, the divestiture of the electric generating plants is expected to be
completed by mid-2000. A summary of DPL's electric generating plants which have
been offered for sale are shown in the table on the following page.
-12-
<PAGE>
<TABLE>
<CAPTION>
DPL Generating Units
----------------------
MW of Net Book
Capacity Value (a)
--------- ---------
<S> <C> <C>
Fossil Units:
Wholly-owned 954.0 $284.7
Jointly-owned 126.8 32.3
Jointly-owned
nuclear units 331.0 245.5
------- ------
1,411.8 $562.5
======= ======
</TABLE>
(a) Net book value is as of December 31, 1998, and is stated in millions of
dollars.
The net book value of some of the electric generating units offered for sale is
expected to be written down in 1999 due to the impairment resulting from
deregulation of DPL's electricity supply business. Since an impaired electric
generating unit is written down to its estimated fair market value net of
estimated selling costs, the sale of an impaired electric generating plant is
not expected to result in a significant gain or loss. Some of the electric
generating plants which are not impaired may be sold at a gain. Under generally
accepted accounting principles, the write-down of impaired assets is not reduced
by expected future gains on sales of assets which are not impaired by electric
utility industry restructuring; the gain on the sale of an asset is recognized
when the sale occurs.
DPL's agreements with some participants in restructuring proceedings being
conducted by the DPSC and MPSC provide that electric rates will not be changed
in the event DPL sells or transfers assets. Accordingly, subject to DPSC and
MPSC approval of these agreements, the Delaware and Maryland portions of any
gains, or losses, realized on the sale of DPL electric generating plants would
affect future earnings. There can be no assurances, however, that DPL will elect
or be able to sell any such electric generating plants, or that any gains will
be realized from such sales of electric generating plants.
Delaware Retail Natural Gas Pilot Program
On April 27, 1999, the DPSC approved DPL's plan for a Natural Gas Pilot Program.
Beginning on July 1, 1999, 15,000 current DPL residential natural gas customers
and 1,500 current DPL commercial natural gas customers will be able to choose a
natural gas supplier other than DPL. The pilot program will last two years, with
third-party gas supply beginning on November 1, 1999.
Electric Revenues
- -----------------
The table below shows the amounts of electric revenues earned which are subject
to price regulation (Regulated) and which are not subject to price regulation
(Non-regulated).
<TABLE>
<CAPTION>
Three Months Ended Six Months Ended
June 30, June 30,
------------------ ----------------
1999 1998 1999 1998
------ ------ ------ ------
(Dollars in millions)
<S> <C> <C> <C> <C>
Regulated electric revenues $247.5 $255.6 $505.1 $492.2
Non-regulated electric revenues 61.8 31.6 125.1 73.3
------ ------ ------ ------
Total electric revenues $309.3 $287.2 $630.2 $565.5
====== ====== ====== ======
</TABLE>
Fluctuations in revenues from regulated resale and interchange sales, and non-
regulated Merchant and competitive retail electricity sales, generally do not
impact earnings to the same extent as fluctuations in regulated retail
electricity sales. Gross margin percentages earned from regulated and non-
regulated bulk power sales and competitive retail electricity sales are
generally lower than the gross margin percentages earned in regulated retail
electricity markets due to product and pricing differences. Also, interchange
revenues are currently included in energy adjustment clauses, resulting in no
earnings effect from gross margins on these sales. After restructuring becomes
effective, gross margins from
-13-
<PAGE>
interchange revenues generally will affect earnings and gross margins from
regulated retail electricity sales will decrease due to rate reductions provided
for in restructuring legislation and agreements.
Electric revenues increased by $22.1 million, from $287.2 million for the second
quarter of 1998 to $309.3 million for the second quarter of 1999. The $22.1
million increase was due to a $30.2 million increase from non-regulated Merchant
bulk sales of power and competitive retail electricity sales, partly offset by
an $8.1 million decrease in regulated electric revenues. Merchant bulk sales of
power increased due to higher selling prices and sales volumes. Competitive
retail electricity sales increased mainly due to higher sales in Pennsylvania,
which introduced customer choice of electric suppliers to most Pennsylvania
electricity consumers during 1999. Regulated electric revenues decreased $8.1
million due to a $3.0 million decrease in interchange revenues and a $5.1
million decrease in resale revenues. Resale revenues decreased principally due
to lower kWh sales, mainly a result of a 60 MW contract load reduction on
September 1, 1998 by DPL's largest resale customer, Old Dominion Electric
Cooperative (ODEC). The growth in regulated electric revenues attributed to a
1.4% increase in kWh sold to retail customers was offset by the effect of lower
average rates charged under energy adjustment clauses.
Electric revenues increased by $64.7 million, from $565.5 million for the first
six months of 1998 to $630.2 million for first six months of 1999, mainly due to
a $51.8 million increase in non-regulated electric revenues. Non-regulated
electric revenues increased due to higher selling prices and sales volumes for
Merchant bulk power sales, and increased competitive retail electricity sales,
mainly due to higher sales in Pennsylvania, where most consumers became eligible
to choose their electric suppliers in 1999. Regulated electric revenues
increased $12.9 million primarily due to an $18.4 million increase in
interchange revenues partially offset by a $6.4 million decrease in resale
revenues, largely due to ODEC's 60 MW load reduction. Regulated electric retail
revenues increased $0.9 million due to a 4.3% increase in kWh sales, reflecting
colder winter weather and more customers, substantially offset by the effect of
lower average rates charged under energy adjustment clauses and two additional
months of the $11.5 million (annualized basis) Merger-related rate reduction
which became effective March 1, 1998.
Gas Revenues
- ------------
The table below shows the amounts of gas revenues earned which are subject to
price regulation (Regulated) and which are not subject to price regulation (Non-
regulated).
<TABLE>
<CAPTION>
Three Months Ended Six Months Ended
June 30, June 30,
------------------ ----------------
1999 1998 1999 1998
------ ------ ------ ------
(Dollars in millions)
<S> <C> <C> <C> <C>
Regulated gas revenues $ 22.9 $20.9 $ 75.4 $ 65.9
Non-regulated gas revenues 108.5 52.0 347.0 122.7
------ ----- ------ ------
Total gas revenues $131.4 $72.9 $422.4 $188.6
====== ===== ====== ======
</TABLE>
Regulated gas revenues increased $9.5 million for the six-month period ended
June 30, 1999, due primarily to a 14.2% increase in residential gas sales (based
on cubic feet sold) from colder winter weather which caused more cubic feet of
gas to be used to operate heating systems. Higher average rates charged under
the energy adjustment clause also contributed to the increase. Non-regulated
gas revenues increased $56.5 million for the three-month period and $224.3
million for the six-month period mainly due to higher volumes of bulk gas sales.
The margin earned from non-regulated bulk gas sales in excess of related
purchased gas costs is relatively small mainly due to the competitive nature of
bulk commodity sales.
-14-
<PAGE>
Other Services Revenues
- -----------------------
Total revenues from "Other services" decreased from $24.3 million to $17.9
million for the six-month period. The $6.4 million revenue decrease reflects a
$19.5 million decrease attributed to the transfer of DPL's nonutility
subsidiaries to Conectiv on March 1, 1998, partially offset by revenue received
for administrative facilities used by Conectiv's service company pursuant to
regulations of the 1935 Public Utility Holding Company Act. Total revenues from
"Other services" increased from $2.4 million to $10.1 million for the three-
month period, primarily due to revenues received for administrative facilities
used by Conectiv's service company.
Operating Expenses
- ------------------
Electric Fuel and Purchased Energy Expenses
Electric fuel and purchased energy expenses increased $16.0 million for the
three-month period mainly due to more energy supplied for non-regulated
electricity sales and a higher average cost per kWh of output. The $16.0
million increase was reduced by a $19.4 million decrease in energy expense
recorded pursuant to regulated energy adjustment clauses.
Electric fuel and purchased energy expenses increased $53.3 million for the six-
month period primarily due to more energy supplied for greater volumes of
regulated and non-regulated electricity sales and a higher average cost per kWh
of output. The $53.3 million increase was reduced by a $17.7 million decrease
in energy expense recorded pursuant to regulated energy adjustment clauses.
Gas Purchased
Gas purchased increased by $56.7 million to $119.2 million for the second
quarter of 1999, and by $229.6 million to $390.8 million for the first six
months of 1999. These increases were mainly due to larger volumes of gas
purchased for resale off-system and to satisfy higher on-system sales demand due
to the colder winter weather.
Other Services' Cost of Sales
Other services' cost of sales increased by $6.8 million for the three-month
period mainly due to expenses associated with the administrative facilities
being used by Conectiv's service company. Other services' cost of sales
decreased by $0.5 million for the six-month period primarily due to the transfer
of DPL's nonutility subsidiaries to Conectiv on March 1, 1998, partially offset
by the expenses associated with the administrative facilities being used by
Conectiv's service company.
Employee Separation and Other Merger-Related Costs
In the second quarter of 1998, "Employee Separation and Other Merger-Related
Costs" decreased $14.3 million ($8.6 million after taxes) primarily due to
additional settlement gains on DPL's pension obligations to separated employees.
For the six months ended June 30, 1998, $26.0 million ($15.8 million after
taxes) of "Employee Separation and Other Merger-Related Costs" were recorded
primarily for employee separation programs associated with the Merger.
Operation and Maintenance Expenses
Operation and maintenance expenses increased to $68.5 million for the three
months ended June 30, 1999 from $62.6 million for the three months ended June
30, 1998. The $5.9 million increase was primarily due to higher expenses
incurred to support the growth of the non-regulated Merchant and retail energy
businesses.
Operation and maintenance expenses decreased to $126.5 million for the first six
months of 1999 from $142.4 million for the first six months of 1998. Excluding
a $10.6 million decrease due to the transfer of the nonutility subsidiaries to
Conectiv on March 1, 1998, operation and maintenance expenses decreased $5.3
million; lower costs due to fewer employees were partly offset by higher
expenses incurred to support the growth of the non-regulated Merchant and retail
energy businesses.
-15-
<PAGE>
Year 2000
- ---------
The Year 2000 issue is the result of computer programs and embedded systems
using a two-digit format, as opposed to four digits, to indicate the year.
Computer and embedded systems with this characteristic may be unable to
interpret dates during and beyond the year 1999, which could cause a system
failure or other computer errors, leading to disruption of operations. A
project team, originally started in 1996 by ACE, is managing Conectiv's response
to this situation. A Conectiv corporate officer, reporting directly to the
Chief Executive Officer, is coordinating all Year 2000 activities. There have
been substantial challenges in identifying and correcting the computer and
embedded systems critical to generating and delivering power, delivering natural
gas and providing other services to customers.
The project team is using a phased approach to managing its activities. The
first phase was inventory and assessment of all systems, equipment, and
processes. Each identified item was given a criticality rating of high, medium
or low. Those items rated as high or medium were then subject to the second
phase of the project. The second phase -- determining and implementing
corrective action for the identified systems, equipment and processes -- will
conclude with a test of the unit being remediated. The third phase involves
system testing and compliance certification. Additionally, DPL is actively
completing contingency plans in the event that Year 2000 outages do occur.
Contingency plans have been drafted for all mission critical systems and are
being coordinated into a detailed overall Year 2000 restoration plan under the
direction of a senior-level engineering manager. Contingency plans are also
being developed for non-mission critical systems. The Year 2000 plans build on
DPL's existing expertise in service restorations. DPL is also coordinating its
efforts with state and local emergency management agencies.
Overall, Conectiv's Year 2000 Project covers approximately 140 different systems
(some with numerous components) that had been originally identified as high or
medium in criticality. However, only 21 of those 140 systems are essential for
continued operations and customer response across Conectiv's several businesses;
these are regarded as "mission critical." The Year 2000 Project team has
focused on these 21 systems, with work on the other systems continuing based on
their relative importance to Conectiv's businesses.
The following chart sets forth the current estimated completion percentage of
the 140 different systems in the Year 2000 Project by major business group, and
for the information technology systems used in managing Conectiv's business.
Conectiv expects to continue to see significant progress in remediation and
testing over the next quarter based on work that is in process and material that
has been ordered or already received, resulting in timely completion of this
work.
<TABLE>
<CAPTION>
Inventory and Corrective Action/ System Testing/
Business Group Assessment Unit Testing Compliance
- -------------- ------------- ------------------ ---------------
<S> <C> <C> <C>
Business systems 100% 98% 90%
Power production 100% 95% 90%
Electricity distribution 100% 87% 49%
Gas delivery 100% 97% 95%
Competitive services 100% 85%-100% 95%
</TABLE>
Conectiv has also been contacting vendors and service providers to review their
Year 2000 efforts. Many aspects of Conectiv's businesses are dependent on third
parties. For example, fuel suppliers must be able to provide coal or gas to
allow DPL to generate electricity.
Distribution of electricity is dependent on the overall reliability of the
electric grid. DPL has been cooperating with the North American Electric
Reliability Council (NERC) and the PJM Interconnection in Year 2000 remediation,
contingency planning and restoration planning efforts. Recent reports issued by
NERC indicate a small risk of disruption to the electric grid caused by Year
2000 issues. Conectiv's Year 2000 Project timeline and status are in line with
the recommendations of those groups, with limited exceptions.
-16-
<PAGE>
As requested by NERC, DPL filed its Year 2000 Readiness Statement with NERC
stating that 96% of work on mission critical systems had been completed as of
June 30, 1999. The exceptions to full readiness status were reported to NERC in
the regular monthly filing made on June 30, 1999. They are limited in nature and
are expected to be complete in advance of critical date changes. On the basis of
Conectiv's filings, NERC has designated Conectiv (including DPL) as "Ready with
Limited Exceptions". NERC regards exceptions as "limited" only if they "do not
pose a measurable risk to reliable electric operations into the Year 2000."
NERC, in its report to the Department of Energy dated August 3,1999, stated
that the factors it considers in making this evaluation include the number of
facilities in a reporting company, the percent of that company's capacity
included in the exception, expected completion date, importance of the
facilities included in the exception and steps taken to mitigate risks. In that
Report, NERC stated that based "on data received through June 30, 1999, NERC
believes that the electric power industry will operate reliably into the Year
2000 with the resources that are Y2k Ready today." (NERC Report, cover letter to
Department of Energy.)
In addition, DPL participated in the first of two NERC drills on April 9, 1999;
a small number of manageable issues similar to those found by other utilities
were identified and have been addressed. DPL will also participate in the second
NERC drill scheduled for September 8-9, 1999, and will conduct its own drill on
November 10, 1999. All of these drills are exercises only and, are not expected
to result in service interruptions.
Conectiv has incurred approximately $10.8 million in costs for the Year 2000
Project. The current budget for the Year 2000 Project is $10 million to $15
million, although this budget may exceed total project costs. The costs set
forth above do not include significant expenditures covering new systems, such
as Conectiv's SAP business, financial and human resources management systems, an
energy control system, and a customer information system. While these new
systems effectively remediated Year 2000 problems in the systems they replaced,
Conectiv is not reporting the expenditures on these systems in its costs for the
Year 2000 Project, because the new systems were installed principally for other
reasons. The total cost of these other projects over several years exceeds $87
million.
During July 1999, President Clinton signed the Year 2000 litigation reform bill,
known as the "Y2K Act." The Y2K Act provides some new partial liability and
damages protections to defendants in Year 2000 failure-related cases. It also
establishes new litigation procedures that plaintiffs and defendants must
follow. In general, the Y2K Act provides a pre-litigation notice period,
proportionate liability among defendants in Year 2000 cases, a requirement that
plaintiffs mitigate damages from Year 2000-related failures, and federal court
jurisdiction for Year 2000 claims. The law covers many types of civil actions
that allege harm or injury related to an actual or potential Year 2000-related
failure, or a claim or defense arising or related to such a failure. The Y2K Act
does not, however, cover civil actions for personal injury or wrongful death or
most actions brought by a government entity acting in a regulatory, supervisory
or enforcement capacity. The law governs actions brought after January 1, 1999
for a Year 2000-related failure occurring before January 1, 2003. Although the
Y2K Act will not afford DPL complete protection from Year 2000-related claims,
it should serve to help limit any liability related to any Year 2000-related
failures. DPL cannot predict the extent to which such liability will be limited
by the Y2K Act.
Since the project work is ongoing, DPL cannot with certainty determine whether
the Year 2000 issue might cause disruptions to its operations and impact related
costs and revenues. DPL assesses the status of the Year 2000 Project on at
least a semi-monthly basis to determine the likelihood of disruption. Based on
its own Year 2000 program, as well as reports from NERC and other utilities,
management believes it is unlikely that significant Year 2000-related
disruptions will occur. However, any substantial disruption to DPL's operations
could negatively impact DPL's revenues, significantly impact its customers and
could generate legal claims against DPL, liability from which may be mitigated
under the provisions of the Y2K Act. DPL's results of operations and financial
position would likely suffer an adverse impact if other entities, such as
suppliers, customers and service providers do not effectively address their Year
2000 issues.
-17-
<PAGE>
Liquidity and Capital Resources
- -------------------------------
For the six months ended June 30, 1999, operating activities provided $150.5
million of net cash, which was used primarily for $46.1 million of capital
expenditures, $47.3 million of common dividend payments to Conectiv, and to
repay $31.2 million and $9.7 million of long- and short-term debt, respectively.
The $150.5 million of net cash provided by operating activities for the six
months ended June 30, 1999 represented a $21.9 million increase compared to the
$128.6 million of net cash provided by operating activities for the six months
ended June 30, 1998. The $21.9 million increase was primarily due to the
absence of last year's employee separation payments and to higher electric and
gas revenues, net of related energy costs.
Accounts receivable and accounts payable decreased by $39.3 million and $45.6
million, respectively, as of June 30, 1999 in comparison to the balances as of
December 31, 1998. These decreases were primarily attributed to the higher
level of gas Merchant business which was being conducted during the winter, when
demand for gas is higher.
In May 1999, DPL repaid at maturity $30.0 million of 7.50% Medium Term Notes.
In June 1999, DPL repaid $1.2 million of 6.95% Amortizing First Mortgage Bonds.
Under the Public Utility Holding Company Act of 1935, as amended, DPL may not
pay dividends on common stock or preferred stock from a retained deficit or
paid-in-capital without SEC approval. In anticipation of the possibility that
retained earnings might be temporarily inadequate, due to the extraordinary
charges expected to result from electric utility industry restructuring, to fund
such dividend payments, DPL has made the necessary SEC filing which has been
duly noticed. DPL will request an appropriate order from the SEC when the final
impact and timing of the pending DPSC and MPSC electric restructuring orders is
known. It may be necessary for DPL to obtain similar such approval from the
Federal Energy Regulatory Commission (FERC). An appropriate FERC filing will be
made in the near future.
DPL's ratios of earnings to fixed charges and earnings to fixed charges and
preferred stock dividends under the SEC Method are shown below:
<TABLE>
<CAPTION>
12 Months Year Ended December 31,
Ended --------------------------------
June 30, 1999 1998 1997 1996 1995 1994
------------- ---- ---- ---- ---- ----
<S> <C> <C> <C> <C> <C> <C>
Ratio of Earnings to:
Fixed Charges (SEC Method) 3.53 2.92 2.83 3.33 3.54 3.49
Fixed Charges and Preferred Stock
Dividends (SEC Method) 3.29 2.72 2.63 2.83 2.92 2.85
</TABLE>
Under the SEC Method, earnings, including allowance for funds used during
construction, have been computed by adding income taxes and fixed charges to net
income. Fixed charges include gross interest expense, the estimated interest
component of rentals, and dividends on preferred securities of a subsidiary
trust. For the ratio of earnings to fixed charges and preferred stock
dividends, preferred stock dividends represent annualized preferred stock
dividend requirements multiplied by the ratio that pre-tax income bears to net
income.
Quantitative and Qualitative Disclosures About Market Risk
- ----------------------------------------------------------
As of June 30, 1999, there were no material changes in the information
previously disclosed under "Quantitative and Qualitative Disclosures About
Market Risk" on pages II-11 and II-12 of DPL's 1998 Annual Report on Form 10-K.
-18-
<PAGE>
Foward-Looking Statements
- -------------------------
The Private Securities Litigation Reform Act of 1995 (Litigation Reform Act)
provides a "safe harbor" for forward-looking statements to encourage such
disclosures without the threat of litigation, provided those statements are
identified as forward-looking and are accompanied by meaningful, cautionary
statements identifying important factors that could cause the actual results to
differ materially from those projected in the statement. Forward-looking
statements have been made in this report. Such statements are based on
management's beliefs as well as assumptions made by and information currently
available to management. When used herein, the words "will," "anticipate,"
"estimate," "expect," "believe," "objective," and similar expressions are
intended to identify forward-looking statements. In addition to any assumptions
and other factors referred to specifically in connection with such forward-
looking statements, factors hat could cause actual results to differ materially
from those contemplated in any forward-looking statements include, among others,
the following: deregulation of energy supply and the unbundling of delivery
services; an increasingly competitive marketplace; results of any asset
dispositions; sales retention and growth; federal and state regulatory actions;
future litigation results; costs of construction; operating restrictions;
increased costs and construction delays attributable to environmental
regulations; nuclear decommissioning and the availability of reprocessing and
storage facilities for spent nuclear fuel; and credit market concerns. DPL
undertakes no obligation to publicly update or revise any forward-looking
statements, whether as a result of new information, future events or otherwise.
The foregoing list of factors pursuant to the Litigation Reform Act should not
be construed as exhaustive or as any admission regarding the adequacy of
disclosures made by DPL prior to the effective date of the Litigation Reform
Act.
-19-
<PAGE>
PART II. OTHER INFORMATION
--------------------------
Item 5. Other Information
- --------------------------
Electric System Outages
- -----------------------
During early July 1999, including the July 4th holiday weekend, there were
electric service outages affecting customers in DPL's service territory. These
interruptions occurred during an extended period of hot and humid weather in the
mid-Atlantic region and northeastern United States. The weather caused there to
be high demands for electricity, and the weather adversely affected both
regional and local electric transmission and distribution system equipment and
operations. DPL power plant operations also were adversely affected by the
weather and then-prevailing regional and local electric system conditions.
On July 27, 1999, the DPSC initiated an investigation of outages occurring in
DPL's service territory during the same early-July period. These interruptions
of service included so-called "rolling blackouts" during which electric service
to customers was interrupted in order to preserve the overall integrity of DPL's
electric system. The DPSC investigation also is expected to address, among
other topics, customer service issues arising before and during the outages.
The MPSC has asked DPL to provide information to it about the outages occurring
in DPL's Maryland service territory.
DPL is currently responding to information requests submitted by the DPSC and
MPSC.
Item 6. Exhibits and Reports on Form 8-K
- -----------------------------------------
Exhibits
- --------
Exhibit 12-A, Computation of Ratio of Earnings to Fixed Charges
Exhibit 12-B, Computation of Ratio of Earnings to Fixed Charges and Preferred
Dividends
Exhibit 27, Financial Data Schedule
Reports on Form 8-K
- -------------------
DPL filed a Report on Form 8-K dated July 27, 1999 reporting on Item 5, Other
Events.
-20-
<PAGE>
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
Delmarva Power & Light Company
------------------------------
(Registrant)
Date: August 13, 1999 /s/ John C. van Roden
------------------- -----------------------------------
John C. van Roden, Senior Vice
President and Chief Financial Officer
-21-
<PAGE>
EXHIBIT INDEX
--------------------------
Exhibit
Title of Exhibit Number
- ------------------------------------------------------- ---------
Computation of Ratio of Earnings to Fixed Charges 12-A
Computation of Ratio of Earnings to Fixed Charges
and Preferred Dividends 12-B
Financial Data Schedule 27
<PAGE>
Exhibit 12-A
Delmarva Power & Light Company
Ratio of Earnings to Fixed Charges
----------------------------------
(Dollars in Thousands)
----------------------
<TABLE>
<CAPTION>
12 Months
Ended Year Ended December 31,
June 30, ------------------------------------------------------------
1999 1998 1997 1996 1995 1994
--------- --------- --------- --------- --------- ---------
<S> <C> <C> <C> <C> <C> <C>
Net income $ 144,398 $ 112,410 $ 105,709 $ 116,187 $ 117,488 $ 108,310
--------- --------- --------- --------- --------- ---------
Income taxes 92,448 72,276 72,155 78,340 75,540 67,613
--------- --------- --------- --------- --------- ---------
Fixed charges:
Interest on long-term debt
including amortization of
discount, premium and
expense 79,394 81,132 78,350 69,329 65,572 61,128
Other interest 8,710 9,328 12,835 12,516 10,353 9,336
Preferred dividend require-
ments of a subsidiary
trust 5,688 5,688 5,687 1,390 - -
--------- --------- --------- --------- --------- ---------
Total fixed charges 93,792 96,148 96,872 83,235 75,925 70,464
--------- --------- --------- --------- --------- ---------
Nonutility capitalized interest - - (208) (311) (304) (256)
--------- --------- --------- --------- --------- ---------
Earnings before income taxes
and fixed charges $ 330,638 $ 280,834 $ 274,528 $ 277,451 $ 268,649 $ 246,131
========= ========= ========= ========= ========= =========
Ratio of earnings to fixed charges 3.53 2.92 2.83 3.33 3.54 3.49
</TABLE>
For purposes of computing the ratio, earnings are net income plus income taxes
and fixed charges, less nonutility capitalized interest. Fixed charges consist
of interest on long- and short-term debt, amortization of debt discount,
premium, and expense, dividends on preferred securities of a subsidiary trust,
plus the interest factor associated with DPL's major leases, and one-third of
the remaining annual rentals.
<PAGE>
Exhibit 12-B
Delmarva Power & Light Company
Ratio of Earnings to Fixed Charges and Preferred Dividends
----------------------------------------------------------
(Dollars in Thousands)
--------------------
<TABLE>
<CAPTION>
12 Months
Ended Year Ended December 31,
June 30, -------------------------------------------------------------------
1999 1998 1997 1996 1995 1994
-------------- ----------- ------------ ----------- ------------ -------------
<S> <C> <C> <C> <C> <C> <C>
Net income $ 144,398 $ 112,410 $ 105,709 $ 116,187 $ 117,488 $ 108,310
-------------- ----------- ------------ ----------- ------------ -------------
Income taxes 92,448 72,276 72,155 78,340 75,540 67,613
-------------- ----------- ------------ ----------- ------------ -------------
Fixed charges:
Interest on long-term debt
including amortization of
discount, premium and
expense 79,394 81,132 78,350 69,329 65,572 61,128
Other interest 8,710 9,328 12,835 12,516 10,353 9,336
Preferred dividend require-
ments of a subsidiary
trust 5,688 5,688 5,687 1,390 - -
-------------- ----------- ------------ ----------- ------------ -------------
Total fixed charges 93,792 96,148 96,872 83,235 75,925 70,464
-------------- ----------- ------------ ----------- ------------ -------------
Nonutility capitalized interest - - (208) (311) (304) (256)
-------------- ----------- ------------ ----------- ------------ -------------
Earnings before income taxes
and fixed charges $ 330,638 $ 280,834 $ 274,528 $ 277,451 $ 268,649 $ 246,131
============== =========== ============ =========== ============ =============
Fixed charges $ 93,792 $ 96,148 $ 96,872 $ 83,235 $ 75,925 $ 70,464
Preferred dividend requirements 6,843 7,150 7,556 14,961 16,185 15,948
-------------- ----------- ------------ ----------- ------------ -------------
$ 100,635 $ 103,298 $ 104,428 $ 98,196 $ 92,110 $ 86,412
============== =========== ============ =========== ============ =============
Ratio of earnings to fixed charges
and preferred dividends 3.29 2.72 2.63 2.83 2.92 2.85
</TABLE>
For purposes of computing the ratio, earnings are net income plus income taxes
and fixed charges, less nonutility capitalized interest. Fixed charges consist
of interest on long- and short-term debt, amortization of debt discount,
premium, and expense, dividends on preferred securities of a subsidiary trust,
plus the interest factor associated with DPL's major leases, and one-third of
the remaining annual rentals. Preferred dividend requirements represent
annualized preferred dividend requirements multiplied by the ratio that pre-tax
income bears to income.
<TABLE> <S> <C>
<PAGE>
<ARTICLE> UT
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE
CONSOLIDATED BALANCE SHEET AND STATEMENT OF INCOME FROM DPL's 2ND QUARTER 1999
10-Q AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 6-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-START> JAN-01-1999
<PERIOD-END> JUN-30-1999
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 1,947,655
<OTHER-PROPERTY-AND-INVEST> 72,008
<TOTAL-CURRENT-ASSETS> 338,958
<TOTAL-DEFERRED-CHARGES> 262,036
<OTHER-ASSETS> 227,855
<TOTAL-ASSETS> 2,848,512
<COMMON> 2
<CAPITAL-SURPLUS-PAID-IN> 528,893
<RETAINED-EARNINGS> 335,148
<TOTAL-COMMON-STOCKHOLDERS-EQ> 864,043
70,000
89,703
<LONG-TERM-DEBT-NET> 950,555
<SHORT-TERM-NOTES> 12,000
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 1,545
0
<CAPITAL-LEASE-OBLIGATIONS> 13,828
<LEASES-CURRENT> 12,487
<OTHER-ITEMS-CAPITAL-AND-LIAB> 834,351
<TOT-CAPITALIZATION-AND-LIAB> 2,848,512
<GROSS-OPERATING-REVENUE> 1,070,509
<INCOME-TAX-EXPENSE> 39,737
<OTHER-OPERATING-EXPENSES> 931,753
<TOTAL-OPERATING-EXPENSES> 971,490
<OPERATING-INCOME-LOSS> 99,019
<OTHER-INCOME-NET> 3,622
<INCOME-BEFORE-INTEREST-EXPEN> 102,641
<TOTAL-INTEREST-EXPENSE> 42,434
<NET-INCOME> 60,207
1,992
<EARNINGS-AVAILABLE-FOR-COMM> 58,215
<COMMON-STOCK-DIVIDENDS> 45,666
<TOTAL-INTEREST-ON-BONDS> 0
<CASH-FLOW-OPERATIONS> 150,547
<EPS-BASIC> 0
<EPS-DILUTED> 0
</TABLE>
