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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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FORM 10-K
[X]ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934
For the fiscal year ended December 31, 1998
OR
[_]TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES
EXCHANGE ACT OF 1934
Commission file number 1-3559
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ATLANTIC CITY ELECTRIC COMPANY
(Exact name of registrant as specified in its charter)
New Jersey 21-0398280
(State of Incorporation) (I.R.S. Employer Identification No.)
800 King Street, P.O. Box 231
Wilmington, Delaware 19899
(Address of principal executive offices)
Registrant's telephone number (302) 429-3114
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Securities registered pursuant to Section 12(b) of the Act:
Title of each class Name of each exchange on which registered
------------------- -----------------------------------------
8.25% Cumulative Quarterly Income New York Stock Exchange
Preferred
Securities, liquidation
preference $25 per preferred
security issued by Atlantic
Capital I
7 3/8% Cumulative Trust Preferred New York Stock Exchange
Capital Securities, liquidation
preference $25 per preferred
security issued by Atlantic
Capital II
Securities registered pursuant to Section 12(g) of the Act: None
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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 by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to
the best of registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any
amendment to this Form 10-K. [X]
All 18,320,937 issued and outstanding shares of Atlantic City Electric
Company common stock, $3 per share par value, are owned by Conectiv.
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TABLE OF CONTENTS
Page
------
Glossary............................................................................. ii
PART I
Item 1. Business
General............................................................................. I-1
Competition and Electric Utility Industry Restructuring............................. I-1
Installed Capacity.................................................................. I-2
Electricity Supply.................................................................. I-2
Pennsylvania-New Jersey-Maryland Interconnection Association........................ I-3
Purchased Power..................................................................... I-3
Nuclear Power Plants................................................................ I-4
Fuel Supply for Electric Generation................................................. I-5
Coal.............................................................................. I-5
Oil............................................................................... I-5
Gas............................................................................... I-6
Nuclear........................................................................... I-6
Regulatory Matters.................................................................. I-6
Electric Retail Rates............................................................. I-6
Off-Tariff Rates.................................................................. I-7
Levelized Energy Adjustment Clause................................................ I-7
Electric Distribution Service Reliability and Quality Standards................... I-7
Other Regulatory Matters.......................................................... I-8
Capital Spending and Financing Program.............................................. I-8
Environmental Matters............................................................... I-9
Air Quality Regulations........................................................... I-9
Water Quality Regulations......................................................... I-9
Hazardous Substances.............................................................. I-10
Executive Officers................................................................ I-11
Item 2. Properties................................................................. I-12
Item 3. Legal Proceedings.......................................................... I-13
Item 4. Submission of Matters to a Vote of Security Holders........................ I-13
PART II
Item 5. Market for Registrant's Common Equity and Related Stockholder Matters...... II-1
Item 6. Selected Financial Data.................................................... II-2
Item 7. Management's Discussion and Analysis of Financial Condition and Results of
Operations................................................................ II-3
Item 8. Financial Statements and Supplementary Data................................ II-11
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial
Disclosure................................................................ II-37
PART III
Item 10. Directors and Executive Officers of the Registrant......................... III-1
Item 11. Executive Compensation..................................................... III-2
Item 12. Security Ownership of Certain Beneficial Owners and Management............. III-11
Item 13. Certain Relationships and Related Transactions............................. III-11
PART IV
Item 14. Exhibits, Financial Statement Schedules, and Reports on Form 8-K........... IV-1
Signatures........................................................................... IV-5
i
GLOSSARY
The following glossary lists the abbreviations used in this report.
Term Definition
---- ----------
7 3/8% Debentures..................... 7 3/8% Junior Subordinated Debentures
8.25% Debentures...................... 8.25% Junior Subordinated Deferrable
Interest Debentures
1992 Energy Act....................... National Energy Policy Act of 1992
ACE................................... Atlantic City Electric Company
the Act............................... The Electric Discount and Energy
Competition Act
AFUDC................................. Allowance For Funds Used During
Construction
Atlantic.............................. Atlantic Energy, Inc.
ALJ................................... Administrative Law Judge
BGS................................... Basic Generation Service
Clean Water Act....................... Federal Water Pollution Control Act
CRP................................... Conectiv Resource Partners, Inc.
D&D Fund.............................. Decontamination & Decommissioning Fund
DOE................................... United States Department of Energy
DPL................................... Delmarva Power & Light Company
DSM................................... Demand Side Management Plan
FASB.................................. Financial Accounting Standards Board
FERC.................................. Federal Energy Regulatory Commission
GAAP.................................. Generally Accepted Accounting
Principles
Hope Creek............................ Hope Creek Nuclear Generating Station
IPP................................... Independent Power Producer
kWh................................... Kilowatt-hour
LEC................................... Levelized Energy Clause
Litigation Reform Act................. The Private Securities Litigation
Reform Act of 1995
LLRW.................................. Low Level Radioactive Waste
LMP................................... Locational Marginal Pricing
MD&A.................................. Management's Discussion and Analysis
of Financial Condition and Results of
Operations
Merger................................ A series of merger transactions by
which DPL and ACE became subsidiaries
of Conectiv
Mortgage.............................. Mortgage and Deed of Trust
MW.................................... Megawatt
NERC.................................. North American Electric Reliability
Council
NJBPU................................. New Jersey Board of Public Utilities
NJDEP................................. New Jersey Department of Environmental
Protection
NJPDES................................ New Jersey Pollution Discharge
Elimination System
NOTR.................................. Northeast Ozone Transport Region
NOx................................... Oxides of Nitrogen
NPDES................................. National Pollution Discharge
Elimination System
NRC................................... Nuclear Regulatory Commission
NWPA.................................. Nuclear Waste Policy Act of 1982
Peach Bottom.......................... Peach Bottom Atomic Power Station
PECO.................................. PECO Energy Company
PJM Interconnection................... Pennsylvania-New Jersey-Maryland
Interconnection Association
Public Service Electric and Gas
PSE&G................................. Company
PUHCA................................. Public Utility Holding Company Act of
1935
ii
Term Definition
---- ----------
PURPA................................. Public Utility Regulatory Policy Act
of 1978
RACT.................................. Reasonably Available Control
Technology
RISC.................................. Rate Intervention Steering Committee
RTP................................... Real Time Pricing
Salem................................. Salem Nuclear Generating Station
SALP.................................. Systematic Assessment of Licensee
Performance
SEC................................... Securities and Exchange Commission
SFAS.................................. Statement of Financial Accounting
Standards
SFAS No. 71........................... SFAS No. 71, "Accounting For the
Effects of Certain Types of
Regulation"
SFAS No. 88........................... SFAS No. 88, "Employers' Accounting
For Settlements and Curtailments of
Defined Benefit Pension Plans and for
Termination Benefits"
SFAS No. 128.......................... SFAS No. 128, "Earnings Per Share"
SFAS No. 131.......................... SFAS No. 131, "Disclosures about
Segments of an Enterprise and Related
Information"
SFAS No. 133.......................... SFAS No. 133, "Accounting for
Derivative Instruments and Hedging
Activities"
SO/2/ ................................ Sulfur Dioxide
TEFA.................................. Transitional Energy Facility
Assessment Tax
USEPA................................. United States Environmental Protection
Agency
VRDB.................................. Variable Rate Demand Bonds
Westinghouse.......................... Westinghouse Electric Corporation
iii
PART I
Item 1. Business
General
Atlantic City Electric Company (ACE) is a regulated public electric utility
and a subsidiary of Conectiv, which is a Delaware corporation and a registered
holding company under the Public Utility Holding Company Act of 1935 (PUHCA).
ACE was organized under the laws of New Jersey on April 28, 1924 by merger and
consolidation of several utility companies. ACE holds the franchises necessary
to provide regulated electric service in its service territory.
ACE is primarily engaged in generating, purchasing, delivering, and selling
electricity. ACE serves approximately 488,800 customers in its service
territory which covers an area of about 2,700 square miles in the southern
one-third of New Jersey and has a population of approximately 850,000. ACE's
customer base is comprised primarily of residential and commercial customers.
In 1998, the percentages of retail electric revenues contributed by customer
class were as follows: residential--47.3%; commercial--41.1%; and industrial /
other--11.6%.
ACE's utility business is subject to regulation with respect to its retail
electric sales by the New Jersey Board of Public Utilities (NJBPU). The
Federal Energy Regulatory Commission (FERC) also has regulatory authority over
certain aspects of ACE's electric utility business, including the transmission
of electricity, the sale of electricity to municipalities and electric
cooperatives, and interchange and other purchases and sales of electricity
involving other utilities. ACE is also subject to regulation by the
Pennsylvania Public Utility Commission in limited respects concerning property
and operations in Pennsylvania.
On March 1, 1998, ACE and Delmarva Power & Light Company (DPL) became
wholly-owned subsidiaries of Conectiv (the Merger). Before the Merger, ACE was
owned by Atlantic Energy, Inc. (Atlantic). As a result of the Merger, Atlantic
no longer exists and Conectiv owns, directly or indirectly, ACE, DPL and the
nonutility subsidiaries formerly held separately by Atlantic and DPL. Conectiv
is a registered holding company under PUHCA, which imposes certain
restrictions on the operations of registered holding companies and their
subsidiaries.
As of December 31, 1998, ACE had 857 employees, of which 524 were
represented by a collective bargaining labor organization. During 1998, ACE
reduced its workforce by 573 employees, including 354 employees separated
through Merger-related employee separation programs and 219 employees
transferred to Conectiv Resource Partners, Inc. (CRP), a Conectiv subsidiary
and service company established pursuant to PUHCA. CRP provides a variety of
support services to Conectiv subsidiaries, and its employees are primarily
former DPL and ACE employees. The costs of CRP are directly assigned,
distributed and allocated to the Conectiv subsidiaries using CRP's services,
including ACE.
For additional information about the Merger, refer to Note 4 to ACE's 1998
Consolidated Financial Statements included in Item 8 of Part II.
For information concerning ACE's business segments, refer to Note 18 to
ACE's 1998 Consolidated Financial Statements included in Item 8 of Part II.
Competition and Electric Utility Industry Restructuring
For information concerning restructuring the electric utility industry in
New Jersey and the Electric Discount and Competition Act (the Act), see Note 5
to ACE's 1998 Consolidated Financial Statements included in Item 8 of Part II.
Under the Act, New Jersey electric customers may choose an electricity
supplier beginning August 1, 1999. Customers will continue to pay the local
utility a regulated price for delivery of electricity over the transmission
and distribution system. As electric utility industry restructuring is
implemented in ACE's and other utilities' service territories, gross margins
earned from supplying electricity are expected to decrease as
I-1
competition to supply customers with electricity increases. As a greater
percentage of ACE's revenues become subject to competition, financial risks
and rewards, and the volatility of earnings are expected to increase. ACE's
ability to continue reducing costs by streamlining operations, regulatory
decisions pursuant to restructuring under the Act, retention of existing
customers and the ability to gain new customers are significant determinants
of ACE's future success.
Installed Capacity
The megawatts (MW) of net installed summer electric generating capacity
available to ACE to serve its peak load as of December 31, 1998, are presented
below. See Item 2, Properties, for additional information.
% of
Source of Capacity MW Total
------------------ ----- -----
Coal-fired generating units.................................... 471 19
Oil-fired generating units..................................... 295 12
Combustion turbines/combined cycle generating units............ 524 21
Nuclear generating units....................................... 380 15
Diesel units................................................... 9 --
Long-term purchased capacity................................... 828 33
----- ---
Subtotal....................................................... 2,507 100
Short-term purchased capacity.................................. 9 --
----- ---
Total.......................................................... 2,516 100
===== ===
The net generating capacity available for operations at any time may be less
than the total net installed generating capacity due to generating units being
out of service for inspection, maintenance, repairs, or unforeseen
circumstances.
As restructuring of the electric utility industry is implemented, ACE
expects to sell some of its generating units. ACE has identified certain
generating assets that may be sold, but has not determined when such sale, or
sales, would occur.
Electricity Supply
As a member of the Pennsylvania-New Jersey-Maryland Interconnection
Association (PJM Interconnection), ACE is obligated to maintain capacity
levels based on its allocated share of estimated aggregate PJM Interconnection
capacity requirements. (The PJM Interconnection is discussed on page I-3.) ACE
periodically updates its forecast of peak demand and PJM Interconnection
reserve requirements, and re-evaluates resources available to supply projected
growth. Any short-term capacity deficiencies related to obligations to the PJM
Interconnection are expected to be satisfied through short-term capacity-only
purchases. Incremental energy supply needs are expected to be filled through
purchased power.
ACE experienced it highest historical peak demand of 2,162 MW on July 22,
1998, which was 1.6% above the previous peak demand of 2,127 MW recorded on
August 16, 1997. ACE's capacity obligation to the PJM Interconnection, which
includes a reserve margin, is based on normal weather conditions and full
implementation of its demand-side management programs. Under these conditions,
ACE's 1998 peak demand would have been approximately 2,115 MW. ACE's installed
capacity of 2,501 MW at the time of the peak resulted in a reserve margin of
18%, computed under PJM Interconnection guidelines. ACE's reserve obligation
to the PJM Interconnection is approximately 20%.
I-2
The sources of the electricity supplied to ACE's customers during 1998, 1997,
and 1996 are shown below:
Source of Electricity 1998 1997 1996
--------------------- ---- ---- ----
Generation fuel type
Coal...................................................... 26% 26% 28%
Nuclear................................................... 29 18 15
Oil/Natural Gas........................................... 4 3 2
Interchange and Purchased Power............................ 12 30 35
Nonutility Purchased Power................................. 29 23 20
--- --- ---
Total..................................................... 100% 100% 100%
=== === ===
Pennsylvania-New Jersey-Maryland Interconnection Association
As a member of the PJM Interconnection, ACE's generation and transmission
facilities are operated on an integrated basis with other electricity
suppliers in Pennsylvania, New Jersey, Maryland, and the District of Columbia,
and are interconnected with other major utilities in the United States. This
power pool improves the reliability and operating economies of the systems in
the group and provides capital economies by permitting shared reserve
requirements. The PJM Interconnection's installed capacity as of December 31,
1998, was 57,551 MW. The PJM Interconnection peak's demand during 1998 was
48,663 MW on August 15, which resulted in a summer reserve margin of 18.2%
(based on installed capacity of 57,511 MW on that date).
On October 15, 1998, the PJM Interconnection began operating a centralized
capacity credit market, providing a new option to participants for procuring
and selling surplus capacity to meet reliability obligations within the PJM
Interconnection region. Capacity is the capability to produce electric power,
typically from owned generation or third-party purchase contracts and differs
from the electric energy markets, which trade the actual energy being
generated. This market facilitates the selling and buying of capacity for
participants by providing a single point of contact for market participants
and a published capacity market clearing price.
Effective April 1, 1998, the PJM Interconnection implemented locational
marginal pricing (LMP) to establish the market clearing prices for electric
energy and to price electric transmission usage based upon costs associated
with transmission system congestion. When there is no congestion on the power
system and energy is flowing on the grid in an unconstrained manner, energy
prices are cleared at the highest bid accepted by the PJM Interconnection for
the entire PJM Interconnection region. When a limit is reached on the
transmission grid, the PJM Interconnection will operate generators to preserve
system reliability. LMP allows the PJM Interconnection to send price signals
to raise and lower generator output when the power flows are constrained.
Different energy market clearing prices are paid by wholesale power buyers and
sellers on the power grid that reflect the value relative to a system
constraint. LMP provides for an efficient allocation of congestion costs to
transmission users within the PJM Interconnection region. The FERC has
approved the use of the LMP congestion management system to allow electric
energy market participants with power contracts on neighboring electric
systems to compensate the PJM Interconnection for any unintended flows on the
PJM Interconnection system, rather than forcing those participants to curtail
their contracts.
Currently, the PJM Interconnection Operating Agreement requires bids to sell
electricity received from generation located within the PJM Interconnection
control area not to exceed the variable cost of producing such electricity.
Transactions that are bid into the PJM pool from generation located outside
the PJM Interconnection control area are capped at $1,000 per megawatt hour.
All power providers are paid the LMP set through power providers' bids.
Certain PJM Interconnection members have requested that FERC revise the PJM
Interconnection Operating Agreement to allow the submission of market based
bids to the PJM Interconnection energy market.
Purchased Power
The Public Utility Regulatory Policy Act of 1978 (PURPA) established a class
of nonutility power suppliers, known as independent power producers (IPPs),
and required electric utilities to purchase the excess power from IPPs. As a
result of PURPA, ACE has long-term contracts with four IPPs for the purchase
of 659 MW of capacity and energy. In view of electric utility industry
restructuring, various parties continue to seek the repeal of PURPA; however,
federal action with regard to PURPA is not likely to affect ACE's IPP
contracts.
I-3
ACE's NJBPU-approved IPP contracts are shown below.
MW Date of
Project Location Fuel Type Provided Commercial Operation
---------------- --------- -------- --------------------
Chester, Pennsylvania............. solid waste 75 September 1991
Pedricktown, New Jersey........... gas 116 March 1992
Carney's Point, New Jersey........ coal 249 March 1994
Logan Township, New Jersey........ coal 219 September 1994
---
Total......................... 659
===
ACE is also currently purchasing 125 MW of capacity and energy from PECO
Energy Company (PECO) under a contract which ends May 31, 2000. This agreement
replaced a terminated agreement with Pennsylvania Power & Light Company,
effective March 1998. ACE also contracts with other electric suppliers on an
as-needed basis for the purchase of short-term generating capacity, energy and
transmission capacity.
Nuclear Power Plants
ACE owns 5% of the 1,031 MW, Hope Creek Nuclear Generating Station (Hope
Creek) and 7.41% of the 2,212 MW, Salem Nuclear Generating Station (Salem).
The Hope Creek Unit and Salem Units 1 and 2 are located adjacent to each other
in Salem County, New Jersey, and are operated by Public Service Electric & Gas
(PSE&G). ACE also owns 7.51% of the 2,186 MW, Peach Bottom Atomic Power
Station (Peach Bottom), which has Units 2 and 3, is located in York County,
Pennsylvania, and is operated by PECO.
ACE's ownership share in nuclear power plants provided approximately 15% of
its installed capacity as of December 31, 1998. In 1998, ACE's share of output
from the jointly-owned nuclear power plants provided 29% of the electricity
used by ACE's customers. See Note 7 to ACE's 1998 Consolidated Financial
Statements included in Item 8 of Part II for information about ACE's
investment in jointly-owned generating stations.
The operation of nuclear generating units is regulated by the Nuclear
Regulatory Commission (NRC). Such regulation requires that all aspects of
plant operation be conducted in accordance with NRC safety and environmental
requirements and that continuous demonstrations be made to the NRC that plant
operations meet applicable requirements. The NRC has the ultimate authority to
determine whether any nuclear generating unit may operate.
As a by-product of nuclear operations, nuclear generating units produce low-
level radioactive waste (LLRW). LLRW is accumulated on-site until shipped to a
federally licensed permanent disposal facility. Salem, Hope Creek, and Peach
Bottom have on-site interim storage facilities with five-year storage
capacities.
For a discussion of the cycle of production, use and disposal of nuclear
fuel, see "Nuclear" on page I-6.
For a discussion of ACE's funding of its share of the estimated future cost
of decommissioning the Hope Creek, Peach Bottom, and Salem nuclear reactors,
see Note 15 to ACE's 1998 Consolidated Financial Statements included in Part
II, Item 8.
The NRC is requiring nuclear plant operators to report by July 1, 1999, that
their nuclear power plants are Year 2000 ready, or will be Year 2000 ready, by
January 1, 2000. PSE&G and PECO have informed ACE that they are on schedule to
meet the July 1, 1999 response date and that their nuclear operations' Year
2000 programs will make Salem, Hope Creek, and Peach Bottom Year 2000 ready by
January 1, 2000.
Salem Units 1 and 2 were removed from operation by PSE&G in the second
quarter of 1995 due to operational problems, and maintenance and safety
concerns. Due to degradation of a significant number of tubes in the Unit 1
steam generators, PSE&G replaced the Unit 1 steam generators. After receiving
NRC authorization, PSE&G returned Unit 2 to service on August 30, 1997, and
Unit 1 to service on April 17, 1998. On July 29, 1998, the NRC removed Salem
from its "watch list" of troubled nuclear plants. The Salem Unit 2 steam
generators will be inspected for tube degradation in upcoming outages.
I-4
See Note 13 to ACE's 1998 Consolidated Financial Statements included in Part
II, Item 8, for information concerning ACE's lawsuit against Westinghouse
Electric Corporation, the designer and manufacturer of the Salem steam
generators, and the financial impact of the outages.
Systematic Assessment of Licensee Performance (SALP) reports issued by the
NRC rate licensee performance in four assessment areas: Operations,
Maintenance, Engineering and Plant Support. Ratings range from a high of "1"
to a low of "3." In September 1998, the NRC issued a SALP Report on the
performance of activities at Salem for the period March 1, 1997, to August 1,
1998. Salem received a rating of 1 in Operations, a 2 in Maintenance, a 2 in
Engineering, and a 1 in Plant Support. The NRC noted that the overall
performance at Salem improved, as demonstrated by a nearly event-free return
of both units to operation following the extended outage.
On June 8, 1998, the NRC issued a SALP report on Hope Creek for the period
November 10, 1996, to May 16, 1998. Hope Creek received a rating of 2 in the
areas of Operations, Maintenance, and Engineering, and a rating of 1 in the
area of plant support. The NRC noted improved performance in all functional
areas during the period.
On July 17, 1997, the NRC issued a SALP report on Peach Bottom for the
period October 15, 1995, to June 7, 1997. Peach Bottom received a rating of 1
in the areas of Operations, Maintenance, and Plant Support, and 2 in
Engineering.
On September 16, 1998, the NRC announced that it was suspending the SALP
report process until it completes a review of its nuclear power plant
performance assessment process. The SALP process has not yet been resumed or
replaced.
Fuel Supply for Electric Generation
ACE's electric generating capacity by fuel type is shown under "Installed
Capacity" on page I-2. To facilitate the purchase of adequate amounts of fuel
at reasonable prices, ACE contracts with various suppliers of coal, oil, and
natural gas on both a long- and short-term basis. Prices under oil and natural
gas contracts are generally determined by market-based indices.
Coal
B.L. England Units 1 and 2, Deepwater Unit 6, and the Keystone and Conemaugh
Generating Stations are coal-fired. During 1998, 92% of ACE's coal supply for
these units was purchased under two long-term contracts, which expire in April
1999 and June 2001, and the balance was purchased on the spot market.
Approximately 56% of ACE's projected coal requirements are expected to be
provided under supply contracts. ACE does not anticipate any difficulty in
obtaining adequate amounts of coal at reasonable prices.
Oil
Currently, 100% of the residual oil used in B.L. England Unit 3 and
Deepwater Unit 1 is supplied under a three-year contract that expires October
31, 2000. Another three-year contract which expires October 31, 2000, provides
all of the distillate oil supply for ACE's combustion turbines.
I-5
Gas
Natural gas is the primary fuel for six of ACE's combustion turbines and a
secondary fuel at Deepwater Units 1 and 6. Natural gas for ACE's gas-fired
generating units is purchased primarily from the local gas distribution
company on a firm basis and is also purchased from other suppliers, such as
marketers, producers, and utilities. The gas is delivered under contract
through the interstate pipeline system.
Nuclear
The supply of fuel for nuclear generating units involves the mining and
milling of uranium ore to uranium concentrate, conversion of the uranium
concentrate to uranium hexaflouride, enrichment of the uranium hexaflouride
gas, conversion of the enriched gas to fuel pellets, and fabrication of fuel
assemblies. After spent fuel is removed from a nuclear reactor, it is placed
in temporary storage for cooling in a spent fuel pool at the nuclear station
site. The federal government has an obligation for the transportation and
ultimate disposal of the spent fuel, as discussed below.
PSE&G has informed ACE it has several long-term contracts with uranium ore
operators, converters, enrichers and fabricators to process uranium ore to
uranium concentrate to meet the currently projected requirements for Salem and
Hope Creek. ACE has also been advised by PECO that it has similar contracts to
satisfy the fuel requirements of Peach Bottom. Currently, there is an adequate
supply of nuclear fuel for Salem, Hope Creek, and Peach Bottom.
In conformity with the Nuclear Waste Policy Act of 1982 (NWPA), PSE&G and
PECO have entered into contracts with the United States Department of Energy
(DOE) on behalf of the joint owners providing that the federal government
shall for a fee take title to, transport, and dispose of spent nuclear fuel
and high level radioactive waste from the Salem, Hope Creek, and Peach Bottom
reactors. In accordance with the NWPA, ACE pays the DOE one-tenth of one cent
per kilowatt-hour (kWh) of nuclear generation (net of station use) for the
future cost of spent nuclear fuel disposal. Under the NWPA, the DOE was to
begin accepting spent fuel for permanent off-site storage no later than
January 1998. However, no such repositories are in service or under
construction. The DOE has stated that it would not be able to open a
permanent, high level nuclear waste storage facility until 2010, at the
earliest.
Pursuant to NRC rules, spent nuclear fuel generated in any reactor can be
stored in reactor facility storage pools or in independent spent nuclear fuel
storage installations located at or away from reactor sites for at least 30
years beyond the licensed life for operation (which may include the term of a
revised or renewed license).
PSE&G has advised ACE that, as a result of reracking the two spent fuel
storage pools at Salem, the availability of spent fuel storage capacity is
estimated to be adequate through 2012 for Unit 1 and 2016 for Unit 2. PSE&G
has also advised ACE that the Hope Creek pool is also fully racked and it is
expected to provide adequate storage capacity until 2006. PECO has advised ACE
that spent fuel racks at Peach Bottom have storage capacity until 2000 for
Unit 2 and until 2001 for Unit 3. PECO has also advised ACE that it is
constructing an on-site dry storage facility, which is expected to be
operational in 2000, to provide additional storage capacity.
Regulatory Matters
For information concerning restructuring the electric utility industry in
New Jersey, see Note 5 to ACE's 1998 Consolidated Financial Statements
included in Item 8 of Part II.
Electric Retail Rates
ACE's base rates for retail electric service are subject to the approval of
the NJBPU. However, the utility ratemaking process is changing in New Jersey,
as discussed in Note 5 to ACE's 1998 Consolidated Financial Statements
included in Item 8 of Part II.
I-6
For information concerning base rate increases and decreases affecting the
1996-1998 results of operations, including the Merger-related base rate
decrease and base rate decreases expected in connection with the electric
utility industry restructuring, see Notes 3, 5 and 13 to ACE's 1998
Consolidated Financial Statements included in Item 8 of Part II.
Off-Tariff Rates
Legislation enacted in New Jersey in July 1995 allows the NJBPU, upon
petition from any electric or gas utility, to adopt a plan of regulation other
than the traditional rate-base/rate-of-return regulation. In addition, on a
case-by-case basis, the law allows utilities to petition the NJBPU for the
right to offer customers, who meet certain conditions, off-tariff, discounted
rates. Off-tariff pricing arrangements with certain ACE customers have been
arranged. Refer to "Electric Revenues" in ACE's Management's Discussion and
Analysis of Financial Condition and Results of Operations (MD&A) herein for
further information regarding off-tariff rates (OTRAs).
Levelized Energy Adjustment Clause
Information concerning the Levelized Energy Adjustment Clause (LEC) is
included in the Notes to ACE's 1998 Consolidated Financial Statements (Part
II, Item 8) as follows: (i) the operation of the LEC and deferred energy
accounting are discussed under "Deferred Energy Costs" in Note 1, (ii) the
nuclear performance standard is discussed under "Other Rate Matters" in Note
5, and (iii) the financial impact of extended outages at Salem is discussed in
Note 13.
In January 1999, ACE filed with the NJBPU a petition requesting that the
estimated cost of oxides of nitrogen (NOx) allowances in 1999 of $4.8 million
be included in LEC rates. A ruling on this matter is expected during 1999. For
information concerning NOx emission regulations, see "Air Quality Regulations"
on page I-9.
On April 11, 1997, the Rate Intervention Steering Committee (RISC) submitted
its brief on its appeal to the Superior Court of New Jersey in response to the
NJBPU's decision which provided for ACE's recovery (through LEC rates) of the
cost of power purchased from IPPs. In May 1998, the Superior Court of New
Jersey rejected RISC's appeal and upheld the NJBPU's decision providing for
LEC recovery of IPP purchased power costs. In May 1998, RISC appealed the
Superior Court's decision to the Supreme Court of New Jersey, which denied
RISC's appeal in July 1998.
The LEC is expected to be superceded by provisions contained in the Act
which permit Basic Generation Service (BGS) suppliers full and timely recovery
of their costs. The Act also authorizes the NJBPU to allow the deferral and
subsequent recovery of BGS costs if necessary for attainment of the rate
reductions required by the Act. Regulations governing BGS are expected to be
promulgated by the NJBPU prior to beginning retail choice of electricity
suppliers in New Jersey.
Electric Distribution Service Reliability and Quality Standards
On December 30, 1997, the NJBPU directed its Staff to initiate an inquiry
into establishing measurable performance and reliability standards for New
Jersey electric and gas utilities. The Staff's most recent draft proposal does
not propose monetary penalties, but does require establishment of utility
specific standards and contains potentially costly and burdensome reporting
requirements. The NJBPU is expected to review this matter in 1999.
I-7
Other Regulatory Matters
The 1992 Energy Act provided for creation of a Decontamination &
Decommissioning (D&D) Fund to pay for the future clean-up of DOE gaseous
diffusion enrichment facilities. Domestic utilities and the federal government
are required to make payments to the D&D Fund until 2008 or $2.25 billion,
adjusted annually for inflation, is collected. The liability accrued for ACE's
share of the D&D Fund was $5.7 million as of December 31, 1998. ACE is
recovering this cost through LEC revenues.
ACE has cost allocation and direct charging mechanisms in place to ensure
that there is no cross-subsidization of its competitive activities by
regulated utility activities. In accordance with the NJBPU's order which
approved the Merger, ACE filed Conectiv's Cost Accounting Manual and the
Service Agreement between ACE and CRP with the NJBPU on October 28, 1998.
Certain types of transactions between ACE and its affiliates may require
prior approval of the NJBPU.
The New Jersey Public Utility Fault Determination Act requires the NJBPU to
make a determination of fault with regard to any past or future accident at
any electric generating or transmission facility, prior to granting a
utility's request for a rate increase to cover accident-related costs in
excess of $10 million. However, the law allows a utility to file for non-
accident related rate increases during such fault determination hearings and
to recover contributions to federally mandated or voluntary cost-sharing
plans. The law further allows the NJBPU to authorize the recovery of certain
fault-related repair, cleanup, replacement power or damage costs, if
appropriate.
Capital Spending and Financing Program
For financial information concerning ACE's capital spending and financing
program, refer to "Liquidity and Capital Resources" in the MD&A included in
Item 7 of Part II and Notes 8 and 9 to ACE's 1998 Consolidated Financial
Statements, included in Item 8 of Part II.
ACE's ratios of earnings to fixed charges and earnings to fixed charges and
preferred stock dividends under the Securities and Exchange Commission (SEC)
Methods for 1994-1998 are shown below.
Year Ended December 31,
------------------------
1998 1997 1996 1995 1994
---- ---- ---- ---- ----
Ratio of Earnings to Fixed Charges (SEC Method)... 1.66 2.84 2.59 3.19 3.07
Ratio of Earnings to Fixed Charges and Preferred
Stock Dividends (SEC Method)..................... 1.55 2.58 2.16 2.43 2.26
Under the SEC Method, earnings, including Allowance For Funds Used During
Construction (AFUDC), 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 subsidiary trusts. 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. Excluding Merger-related pre-tax charges of $79.1 million in
1998 and $22.2 million in 1997, the Ratio of Earnings to Fixed Charges was
2.74 in 1998 and 3.15 in 1997, and the Ratio of Earnings to Fixed Charges and
Preferred Stock Dividends was 2.55 in 1998 and 2.86 in 1997.
I-8
Environmental Matters
ACE is subject to various federal, regional, state, and local environmental
regulations, including air and water quality control, oil pollution control,
solid and hazardous waste disposal, and limitation on land use. Permits are
required for ACE's construction projects and the operation of existing
facilities. ACE has incurred, and expects to continue to incur, capital
expenditures and operating costs because of environmental considerations and
requirements. ACE has a continuing program to assure compliance with the
environmental standards adopted by various regulatory authorities.
Included in ACE's forecasted capital requirements are construction
expenditures for compliance with environmental regulations, which are
estimated to be $2 million in 1999.
Air Quality Regulations
The federal Clean Air Act requires utilities and other industries to
significantly reduce emissions of air pollutants such as sulfur dioxide
(SO/2/) and oxides of nitrogen (NOx). Title IV of the Clean Air Act, the acid
rain provisions, established a two-phase program which mandated reductions of
SO/2/ and NOx emissions from certain utility units by 1995 (Phase I) and
required other utility units to begin reducing SO/2/ and NOx emissions in the
year 2000 (Phase II). Phase I emission reduction requirements have been
achieved by the jointly-owned Conemaugh generating station and B.L. England
Units 1 and 2. The remainder of ACE's wholly- and jointly-owned fossil-fuel
units are required to comply with Phase II emission limits.
ACE's facilities must also comply with Title I of the Clean Air Act, the
ozone nonattainment provisions, which require states to promulgate Reasonably
Available Control Technology (RACT) regulations for existing sources located
within ozone nonattainment areas or within the Northeast Ozone Transport
Region (NOTR). In accordance with New Jersey Department of Environmental
Protection (NJDEP) regulatory requirements, ACE has submitted and received
NJDEP's approval of ACE's RACT compliance plan.
Additional "post RACT" NOx emission regulations are being pursued by states
in the NOTR. In New Jersey, post-RACT NOx control regulations require
attainment of summer seasonal emission reductions of up to 65% below 1990
levels by May 1999 and 90% by 2003 through reduced emissions or the
procurement of NOx emission allowances. ACE anticipates spending approximately
$5 to $8 million over the next five years to achieve compliance with post-RACT
NOx regulations.
In addition to the above requirements, the United States Environmental
Protection Agency (USEPA) has proposed summer seasonal NOx controls
commensurate with reductions of up to 85% below baseline years by the year
2003 for a 22 state region; including Delaware and New Jersey. Since New
Jersey will require a greater percent reduction than EPA, the ACE facilities
will most likely achieve compliance with the EPA requirement by 2003.
In July 1997, the USEPA adopted new federal air quality standards for
particulate matter and ozone. The new particulate matter standard addressed
fine particulate matter. Attainment of the fine particulate matter standard
may require reductions in NOx and SO/2/. However, under the time schedule
announced by the USEPA, particulate matter non-attainment areas will not be
designated until 2002 and control measures to meet this standard will not be
identified until 2005.
Water Quality Regulations
The federal Water Pollution Control Act, as amended (the Clean Water Act)
provides for the imposition of effluent limitations to regulate the discharge
of pollutants, including heat, into the waters of the United States. National
Pollution Discharge Elimination System (NPDES) permits issued by state
environmental regulatory agencies specify effluent limitations, monitoring
requirements, and special conditions with which facilities discharging
wastewaters must comply. To ensure that water quality is maintained, permits
are issued for a term of five years and are modified as necessary to reflect
requirements of new or revised regulations or changes in facility operations.
I-9
ACE holds New Jersey Pollution Discharge Elimination System (NJPDES) permits
issued by the NJDEP for the Deepwater and B.L. England power stations. The
NJDEP has issued a draft revised NJPDES permit for the Deepwater station which
is currently under review. The NJPDES permit for the B.L. England station will
expire in December 1999. Application for renewal will be submitted, as
required, in June 1999.
The Clean Water Act also requires that cooling water intake structures be
designed to minimize adverse environmental impact. The USEPA is required by a
consent order to propose regulations in 1999 for determining whether cooling
water intake structures represent the best technology available for minimizing
adverse environmental impacts. Final action on the proposed regulations is
required in 2001.
PSE&G is implementing the 1994 NJPDES permit issued for the jointly-owned
Salem facility which requires, among other things, water intake screen
modifications and wetlands restoration. Under the 1994 permit, PSE&G is
continuing to restore wetlands and conduct the requisite management and
monitoring associated with the special conditions of the 1994 permit. In 1999,
PSE&G must apply to renew Salem's NJPDES permit.
Hazardous Substances
The nature of the electric utility business results in the production, or
handling, of various by-products and substances which may contain substances
defined as hazardous under federal or state statutes. The disposal of
hazardous substances can result in costs 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. ACE's exposure is
minimized by adherence to environmental standards for ACE-owned facilities and
through a waste disposal contractor screening and audit process. ACE has
accrued a $1.0 million liability for potential future remediation costs
associated with certain hazardous waste sites.
In 1991, the NJDEP identified ACE as one of a number of parties allegedly
responsible for the placement of certain hazardous substances in a sanitary
landfill in Atlantic County, New Jersey. Pursuant to an action in 1992 by the
USEPA, ACE was named as one of several defendants in connection with the
alleged release of hazardous substances at a site located in Gloucester
County, New Jersey. ACE's cumulative contributions to the remediation and
clean-up of these sites have been approximately $0.4 million.
I-10
Executive Officers
The names, ages, and positions of all of the executive officers of ACE as of
December 31, 1998, are listed below, along with their business experiences
during the past five years. Officers are elected annually by Conectiv's Board
of Directors. There are no family relationships among these officers, nor any
arrangement or understanding between any officer and any other person pursuant
to which the officer was selected.
Executive Officers of ACE
(As of December 31, 1998)
Name, Age and Position Business Experience During Past 5 Years
---------------------- ---------------------------------------
Howard E. Cosgrove, 55, ....... Elected 1998 as Chairman of the Board and Chief
Chairman of the Board and Executive Officer of Conectiv, Delmarva Power &
Chief Executive Officer Light Company, and Atlantic City Electric
Company. Elected 1992 as Chairman of the Board,
President and Chief Executive Officer and
Director of Delmarva Power & Light Company.
Meredith I. Harlacher, Jr., 56, Elected 1998 as President and Chief Operating
President Officer of Conectiv, and President and Chief
Operating Officer and Director of Delmarva Power
& Light Company and Atlantic City Electric
Company. Elected 1993 as Senior Vice President
of Atlantic Energy, Inc.
Barry R. Elson, 57, ........... Elected 1998 as Executive Vice President of
Executive Vice President Conectiv, and Executive Vice President and
Director of Delmarva Power & Light Company and
Atlantic City Electric Company. Elected 1997 as
Executive Vice President, Delmarva Power & Light
Company. Executive Vice President, Cox
Communications, Inc., Atlanta, Georgia, from
1995 to 1996. Senior Vice President, Cox
Enterprises/Cox Communications, Inc., Atlanta,
Georgia, from 1984 to 1995.
Thomas S. Shaw, 51, ........... Elected 1998 as Executive Vice President of
Executive Vice President Conectiv, and Executive Vice President and
Director of Delmarva Power & Light Company and
Atlantic City Electric Company. Elected 1992 as
Senior Vice President, Delmarva Power & Light
Company.
Barbara S. Graham, 50, ........ Elected 1998 as Senior Vice President and Chief
Senior Vice President and Financial Officer of Conectiv, and Senior Vice
Chief Financial Officer President and Chief Financial Officer and
Director of Delmarva Power & Light Company and
Atlantic City Electric Company. Elected 1994 as
Senior Vice President, Treasurer and Chief
Financial Officer, Delmarva Power & Light
Company. Vice President and Chief Financial
Officer of Delmarva Power & Light Company from
1992 to 1994.
James P. Lavin, 51............. Elected 1998 as Controller of Conectiv, Delmarva
Controller and Chief Power & Light Company, and Atlantic City
Accounting Officer Electric Company. Elected 1993 as Comptroller,
Delmarva Power & Light Company.
John C. van Roden, 49.......... Elected 1998 as Senior Vice President and Chief
Senior Vice President and Financial Officer, effective January 1999, of
Chief Financial Officer* Conectiv, Delmarva Power & Light Company, and
Atlantic City Electric Company. Principal, Cook
and Belier, Inc. in 1998. Senior Vice
President/Chief Financial Officer and Vice
President/Treasurer, Lukens, Inc. from 1987 to
1998.
- --------
*Effective January 1999
I-11
Item 2. Properties
Substantially all utility plants and properties of ACE are subject to the
lien of the Mortgage under which First Mortgage Bonds are issued.
The following table sets forth the net installed summer electric capacity
available to ACE to serve its peak load as of December 31, 1998.
Net
Installed
Capacity
Station Location (kilowatts)
------- -------- -----------
Coal-Fired
B L England........... Beesley's Pt., NJ................... 284,000
Conemaugh............. New Florence, PA.................... 65,000 (A)
Keystone.............. Shelocta, PA........................ 42,000 (A)
Deepwater............. Pennsville, NJ...................... 80,000
---------
471,000
---------
Oil-Fired
B L England........... Beesley's Pt., NJ................... 155,000
Deepwater............. Pennsville, NJ...................... 140,000
---------
295,000
---------
Combustion
Turbines/Combined Cycle
Cumberland............ Millville, NJ....................... 84,000
Sherman Avenue........ Vineland, NJ........................ 81,000
Middle................ Rio Grande, NJ...................... 77,000
Carll's Corner........ Upper Deerfield Twp, NJ............. 73,000
Cedar................. Cedar Run, NJ....................... 68,000
Missouri Avenue....... Atlantic City, NJ................... 60,000
Mickleton............. Mickleton, NJ....................... 59,000
Deepwater............. Pennsville, NJ...................... 19,000
Salem................. Lower Alloways Creek Twp., NJ....... 3,000 (A)
---------
524,000
---------
Nuclear
Peach Bottom.......... Peach Bottom Twp., PA............... 164,000 (A)
Salem................. Lower Alloways Creek Twp., NJ....... 164,000 (A)
Hope Creek............ Lower Alloways Creek Twp., NJ....... 52,000 (A)
---------
380,000
---------
Diesel Units
B L England........... Beesley's Pt., NJ................... 8,000
Keystone.............. Shelocta, PA........................ 300 (A)
Conemaugh............. New Florence, PA.................... 400 (A)
---------
8,700
---------
Long-term Capacity Purchases................................. 828,000
---------
Subtotal................................................... 2,506,700
---------
Short-term Capacity Purchases................................ 9,500
---------
Total...................................................... 2,516,200
=========
(A)ACE's portion of jointly-owned plants.
I-12
ACE's electric transmission and distribution system includes 1,231
transmission poleline miles of overhead lines, 9,419 distribution poleline
miles of overhead lines, and 1,198 distribution cable miles of underground
cables.
Under New Jersey law, the State of New Jersey owns in fee simple for the
benefit of the public schools all lands now or formerly flowed by the tide up
to the mean high-water line, unless it has made a valid conveyance of its
interests in such property. In 1981, because of uncertainties raised as to
possible claims of State ownership, the New Jersey Constitution was amended to
provide that lands formerly tidal-flowed, but which were not then tidal-flowed
at any time for a period of 40 years, were not to be subject to State claim
unless the State has specifically defined and asserted a claim within one year
period ending November 2, 1982. As a result, the State published maps of the
eastern (Atlantic) coast of New Jersey depicting claims to portions of many
properties, including certain properties owned by ACE. ACE believes it has
good title to such properties and will defend its title, or will obtain such
grants from the State as may ultimately be required. The cost to acquire any
such grants may be covered by title insurance policies. Assuming that all of
such State claims were determined adversely to ACE, they would relate to land,
which, together with the improvements thereon, would amount to less than 1% of
net utility plant. No maps depicting State claims to property owned by ACE on
the western (Delaware River) side of New Jersey were published within one year
period mandated by the constitutional amendment. Nevertheless, ACE believes it
has obtained all necessary grants from the State for its improved properties
along the Delaware River.
Item 3. Legal Proceedings
See Note 13 to ACE's 1998 Consolidated Financial Statements included in Part
II, Item 8, for information concerning ACE's lawsuit against Westinghouse
Electric Corporation, the designer and manufacturer of the Salem steam
generators.
Item 4. Submission of Matters to a Vote of Security Holders
A special meeting of ACE shareholders was held on October 14, 1998 to
approve an amendment to ACE's Charter. Shareholders voted to eliminate
paragraph (7)(B)(c) of Article III of the Charter, removing a restriction on
the amount of securities representing unsecured indebtedness issuable by ACE.
Votes cast on the proposal were as follows:
Number of Shares
--------------------------------------
Outstanding For Against Abstain
----------- ---------- ------- -------
Common Securities: 18,320,937 18,320,937 -- --
Preferred Securities:
Cumulative Preferred Stock ($100 Par
Value)
4% Series............................. 77,000 59,223 232 150
4.10% Series.......................... 72,000 71,496 -- --
4.35% Series.......................... 15,000 12,183 -- --
4.35% 2nd Series...................... 36,000 35,672 -- --
4.75% Series.......................... 50,000 45,550 -- --
5.00% Series.......................... 50,000 46,455 100 --
No Par Preferred Stock
$7.80 Series.......................... 239,500 239,500 -- --
I-13
ATLANTIC CITY ELECTRIC COMPANY
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
All shares of ACE's common stock are owned by Conectiv, its parent company.
ACE is subject to certain limitations on the payment of dividends to
Conectiv. Whenever full dividends on preferred stock have been paid for all
past periods, ACE may pay dividends on its common stock from funds legally
available for such purpose. Until all cumulative dividends have been paid upon
all series of preferred stock and until certain required sinking fund
redemptions of such preferred stock have been made, no dividend or other
distribution may be paid or declared on the common stock of ACE. In addition,
as long as any preferred stock is outstanding, ACE may not pay dividends to
Conectiv if, after giving effect to such payment or distribution, the capital
of ACE represented by its common stock, together with its surplus as then
stated on its books of account, shall in the aggregate, be less than the
involuntary liquidation value of the then outstanding shares of preferred
stock.
II-1
ATLANTIC CITY ELECTRIC COMPANY
ITEM 6. SELECTED FINANCIAL DATA
1998(1) 1997(2) 1996 1995 1994(3)
------- ------- ---- ---- -------
(Thousands of Dollars)
Operating Results and
Data
Operating Revenues...... $1,037,613 $1,084,890 $ 989,647 $ 954,783 $ 913,226
Operating Income........ $ 108,868 $ 190,052 $ 165,120 $ 194,687 $ 135,660
Net Income.............. $ 30,276 $ 85,747 $ 75,017 $ 98,752 $ 93,174
Earnings Applicable to
Common Stock........... $ 29,385 $ 80,926 $ 65,113 $ 84,125 $ 76,458
Capitalization
Variable Rate Demand
Bonds (VRDB)(4)........ $ 22,600 $ 22,600 -- -- --
Long-term Debt.......... 791,127 811,144 802,245 802,356 763,289
Preferred Stock of
Subsidiaries
Subject to Mandatory
Redemption............. 118,950 103,950 113,950 114,750 149,250
Not Subject to
Mandatory Redemption.. 6,231 30,000 30,000 40,000 40,000
Common Stockholder's
Equity................. 730,093 783,033 778,425 796,042 796,260
---------- ---------- ---------- ---------- ----------
Total Capitalization
with VRDB.............. $1,669,001 $1,750,727 $1,724,620 $1,753,148 $1,748,799
========== ========== ========== ========== ==========
Other Information
Total Assets............ $2,367,222 $2,436,755 $2,460,741 $2,459,104 $2,418,784
Long-term Capital Lease
Obligations............ $ 19,523 $ 24,077 $ 24,212 $ 25,277 $ 26,102
Capital Expenditures.... $ 71,342 $ 80,896 $ 88,914 $ 100,904 $ 119,961
Common Dividends
Declared(5)............ $ 81,450 $ 80,857 $ 82,163 $ 81,239 $ 83,482
- --------
(1) As discussed in Note 4 to ACE's 1998 Consolidated Financial Statements, in
1998, employee separation and other Merger-related charges reduced
operating income $79.1 million and net income $47.2 million.
(2) In 1997, employee separation and other Merger-related charges reduced
operating income $22.6 million and net income $15.6 million.
(3) In 1994, employee separation programs reduced operating income $26.6
million and net income $17.3 million.
(4) Although Variable Rate Demand Bonds are classified as current liabilities,
ACE intends to use the bonds as a source of long-term financing as
discussed in Note 9 to ACE's 1998 Consolidated Financial Statements.
(5) Amounts shown as total, rather than on a per-share basis, since ACE is a
wholly-owned subsidiary of Conectiv.
II-2
ATLANTIC CITY ELECTRIC COMPANY
ITEM 7 MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
Merger
On March 1, 1998, Atlantic City Electric Company (ACE) and Delmarva Power &
Light Company (DPL) became wholly-owned subsidiaries of Conectiv (the Merger).
Before the Merger, Atlantic Energy, Inc. (Atlantic) owned ACE and nonutility
subsidiaries. As a result of the Merger, Atlantic no longer exists and
Conectiv owns (directly or indirectly) ACE, DPL and the nonutility
subsidiaries formerly held separately by Atlantic and DPL. Conectiv is a
registered holding company under the Public Utility Holding Company Act of
1935 (PUHCA).
In 1998, enhanced retirement offers and other employee separation programs
were utilized to reduce the workforce by 354 positions. The employee
separation programs and other Merger-related costs resulted in a $61.1 million
pre-tax charge to expense (or $36.6 million after taxes) in 1998 and a $22.2
million pre-tax charge to expenses (or $15.6 million after taxes) in 1997.
Certain of ACE's operational and administrative facilities are being sold
due to consolidation of ACE's and DPL's facilities pursuant to the Merger. The
estimated fair market value of the assets held for sale is $18.0 million less
than their aggregate carrying value of $32.7 million at December 31, 1998. In
accordance with Statement of Financial Accounting Standards (SFAS) No. 121
"Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets
to be Disposed Of," ACE has recorded an estimated impairment loss of $18.0
million ($10.6 million net of taxes).
Earnings Results Summary
ACE's earnings applicable to common stock were $29.4 million for 1998,
compared to $80.9 million for 1997, a $51.5 million decrease. Excluding the
Merger-related charges discussed above, ACE earned $76.6 million in 1998
compared to $96.5 million in 1997. This $19.9 million earnings decrease was
primarily attributed to higher operations and maintenance expenses.
Excluding the Merger-related charge of $15.6 million in 1997, earnings
increased to $96.5 million in 1997 from $65.1 million in 1996. The $31.4
million earnings increase was due to lower operations and maintenance expenses
and higher electric revenues, net of fuel, energy and capacity costs. In 1997,
ACE's share of operations and maintenance expenses associated with an extended
outage at Salem Nuclear Generating Station (Salem) was limited by an agreement
which settled ACE's related suit against the Salem operator, Public Service
Electric & Gas (PSE&G).
Electric Utility Industry Restructuring
As discussed below, the electric utility industry is being deregulated in
New Jersey. Generally, the restructuring will deregulate the supply component
of the price charged to a customer for electricity, and electricity suppliers
will compete to supply electricity to customers. Customers will continue to
pay the local utility a regulated price for the delivery of the electricity
over the transmission and distribution system.
Stranded costs are costs which may not be recoverable in a competitive
energy supply market due to lower prices or customers choosing a different
supplier. Stranded costs generally include above-market costs associated with
generation facilities or long-term purchased power agreements, and regulatory
assets. ACE has quantified stranded costs in a New Jersey regulatory filing
and has proposed a plan seeking approval for recovery of those costs from
customers during the transition to a competitive market.
When the New Jersey Board of Public Utilities (NJBPU) issues an order
specifically addressing deregulation in ACE's service territory, ACE will
cease applying SFAS No. 71, "Accounting for the Effects of Certain Types of
Regulation," to its electricity supply business. To the extent that the
NJBPU's order provides for recovery of
II-3
stranded costs through cash flows from the regulated transmission and
distribution business, the stranded costs would continue to be recognized as
assets under SFAS No. 71. Any stranded costs (including regulatory assets) for
which cost recovery is not provided would be expensed.
The amount of stranded costs ultimately recovered from utility customers, if
any, and the full impact of New Jersey legislation deregulating the electric
utility industry, as discussed below, cannot be predicted. Also, the
quantification of stranded costs under existing generally accepted accounting
principles (GAAP) differs from methods used in regulatory filings. Among other
differences, GAAP precludes recognition of the gains on plants (or purchased
power contracts) not impaired, but requires write down of the plants that are
impaired. Due to these considerations, market conditions, timing and other
factors, ACE's management currently cannot predict the ultimate effects that
electric utility industry deregulation may have on the financial statements of
ACE, although deregulation may have a material adverse effect on ACE's results
of operations.
New Jersey Legislation
The "Electric Discount and Energy Competition Act" (the Act) was signed into
law by the Governor of New Jersey on February 9, 1999. The Act provides for
retail choice of electricity suppliers; deregulation of electric rates and
other competitive services, such as metering and billing; separation of
competitive and regulated services; unbundling of rates for electric service;
and licensing of electric and gas suppliers. August 1, 1999 is the effective
starting date for each utility to provide retail choice of electricity
suppliers to all of its customers.
The Act requires each electric utility to reduce its rates by at least 5% at
the start of retail choice and by 10% within 36 months of the start of choice.
If the NJBPU determines that a rate decrease of more than 10% is warranted, a
"just and reasonable" financial test is applied. The mandated rate reductions
must be sustained through the end of the 48th month after choice begins. The
Act requires that the rate reductions be measured against the rates in effect
on April 30, 1997. The rate reductions mandated by the Act could have a
material adverse effect upon the results of operations of ACE.
In connection with the deregulation of electric rates, the Act authorizes
the NJBPU to permit electric public utilities to recover the full amount of
their stranded costs through a non-bypassable market transition charge, as
long as the mandated rate reductions are achieved. The NJBPU will determine
the utility's stranded cost amount. The NJBPU-determined stranded cost amount
will be subject to periodic recalculation and true-up over the recovery
period. The Act establishes an 8-year recovery period for stranded costs
associated with owned generation. The recovery period can be extended by the
NJBPU so as to allow for the full recovery of the stranded costs and the
meeting of mandated rate reductions. The recovery period for stranded costs
associated with purchased power contracts is to be the remainder of the
contract term. In addition, the Act would allow for the issuance of transition
bonds to finance portions of a given utility's stranded costs, as determined
to be appropriate by the NJBPU. All savings generated through the use of such
transition bonds are to be provided to the customers through rate reductions.
The Act establishes the current incumbent utility as the provider of
"default service" or Basic Generation Service (BGS) for a period of 3 years.
Future proceedings will be held to determine if the provision of BGS should be
made competitive. The Act contains numerous provisions regarding the providing
of competitive services by each utility. The primary focus is to ensure that
there is no cross subsidization from the utility to competitive entities. The
NJBPU also is required to develop fair competition standards and conduct an
audit to determine that the utilities are in compliance with those standards.
The Act gives the NJBPU the authority to order a utility to divest its
generating assets if it is determined through a hearing that competition or
customers are being adversely affected by plant location, market power or non-
competitive rates. The NJBPU may require that the generation function be
separated from a utility's non-competitive functions.
The NJBPU is authorized to establish standards for the licensing of energy
suppliers, standards for switching customers from one supplier to another, and
standards for issues such as credit and collections. The Act also contains
provisions for protecting workers displaced by the impacts of the
restructuring of the utility industry.
II-4
Stranded Cost Filing
Electric utilities in New Jersey, including ACE, previously filed stranded
cost estimates and unbundled rates, as required by the NJBPU. On August 19,
1998, an Administrative Law Judge (ALJ) from the New Jersey Office of
Administrative Law issued an initial decision on ACE's stranded costs and
unbundled rate filing. The ALJ, in reviewing ACE's filing, recognized that
ACE's stranded costs were $812 million for nonutility generation contracts and
$397 million for owned generation. The ALJ made no specific recommendations on
rate issues. A final NJBPU decision on this filing is expected by mid-1999.
Price Regulation of Energy Revenues
Through 1998, customer rates for non-energy costs have been established in
past base rate proceedings before the NJBPU. Changes in non-energy (or base
rate) revenues due to volume, or rate changes, generally affect the earnings
of ACE. Energy costs, including fuel and purchased energy, are currently
billed to ACE's rate-regulated customers under ACE's Levelized Energy Clause
(LEC) rates. These energy rates are adjusted annually for cost changes and are
subject to review by the NJBPU. "Energy revenues," or energy costs billed to
customers, do not generally affect net income, because the amount of under- or
over-recovered energy costs is generally deferred until it is subsequently
recovered from or returned to ACE's rate-regulated customers.
The LEC is expected to be superceded by provisions contained in the Act
which permit BGS suppliers full and timely recovery of their costs. The Act
also authorizes the NJBPU to permit deferral and subsequent recovery of BGS
costs if necessary for attainment of the rate reductions required by the Act.
Regulations governing BGS are expected to be promulgated by the NJBPU prior to
beginning retail choice of electricity suppliers in New Jersey.
Electric revenues also include interchange delivery revenues, which result
primarily from the sale of electricity to other electricity suppliers in the
Pennsylvania-New Jersey-Maryland Interconnection, which is an electric power
pool. Interchange delivery revenues are currently reflected in the calculation
of rates charged to customers under the LEC and, thus, do not affect net
income.
Revenues are also earned from sales not subject to price regulation. These
sales include off-system bulk commodity sales and retail energy sales.
Electric Revenues
In 1998, the percentage of electric retail revenues contributed by the
various retail customer classes were as follows: residential 47.3%; commercial
41.1%; industrial 11.0%; and other 0.6%.
Details of the changes in the various components of electric revenues, from
prior years, are shown below.
1998 1997
Variance Variance
(dollars in millions) -------- --------
Non-energy (base rate) revenues:
Change in New Jersey tax law............................ $(54.1) $ --
Merger-related base rate decrease....................... (13.3) --
Other postretirement benefits (OPEB) costs base rate
increase............................................... 5.0 --
All other variances..................................... 1.3 4.9
------ -----
Subtotal............................................... (61.1) 4.9
Energy revenues.......................................... 22.4 13.0
Interchange revenues..................................... 45.5 (3.9)
Revenues not subject to price regulation................. (40.4) 70.2
------ -----
Total.................................................. $(33.6) $84.2
====== =====
II-5
The $54.1 million decrease in electric revenues which was due to changes in
the New Jersey tax law related to sales of electricity did not affect earnings
due to corresponding reductions in taxes other than income taxes. Sales and
use taxes billed to customers in 1998 are recorded as a current liability,
whereas in prior years, certain other state taxes (which were replaced, in
part, by the sales and use taxes) were recorded as revenues. The $13.3 million
Merger-related base rate decrease shown above resulted from sharing with
utility customers the expected Merger-related cost savings, as discussed under
"Other Rate Matters" in Note 5 to the Consolidated Financial Statements. The
$5.0 million base rate increase for OPEB is for recovery of the non-cash
portion of OPEB costs deferred during 1993-1997.
"All other variances" in electric non-energy revenues primarily reflect
growth in retail kilowatt-hour (kWh) sales and the number of customers. Total
retail kWh sales increased 3.4% in 1998. Sales growth in 1998 was particularly
strong in the commercial and industrial sectors, with increases of 5.3% and
4.4%, respectively. Lower "other electric revenues" in 1998 partly offset the
additional revenues from sales growth. Other electric revenues are primarily
from non-regulated energy-related activities, such as, indoor and outdoor
lighting programs, appliance warranty programs and other energy services,
which are now being conducted through other Conectiv subsidiaries.
The 1997 increase for "All other variances" primarily reflects a 1996 $13.0
million refund to customers, which resulted from a stipulation agreement
related to Salem (as discussed in Note 13 to the Consolidated Financial
Statements), which was substantially offset by ACE's NJBPU-approved Off-Tariff
Rate Adjustments (OTRAs). OTRAs are special reduced rates offered by ACE to
large customers, which aggregated $10.5 million for 1997.
As discussed under "Price Regulation of Energy Revenues," energy and
interchange delivery revenues generally do not affect net income.
Revenues not subject to price regulation decreased $40.4 million in 1998
because non-price regulated bulk power sales have been conducted solely
through DPL subsequent to the Merger in order to achieve synergies. In 1997,
revenues from non-price regulated sales increased $70.2 million because ACE
entered the bulk power market in late-1996 and expanded sales during 1997. The
margin provided by the wholesale market revenues in excess of the related
energy costs is relatively small due to the competitive nature of bulk power
sales.
Other Services Revenues
Other services revenues represent non-regulated energy related services,
including energy management services. Effective with the Merger, most of these
services are being provided by other Conectiv subsidiaries.
Operation and Maintenance Expenses
Operation and maintenance expenses increased $29.1 million for 1998. An
actuarial valuation of ACE's pension plan liability based on updated
assumptions and data resulted in a $5.9 million pension expense increase; the
remaining increase in operation and maintenance expenses was due primarily to
lower capitalized expenses and increased contracted services.
In 1997, operation and maintenance expenses decreased $27.7 million
primarily due to reduced Salem outage expenses. An agreement which settled
ACE's lawsuit against PSE&G limited ACE's 1997 share of Salem's operation and
maintenance expenses.
Depreciation Expense
In 1998, ACE began amortizing OPEB costs deferred during 1993-1997 and
depreciating new assets, including business, financial, and human resource
management systems. Primarily due to these factors, depreciation expense
increased $12.3 million in 1998.
Taxes Other Than Income Taxes
Taxes other than income taxes decreased $65.2 million for 1998 due primarily
to the changes in the New Jersey tax laws which eliminated the state gross
receipts and franchise tax. Earnings generally were not affected
II-6
by this decrease due to related reductions in electric revenues resulting from
the tax law change. See Note 3 to the Consolidated Financial Statements for
further details on the tax law change.
Gain on Preferred Stock Redemption
In October 1998, ACE purchased and retired 237,232 shares, or $23.7 million
of various series of mandatorily redeemable preferred stock, which had an
average dividend rate of 4.4%. ACE purchased these shares at a discount, which
resulted in a gain of $2.5 million that is included in ACE's 1998 results of
operations.
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
Conectiv project team, originally started in 1996 by ACE, is assisting line
management in addressing the issue of computer programs and embedded systems
not properly recognizing the Year 2000. A Conectiv corporate officer,
reporting directly to the Chief Executive Officer, is coordinating all Year
2000 activities. There are substantial challenges in identifying and
correcting the many computer and embedded systems critical to generating and
delivering power and providing other services to customers.
The project team is using a phased approach to managing its activities. The
first phase is inventory and assessment of all systems, equipment, and
processes. Each identified item is given a criticality rating of high, medium
or low. Those items rated as high or medium are then subject to the second
phase of the project. The second phase is determining and implementing
corrective action for the systems, equipment and processes, and concludes with
a test of the unit being remediated. The third phase is system testing and
compliance certification. Additionally, the project team will be updating
existing outage contingency plans to address Year 2000 issues.
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 Conectiv to provide electric and gas service to its customers.
The Year 2000 Project team will be focusing on these 21 systems, with
additional work on other systems continuing based on their relative importance
to Conectiv's business.
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
businesses. Conectiv expects significant progress in remediation and testing
over the next quarter based on work that is in process and material that is
being ordered.
Corrective
Inventory and Action/Unit System Testing/
Business Group Assessment Testing Compliance
-------------- ------------- ----------- ---------------
Business systems................. 95% 85% 65%
Power production................. 95% 30% 30%
Electricity distribution......... 95% 10% 5%
Gas delivery..................... 95% 60% 60%
Competitive services............. 90%-95% 30%-80% 30%-80%
ACE is also contacting vendors and service providers to review remediation
of their Year 2000 issues. Many aspects of ACE's businesses are dependent on
third parties. For example, fuel suppliers must be able to provide coal or gas
to allow ACE to generate electricity.
Distribution of electricity is dependent on the overall reliability of the
electric grid. ACE is cooperating with the North American Electric Reliability
Council (NERC) and the PJM Interconnection in Year 2000 remediation and
remediation planning efforts, and has accelerated its Year 2000 Project
timeline to be generally in-line with the recommendations of those groups. At
this time, a few generating units are scheduled for remediation and
II-7
testing in September to coincide with previously scheduled outages. Recent
reports issued by the NERC indicate a diminished risk of disruption to the
electric grid caused by Year 2000 issues.
Conectiv has incurred approximately $3 million in costs for the Year 2000
Project. Current estimates of the costs for the Year 2000 Project range from
$10 million to $15 million. These estimates could change significantly as the
Year 2000 Project progresses. The costs set forth above do not include several
significant expenditures covering new systems, such as ACE's SAP business,
financial and human resources management system and an Energy Control System.
While the introduction of these new systems effectively remediated Year 2000
problems in the systems they replaced, ACE has not previously reported the
expenditures on these systems in its costs for the Year 2000 Project.
Since the project team is still in the process of assessing and correcting
impacted systems, equipment and processes, ACE cannot currently determine
whether the Year 2000 issue might cause disruptions to its operations and have
impacts on related costs and revenues. ACE assesses the status of the Year
2000 Project on at least a monthly basis to determine the likelihood of
business disruptions. Based on its own Year 2000 Project, as well as, reports
from NERC and other utilities, ACE's management believes that it is unlikely
that significant Year 2000 related disruptions will occur. However, any
substantial disruption to ACE's operations could negatively impact ACE's
revenues, significantly impact its customers and could generate legal claims
against ACE. ACE'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.
Liquidity and Capital Resources
ACE's principal sources of capital are internally generated funds (net cash
provided by operating activities, less common and preferred dividends) and
external funds. The principal capital requirements of ACE are construction
expenditures, the repayment of debt and capital lease obligations.
Internally generated funds were $157.7 million for 1998, $87.0 million for
1997 and $127.4 million for 1996. The yearly fluctuations in internally
generated funds were primarily due to changes in working capital and in fuel
revenues, net of energy and capacity costs. Internally generated funds
provided 221%, 108%, and 143%, respectively, of the cash required for
construction expenditures for 1998, 1997 and 1996. Cash construction
expenditures were $71.3 million for 1998, $80.9 million for 1997 and $88.9
million for 1996.
On an interim basis, ACE finances construction costs and other capital
requirements in excess of internally generated funds through the issuance of
unsecured short-term debt, consisting of commercial paper and notes from
banks. As of December 31, 1998, ACE had authority to issue $150 million in
short-term debt, all of which was available. ACE also has two separate
uncommitted lines of credit in the amount of $25 million and $20 million,
respectively. The facilities are renewable annually and bear interest at
variable rates.
Common dividends paid to Conectiv in 1998 were $81.5 million. Common
dividends paid to Atlantic in 1997 and 1996 were $80.9 million and $82.2
million, respectively.
Presented below are sources and uses of capital from ACE's debt and equity
securities.
1998 1997 1996
---- ---- ----
Debt/Equity Issued Redeemed Issued Redeemed Issued Redeemed
----------- ------ -------- ------ -------- ------ --------
(dollars in millions)
Short term debt......... $ -- $ (72.1) $ 7.2 $ -- $ 34.4 $ --
Long term debt.......... 85.0 (58.6) 87.6 (74.1) -- (12.3)
Preferred stock &
securities............. 25.0 (33.8) -- (20.0) 70.0 (98.9)
------ ------- ----- ------ ------ -------
$110.0 $(164.5) $94.8 $(94.1) $104.4 $(111.2)
====== ======= ===== ====== ====== =======
II-8
In January 1998, ACE issued $85 million of medium-term notes and used $50
million of the proceeds to redeem medium-term notes, which matured in January
1998.
In May 1998, ACE repaid at maturity $6.0 million of 5.5% Medium-Term Notes
and $2.5 million of 7.25% Debentures.
In August 1998, ACE redeemed 100,000 shares of its $8.20 No Par Preferred
Stock at $100 per share, or $10.0 million in total (the book value of the
preferred stock).
In October 1998, ACE redeemed $23.7 million of preferred stock not subject
to mandatory redemption, which had an average dividend rate of 4.4%. In
November 1998, a subsidiary trust of ACE issued $25 million of 7 3/8%
preferred securities subject to mandatory redemption. On a consolidated basis,
Conectiv receives a tax benefit, which is equivalent to the tax effect of a
deduction for the trust's distributions on the preferred securities.
The scheduled maturities and sinking fund requirements of debt and preferred
securities for the next five years are presented below.
Preferred
Year Debt Securities Total
---- ---- ---------- -----
(Dollars in Thousands)
1999............................................ $30,075 -- $30,075
2000............................................ $46,075 -- $46,075
2001............................................ $40,075 $11,500 $51,575
2002............................................ $50,075 $11,500 $61,575
2003............................................ $70,075 $ 950 $71,025
ACE's capital structure as of December 31, 1998 and 1997, expressed as a
percentage of total capitalization is shown below.
1998 1997
---- ----
Long-term debt and variable rate demand bonds................. 48.8% 47.6%
Preferred securities.......................................... 7.5% 7.7%
Common stockholder's equity................................... 43.7% 44.7%
ACE's estimated requirements during 1999 for capital expenditures are $85
million. The uncertainty of the impact of electric utility industry
restructuring, and the extent to which ACE retains or divest certain of its
assets, including generating plants, will affect the ultimate amount of
capital expenditures and the amount of external funds required in excess of
internally generated funds. ACE's management expects that external funds will
be derived from the sale of long-term debt, as required.
Quantitative and Qualitative Disclosures About Market Risks
The following discussion contains "forward looking statements." These
projected results have been prepared based upon certain assumptions considered
reasonable given the information currently available to ACE. Nevertheless,
because of the inherent unpredictability of interest rates and equity market
prices as well as other factors, actual results could differ materially from
those projected in such forward-looking information.
Interest Rate Risk
ACE is subject to the risk of fluctuating interest rates in the normal
course of business. ACE manages interest rates through the use of fixed and,
to a lesser extent, variable rate debt. As of December 31, 1998, a
hypothetical 10% change in interest rates would not have a material impact on
the results of operations of ACE.
II-9
Equity Price Risk
ACE maintains trust funds, as required by the Nuclear Regulatory Commission,
to fund certain costs of nuclear decommissioning. (See Note 15 to the
Consolidated Financial Statements.) These funds are invested primarily in
domestic and international equity securities, fixed-rate, fixed income
securities, and cash and cash equivalents. By maintaining a portfolio that
includes long-term equity investments, ACE is maximizing the returns to be
utilized to fund nuclear decommissioning costs. However, the equity securities
included in ACE's portfolio are exposed to price fluctuations in equity
markets, and the fixed-rate, fixed income securities are exposed to changes in
interest rates. ACE actively monitors its portfolio by benchmarking the
performance of its investments against certain indexes and by maintaining, and
periodically reviewing, established target asset allocation percentages of the
assets in the trusts. Because the accounting for nuclear decommissioning
recognizes that costs are recovered through electric rates, fluctuations in
equity prices and interest rates, while affecting the carrying value of the
investments, are offset by the effects of regulation and therefore do not
affect earnings.
Commodity Price Risk
Due to the LEC, as discussed under "Price Regulation of Energy Revenues" and
in Note 1 to the Consolidated Financial Statements, ACE's exposure to
commodity price risk is immaterial to ACE's results of operations.
Forward-Looking Statements
The Private Securities Litigation Reform Act of 1995 (Litigation Reform Act)
provides a "safe harbor" for forward looking statements to encourage such
disclosure 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," "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 that could cause actual results to differ
materially from those contemplated in any forward-looking statements include,
among others, the following: deregulation and the unbundling of energy
supplies and services; an increasingly competitive energy marketplace; sales
retention and growth; federal and state regulatory actions; costs of
construction; operating restrictions; increased cost 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. ACE 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 review 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 ACE prior to the
effective date of the Litigation Reform Act.
II-10
ATLANTIC CITY ELECTRIC COMPANY
ITEM 8.FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
REPORT OF MANAGEMENT
Management is responsible for the information and representations contained
in the consolidated financial statements of Atlantic City Electric Company
(ACE). Our consolidated financial statements have been prepared in conformity
with generally accepted accounting principles, based upon currently available
facts and circumstances and management's best estimates and judgments of the
expected effects of events and transactions.
ACE and its subsidiary companies maintain a system of internal controls
designed to provide reasonable, but not absolute, assurance of the reliability
of the financial records and the protection of assets. The internal control
system is supported by written administrative policies, a program of internal
audits, and procedures to assure the selection and training of qualified
personnel.
PricewaterhouseCoopers LLP, independent accountants, are engaged to audit
the financial statements and express their opinion thereon. Their audits are
conducted in accordance with generally accepted auditing standards which
include a review of selected internal controls to determine the nature,
timing, and extent of audit tests to be applied.
Conectiv's Audit Committee of the Board of Directors, composed of outside
directors only, meets with management, internal auditors, and independent
accountants to review accounting, auditing, and financial reporting matters.
The independent accountants are appointed by the Board on recommendation of
the Audit Committee, subject to stockholder approval.
/s/ Howard E. Cosgrove /s/ John C. van Roden
- -------------------------- --------------------------
Howard E. Cosgrove John C. van Roden
Chairman of the Board Senior Vice President and
and Chief Executive Officer Chief Financial Officer
February 5, 1999
II-11
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors
Atlantic City Electric Company
Wilmington, Delaware
In our opinion, the consolidated financial statements listed in the
accompanying index appearing under Item 14(a)(1) on page IV-1 present fairly,
in all material respects, the financial position of Atlantic City Electric
Company and subsidiary companies as of December 31, 1998, and the results of
their operations and their cash flows for the year ended December 31, 1998, in
conformity with generally accepted accounting principles. In addition, in our
opinion, the financial statement schedule listed in the accompanying index
appearing under Item 14(a)(2) on page IV-1 presents fairly, in all material
respects, the information set forth therein when read in conjunction with the
related consolidated financial statements. These financial statements and
financial statement schedule are the responsibility of the Company's
management; our responsibility is to express an opinion on these financial
statements and financial statement schedule based on our audit. We conducted
our audit of these statements in accordance with generally accepted auditing
standards which require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements, assessing
the accounting principles used and significant estimates made by management,
and evaluating the overall financial statement presentation. We believe that
our audit provides a reasonable basis for the opinion expressed above.
/s/ PricewaterhouseCoopers LLP
- --------------------------
PricewaterhouseCoopers LLP
2400 Eleven Penn Center
Philadelphia, Pennsylvania
February 5, 1999
II-12
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors
Atlantic City Electric Company
Wilmington, Delaware
We have audited the accompanying consolidated balance sheet of Atlantic City
Electric Company and subsidiary as of December 31, 1997 and the related
consolidated statements of income, changes in common stockholder's equity, and
cash flows for each of the two years in the period ended December 31, 1997.
Our audits also included the financial statement schedule for years ended
December 31, 1997 and 1996 listed in the Index as Item 14. These financial
statements and financial statement schedule are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
financial statements and financial statement schedule based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audits to
obtain reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion, such consolidated financial statements present fairly, in
all material respects, the financial position of Atlantic City Electric
Company and subsidiary at December 31, 1997 and the results of their
operations and their cash flows for each of the two years in the period ended
December 31, 1997, in conformity with generally accepted accounting
principles. Also, in our opinion, such financial statement schedule for the
years ended December 31, 1997 and 1996, when considered in relation to the
basic consolidated financial statements taken as a whole, present fairly in
all material respects the information set forth therein.
/s/ Deloitte & Touche LLP
- -----------------------
Deloitte & Touche LLP
February 2, 1998 (March 1, 1998, as to Note 4)
Parsippany, New Jersey
II-13
ATLANTIC CITY ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF INCOME
(Dollars in Thousands)
For the Year Ended December 31,
-------------------------------
1998 1997 1996
---- ---- ----
Operating Revenues
Electric................................. $ 1,034,894 $ 1,068,534 $ 984,360
Other Services........................... 2,719 16,356 5,287
----------- ----------- ---------
1,037,613 1,084,890 989,647
----------- ----------- ---------
Operating Expenses
Electric Fuel and Purchased Power........ 308,943 293,457 225,185
Cost of Sales--Other Services............ 5,465 13,566 6,742
Purchased Electric Capacity.............. 173,741 180,250 179,282
Employee Separation and Other Merger-
Related Costs........................... 61,091 22,246 --
Merger-Related Impairment Loss on Assets
Held for Sale........................... 18,000 -- --
Operation and Maintenance................ 206,951 177,875 205,615
Depreciation............................. 112,711 100,412 97,262
Taxes Other Than Income Taxes............ 41,843 107,032 110,441
----------- ----------- ---------
928,745 894,838 824,527
----------- ----------- ---------
Operating Income......................... 108,868 190,052 165,120
----------- ----------- ---------
Other Income
Allowance for Equity Funds Used During
Construction............................ 593 815 879
Other Income............................. 8,028 14,595 11,275
----------- ----------- ---------
8,621 15,410 12,154
----------- ----------- ---------
Interest Expense
Interest Charges......................... 63,940 64,501 64,847
Allowance for Borrowed Funds Used During
Construction and Capitalized Interest... (957) (1,003) (976)
----------- ----------- ---------
62,983 63,498 63,871
----------- ----------- ---------
Dividends on Preferred Securities of
Subsidiary Trusts....................... 6,052 5,775 1,428
----------- ----------- ---------
Income Before Income Taxes............... 48,454 136,189 111,975
----------- ----------- ---------
Income Taxes............................. 18,178 50,442 36,958
----------- ----------- ---------
Net Income............................... 30,276 85,747 75,017
----------- ----------- ---------
Dividends on Preferred Stock............. 3,436 4,821 9,904
Gain on Preferred Stock Redemption....... 2,545 -- --
----------- ----------- ---------
Earnings Applicable to Common Stock...... $ 29,385 $ 80,926 $ 65,113
=========== =========== =========
See accompanying Notes to Consolidated Financial Statements.
II-14
ATLANTIC CITY ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in Thousands)
For the Year Ended December 31,
-------------------------------
1998 1997 1996
---- ---- ----
Cash Flows from Operating Actvities
Net Income................................. $ 30,276 $ 85,747 $ 75,017
Adjustments to reconcile net income to net
cash provided by operating activities:
Depreciation and Amortization............. 117,285 109,000 104,408
Investment Tax Credit Adjustments, Net.... (1,690) (2,534) (2,534)
Deferred Income Taxes, Net................ (37,915) 3,330 3,982
Deferred Energy Costs..................... 43,001 6,105 (2,095)
Prepaid State Sales Taxes................. (19,522) -- --
Prepaid State Excise Taxes................ 3,248 3,321 3,628
Unrecovered State Excise Taxes............ 9,560 9,560 9,560
Employee Separation and Merger-Related
Costs.................................... 16,147 -- --
Net Change in:
Accounts Receivable....................... (500) (5,536) 5,795
Inventories............................... 5,077 3,365 (2,523)
Accounts Payable.......................... 18,765 (14,370) 2,814
Other Current Assets and Liabilities (1).. 19,198 (10,245) (2,525)
Impairment Loss on Assets Held for Sale.... 18,000 -- --
Other, Net................................. 21,687 (15,052) 23,960
---------- --------- ----------
Net Cash Provided by Operating Activities.. 242,617 172,691 219,487
---------- --------- ----------
Cash Flows from Investing Activities
Capital Expenditures....................... (71,342) (80,896) (88,914)
Nuclear Decommissioning Trust Fund
Deposits.................................. (6,424) (6,424) (6,424)
Other, Net................................. (1,040) 2,916 (9,283)
---------- --------- ----------
Net Cash Used by Investing Activities...... (78,806) (84,404) (104,621)
---------- --------- ----------
Cash Flows from Financing Activities
Dividends:
Common Stock.............................. (81,450) (80,857) (82,163)
Preferred Stock........................... (3,436) (4,821) (9,904)
Issuances:
Long-term Debt............................ 85,000 87,600 --
Preferred Securities...................... 25,000 -- 70,000
Redemptions:
Long-term Debt............................ (58,575) (74,066) (12,266)
Preferred Stock........................... (33,769) (20,000) (98,876)
Principal Portion of Capital Lease
Payments.................................. (12,295) (8,588) (7,146)
Net Change in Short-term Debt.............. (72,100) 7,150 34,405
Other, Net................................. (4,184) 2,616 (3,879)
---------- --------- ----------
Net Cash Used by Financing Activities...... (155,809) (90,966) (109,829)
---------- --------- ----------
Net Change in Cash and Cash Equivalents.... 8,002 (2,679) 5,037
Cash and Cash Equivalents at Beginning of
the Year.................................. 20,765 23,444 18,407
---------- --------- ----------
Cash and Cash Equivalents at End of the
Year...................................... $ 28,767 $ 20,765 $ 23,444
========== ========= ==========
- --------
(1) Other than debt and deferred income taxes classified as current.
See accompanying Notes to Consolidated Financial Statements.
II-15
ATLANTIC CITY ELECTRIC COMPANY
CONSOLIDATED BALANCE SHEETS
(Dollars in Thousands)
ASSETS
December 31,
------------
1998 1997
---- ----
Current Assets
Cash and Cash Equivalents................................ $ 28,767 $ 20,765
Accounts Receivable ..................................... 130,148 129,648
Allowance for Doubtful Accounts.......................... (3,500) (3,500)
Inventories, at Average Cost:
Fuel (Coal and Oil)..................................... 27,233 29,159
Materials and Supplies.................................. 21,296 20,893
Deferred Energy Costs.................................... -- 27,424
Prepaid New Jersey Sales and Excise Tax.................. 20,078 3,804
Deferred Income Taxes, Net............................... 7,735 --
Other Prepayments........................................ 4,420 3,949
---------- ----------
236,177 232,142
---------- ----------
Investments
Funds Held by Trustee.................................... 102,765 88,743
Other Investments........................................ 112 9
---------- ----------
102,877 88,752
---------- ----------
Property, Plant, and Equipment
Electric Utility Plant................................... 2,600,699 2,591,825
Less: Accumulated Depreciation........................... 1,007,106 945,921
---------- ----------
Net Utility Plant in Service............................. 1,593,593 1,645,904
Utility Construction Work-in-Progress.................... 97,955 106,806
Leased Nuclear Fuel, at Amortized Cost................... 35,003 38,795
Nonutility Property, Net................................. 8,207 8,517
---------- ----------
1,734,758 1,800,022
---------- ----------
Deferred Charges and Other Assets
Unrecovered Purchased Power Costs........................ 48,274 66,264
Deferred Recoverable Income Taxes........................ 102,223 85,858
Unrecovered State Excise Taxes........................... 35,594 45,154
Deferred Debt Refinancing Costs.......................... 28,043 30,002
Deferred Other Postretirement Benefit Costs.............. 34,978 37,476
Unamortized Debt Costs................................... 14,141 13,416
Prepaid Pension Benefit.................................. -- 8,390
Other.................................................... 30,157 29,279
---------- ----------
293,410 315,839
---------- ----------
Total Assets............................................. $2,367,222 $2,436,755
========== ==========
See accompanying Notes to Consolidated Financial Statements.
II-16
ATLANTIC CITY ELECTRIC COMPANY
CONSOLIDATED BALANCE SHEETS
(Dollars in Thousands)
CAPITALIZATION AND LIABILITIES
December 31,
------------
1998 1997
---- ----
Current Liabilites
Short-term Debt.......................................... $ -- $ 55,675
Long-term Debt Due Within One Year....................... 30,075 --
Variable Rate Demand Bonds............................... 22,600 22,600
Accounts Payable......................................... 54,315 37,779
Interest Accrued......................................... 14,774 19,562
Dividends Payable........................................ 22,236 21,215
Taxes Accrued............................................ 22,916 5,922
Current Capital Lease Obligation......................... 15,728 15,653
Accrued Employee Separation & Other Merger-related
Costs................................................... 9,554 --
Deferred Energy Costs.................................... 15,577 --
Deferred Income Taxes, Net............................... -- 9,974
Other.................................................... 28,771 37,226
---------- ----------
236,546 225,606
---------- ----------
Deferred Credits and Other Liabilities
Deferred Income Taxes, Net............................... 343,429 354,127
Deferred Investment Tax Credits.......................... 42,142 44,043
Long-term Capital Lease Obligation....................... 19,523 24,077
Pension Benefit Obligation............................... 10,477 --
Other Postretirement Benefit Obligation.................. 44,607 37,476
Other.................................................... 24,097 23,299
---------- ----------
484,275 483,022
---------- ----------
Capitalization
Common Stock, $3 Par Value; 25,000,000 Shares Authorized;
Shares Outstanding; 1998 and 1997 18,320,937............ 54,963 54,963
Additional Paid-in Capital............................... 493,007 493,161
Retained Earnings........................................ 182,123 234,909
---------- ----------
Total Common Stockholder's Equity........................ 730,093 783,033
Preferred Stock Subject to Mandatory Redemption.......... 23,950 33,950
Preferred Stock Not Subject to Mandatory Redemption...... 6,231 30,000
ACE Obligated Mandatorily Redeemable Preferred Securities
of Subsidiary Trusts Holding Solely ACE Debentures...... 95,000 70,000
Long-term Debt 791,127 811,144
---------- ----------
1,646,401 1,728,127
---------- ----------
Commitments and Contingencies (Notes 11 & 12)
Total Capitalization and Liabilities..................... $2,367,222 $2,436,755
========== ==========
See accompanying Notes to Consolidated Financial Statements.
II-17
ATLANTIC CITY ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF CHANGES
IN COMMON STOCKHOLDER'S EQUITY
(Dollars in Thousands)
Additional Paid-in Capital
--------------------------
Premium Contri- Capital
Common Capital buted Stock Retained
Stock Stock Capital Expense Earnings
------ ------- ------- ------- --------
Balance, December 31, 1995..... $54,963 $231,081 $259,645 $(2,131) $252,484
------- -------- -------- ------- --------
Net Income..................... 75,017
Capital Stock Expense.......... 486 (486)
Capital Contributed from
Parent, Net................... (567)
Less Dividends:
Preferred Stock............... (9,904)
Common Stock.................. (82,163)
------- -------- -------- ------- --------
Balance, December 31, 1996..... 54,963 231,081 259,078 (1,645) 234,948
------- -------- -------- ------- --------
Net Income..................... 85,747
Capital Stock Expense.......... 108 (108)
Capital Contributed from
Parent, Net................... 4,539
Less Dividends:
Preferred Stock............... (4,821)
Common Stock.................. (80,857)
------- -------- -------- ------- --------
Balance, December 31, 1997..... 54,963 231,081 263,617 (1,537) 234,909
------- -------- -------- ------- --------
Net Income..................... 30,276
Preferred Stock Redemption..... (64) 199 1,824
Capital Contributed from
Parent, Net................... (289)
Less Dividends:
Preferred Stock............... (3,436)
Common Stock.................. (81,450)
------- -------- -------- ------- --------
Balance, December 31, 1998..... $54,963 $231,017 $263,328 $(1,338) $182,123
======= ======== ======== ======= ========
- --------
As of December 31, 1998, ACE had 25 million authorized shares of common stock
at $3 par value. Shares outstanding at December 31, 1998, 1997 and 1996 were
18,320,937.
See accompanying Notes to Consolidated Financial Statements.
II-18
ATLANTIC CITY ELECTRIC COMPANY
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
1. SIGNIFICANT ACCOUNTING POLICIES
Nature of Business
As discussed in Note 4 to the Consolidated Financial Statements, effective
March 1, 1998, Atlantic Energy, Inc. (Atlantic), and Delmarva Power & Light
(DPL) consummated a series of merger transactions (the Merger) by which
Atlantic City Electric Company (ACE) and DPL became wholly-owned subsidiaries
of Conectiv.
ACE is a public utility primarily engaged in the generation, purchase,
transmission, distribution and sale of electricity. Sales of electricity
include sales at regulated retail and unregulated wholesale levels. Subsequent
to the Merger, unregulated wholesale or bulk power sales have been transacted
through DPL, in order to achieve Merger synergies. ACE serves approximately
488,800 customers within its service territory, which covers an area of
approximately 2,700 square miles within the southern one-third of New Jersey
and has a population of approximately 850,000. The majority of customers are
residential and commercial.
Principles of Consolidation
The consolidated financial statements include the accounts of ACE and its
wholly-owned subsidiaries. All significant intercompany accounts and
transactions have been eliminated in consolidation.
Use of Estimates
The preparation of financial statements in conformity with generally
accepted accounting principles (GAAP) requires management to make certain
estimates and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenues and expenses
during the reporting period. Actual results could differ from those estimates
and assumptions.
Reclassifications
Certain prior year amounts have been reclassified to conform to the current
year reporting of these items.
Regulation of Utility Operations
ACE is subject to regulation with respect to retail electric sales by the
New Jersey Board of Public Utilities (NJBPU). The Federal Energy Regulatory
Commission (FERC) also has regulatory authority over certain aspects of ACE's
business, including the transmission of electricity, the sale of electricity
to municipalities and electric cooperatives, and interchange and other
purchases and sales of electricity involving other utilities.
ACE is subject to the requirements of Statement of Financial Accounting
Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of
Regulation." The NJBPU occasionally provides for future recovery from
customers of current period expenses. When this happens, the expenses are
deferred as regulatory assets and subsequently recognized in the Consolidated
Statement of Income during the period the utility expenses are recovered from
customers. Similarly, regulatory liabilities may also be created due to the
economic impact of an action taken by the NJBPU. See Notes 3, 5 and 14 to the
Consolidated Financial Statements for additional information.
Revenue Recognition
At the end of each month, there is an amount of electric service rendered
from the last meter reading to the month-end, which has not yet been billed to
customers. The revenues associated with such unbilled services are
II-19
accrued by ACE and the accrued amounts receivable for unbilled electric
service were $29.7 million as of December 31, 1998 and $36.9 million as of
December 31, 1997. When interim rates are placed in effect subject to refund,
ACE recognizes revenues based on expected final rates.
Revenues from "Other services" are recognized when services are performed or
products are delivered.
Nuclear Fuel
ACE's share of nuclear fuel at the Peach Bottom Atomic Power Station (Peach
Bottom), the Salem Nuclear Generating Station (Salem), and the Hope Creek
Nuclear Generating Station (Hope Creek) is financed through contracts
accounted for as capital leases. Nuclear fuel costs, including a provision for
the future disposal of spent nuclear fuel, are charged to fuel expense on a
unit-of-production basis.
Electric Utility Plant and Allowance for Funds Used During Construction
Electric utility plant is stated at original cost, including property
additions. Generally, utility plant is subject to a First Mortgage lien.
Allowance for Funds Used During Construction (AFUDC) is included in the cost
of utility plant and represents the cost of borrowed and equity funds used to
finance construction of new utility facilities. In the Consolidated Statements
of Income, the borrowed funds component of AFUDC is reported as a reduction of
interest expense and the equity funds component of AFUDC is reported as other
income. AFUDC has been calculated using a semi-annually compounded rate of
8.25% for all periods.
Depreciation
ACE provides for straight-line depreciation based on the following:
transmission and distribution property--estimated remaining life; nuclear
property--remaining life of the related plant operating license in existence
at the time of the last base rate case; other depreciable property--estimated
average service life. Depreciation expense includes a provision for ACE's
share of the estimated cost of decommissioning nuclear power plant reactors
based on site-specific studies. Refer to Note 15 to the Consolidated Financial
Statements for additional information on nuclear decommissioning. ACE's
overall composite rate of depreciation was 3.9% for 1998 and 3.3% for 1997 and
1996. Accumulated depreciation is charged with the cost of depreciable
property retired including removal costs less salvage and other recoveries.
Funds Held by Trustee
Funds held by trustee are stated at fair market value and primarily include
deposits for nuclear decommissioning costs.
Deferred Energy Costs
As approved by the NJBPU, ACE has a Levelized Energy Clause (LEC) through
which energy and energy-related costs (energy costs) are charged to customers.
LEC rates are based on projected energy costs and prior period underrecoveries
or overrecoveries. Generally, energy costs are recovered through levelized
rates over the period of projection, which is usually a 12-month period. In
any period, the actual amount of LEC revenues recovered from customers may be
greater or less than the recoverable amount of energy costs incurred in that
period. Electric Fuel and Purchased Power expenses are adjusted to match the
associated LEC revenues. Any underrecovery (an asset representing energy costs
incurred that are to be collected from customers) or overrecovery (a liability
representing previously collected energy costs to be returned to customers) of
costs is deferred on the Consolidated Balance Sheet as Deferred Energy Costs.
These deferrals are recognized in the Consolidated Statement of Income during
the period in which they are subsequently included in the LEC rates.
Income Taxes
The consolidated financial statements include two categories of income
taxes--current and deferred. Current income taxes represent the amounts of tax
expected to be reported on ACE's federal and state income tax returns.
Deferred income taxes are discussed below.
II-20
Deferred income tax assets and liabilities represent the tax effects of
temporary differences between the financial statement and tax bases of
existing assets and liabilities and are measured using presently enacted tax
rates. The portion of ACE's deferred tax liability applicable to utility
operations that has not been recovered from utility customers represents
income taxes recoverable in the future and is shown on the Consolidated
Balance Sheets as "Deferred recoverable income taxes." Deferred recoverable
income taxes were $102.2 million and $85.9 million as of December 31, 1998,
and 1997, respectively.
Deferred income tax expense represents the net change during the reporting
period in the net deferred tax liability and deferred recoverable income
taxes.
Investment tax credits from utility plant purchased in prior years are
reported on the Consolidated Balance Sheets as "Deferred investment tax
credits." These investment tax credits are being amortized to income over the
useful lives of the related utility plant.
Energy Trading and Risk Management Activities
Since the Merger, ACE has not used derivative financial instruments because
ACE ceased its unregulated electricity trading activities. In 1997, to
minimize the risk of market fluctuations associated with unregulated
electricity trading, ACE entered into various transactions involving
derivative financial instruments for hedging purposes. Gains or losses
associated with the derivative transactions were recognized in operations in
the period the derivative instrument was terminated or extinguished or ceased
to be qualified as a hedge.
In June 1998, the Financial Accounting Standards Board (FASB) issued SFAS
No. 133, " Accounting for Derivative Instruments and Hedging Activities,"
which becomes effective in the first quarter of fiscal years beginning after
June 15, 1999, unless early adoption is elected. 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. ACE currently cannot
determine the effect that SFAS No. 133 will have on its financial statements.
Cash Equivalents
ACE considers all highly liquid investments and debt securities purchased
with a maturity of three months or less to be cash equivalents.
Debt Costs
Debt premium, discount and expense are amortized over the life of the
related debt. Costs associated with refinancing debt are deferred and
amortized over the life of the new debt.
2. SUPPLEMENTAL CASH FLOW INFORMATION
Cash paid during the year
1998 1997 1996
(Dollars in Thousands) ---- ---- ----
Interest........................................... $68,278 $64,966 $65,269
Taxes, net of refunds.............................. $48,215 $48,400 $36,937
II-21
3. INCOME TAXES
ACE, as a subsidiary of Conectiv, is included in the consolidated federal
income tax return of Conectiv. Income taxes are allocated to ACE based upon
its taxable income or loss, determined on a separate return basis.
The components of income tax expense for the years ended December 31, 1998,
1997, and 1996 are as follows:
1998 1997 1996
(Dollars in Thousands) ---- ---- ----
Federal:
Current........................................ $43,133 $49,646 $35,510
Deferred....................................... (27,694) 3,330 3,982
State:
Current........................................ 14,650 -- --
Deferred....................................... (10,221) -- --
Investment tax credit adjustments............... (1,690) (2,534) (2,534)
------- ------- -------
$18,178 $50,442 $36,958
======= ======= =======
The amount computed by multiplying income before tax by the federal
statutory rate is reconciled below to the total income tax expense.
1998 1997 1996
---- ---- ----
Amount Rate Amount Rate Amount Rate
(Dollars in Thousands) ------ ---- ------ ---- ------ ----
Statutory federal income tax
expense....................... $16,959 35% $47,666 35% $39,191 35%
State income taxes, net of
federal tax benefit........... 2,878 6 -- -- -- --
Plant basis differences........ 3,767 8 4,952 4 3,096 3
Amortization of investment tax
credits....................... (1,690) (3) (2,534) (2) (2,534) (2)
Other, net..................... (3,736) (8) 358 -- (2,795) (3)
------- --- ------- --- ------- ---
Total income tax expense....... $18,178 38% $50,442 37% $36,958 33%
======= === ======= === ======= ===
Effective January 1, 1998, New Jersey eliminated the Gross Receipts and
Franchise Tax paid by electric, natural gas and telecommunication public
utilities. In its place, utilities are now subject to the state's corporate
business tax. In addition, the state's existing sales and use tax was expanded
to include retail sales of electric power and natural gas. A Transitional
Energy Facility Assessment Tax (TEFA) on electric and natural gas utilities
will be phased-out over a five-year period. On January 1, 1999, and each of
the four years thereafter, the TEFA will be reduced by 20%. When fully
implemented, the tax law changes will reduce ACE's effective state tax rate
from 13% to approximately 7%. Savings from these changes in New Jersey tax law
will be passed through to ACE's customers.
II-22
Items comprising deferred tax balances as of December 31, 1998 and 1997 are
as follows:
1998 1997
(Dollars in Thousands) ---- ----
Deferred tax liabilities:
Utility plant basis differences......................... $274,773 $302,238
Deferred recoverable income taxes....................... 35,944 30,050
Unrecovered purchase power costs........................ 12,239 16,813
State excise taxes...................................... 12,822 16,326
Other................................................... 31,852 34,190
-------- --------
Total deferred tax liabilities........................ 367,630 399,617
-------- --------
Deferred tax assets:
Deferred investment tax credits......................... 22,749 23,775
Other................................................... 9,187 11,741
-------- --------
Total deferred tax assets............................. 31,936 35,516
-------- --------
Total deferred taxes, net............................... $335,694 $364,101
======== ========
4. MERGER
On March 1, 1998, ACE and DPL became wholly-owned subsidiaries of Conectiv
(the Merger). Before the Merger, Atlantic owned ACE and nonutility
subsidiaries. As a result of the Merger, Atlantic no longer exists and
Conectiv owns (directly or indirectly) ACE, DPL and the nonutility
subsidiaries formerly held separately by Atlantic and DPL. Conectiv is a
registered holding company under the Public Utility Holding Company Act of
1935 (PUHCA).
The Merger was accounted for under the purchase method, with DPL as the
acquirer. ACE's financial statements do not reflect "push-down" accounting--
the adjustment of the values of assets and liabilities as of the Merger date
and recording of goodwill. Push-down accounting was not used because ACE had
preferred stock and public debt outstanding as of the Merger date.
Under the terms of the agreement, Atlantic stockholders received 0.75 shares
of Conectiv's common stock and 0.125 shares of Conectiv's Class A common stock
for each share of Atlantic stock held. DPL stockholders received one share of
Conectiv's common stock for each share of DPL common stock held.
ACE has recorded the financial effects of enhanced retirement offers and
other employee separation programs utilized to reduce the workforce by 354
positions. The employee separation programs and other Merger-related costs
resulted in a $61.1 million pre-tax charge to expense (or $36.6 million after
taxes) for the year ended December 31, 1998 and a $22.2 million pre-tax charge
to expenses (or $15.6 million after taxes) for the year ended December 31,
1997. The pre-tax expenses are shown on the Statement of Income as "Employee
separation and other merger-related costs." As of December 31, 1998, $35.4
million of the $61.1 million expense for the year ended December 31, 1998 had
been paid, $16.1 million will not require the use of operating funds, and $9.6
million remains to be paid from operating funds.
As part of the Merger, ACE has consolidated its operational and
administrative facilities throughout its regulated service territory, causing
certain assets to be held for sale. The estimated fair market value of these
assets is $18.0 million less than their aggregate carrying value of $32.7
million as of December 31, 1998. In accordance with, SFAS No. 121, "Accounting
for the Impairment of Long-Lived Assets and for Long-Lived Assets to be
Disposed Of," ACE recorded in the fourth quarter of 1998 an estimated
impairment loss of $18.0 million ($10.6 million net of taxes).
NOTE 5. RATE MATTERS
Electric Utility Industry Restructuring
As discussed below, the electric utility industry is being deregulated in
New Jersey. Generally, the restructuring will deregulate the supply component
of the price charged to a customer for electricity, and
II-23
electricity suppliers will compete to supply electricity to customers.
Customers will continue to pay the local utility a regulated price for the
delivery of the electricity over the transmission and distribution system.
Stranded costs are costs which may not be recoverable in a competitive
energy supply market due to lower prices or customers choosing a different
supplier. Stranded costs generally include above-market costs associated with
generation facilities or long-term purchased power agreements, and regulatory
assets. ACE has quantified stranded costs in a New Jersey regulatory filing
and has proposed a plan seeking approval for recovery of those costs from
customers during the transition to a competitive market.
When the NJBPU issues an order specifically addressing deregulation in ACE's
service territory, ACE will cease applying SFAS No. 71 to its electricity
supply business. To the extent that the NJBPU's order provides for recovery of
stranded costs through cash flows from the regulated transmission and
distribution business, the stranded costs would continue to be recognized as
assets under SFAS No. 71. Any stranded costs (including regulatory assets) for
which cost recovery is not provided would be expensed.
The amount of stranded costs ultimately recovered from utility customers, if
any, and the full impact of New Jersey legislation deregulating the electric
utility industry, as discussed below, cannot be predicted. Also, the
quantification of stranded costs under existing GAAP differs from methods used
in regulatory filings. Among other differences, GAAP precludes recognition of
the gains on plants (or purchased power contracts) not impaired, but requires
write down of the plants that are impaired. Due to these considerations,
market conditions, timing and other factors, ACE's management currently cannot
predict the ultimate effects that electric utility industry deregulation may
have on the financial statements of ACE, although deregulation may have a
material adverse effect on ACE's results of operations.
New Jersey Legislation
The "Electric Discount and Energy Competition Act" (the Act) was signed into
law by the Governor of New Jersey on February 9, 1999. The Act provides for
retail choice of electricity suppliers; deregulation of electric rates and
other competitive services, such as metering and billing; separation of
competitive and regulated services; unbundling of rates for electric service;
and licensing of electric and gas suppliers. August 1, 1999 is the effective
starting date for each utility to provide retail choice of electricity
suppliers to all of its customers.
The Act requires each electric utility to reduce its rates by at least 5% at
the start of retail choice and by 10% within 36 months of the start of choice.
If the NJBPU determines that a rate decrease of more than 10% is warranted, a
"just and reasonable" financial test is applied. The mandated rate reductions
must be sustained through the end of the 48th month after choice begins. The
Act requires that the rate reductions be measured against the rates in effect
on April 30, 1997. The rate reductions mandated by the Act could have a
material adverse effect upon the results of operations of ACE.
In connection with the deregulation of electric rates, the Act authorizes
the NJBPU to permit electric public utilities to recover the full amount of
their stranded costs through a non-bypassable market transition charge, as
long as the mandated rate reductions are achieved. The NJBPU will determine
the utility's stranded cost amount. The NJBPU-determined stranded cost amount
will be subject to periodic recalculation and true-up over the recovery
period. The Act establishes an 8-year recovery period for stranded costs
associated with owned generation. The recovery period can be extended by the
NJBPU so as to allow for the full recovery of the stranded costs and the
meeting of mandated rate reductions. The recovery period for stranded costs
associated with purchased power contracts is to be the remainder of the
contract term. In addition, the Act would allow for the issuance of transition
bonds to finance portions of a given utility's stranded costs, as determined
to be appropriate by the NJBPU. All savings generated through the use of such
transition bonds are to be provided to the customers through rate reductions.
The Act establishes the current incumbent utility as the provider of
"default service" or Basic Generation Service (BGS) for a period of 3 years.
Future proceedings will be held to determine if the provision of BGS
II-24
should be made competitive. The Act contains numerous provisions regarding the
providing of competitive services by each utility. The primary focus is to
ensure that there is no cross subsidization from the utility to competitive
entities. The NJBPU also is required to develop fair competition standards and
conduct an audit to determine that the utilities are in compliance with those
standards. The Act gives the NJBPU the authority to order a utility to divest
its generating assets if it is determined through a hearing that competition
or customers are being adversely affected by plant location, market power or
non-competitive rates. The NJBPU may require that the generation function be
separated from a utility's non-competitive functions.
The NJBPU is authorized to establish standards for the licensing of energy
suppliers, standards for switching customers from one supplier to another, and
standards for issues such as credit and collections. The Act also contains
provisions for protecting workers displaced by the impacts of the
restructuring of the utility industry.
Stranded Cost Filing
Electric utilities in New Jersey, including ACE, previously filed stranded
cost estimates and unbundled rates, as required by the NJBPU. On August 19,
1998, an Administrative Law Judge (ALJ) from the New Jersey Office of
Administrative Law issued an initial decision on ACE's stranded costs and
unbundled rate filing. The ALJ, in reviewing ACE's filing, recognized that
ACE's stranded costs were $812 million for nonutility generation contracts and
$397 million for owned generation. The ALJ made no specific recommendations on
rate issues. A final NJBPU decision on this filing is expected by mid-1999.
Other Rate Matters
ACE is sharing a portion of the net cost savings expected to result from the
Merger (see Note 4 to the Consolidated Financial Statements) with its
customers through reduced electric retail customer base rates. ACE's total
Merger-related electric base rate decrease of $15.7 million was phased-in as
follows: (1) $5.0 million effective January 1, 1998 coincident with a $5.0
million increase for recovery of deferred other postretirement benefit costs
(OPEB); (2) $9.9 million effective March 1, 1998, and (3) $0.8 million
effective January 1, 1999.
ACE is subject to a performance standard for its five jointly-owned nuclear
units. Under the standard, the composite target capacity factor for such units
is 70%, based upon the maximum dependable capacity of the units. The zone of
reasonable performance (deadband) is between 65% and 75%. Penalties or rewards
are based on graduated percentages of estimated costs of replacement power.
LEC rates are adjusted annually to include any penalty or reward resulting
from the nuclear unit performance standard. Pursuant to a December 1996
stipulation agreement, the performance of Salem Units 1 and 2, during
prolonged outages which began in the second quarter of 1995, is not included
in the calculation of a nuclear performance penalty. ACE was not subject to a
nuclear performance penalty in 1996, 1997 or 1998.
Refer to Note 3 to the Consolidated Financial Statements for information
concerning rate changes related to changes in the New Jersey tax laws.
ACE submitted its second Demand Side Management (DSM) Plan for the period
from September 1997 through August 1998 in April 1997. The DSM Plan includes
programs that address energy conservation needs of the residential, commercial
and industrial markets. During the course of DSM Plan proceedings, New
Jersey's Division of the Ratepayer Advocate (Ratepayer Advocate) alleged that
ACE has been recovering more in rates for DSM programs than it is spending on
such programs. ACE's position is that the level of DSM expenditures cannot be
viewed in isolation, but must be considered in light of both the overall
history of DSM expenditures under current rates, as well as ACE's overall
revenue requirement needs in a rate proceeding. The Ratepayer Advocate
contends that any over-recovery and treatment of such over-recovery should be
addressed outside the context of a base rate proceeding. The NJBPU has not yet
taken any action on this matter. ACE cannot predict the outcome of this
matter.
II-25
NOTE 6. PENSION AND OTHER POSTRETIREMENT BENEFITS
1998 1997 1996
Assumptions ---- ---- ----
Discount rates used to determine projected benefit
obligation as of December 31........................ 6.75% 7.00% 7.50%
Rates of increase in compensation levels............. 4.50% 3.50% 3.50%
Expected long-term rates of return on pension
assets.............................................. 9.00% 9.00% 8.50%
Expected long-term rates of return on other
postretirement benefit assets....................... 9.00% 7.00% 7.00%
Health care cost trend rate on covered charges....... 7.00% 7.50% 8.00%
The health-care cost trend rate, or the expected rate of increase in health-
care costs, is assumed to continue to gradually decrease to 5.0% by 2002.
Increasing the health-care cost trend rates of future years by one percentage
point would increase the accumulated postretirement benefit obligation by
$11.8 million and would increase annual aggregate service and interest costs
by $1.5 million. Decreasing the health-care cost trend rates of future years
by one percentage point would decrease the accumulated postretirement benefit
obligation by $10.4 million and would decrease annual aggregate service and
interest costs by $1.3 million.
The following schedules reconcile the beginning and ending balances of the
pension and other postretirement benefit obligations and related plan assets.
Other postretirement benefits include medical benefits for retirees and their
spouses and retiree life insurance.
Change in Benefit Obligation
Other
Postretirement
Pension Benefits Benefits
---------------- --------------
1998 1997 1998 1997
(Dollar in Thousands) ---- ---- ---- ----
Benefit obligation at beginning
of year......................... $239,000 $207,340 $103,824 $107,105
Service cost..................... 7,558 6,763 3,643 2,531
Interest cost.................... 20,583 15,840 8,816 6,843
Plan amendments.................. (10,622) -- -- --
Actuarial (gain) loss............ 90,862 25,122 15,460 (7,955)
Special termination benefits..... 11,846 -- 1,270 --
Curtailment (gain) loss.......... (3,883) -- 6,597 --
Settlement (gain) loss........... 318 4,475 -- --
Benefits paid.................... (54,722) (20,540) (4,275) (4,700)
-------- -------- -------- --------
Benefit obligation at end of
year............................ $300,940 $239,000 $135,335 $103,824
======== ======== ======== ========
Change in Plan Assets
Other
Postretirement
Pension Benefits Benefits
---------------- --------------
1998 1997 1998 1997
(Dollars in Thousands) ---- ---- ---- ----
Fair value of assets at beginning
of year......................... $259,500 $236,000 $ 20,100 $ 18,000
Actual return on plan assets..... 10,062 35,414 1,119 800
Employer contributions........... -- 8,626 13,261 6,000
Benefits paid.................... (54,722) (20,540) (4,275) (4,700)
-------- -------- -------- --------
Fair value of assets at end of
year............................ $214,840 $259,500 $ 30,205 $ 20,100
======== ======== ======== ========
II-26
Reconciliation of Funded Status of the Plans
Other
Postretirement
Pension Benefits Benefits
---------------- --------------
1998 1997 1998 1997
(Dollars in Thousands) ---- ---- ---- ----
Funded status at end of year..... $(86,100) $20,500 $(105,130) $(83,724)
Unrecognized net actuarial (gain)
loss............................ 86,070 (10,810) 27,886 4,727
Unrecognized prior service cost.. (10,447) 232 -- --
Unrecognized net transition
(asset) obligation.............. -- (1,532) 32,637 41,521
-------- ------- --------- --------
Net amount recognized at end of
year............................ $(10,477) $ 8,390 $ (44,607) $(37,476)
======== ======= ========= ========
Based on fair values as of December 31, 1998, the pension plan assets were
comprised of publicly traded equity securities ($143.9 million or 67%) and
fixed income obligations ($70.9 million or 33%). As of December 31, 1998, the
other postretirement benefit plan assets were comprised entirely of fixed
income securities.
Components of Net Periodic Benefit Cost
Other Postretirement
Pension Benefits Benefits
---------------- --------------------
1998 1997 1996 1998 1997 1996
(Dollars in Thousands) ---- ---- ---- ---- ---- ----
Service cost............. $ 7,558 $ 6,763 $ 6,870 $ 3,643 $ 2,531 $ 2,688
Interest cost............ 20,583 15,840 14,569 8,816 6,843 7,482
Expected return on
assets.................. (20,414) (20,160) (17,376) (1,015) (1,275) (1,122)
Amortization of:
Transition obligation
(asset)................ (41) 24 24 2,404 2,768 2,768
Prior service cost...... 20 (172) (172) 50 -- --
Actuarial loss.......... 2,131 263 204 710 -- 566
------- ------- ------- ------- ------- -------
Cost before items
below................. 9,837 2,558 4,119 14,608 10,867 12,382
Special termination
benefits................ 11,846 -- -- 1,270 -- --
Curtailment (gain) loss.. (3,883) 5,932 -- 6,597 -- --
Settlement loss.......... 318 330 -- -- -- --
------- ------- ------- ------- ------- -------
Total net periodic
benefit cost........... $18,118 $ 8,820 $ 4,119 $22,475 $10,867 $12,382
======= ======= ======= ======= ======= =======
Portion of net periodic
benefit cost included in
results of operations... $15,514 $ 8,162 $ 3,040 $19,553 $ 3,640 $ 3,104
======= ======= ======= ======= ======= =======
The components of 1998 and 1997 pension and other postretirement periodic
benefit costs attributed to special benefits, curtailment (gain) loss, and
settlement loss resulted from the enhanced retirement offer and other employee
separation programs associated with the Merger.
Other postretirement benefit costs in excess of the amount recovered in
customer rates were deferred from 1993 to 1997, including $4.9 million in 1997
and $6.4 million in 1996. ACE began to recover these costs, through customer
rates, over a 15 year period beginning in 1998. See Note 5 and Note 14 to the
Consolidated Financial Statements for additional information.
Effective January 1, 1999, ACE's covered employees began participating in a
"cash balance" pension plan adopted by Conectiv. Contributions, which vary
based on the covered employee's age and years of service, will
II-27
be made to individual employee accounts provided for under the plan. The "cash
balance" of each employee's account increases based on employer contributions
and interest income credited to the account. The aggregate of the employee's
accounts will be ACE's pension obligation.
During 1998, ACE's covered employees began participating in the Conectiv
401(k) plans. Conectiv contributes to the plans, in the form of Conectiv
stock, at varying levels up to $0.50 for each dollar contributed by covered
employees, for up to 6% of employee base pay. Prior to the Merger, ACE had
401(k) plans for its employees, under which ACE contributed up to $0.50 for
each dollar contributed by covered employees, for up to 6% of employee base
pay. The cost of the plans for 1998, 1997, and 1996 was $1.9 million, $2.0
million and $1.9 million, respectively.
7. JOINTLY-OWNED GENERATING STATIONS
ACE owns jointly with other utilities several electric generating
facilities. ACE is responsible for its pro-rata share of the costs of
construction, operation and maintenance of each facility. ACE provides
financing during the construction period for its share of the jointly-owned
facilities and includes its share of direct operations and maintenance
expenses in the Consolidated Statements of Income.
The amounts shown below represent ACE's share of each facility at, or for
the year ended, December 31, 1998, including AFUDC as appropriate.
Cone- Peach Hope
Keystone maugh Bottom Salem Creek
(Dollars in Thousands) -------- ----- ------ ----- -----
Energy Source................ Coal Coal Nuclear Nuclear Nuclear
Ownership Share.............. 2.47% 3.83% 7.51% 7.41% 5.00%
MW Capability Owned.......... 42 65 164 164 52
Electric Plant in Service.... $13,640 $33,956 $135,775 $245,628 $241,062
Accumulated Depreciation*.... $ 3,815 $ 8,310 $ 62,688 $ 90,120 $ 82,854
Construction Work in
Progress.................... $ 104 $ 456 $ 13,037 $ 7,260 $ 1,251
- --------
* Excludes Nuclear Decommissioning Reserve.
8. CUMULATIVE PREFERRED SECURITIES
ACE has authorized 799,979 shares of Cumulative Preferred Stock, $100 Par
Value, two million shares of No Par Preferred Stock and three million shares
of Preference Stock, No Par Value. If preferred dividends are in arrears for
at least a full year, preferred stockholders have the right to elect a
majority of directors to the Board of Directors until all dividends in arrears
have been paid.
Preferred Stock Subject to Mandatory Redemption
1998 1997
---- ----
Series Shares (000) Shares (000)
- ------ ------ ---- ------ ----
$8.20, no par value............................. -- $ -- 100,000 $10,000
$7.80, no par value............................. 239,500 23,950 239,500 23,950
------- ------- ------- -------
Total........................................... 239,500 $23,950 339,500 $33,950
======= ======= ======= =======
Beginning May 1, 2001, 115,000 shares of the remaining $7.80 No Par
Preferred Stock must be redeemed annually through the operation of a sinking
fund at a redemption price of $100 per share. ACE has the option to redeem up
to an additional 115,000 shares without premium on any annual sinking fund
date.
ACE redeemed its $8.20 No Par Preferred Stock ($100 per share stated value)
as follows: 100,000 shares in August 1998; 200,000 shares in August 1997, and
200,000 shares in August 1996. In September 1996, ACE
II-28
redeemed the remaining 50,000 shares of its $8.25 Preferred Stock ($100 per
share stated value). In August 1996, ACE repurchased 460,500 shares of its
$7.80 No Par Preferred Stock ($100 per share stated value). In February 1996,
ACE redeemed the remaining 120,000 shares of its $8.53 No Par Preferred Stock
($100 per share stated value).
Preferred Stock Not Subject to Mandatory Redemption
1998 1997 Current
------------- --------------- Redemption
Shares (000) Shares (000) Price
Series ------ ------ ------- ------- ----------
4%, $100 par value..................... 24,268 $2,427 77,000 $ 7,700 $105.50
4.1%, $100 par value................... 20,504 2,051 72,000 7,200 101.00
4.35%, $100 par value.................. 3,102 310 15,000 1,500 101.00
4.35%, $100 par value.................. 1,680 168 36,000 3,600 101.00
4.75%, $100 par value.................. 8,631 863 50,000 5,000 101.00
5%, $100 par value..................... 4,120 412 50,000 5,000 100.00
------ ------ ------- -------
Total................................ 62,305 $6,231 300,000 $30,000
====== ====== ======= =======
Cumulative Preferred Stock Not Subject to Mandatory Redemption is redeemable
solely at the option of ACE. In October 1998, ACE purchased and retired
237,695 shares, or $23.77 million of various series of mandatorily redeemable
preferred stock, which had an average dividend rate of 4.4%. ACE realized a
$2.5 million gain on this preferred stock redemption which is presented as
Gain on Preferred Stock Redemption within the 1998 Consolidated Statement of
Income. In September 1996, ACE redeemed 100,000 shares of its 7.52% Preferred
Stock $100 Par Value.
ACE Obligated Mandatorily Redeemable Preferred Securities of Subsidiary
Trusts Holding Solely Junior Subordinated Debentures of ACE
In November 1998, Atlantic Capital II, a wholly-owned subsidiary financing
trust, issued $25 million in aggregate liquidation amount of 7 3/8% Cumulative
Trust Preferred Capital Securities (representing 1,000,000 preferred
securities at $25 per security). At the same time, $25.8 million in aggregate
principal amount of 7 3/8% Junior Subordinated Debentures, Series I, due 2028
(7 3/8% Debentures) were issued to Atlantic Capital II. For consolidated
financial reporting purposes, the 7 3/8% Debentures are eliminated in
consolidation against the trust's investment in the 7 3/8% Debentures. The
preferred trust securities are subject to mandatory redemption upon payment of
the 7 3/8% Debentures at maturity or upon redemption. The 7 3/8% Debentures
are subject to redemption, in whole or in part at the option of ACE, at 100%
of their principal amount plus accrued interest, after an initial period
during which they may not be redeemed and at any time upon the occurrence of
certain events.
The combination, of the obligations of ACE, pursuant to the 7 3/8%
Debentures and ACE's guarantee of distributions with respect to trust
securities, to the extent the trust has funds available therefor, constitute a
full and unconditional guarantee by ACE of the obligations of the trust under
the trust securities that the trust has issued. ACE is the owner of all of the
common securities of the trust, which constitute approximately 3% of the
liquidation amount of all of the trust securities issued by the trust.
Atlantic Capital I is a wholly-owned subsidiary financing trust which is
structured similarly to Atlantic Capital II (discussed above). In October
1996, Atlantic Capital I, issued $70 million (2,800,000 shares) of 8.25%
Cumulative Quarterly Income ACE Obligated Mandatorily Redeemable Preferred
Securities with a stated liquidation preference of $25 each. Atlantic Capital
I's sole investment is in ACE's 8.25% Junior Subordinated Deferrable Interest
Debentures (8.25% Debentures). The 8.25% Debentures and Preferred Securities
mature in 2026.
II-29
9. DEBT
December 31,
Maturity ------------------
Secured debt Date 1998 1997
- ------------ -------- ---- ----
(Dollars in
Thousands)
Medium Term Notes Series B (6.28%).............. 2/1/1998 $ -- $ 56,000
Medium Term Notes Series A (7.52%).............. 1999 30,000 30,000
Medium Term Notes Series B (6.83%).............. 2000 46,000 46,000
Medium Term Notes Series C (6.86%).............. 2001 40,000 40,000
Medium Term Notes Series C (7.02%).............. 2002 30,000 30,000
Medium Term Notes Series B (7.18%).............. 2003 20,000 20,000
Medium Term Notes Series D (6.00%).............. 2003 20,000 --
Medium Term Notes Series A (7.98%).............. 2004 30,000 30,000
Medium Term Notes Series B (7.125%)............. 2004 28,000 28,000
Medium Term Notes Series C (7.15%).............. 2004 9,000 9,000
Medium Term Notes Series B (6.45%).............. 2005 40,000 40,000
Medium Term Notes Series D (6.19%).............. 2006 65,000 --
6 3/8% Pollution Control Series................. 12/1/2006 2,350 2,425
Medium Term Notes Series C (7.15%).............. 2007 1,000 1,000
Medium Term Notes Series B (6.76%).............. 2008 50,000 50,000
Medium Term Notes Series C (7.25%).............. 2010 1,000 1,000
6 5/8% First Mortgage Bonds..................... 8/1/2013 75,000 75,000
Medium Term Notes Series C (7.63%).............. 2014 7,000 7,000
Medium Term Notes Series C (7.68%).............. 2015 15,000 15,000
Medium Term Notes Series C (7.68%).............. 2016 2,000 2,000
6.80% Pollution Control Series A................ 3/1/2021 38,865 38,865
7% First Mortgage Bonds......................... 9/1/2023 75,000 75,000
5.60% Pollution Control Series A................ 11/1/2025 4,000 4,000
7% First Mortgage Bonds......................... 8/1/2028 75,000 75,000
6.15% Pollution Control Series A................ 6/1/2029 23,150 23,150
7.20% Pollution Control Series A................ 11/1/2029 25,000 25,000
7% Pollution Control Series B................... 11/1/2029 6,500 6,500
-------- --------
758,865 729,940
-------- --------
Unsecured debt
- --------------
6.46% Medium Term Notes Series A................ 4/1/2002 20,000 20,000
6.63% Medium Term Notes Series A................ 6/2/2003 30,000 30,000
7.52% Medium Term Notes Series A................ 4/2/2007 5,000 5,000
7.50% Medium Term Notes Series A................ 4/2/2007 10,000 10,000
-------- --------
65,000 65,000
-------- --------
7 1/4% Debentures............................... 5/1/1998 -- 2,500
-------- --------
Unamortized Premium and Discount-Net............ (2,663) (2,721)
-------- --------
Total Long Term Debt............................ 821,202 794,719
Add: Short Term Debt to be Refinanced........... -- 16,425
Less: Current Portion of Long-Term Debt......... (30,075) --
-------- --------
Total Long Term Debt............................ 791,127 811,144
-------- --------
Variable Rate Demand Bonds, Pollution Control
Series A....................................... 2014 18,200 18,200
Variable Rate Demand Bonds, Pollution Control
Series B....................................... 2017 4,400 4,400
-------- --------
Total Long Term Debt & Variable Rate Demand
Bonds.......................................... $813,727 $833,744
======== ========
II-30
Substantially all of ACE's utility plant is subject to the lien of the
Mortgage and Deed of Trust dated January 15, 1937, as amended and
supplemented, collateralizing ACE's First Mortgage Bonds and Secured Medium
Term Notes.
Variable Rate Demand Bonds (VRDB) are classified as current liabilities
because the VRDB are due on demand by the bondholder. However, bonds submitted
to ACE for purchase are remarketed by a remarketing agent on a best efforts
basis. ACE expects that bonds submitted for purchase will continue to be
remarketed successfully due to ACE's credit worthiness and the bonds' interest
rates being set at market. ACE also may utilize one of the fixed rate/fixed
term conversion options of the bonds. Thus, ACE considers the VRDB to be a
source of long-term financing. Average interest rates on the VRDB were 3.2%
for 1998 and 3.6% for 1997.
ACE funds its interim financing requirements by issuing commercial paper and
borrowing against bank credit lines. At December 31, 1998, ACE had no
outstanding short-term debt and had total bank credit lines of $195 million,
all of which was available for borrowing. ACE's weighted daily average
interest rate on short-term debt outstanding at December 31, 1997 was 5.8%.
On January 12, 1998, ACE issued $85 million of Secured Medium Term Notes,
Series D maturing in January 2003 and January 2006 (6.1% average interest
rate). The net proceeds received by ACE from the issuance of the Medium Term
Notes was used to repay short-term debt and long-term debt (see schedule
below) and $10 million of $8.20 No Par Preferred Stock in 1998.
The following schedule shows debt redemptions made, at maturity in 1998.
Series Maturity Date Principal
------ ------------- ---------
(Dollars in Thousands)
6.35% Medium-Term Notes........................... 1/26/98 $ 4,000
6.37% Medium-Term Notes........................... 1/27/98 46,000
7.25% Debentures.................................. 5/01/98 2,500
5.50% Medium-Term Notes........................... 5/14/98 6,000
6.375% Pollution Control Bonds*................... 12/01/09 75
-------
$58,575
=======
- --------
* Annual sinking fund requirement on bonds due December 1, 2006.
Maturities and Sinking Fund Requirements for Long-Term Debt
(Dollars in thousands)
1999........................ $30,075
2000........................ 46,075
2001........................ 40,075
2002........................ 50,075
2003........................ 70,075
10. COMMON STOCKHOLDER'S EQUITY
For information concerning changes to the common equity accounts of ACE, see
the Consolidated Statements of Changes in Common Stockholder's Equity.
Effective March 1, 1998, all of the outstanding shares of ACE were acquired
by Conectiv, pursuant to the Merger, as discussed in Note 4 to the
Consolidated Financial Statements.
Under ACE's certificate of incorporation, ACE is subject to certain
limitations on the payment of dividends to Conectiv, which is the holder of
all of ACE's common stock. When full dividends have been paid on the Preferred
Stock Securities of ACE for all past dividend periods, dividends may be
declared and paid by ACE on
II-31
its common stock, as determined by the Board of Directors of ACE, out of funds
legally available for the payment of dividends.
11. COMMITMENTS
Construction Program
Capital expenditures for 1999 are estimated to be approximately $85.4
million.
Purchased Capacity and Energy Arrangements
ACE arranges with various providers of bulk energy to obtain sufficient
supplies of capacity and energy. Terms of the arrangements vary in length to
enable ACE to optimally manage its supply portfolio in response to changing
market conditions. At December 31, 1998, ACE has contracted for 828 megawatts
(MWs) of purchased capacity with terms remaining of 1 to 26 years. Information
regarding these arrangements relative to ACE was as follows:
1998 1997 1996
---- ---- ----
Percentage of MW capacity................................ 33% 29% 30%
Percentage of energy output.............................. 41% 54% 55%
Capacity charges (millions).............................. $173 $180 $179
Energy charges (millions)................................ $126 $137 $145
Electric capacity purchased from certain nonutility suppliers is recoverable
through the LEC, which amounted to $166.9 million, $166.8 million and $165.3
million in 1998, 1997 and 1996, respectively. Based on existing contracts as
of December 31, 1998, ACE's future commitments for capacity and energy under
long-term purchased power contracts are estimated to be $269 million in 1999;
$275 million in 2000; $266 million in 2001; $266 million in 2002; $268 million
in 2003. Due to uncertainties surrounding restructuring of the electric
utility industry, ACE has not forecasted its long-term purchased power
commitments beyond 2003.
Leases
ACE has a contractual obligation to obtain nuclear fuel for the Salem, Hope
Creek and Peach Bottom stations. The asset and related obligation for the
leased fuel are reduced as the fuel is burned and are increased as additional
fuel purchases are made. ACE's obligation under the contract is generally the
net book value of the nuclear fuel financed, which was $35.0 million as of
December 31, 1998. Operating expenses for 1998, 1997 and 1996 include leased
nuclear fuel costs of $11.7 million, $9.8 million and $8.7 million,
respectively.
ACE also leases other types of property and equipment for use in its
operations. Amounts charged to operating expenses for these leases were $4.6
million in 1998, $2.4 million in 1997 and $2.6 million in 1996. Future minimum
rental payments for all non-cancellable lease agreements, excluding nuclear
fuel, are less than $3.0 million per year for each of the next five years.
12. CONTINGENCIES
Environmental Matters
ACE is subject to regulation with respect to the environmental effects 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. ACE is a
potentially responsible party at a state superfund site and has agreed, along
with other responsible parties, to remediate the site pursuant to an
Administrative Consent Order with the New Jersey Department of Environmental
Protection. ACE is also a
II-32
defendant in an action to recover costs at a federal superfund site in
Gloucester, New Jersey. There is $1.0 million included in ACE's current
liabilities as of December 31, 1998, for remediation activities at these
sites. ACE does not expect such future costs to have a material effect on its
financial position or results of operations.
Nuclear Insurance
In conjunction with ACE's ownership interests in Peach Bottom, Salem, and
Hope Creek, ACE 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 (the amount of primary
insurance), ACE could be assessed up to $30.7 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, Salem, and Hope Creek 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, ACE 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,
ACE is subject to potential retrospective loss experience assessments of up to
$5.4 million.
13. SALEM NUCLEAR GENERATING STATION
In December 1996, the NJBPU issued an Order approving a stipulation of
settlement reached among the parties settling the issues primarily regarding
replacement power costs related to an extended Salem outage, which began in
the second quarter of 1995. The stipulations provided for recovery through LEC
rates of ACE's replacement power costs for the Salem outage, up to each Salem
Unit's agreed-upon return-to-service date (June 30, 1997 for Unit 1 and
December 31, 1996 for Unit 2). The Salem Units returned to service in August
1997 (Unit 2) and April 1998 (Unit 1). As a result, unrecovered purchased
power costs of $2.1 million in 1998 and $10.2 million in 1997 were expensed.
The stipulation of settlement approved by the NJBPU in December 1996 also
provided customers with a $13 million base rate credit, primarily for
resolution of issues associated with the extended Salem outage. ACE accrued
the $13 million base rate credit in 1996 as a reduction of electric revenues.
As previously reported, on February 27, 1996, the co-owners of Salem,
including ACE and DPL, filed a complaint in the United States District Court
for New Jersey against Westinghouse Electric Corporation (Westinghouse), the
designer and manufacturer of the Salem steam generators. The complaint, which
sought to recover from Westinghouse the costs associated with and resulting
from the cracks discovered in Salem's steam generators and with replacing such
steam generators, alleged violations of federal and New Jersey Racketeer
Influenced and Corrupt Organizations Acts, fraud, negligent misrepresentation
and breach of contract. On November 4, 1998, the Court granted Westinghouse's
motion for summary judgment with regard to the federal Racketeer Influenced
and Corrupt Organizations Act claim, and dismissed the remaining state law
claims without prejudice. On November 18, 1998, the co-owners re-filed their
state law claims against Westinghouse in the Superior Court of New Jersey. The
co-owners also filed an appeal of the District Court's dismissal with the
United States Court of Appeals for the Third Circuit.
14. REGULATORY ASSETS
In conformity with generally accepted accounting principles, ACE's
accounting policies reflect the financial effects of rate regulation and
decisions issued by the NJBPU and the FERC. In accordance with the provisions
II-33
of SFAS No. 71, ACE defers expense recognition of certain costs and records an
asset, as a result of the effects of rate regulation. Except for deferred
energy costs, which are classified as a current asset or liability, these
"regulatory assets" are included on ACE's Consolidated Balance Sheets under
"Deferred Charges and Other Assets." The costs of these assets are either
being recovered or are probable of being recovered through customer rates.
Generally, the costs of these assets are recognized in operating expenses over
the period the cost is recovered from customers. For information about the
impact of electric utility industry restructuring on accounting for regulatory
assets, see Note 5 to the Consolidated Financial Statements.
The table shown below details total regulatory assets as of December 31,
1998 and 1997.
Remaining
Amortization/
Recovery
1998 1997 Period*
(Dollars in Thousands) ---- ---- -------------
Deferred recoverable income taxes............ $102,223 $ 85,858 (A)
Unrecovered purchased power costs:
Capacity costs.............................. 30,608 48,038 2 years
Contract renegotiation costs................ 17,666 18,226 16 years
Unrecovered state excise taxes............... 35,594 45,154 4 years
Deferred debt refinancing costs.............. 28,043 30,002 1-28 years
Under (Over) recovered deferred energy
costs....................................... (15,577) 27,424 (B)
Deferred other postretirement benefit costs.. 34,978 37,476 14 years
Asbestos removal costs....................... 8,546 8,816 31 years
Nuclear decontamination and decommissioning
of federally-owned nuclear units............ 6,217 5,032 10 years
Other........................................ 10,253 10,789 1-5 years
-------- --------
$258,551 $316,815
======== ========
- --------
*From December 31, 1998
(A) Amortized as temporary differences between the financial statement and tax
bases of assets and liabilities reverse.
(B) Recovered from or credited to customers over annual LEC Period.
Deferred recoverable income taxes represent the portion of ACE's deferred
tax liability applicable to utility operations that has not been recovered
from customers and is recoverable in the future.
Unrecovered purchased power capacity costs represent prior deferrals of
capacity costs which had exceeded the related cost recovery from customers.
Unrecovered purchased power contract renegotiation costs were incurred
through renegotiation of a long-term capacity and energy contract with a
certain independent power producer.
Unrecovered state excise taxes represent additional amounts paid as a result
of prior legislative changes in the computation of state excise taxes.
Deferred debt refinancing costs represent costs incurred to refinance debt
and are amortized over the life of the related new debt.
Deferred other postretirement benefit costs represent the non-cash portion
of OPEB costs deferred during 1993-1997.
Asbestos removal costs were incurred to remove asbestos insulation from a
wholly-owned generating station.
II-34
Nuclear decontamination and decommissioning costs represent costs associated
with decommissioning and decontaminating United States Department of Energy
gaseous diffusion enrichment facilities.
Other includes certain amounts being recovered over periods of one to five
years.
15. NUCLEAR PLANT DECOMMISSIONING
ACE has a trust to fund the future costs of decommissioning each of the five
nuclear units in which it has an ownership interest. The current annual
funding amount, as authorized by the NJBPU, totals $6.4 million and is
provided for in rates charged to customers. The funding amount is based on
estimates of the future cost of decommissioning each of the units; the dates
that decommissioning activities are expected to begin and the return expected
to be earned by the assets of the fund. The present value of ACE's nuclear
decommissioning obligation is estimated to be $185 million based on site
specific studies filed with and approved by the NJBPU. Decommissioning
activities as approved by the NJBPU are expected to begin in 2006 and continue
through 2032.
ACE's accrued nuclear decommissioning liability, which is reflected in the
accumulated reserve for depreciation, was $98.2 million as of December 31,
1998. The provision reflected in depreciation expense for nuclear
decommissioning was $6.4 million annually for 1998, 1997 and 1996. External
trust funds established by ACE for the purpose of funding nuclear
decommissioning costs had an aggregate book balance (stated at fair market
value) of $98.2 million as of December 31, 1998. Earnings on the trust funds
are recorded as an increase to the accrued nuclear decommissioning liability,
which, in effect, reduces the expense recorded for nuclear decommissioning.
The staff of the Securities and Exchange Commission has questioned certain
of the current accounting practices of the electric utility industry,
including ACE, regarding the recognition, measurement and classification of
decommissioning costs for nuclear generating stations in the financial
statements of electric utilities. In February 1996, the FASB issued the
Exposure Draft, "Accounting for Certain Liabilities Related to Closure or
Removal of Long-Lived Assets," which proposed changes in the accounting for
closure and removal costs of long-lived assets, including the recognition,
measurement, and classification of decommissioning costs for nuclear
generating stations. If the proposed changes were adopted: (1) annual
provisions for decommissioning would increase, (2) the estimated cost for
decommissioning would be recorded as a liability rather than as accumulated
depreciation, and (3) trust fund income from the external decommissioning
trusts would be reported as investment income rather than as a reduction of
decommissioning expense. The FASB expects to issue a revised Exposure Draft in
the second quarter of 1999.
16. FAIR VALUE OF FINANCIAL INSTRUMENTS
A number of items within Current Assets and Current Liabilities on the
Consolidated Balance Sheet are considered to be financial instruments because
they are cash or are to be settled in cash. Due to their short-term nature,
the carrying values of these items approximate their fair market values.
Accounts Receivable--Utility Service and Unbilled Revenues are subject to
concentration of credit risk because they pertain to utility service conducted
within a fixed geographic region.
II-35
The year-end fair value of certain financial instruments are listed below.
The fair values were based on quoted market prices of ACE's securities or
securities with similar characteristics.
1998 1997
---- ----
Carrying Fair Carrying Fair
Value Value Value Value
-------- ----- -------- -----
(Dollars in Millions)
Funds Held By Trustee..................... $102.8 $102.8 $88.7 $88.7
Long Term Debt............................ 791.1 832.6 811.1 836.9
Preferred Stock Subject to Mandatory
Redemption............................... 24.0 24.1 34.0 37.0
Preferred Securities*..................... 95.0 98.3 70.0 72.3
- --------
* ACE Obligated Mandatorily Redeemable Preferred Securities of Subsidiary
Trust Holding Solely Junior Subordinated Debentures of ACE
17. QUARTERLY FINANCIAL RESULTS (UNAUDITED)
Quarterly financial data, reflecting all adjustments necessary in the
opinion of management for a fair presentation of such amounts, are presented
below. Certain prior year amounts have been reclassified, not affecting net
income, to conform to the current year reporting of these items. Third quarter
results generally exceed those of other quarters due to increased sales and
higher residential rates.
Earnings(Loss)
Quarter Operating Operating Net Applicable to
Ended Revenues Income/(Loss) Income/(Loss) Common Stock
------- --------- ------------- ------------- --------------
(Dollars in Thousands)
1998
March 31.............. $ 237,949 $(17,823) $(20,737) $(21,737)
June 30............... 241,883 46,028 19,314 18,314
September 30.......... 331,403 87,761 41,550 40,687
December 31........... 226,378 (7,098) (9,851) (7,879)
---------- -------- -------- --------
$1,037,613 $108,868 $ 30,276 $ 29,385
========== ======== ======== ========
1997
March 31.............. $ 243,422 $ 47,378 $ 20,371 $ 18,961
June 30............... 242,475 45,011 18,676 17,266
September 30.......... 338,162 89,580 47,541 46,541
December 31........... 260,831 8,083 (841) (1,842)
---------- -------- -------- --------
$1,084,890 $190,052 $ 85,747 $ 80,926
========== ======== ======== ========
As discussed in Note 4 to the Consolidated Financial Statements, ACE
recorded an impairment loss on assets held for sale in the fourth quarter of
1998 which reduced operating income $18.0 million and net income $10.6
million.
II-36
Employee separation programs and other Merger-related costs recorded in 1998
(as discussed in Note 4 to Consolidated Financial Statements) had the effects
shown below on 1998 quarterly operating results.
Earnings(Loss)
Quarter Operating Net Applicable to
Ended Incomne/(Loss) Income/(Loss) Common Stock
------- -------------- ------------- --------------
(Dollars in Thousands)
March 31......................... $(51,479) $(30,946) $(30,946)
June 30.......................... 3,361 1,987 1,987
September 30..................... (1,014) (600) (600)
December 31...................... (11,959) (7,074) (7,074)
-------- -------- --------
$(61,091) $(36,633) $(36,633)
======== ======== ========
Due to the Merger, various pension and compensation plans were terminated in
the fourth quarter of 1997, resulting in a $22.2 million decrease in operating
income and a $15.6 million decrease in net income.
18. BUSINESS SEGMENTS
Conectiv's organizational structure and management reporting information is
aligned with Conectiv's business segments, irrespective of which subsidiary,
or subsidiaries, a business is conducted through. Businesses are managed based
on lines of business, not based on 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 ACE on a stand-alone basis.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
Reference is made to Item 4 of Report on Form 8-K filed March 5, 1998.
II-37
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Directors Business Experience During Past 5 Years
As of December 31, 1998
Howard E. Cosgrove, 55,.......... Elected 1998 as Chairman of the Board
Chairman of the Board and Chief Executive Officer of Conectiv,
Delmarva Power & Light Company, and
Atlantic City Electric Company. Elected
1992 as Chairman of the Board, President
and Chief Executive Officer and Director
of Delmarva Power & Light Company.
Meredith I. Harlacher, Jr., 56,.. Elected 1998 as President and Chief
Director Operating Officer of Conectiv, and
President and Chief Operating Officer
and Director of Delmarva Power & Light
Company and Atlantic City Electric
Company. Elected 1993 as Senior Vice
President of Atlantic Energy, Inc.
Barry R. Elson, 57,.............. Elected 1998 as Executive Vice President
Director of Conectiv, and Executive Vice
President and Director of Delmarva Power
& Light Company and Atlantic City
Electric Company. Elected 1997 as
Executive Vice President, Delmarva Power
& Light Company. Executive Vice
President, Cox Communications, Inc.,
Atlanta, Georgia, from 1995 to 1996.
Senior Vice President, Cox
Enterprises/Cox Communications, Inc.,
Atlanta, Georgia, from 1984 to 1995.
Thomas S. Shaw, 51,.............. Elected 1998 as Executive Vice President
Director of Conectiv, and Executive Vice
President and Director of Delmarva Power
& Light Company and Atlantic City
Electric Company. Elected 1992 as Senior
Vice President, Delmarva Power & Light
Company.
Barbara S. Graham, 50,........... Elected 1998 as Senior Vice President
Director and Chief Financial Officer of Conectiv,
and Senior Vice President and Chief
Financial Officer and Director of
Delmarva Power & Light Company and
Atlantic City Electric Company. Elected
1994 as Senior Vice President, Treasurer
and Chief Financial Officer, Delmarva
Power & Light Company. Vice President
and Chief Financial Officer of Delmarva
Power & Light Company from 1992 to 1994.
Executives
Information about ACE's executive officers is included under Item 1.
III-1
ITEM 11. EXECUTIVE COMPENSATION
As previously noted, ACE is a wholly owned electric utility subsidiary of
Conectiv. The Chief Executive Officer and the four most highly compensated
executive officers of Conectiv maintain the same position at both ACE and DPL.
In 1998, the salaries and other compensation awarded to the Chief Executive
Officer and the four most highly compensated executive officers of ACE were
paid by Conectiv for their service as executive officers of Conectiv, ACE and
DPL. The Board Personnel & Compensation Committee Report was provided
initially in the Conectiv Proxy Statement and is enclosed herein for the
purpose of providing additional informational. The following tables show
information concerning the total compensation paid or awarded to ACE's Chief
Executive Officer and each of the four most highly compensated executive
officers for the fiscal year ended December 31, 1998.
Board Personnel & Compensation Committee Report
Principles of Executive Compensation Program
The Personnel & Compensation Committee of the Board of Directors is
comprised of four non-employee Directors. The Committee provides an
independent review of the Company's performance objectives and executive
compensation.
Overall Objectives
The Company's philosophy is to link compensation to business strategies and
results, to align total compensation of executives with the long-term
interests of stockholders, to motivate its senior executives to meet the
challenging objectives established for the Company and to create an urgency
for success in the newly-formed Company. The Company's executive compensation
program is designed to:
. provide total compensation that emphasizes long-term performance which
creates stockholder value;
. facilitate the rapid transition to a competitive business environment;
. reflect the market conditions for attracting and retaining high-quality
executives and ensure that such executives have a continuing stake in
the long-term success of the Company; and
. create significant levels of stock ownership.
The elements of the executive compensation program are:
. total compensation levels that are competitive with those provided by
the competitive market, defined as a blend of companies in the utility
and industrial markets;
. base compensation levels related to responsibility level and individual
performance;
. annual variable compensation that varies based on corporate, unit and
individual performance; and,
. long-term variable compensation based on long-term increases in
stockholder value.
Total Compensation
Total compensation opportunities are developed for Company executives by
Watson Wyatt, the firm that provides executive compensation consulting
services to the Company. This is done using several published compensation
survey sources and public proxy data to define the competitive market.
Overall, the total compensation structure for executives is targeted at the
median for similar positions at companies of similar size, including both
utilities and industrial companies (Compensation Comparison Group)/1/.
Individual reward levels vary based on individual contributions and
performance. Total compensation includes three components: base compensation,
annual variable compensation and long-term variable compensation. The targets
for each component of the executive compensation program are reviewed on an
annual basis to ensure alignment with the Company's compensation philosophy
and a proper balance between short-and long-term objectives.
- --------
1. The Compensation Comparison Group does not include all of the same
companies as the published industry indices in the Comparison of 10 Month
Cumulative Total Return chart included in this Proxy Statement. However, 34
of the 85 companies included in the EEI Executive Compensation Report,
which is one element of the Compensation Comparison Group, are also part of
either the Dow Jones Electric Utilities Index or the S&P 500 Index.
III-2
Base Compensation
Base compensation for executive officers is determined by evaluating the
responsibilities of the positions held and the experience of the individuals,
coupled with a review of compensation for comparable positions at other
companies. Base compensation is reviewed on an annual basis and adjustments
are based on the performance of the Company and each executive officer. Annual
base compensation increases reflect the individual's performance and
contribution over several years in addition to the results for a single year.
Following the 1998 increases, the overall base compensation level for the five
named executive officers was slightly below the median of the base
compensation targeted levels defined by the surveys and proxies.
Annual Variable Compensation
The Company's annual variable compensation is designed to motivate
participants to accomplish stretch financial and individual goals and to
increase the sense of urgency to deliver significant results on an annual
basis. Annual variable compensation target opportunities are designed to be at
or above the median of the blended utility and industrial market and for the
named executive officers vary from 40% to 50% of base compensation, with
maximum awards of 60% to 75% of base compensation.
Annual variable compensation is paid in a combination of cash (80%) and
restricted stock units (20%) and is based on the achievement of predetermined
corporate and individual goals. The plan for 1998 provides that payouts will
occur only after a specified earnings target is achieved.
For 1998, each individual covered by the plan was eligible to earn a
variable compensation award between 0% and 150% of target. The portion of each
individual award attributable to corporate, line of business, and group
performance were determined and specific measures were developed at the
beginning of the year. These measures were primarily financial for 1998 to
accelerate the transition of the Company to a more competitive environment and
included corporate measures of earnings, cash flow return on capital employed
and cash flow. Each business group and line of business also developed
specific financial measures to support their business plans.
The Management Stock Purchase Program (MSPP) was designed as a means to
promote significant executive stock ownership in the new company and to help
meet stock ownership guidelines. The program requires that 20% of the
individual's earned annual variable compensation must be used to acquire
restricted stock units (RSUs). Individuals may also voluntarily use up to an
additional 30% (for a total of 50%) of their earned annual variable
compensation to acquire RSUs. All RSUs are acquired at a 20% discount from
Fair Market Value on the date paid. Each RSU is a proxy for one share of
Common Stock, has a value equal to one share and earns at the rate of the
Common Stock dividend. RSUs are restricted from sale or use for a 3-year
period and are distributed in shares of Common Stock.
Long-Term Variable Compensation
The Company's long-term variable compensation reinforces the importance of
providing stockholders with a competitive return on their investment. Long-
term variable compensation awards also strengthen the ability of the Company
to attract, motivate and retain executives of superior capability and more
closely align the interests of management with those of stockholders.
Long-term grants for Conectiv executives are determined by setting a target
percentage of base compensation based on median data in the Compensation
Comparison Group and converting the target amounts to actual grants using the
"Black-Scholes Model" for options and time and forfeiture discount methods for
the other elements of the long-term grants.
Long-term awards granted in 1998 consisted of non-qualified stock options,
dividend equivalent units and performance accelerated restricted stock. Non-
qualified stock options and dividend equivalent units were awarded to provide
approximately two-thirds of the targeted value of the grant while the other
one-third of the
III-3
targeted value was provided through performance accelerated restricted stock.
This stock vests as unrestricted Common Stock seven years from the award date.
However, vesting may be accelerated if the price of Common Stock reaches
certain predetermined levels prior to the seven years. All stock options were
granted with exercise prices equal to the fair market value of Common Stock at
the time of the grant.
Performance accelerated restricted stock granted to the CEO and three other
named executive officers is also subject to an additional condition tied to
Total Shareholder Return over the seven year period. Failure to meet a
predetermined Total Shareholder Return level over the restriction period will
result in total forfeiture of their shares granted.
The CEO and three other named executive officers also were given a special
grant of performance accelerated stock options to increase emphasis on
creating long-term shareholder value. All performance accelerated stock
options were granted with exercise prices equal to the fair market value of
Common Stock at the time of grant. These options do not vest and cannot be
exercised for 9-1/2 years from the date of their grant unless the stock price
increases to predetermined levels. Absent accelerated vesting at these
predetermined stock prices, the shares will become exercisable in 9-1/2 years
with expiration occurring at 10 years. This special grant resulted in the
long-term variable compensation component and total compensation exceeding the
targeted median values for these four executives for 1998 using the Black-
Scholes valuation methodology.
Stock Ownership Guidelines
To further reinforce the interests of stockholders, stock ownership
guidelines have been established for the Board of Directors, Company officers,
and other Company management. These guidelines require the individuals covered
by the guidelines to have beneficial ownership of Common Stock, or securities
convertible into Common Stock, with an aggregate value equal to certain
multiples of each individual's salary (or annual retainers in the case of
outside directors). Multiples range from five times to one times salary. The
Chief Executive Officer's multiple is set at five times salary and outside
Directors' multiples are set at three times the annual retainer.
Internal Revenue Code Section 162(m)
The Committee considers the tax deductibility of compensation paid to
executive officers and the impact of Section 162(m) of the Internal Revenue
Code of 1986, as amended (the "Code"), on the Company. This provision limits
the amount of compensation that the Company may deduct from its taxable income
for any year to $1 million for any of its five most highly compensated
executive officers, unless certain requirements are met.
The Committee has taken actions to limit the impact of the Code in the event
that compensation paid to a named executive officer might otherwise not be
deductible. The Committee will continue to seek ways to limit the impact of
the Code; however, the Committee believes that the tax deduction limitation
should not compromise the Company's ability to create incentive programs that
support the business strategy and also attract and retain the executive talent
required to compete successfully. Accordingly, achieving the desired
flexibility in the design and delivery of compensation may periodically result
in some compensation that is not deductible for federal income tax purposes.
Summary of Actions Taken by the Personnel & Compensation Committee
The Personnel & Compensation Committee, consisting entirely of outside
directors, provides direction and oversight to the Company's executive
compensation plans, establishes the Company's compensation philosophy and
assesses the effectiveness of the program as a whole. This includes activities
such as reviewing the design of various plans and assessing the reasonableness
of the total program consistent with the total compensation philosophy.
III-4
The Committee also assists in administering key aspects of the Company's
annual compensation program and variable compensation plan, such as reviewing
annual compensation budgets and setting targets and corporate performance
measures for the annual and long-term variable compensation plans.
Finally, the Committee specifically implements the Company's executive
compensation program as it directly pertains to the Chief Executive Officer
and the Company's four other most highly compensated executives, i.e., the
five "named executive officers."
The Committee has determined that in an environment where competition is
increasing, it is essential that the Company have the ability to attract,
motivate and retain high quality executives from within and outside the
utility industry.
Because of the extremely competitive market for executive talent, the
Personnel & Compensation Committee has adopted a compensation structure based
on a blend of utility and general competitive industry markets. The structure
is also flexible to allow setting salaries at pure general industry levels
where that may be necessary to attract certain specific skills and experience.
Consistent with this approach, the total compensation program relies on
competitive base compensation generally at or below the median of the market
with annual and long-term variable compensation opportunities generally above
the median of the market. This places a much greater emphasis on variable
compensation that aligns executive and stockholder interests.
This total compensation philosophy is important to the success of the
Company because the Company is facing increasing competition and related
risks. The Company is not simply a utility anymore, but is rapidly becoming
part of the general competitive industry market and, therefore, just as
strategies for success must change, the compensation to drive success must
also change. Prior to the merger involving Atlantic Energy and Delmarva and
during 1998, this compensation philosophy enabled the Company to attract
several key executives with experience and skills critical to the emerging
competitive environment. These executives would not have been available under
a traditional utility compensation philosophy.
Significant actions by the Committee for fiscal year 1998 included adoption
of the new Conectiv executive plans (Conectiv Variable Compensation Plan,
Deferred Compensation Plan, Supplemental Executive Retirement Plan [SERP], and
Change In Control Agreements) and other compensation and benefit plans for
Conectiv employees. The Committee also sets base compensation, annual variable
targets and performance measures and long-term grants under the various
executive programs, including special awards of performance accelerated stock
options to the CEO and the three other named executive officers described
above.
Chief Executive Officer Compensation
Mr. Cosgrove's compensation reflects Conectiv's compensation philosophy. His
base compensation, annual and regular long-term variable compensation place
him at total compensation levels consistent with the median level of other
CEO's at similarly-sized utility and manufacturing companies represented in
the Compensation Comparison Group. Additional emphasis on achieving increased
stockholder value has been created with a special grant of performance
accelerated stock options. This special grant will cause his long term
compensation and total compensation to exceed the median targets for 1998.
Base Compensation Action
Conectiv was formed by a merger involving Delmarva and Atlantic Energy in
early 1998. Mr. Cosgrove's base compensation was set during the merger process
to reflect the size of Conectiv and the increasing competitive environment in
which Conectiv does business. His 1998 base compensation is at the median
target level developed through a comparison of other Chief Executive Officers
of similarly-sized corporations using a blend of utilities and general
industry. His salary for 1999 will remain the same as in 1998.
III-5
Annual Variable Compensation
To provide clear focus on increasing stockholder value through the
successful completion of the merger and growing the new Conectiv businesses,
Mr. Cosgrove received additional levels of long-term awards in place of an
annual variable opportunity for 1997. Therefore, there is no annual variable
pay for 1997 reflected in 1998 compensation.
Mr. Cosgrove's annual variable compensation target opportunity for 1998 was
set at 50% of base compensation, with a minimum payout of 0% and a maximum
payout of 75% of base compensation. Payment of any award requires achieving a
predetermined level of 1998 earnings established by this Committee.
Performance measures for 1998, predetermined by this Committee, included
earnings available for common stock, cash flow return on capital employed and
cash flow. Awards for 1998 for Mr. Cosgrove and the four other named executive
officers have not been determined.
Long-Term Variable Compensation
Long-term incentive grants are a critical component of the Conectiv
executive compensation philosophy, since they align executive interests very
clearly with increased stockholder value. For 1998, Mr. Cosgrove received
grants of non-qualified stock options, dividend equivalent units, performance
accelerated restricted stock, and performance accelerated stock options
(reflected in the Compensation Tables). The regular grants of non-qualified
stock options, dividend equivalent units and performance accelerated
restricted stock provided a long-term variable compensation opportunity
approximately at the median of the defined competitive market.
The special, non-recurring grant of performance accelerated stock options
was awarded to create additional emphasis on achieving higher levels of
stockholder value. In order for Mr. Cosgrove to receive any value from this
grant prior to vesting at nine and one-half years, there must be a significant
increase in stockholder value. Such increases prior to nine and one-half years
will result in accelerated vesting of this grant in increments of one-third.
The first third would vest when stockholder value increases by $400,000,000,
at which time Mr. Cosgrove's options would vest at a value of $1,200,000, or
.3% of the increase in stockholder value. The entire grant would vest if
stockholder value increases by $800,000,000, at which time Mr. Cosgrove's
options would vest at a value of $2,400,000 or .3% of the increase in
stockholder value. Only under results that yield increases in stockholder
value and trigger accelerated vesting of this grant would Mr. Cosgrove's 1998
compensation exceed the median target compensation level.
Personnel & Compensation Committee
S.I. Gore, Chairperson R.B. McGlynn
M.B. Emery B.J. Morgan
Personnel & Compensation Committee Interlocks and Insider Participation
The Personnel & Compensation Committee is comprised solely of non-officer
directors. Logical Business Solutions, which is owned by Mr. Emery's son-in-
law, Paul Kleiman, had contracts with Conectiv Resource Partners, Inc., a
subsidiary of the Company, with a gross value of $227,000 during 1998 for
information technology consulting services. Except as described in the
preceding sentence, there are no Personnel & Compensation Committee
interlocks.
III-6
Summary Compensation Table
Table 1--SUMMARY COMPENSATION TABLE
Long-Term Compensation
----------------------
Annual Compensation Awards Payouts
------------------- ------ -------
Variable Securities LTIP All Other
Annualized Compensation Other Annual Restricted Underlying Payouts Compensation
Salary (Bonus)(2) Compensation Stock(5) Options (3) (4,6)
---------- ------------ ------------ ---------- ---------- ------- ------------
Name and
Principal Position Year(1)
------------------ -------
H.E. Cosgrove,.......... 1998 $600,000 -- -- -- 360,000 572,134 $ 12,329
Chairman of the Board
and Chief Executive
Officer
M.I. Harlacher,......... 1998 $340,000 -- -- -- -- -- $ 3,742
President 1997 $224,525 $96,800 $814,696 -- -- -- $3,208,196
1996 $215,317 $27,500 $ 8,527 $305,138 15,800 10,429 $ 7,413
B.R. Elson,............. 1998 $325,000 -- -- -- 170,000 21,560 $ 4,074
Executive Vice
President
T.S. Shaw,.............. 1998 $325,000 -- -- -- 170,000 155,267 $ 9,478
Executive Vice
President
B.S. Graham,............ 1998 $250,000 -- -- -- 170,000 155,267 $ 5,308
Senior Vice President
- --------
(1) Base salary is shown as an annualized amount. Other items of compensation
reflect the full calendar 1998 compensation received from Conectiv and
either Delmarva or Atlantic City Electric Company.
(2) The 1998 bonus, which is an annual variable award, has not yet been
determined. The target award is 50% of annualized salary for Mr. Cosgrove
and 40% for Messrs. Harlacher, Elson and Shaw and Mrs. Graham.
(3) During 1998 all restrictions lapsed on the performance-based restricted
stock granted in 1995 and 1996 under the Delmarva LTIP due to the merger
involving Delmarva and Atlantic Energy. Under the "change in control"
provisions, the awards fully vested resulting in a payout to Mr. Cosgrove
of 21,160 shares (11,570 for 1995 and 9,590 for 1996) valued at $454,940;
to Mr. Shaw of 5,450 shares (2,870 for 1995 and 2,580 for 1996) valued at
$117,175; and to Mrs. Graham of 5,450 shares (2,870 for 1995 and 2,580 for
1996) valued at $117,175. Shares were valued at $21.50 at the time of
payout. Dividends on shares of restricted stock and dividend equivalents
are accrued at the same rate as that paid to all holders of Common Stock.
As of December 31, 1998; Mr. Cosgrove held 45,520 shares of restricted
stock (35,520 for 1997 and 10,000 for 1998) and 30,000 Dividend Equivalent
Units ("DEU's"); Mr. Elson held 4,000 shares of restricted stock for 1998
and 10,000 DEU's; Mr. Shaw held 12,010 shares of restricted stock (8,010
for 1997 and 4,000 for 1998) and 10,000 DEU's; Mrs. Graham held 12,010
shares of restricted stock (8,010 for 1997 and 4,000 for 1998) and 10,000
DEU's. Holders of restricted stock are entitled to receive dividends as
declared.
(4) The amount of All Other Compensation for each of the named executive
officers for fiscal year 1998 include the following: Mr. Cosgrove, $2,125
in Company matching contributions to the Company's Savings and Investment
Plan, $10,000 in Company matching contributions to the Company's Deferred
Compensation Plan and $204 in term life insurance premiums paid by the
Company; for Mr. Shaw, $2,630 in Company matching contributions to the
Company's Savings and Investment Plan, $6,644 in Company matching
contributions to the Company's Deferred Compensation Plan and $204 in term
life insurance premiums paid by the Company; for Mrs. Graham, $2,604 in
Company matching contributions to the Company's Savings and Investment
Plan, $2,500 in Company matching contributions to the Company's Deferred
Compensation Plan and $204 in term life insurance premiums paid by the
Company; for Mr. Elson, $2,969 in Company matching contributions to the
Company's Savings and Investment Plan and $1,105 in term life insurance
premiums paid by the Company; and for Mr. Harlacher, $3,300 in Company
matching contributions to the Company's Savings and Investment Plan and
$442 in term life insurance premiums paid by the Company.
(5) Pursuant to the change-of-control provisions of Atlantic Energy's equity
based long term incentive plan for executives ("EIP"), Mr. Harlacher
elected to receive the cash equivalent of the restricted stock which had
been awarded under the plan.
(6) The amount of All Other Compensation for Mr. Harlacher for the fiscal year
ended 1997 include the following: $4,750 in Company matching contributions
to the Atlantic City Electric Company 401(k) Savings and Investment Plan;
$1,986 in Company matching contributions to the Atlantic City Electric
Company Deferred Compensation Plan; $1,065 in term life insurance premiums
paid by Atlantic City Electric Company; $996,238 in payouts under the
Atlantic City Electric Company supplemental executive retirement plan;
$674,340 cash payout for restricted stock awarded under the Atlantic
Energy EIP which vested due to change-in-control; $1,358,817 in excess
retirement benefits from the Atlantic City Electric Company Retirement
Plan; $171,000 adjustment to compensate Mr. Harlacher for certain economic
disadvantages associated with the payout of benefits in 1997 rather than
in 1998.
III-7
Table 2 -- Option Grants in Last Fiscal Year (1)
Number % of
of Securities Total Options
Underlying Granted Grant Date
Options to Employees Exercise Price Expiration Present
Name Granted (#) in Fiscal Year ($/Sh) Date Value(4)
---- ------------- -------------- -------------- ---------- ----------
H.E. Cosgrove........... 300,000(2) 29% $22.84375 1/2/08 $385,831
60,000(3) 6% $22.84375 1/2/08 $137,063
M.I. Harlacher.......... -- 0% -- -- --
-- 0% -- -- --
B.R. Elson.............. 150,000(2) 14% $22.84375 1/2/08 $192,915
20,000(3) 2% $22.84375 1/2/08 $ 45,688
T.S. Shaw............... 150,000(2) 14% $22.84375 1/2/08 $192,915
20,000(3) 2% $22.84375 1/2/08 $ 45,688
B.S. Graham............. 150,000(2) 14% $22.84375 1/2/08 $192,915
20,000(3) 2% $22.84375 1/2/08 $ 45,688
- --------
(1) Currently, Delmarva does not grant stock appreciation rights. The options
reflected in this table are for payouts in shares of Conectiv Common
Stock.
(2) Denotes Performance Accelerated Stock Options ("PASO's") which were
granted on a one-time basis. PASO's have a ten-year term and vest and are
first exercisable 9 and 1/2 years from date of grant without regard to
stock price performance. Exercise date will accelerate for favorable stock
price performance (i.e., first 1/3, second 1/3 and third 1/3 of PASO's
vest after stock trades at $26, $28 or $30 per share, respectively, for
ten consecutive trading days). There is a minimum holding period of three
years from date of grant during which these options are not exercisable.
(3) Denotes Nonqualified Stock Options. One-half of such Options vest and are
exercisable at end of second year from date of grant. Second one-half vest
and are exercisable at end of third year from date of grant.
(4) Determined using the Black-Scholes model, incorporating the following
material assumptions and adjustments: (a) exercise price of $22.84375,
equal to the Fair Market Value ("FMV") as of date of grant; (b) an option
term of ten years; (c) risk-free rate of return of 6.00%; (d) volatility
of 20.00%; and (e) dividend yield of 7.00%. For valuation purposes, PASO's
are valued as a premium-priced stock option as of the date of grant with
an exercise price of $30 on a FMV of $22.84375.
Table 3 -- Aggregated Option Exercises in Last Fiscal Yearand FY-End Option
Values
Number of
Securities Underlying Value of Unexercised In-
Unexercised Options at the-MoneyOptions at FY-
Shares Acquired Value Realized FY-End(2) End(1)
Name on Exercise ($)(1) Exercisable/Unexercisable Exercisable/Unexercisable
---- --------------- -------------- ------------------------- -------------------------
H. E. Cosgrove.......... 0 0 14,400/360,000 $51,225/$596,250
M. I. Harlacher......... 0 0 -- $ --
B. R. Elson............. 0 0 0/170,000 $ 0/$281,563
T. S. Shaw.............. 0 0 0/170,000 $ 0/$281,563
B. S. Graham............ 0 0 0/170,000 $ 0/$281,563
- --------
(1) The closing price for Conectiv's common stock as reported by the New York
Stock Exchange on December 31, 1998 was $24.50. Any value in the options
would be based on the difference between the exercise price of the options
and the value at the time of the exercise (e.g., $24.50 as of close of
business on 12/31/98), which difference would be multiplied by the number
of options exercised.
(2) Only 14,400 stock options of Mr. Cosgrove are currently exercisable. None
of the remaining options may be exercised earlier than two years from date
of grant for regular, non-performance based options and nine and one half
years from date of grant for performance based options (subject to
accelerated vesting for favorable stock price performance).
III-8
Table 4 -- Long-Term Incentive Plans--Awards in Last Fiscal Year Name
Performance
Number of Period Until
Restricted Shares/Dividend Equivalent Maturation
Units (#)(1) or Payout(2)
------------------------------------- ------------
H. E. Cosgrove............... 10,000 shs/30,000 units 3/2/05
M. I. Harlacher.............. -- --
B. R. Elson.................. 4,000 shs/10,000 units 3/2/05
T. S. Shaw................... 4,000 shs/10,000 units 3/2/05
B. S. Graham................. 4,000 shs/10,000 units 3/2/05
- --------
(1) In addition, Mr. Cosgrove held 35,520 performance shares (valued at
$870,240) and Mr. Shaw and Mrs. Graham held 8,010 performance shares
(valued at $196,245) from a 1997 award with a four year performance cycle
under the Delmarva Power Long Term Incentive Plan.
(2) Awards of Restricted Shares (Performance Accelerated Restricted Stock or
"PARS") and Dividend Equivalent Units ("DEU's") were made to four of the
named executive officers. The payout of shares of PARS may potentially be
"performance accelerated." Restrictions may lapse any time after 3 years
(i.e., after March 1, 2001) upon on achievement of favorable stock price
performance goals. In the absence of such favorable performance,
restrictions lapse after 7 years (i.e., March 2, 2005) provided that at
least a defined level of average, total return to shareholders is
achieved. As of December 31, 1998, Mr. Cosgrove's 10,000 Restricted Shares
were valued at $245,000 and Messrs. Elson and Shaw and Mrs. Graham's 4,000
PARS were valued at $98,000. These values for both Restricted Shares and
performance shares are based on the December 31, 1998 closing stock price
of $24.50. For Dividend Equivalent Units, one DEU is equal in value to the
regular quarterly dividend paid on one share of Conectiv common stock. The
Dividend Equivalent Units shown are payable in cash for twelve quarters
over a three year period ending with the quarterly dividend equivalent
payable January 31, 2001. At that point, the 1998 DEU award lapses.
Pension Plan
The Conectiv Retirement Plan includes the Cash Balance Pension Plan and
grandfathered provisions relating to the Delmarva Retirement Plan and the
Atlantic Retirement Plan that apply to employees who had either 20 years of
service or were age 50 on the effective date of the Cash Balance Pension Plan
(January 1, 1999). Certain executives whose benefits from the Conectiv
Retirement Plan are limited by the application of Federal tax laws also
receive benefits from the Supplemental Executive Retirement Plan.
Cash Balance Pension Plan
The named executive officers participate in the Conectiv Retirement Plan and
earn benefits that generally become vested after five years of service. On an
annual basis, a recordkeeping account in a participant's name is credited with
an amount equal to a percentage of the participant's total pay, including base
salary, overtime and bonuses, depending on the employee's age at the end of
the plan year, as follows:
% of
Age at end of Plan Year Pay
----------------------- ----
Under 30............................................................... 5
30 to 34............................................................... 6
35 to 39............................................................... 7
40 to 44............................................................... 8
45 to 49............................................................... 9
50 and over............................................................ 10
These accounts also receive interest credits based on average U.S. Treasury
Bill rates for the year. In addition, certain annuity benefits earned by
participants under the former Delmarva and Atlantic Retirement Plans are fully
protected as of December 31, 1998, and will be converted to an equivalent cash
amount and included in each employee's initial cash balance account. When an
employee terminates employment, the amount credited to his or her account is
converted into an annuity or paid in a lump sum.
III-9
Supplemental Retirement Benefits
Supplemental retirement benefits are provided to certain employees,
including each executive officer, whose benefits under the Conectiv Retirement
Plan are limited by type of compensation or amount under applicable Federal
tax laws and regulations. Designated employees may also receive an annual
benefit at retirement equal to a percentage of final average compensation
multiplied by years of service reduced by the amount of all benefits received
under the Conectiv Retirement Plan and other nonqualified arrangements.
Estimated Retirement Benefits Payable to Named Executive Officers
The following table shows the estimated retirement benefits, including
supplemental retirement benefits under the plans applicable to the named
executive officers, which would be payable if he or she were to retire at
normal retirement age, which is age 65, at 1998 compensation, expressed in the
form of a lump sum payment. Years of service credited to each named executive
officer as of his or her normal retirement date are as follows: Mr. Cosgove,
42; Ms. Graham, 30; Mr. Shaw, 40; Mr. Elson, 16 (8 of which are additional
years of service for purposes of the supplemental retirement benefits), and
Mr. Harlacher, 43.
Estimated Retirement Benefits
Name Year of 65th Birthday Lump Sum Value
---- --------------------- --------------
H. E. Cosgrove......................... 2008 $2,993,000(2)
B. S. Graham........................... 2013 1,540,000(1)
T. S. Shaw............................. 2012 1,789,000(2)
B. R. Elson............................ 2006 1,213,000(2)
M. I. Harlacher........................ 2007 2,323,000(2)
- --------
(1) Amounts include (i) interest credits for cash balances projected to be
5.01% per annum on annual salary credits and prior service balances, if
any, and (ii) accrued benefits as of December 31, 1998 under retirement
plans then applicable to the named executive officer. Benefits are not
subject to any offset for Social Security payments or other offset amounts
and assume no future increases in base salary or total pay.
(2) Under the Conectiv Retirement Plan's grandfather provisions, employees who
participated in the Delmarva or Atlantic Retirement Plans and who met
certain age and service requirements as of December 31, 1998, will have
retirement benefits for all years of service up to retirement calculated
according to their original final pay formula benefit. This benefit will
be compared to the cash balance account and the employee will receive
whichever is greater. Estimated benefits are based on the Delmarva
Retirement Plan for Messrs. Cosgrove, Shaw and Elson, the Cash Balance
Pension Plan for Mrs. Graham and the Atlantic Retirement Plan for Mr.
Harlacher. The amount of benefit under such grandfathering is illustrated
in the following tables applicable to the Delmarva and Atlantic Retirement
Plans, respectively:
Delmarva Retirement Plan
PENSION PLAN TABLE
Annual Retirement Benefits in Specified Remuneration and Years of Service
Classifications
Average Annual Earnings for the 5
Consecutive Years of Earnings that
Result in the Highest Average 15 Yrs. 20 Yrs. 25 Yrs. 30 Yrs. 35 Yrs.
---------------------------------- ------- ------- ------- ------- -------
$125,000................ 28,599 38,132 47,665 57,198 66,732
200,000(1).............. 46,599 62,132 77,665 93,198 108,732
300,000(1).............. 70,599 94,132 117,665 141,198(2) 164,732(2)
400,000(1).............. 94,599 126,132 157,665(2) 189,198(2) 220,732(2)
500,000(1).............. 118,599 158,132(2) 197,665(2) 237,198(2) 276,732(2)
- --------
(1) Effective January 1, 1998, annual compensation recognized may not exceed
$160,000.
(2) For 1998, the limit on annual benefits is $130,000.
Benefits are payable in the form of a 50% joint and surviving spouse annuity
or lump sum and earnings include base salary, overtime and bonus.
III-10
Atlantic Retirement Plan PENSION PLAN TABLE
Annual Retirement Benefits in Specified Remuneration and Years of Service
Classifications
Average Annual Earnings for the 5
Consecutive Years of Earnings that
result in the Highest Average 15 Yrs. 20 Yrs. 25 Yrs. 30 Yrs. 35 Yrs.
---------------------------------- ------- ------- ------- ------- -------
$125,000................ 30,000 40,000 50,000 60,000 70,000
200,000(1).............. 48,000 64,000 80,000 96,000 112,000
300,000(1).............. 72,000 96,000 120,000 144,000(2) 168,000(2)
400,000(1).............. 96,000 128,000 160,000(2) 192,000(2) 224,000(2)
500,000(1).............. 120,000 160,000(2) 200,000(2) 240,000(2) 280,000(2)
- --------
(1) Effective January 1, 1998, annual compensation recognized may not exceed
$160,000.
(2) For 1998, the limit on annual benefits is $130,000.
Benefits are paid in the form of a life annuity or lump sum and earnings
include base salary and bonus.
Change in Control Severance Agreements And Other Provisions Relating to
Possible Change in Control
Conectiv has entered into change in control severance agreements with
Messrs. Cosgrove, Elson and Shaw and Mrs. Graham and two other senior
executives. The agreements are intended to encourage the continued dedication
of members of Conectiv's senior management team. These agreements provide
potential benefits for such executives upon actual or constructive termination
of employment (other than for cause) following a change in control of
Conectiv, as defined in such agreements. Each affected executive would receive
a severance payment equal to three times Base Salary and Bonus and Conectiv-
paid medical, dental, vision, group life and disability benefits during the
three years after termination of employment, and a cash payment equal to the
actuarial equivalent of accrued retirement pension credits equal to 36 months
of additional service.
In the event of a change in control, the Variable Compensation Plan provides
that outstanding options become exercisable in full immediately, all
conditions to the vesting of PARS are deemed satisfied and shares will be
fully vested and nonforfeitable, DEU's will become fully vested and be
immediately payable, variable compensation deferred under the Management Stock
Purchase Program will be immediately distributed, and payment of variable
compensation, if any, for the current year will be decided by the Board's
Personnel & Compensation Committee. For the Deferred Compensation Plan, the
Committee may decide to distribute all deferrals in cash immediately or
continue the deferral elections of participants in which event Conectiv will
fully fund a "springing rabbi trust" to satisfy the obligations. An
independent institutional trustee will maintain any such trust established by
reason of this provision.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
All shares of ACE's common stock are owned by Conectiv, ACE's parent
company.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None
III-11
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) The following documents are filed as part of this report.
1. Financial Statements--The following financial statements are contained in
Item 8 of Part II.
Page No.
--------
Report of Independent Accountants.................................... II-12, 13
Consolidated Statements of Income for the years ended December 31,
1998, 1997, and 1996................................................ II-14
Consolidated Statements of Cash Flows for the years ended December
31, 1998, 1997, and 1996............................................ II-15
Consolidated Balance Sheets as of December 31, 1998 and 1997......... II-16,17
Consolidated Statements of Changes in Common Stockholder's Equity for
the years ended December 31, 1998, 1997, and 1996................... II-18
Notes to Consolidated Financial Statements........................... II-19
2. Financial Statement Schedules
Schedule II--Valuation and Qualifying Accounts for each of the three years
in the period ended December 31, 1998, is presented below. No other financial
statement schedules have been filed since the required information is not
present in amounts sufficient to require submission of the schedule or because
the information required is included in the respective financial statements or
the notes thereto.
Schedule II--Valuation and Qualifying Accounts
Years Ended December 31, 1998, 1997, 1996
(Dollars in thousands)
Column B Column C Column D Column E
-------- ------------------------- -------- --------
Additions
-------------------------
Balance at Charged to Balance at
beginning cost and Charged to end of
Description of period expenses other accounts Deductions period
- ----------- ---------- ---------- -------------- ---------- ----------
1998
Allowance for doubtful
accounts............... $3,500 $ 5,003 -- $5,003(A) $ 3,500
Merger-related
impairment loss on
assets held for sale... -- $18,000 -- -- $18,000
1997
Allowance for doubtful
accounts............... $3,500 $ 3,935 -- $3,935(A) $ 3,500
1996
Allowance for doubtful
accounts............... $3,300 $ 5,359 -- $5,159(A) $ 3,500
(A) Accounts receivable written off.
3. Schedule of Operating Statistics for the three years ended December 31,
1997 can be found on page IV-4 of this report.
IV-1
4. Exhibits
Exhibit
Number
-------
2 Amended and Restated Agreement and Plan of Merger, dated as of
December 26, 1996, between DPL, Atlantic Energy, Inc., Conectiv, Inc.
and DS Sub, Inc. (Filed with Registration Statement No. 333-18843)
3-A A Restated Certificate of Incorporation of Atlantic Energy, Inc. (File
No. 1-9760, Form 10-Q for quarter ended September 30, 1987--Exhibit
4(a)); Certificate of Amendment to restated Certificate of
Incorporation of Atlantic Energy, Inc. dated April 15, 1992. File No.
33-53511, Form S-8 dated May 6, 1994--Exhibit No. 3(ii).
3-B By Laws of Atlantic Energy, Inc. as amended July 13, 1995 (File No. 1-
9760, Form 10-Q for the quarter ended June 30, 1995--Exhibit 3b(1).
3-C Agreement of Merger between Atlantic City Electric Company and South
Jersey Power & Light Company filed June 30, 1949, and Amendments
through May 3, 1991 (File No. 2-71312--Exhibit No. 3(a); File No. 1-
3559, Form 10-Q for quarter ended June 30, 1982-- Exhibit No. 3(b);
Form 10-Q for quarter ended March 31, 1985-- Exhibit No. 3(a); Form
10-Q for quarter ended March 31, 1987-- Exhibit No. 3(a): Form 8-K
dated October 12, 1988--Exhibit No. 3(a); Form 10-K for fiscal year
ended December 31, 1990--Exhibit No. 3c; and Form 10-Q for quarter
ended September 30, 1991-- Exhibit No. 3c).
3-D Certificate of Merger of Atlantic Energy, Inc. with and into Conectiv,
Inc. filed with Delaware Secretary of State, effective as of March 1,
1998, filed herewith.
3-E Certificate of Merger of Atlantic Energy, Inc. with and into Conectiv,
Inc. filed with New Jersey Department of State, effective as of March
1, 1998, filed herewith.
3-F Certificate to change name from Conectiv, Inc., to Conectiv filed with
the Delaware Secretary of State pursuant to Section 102(a) of the
Delaware General Corporation Law, filed herewith.
3-G By-Laws of Atlantic City Electric Company, as amended April 24, 1989
(File No. 1-3559, Form 10-Q for the quarter ended September 31, 1989--
Exhibit No. 3).
4-A Mortgage and Deed of Trust, dated January 15, 1937, between Atlantic
City Electric Company and The Bank of New York (formerly Irving Trust
Company) and Supplemental Indentures through November 1, 1994 (File
No. 2-66280--Exhibit No. 2(b); File No. 1- 3559, Form 10-K for year
ended December 31, 1980--Exhibit No. 4(d); Form 10-Q for quarter ended
June 30, 1981--Exhibit No. 4(a); Form 10-K for year ended December 31,
1983--Exhibit No. 4(d); Form 10-Q for quarter ended March 31, 1984--
Exhibit No. 4(a); Form 10-Q for quarter ended June 30, 1984--Exhibit
4(a); Form 10-Q for quarter ended September 30, 1985--Exhibit 4; Form
10-Q for quarter ended March 31, 1986--Exhibit No. 4; Form 10-K for
year ended December 31, 1987--Exhibit No. 4(d); Form 10-Q for quarter
ended September 30, 1989--Exhibit No. 4(a); Form 10-K for year ended
December 31, 1990--Exhibit No. 4(c); File No. 33-49279--Exhibit No.
4(b); File No. 1-3559, Form 10-Q for the quarter ended September 30,
1993--Exhibits 4(a) & 4(b); Form 10-K for the year ended December 31,
1993--Exhibit 4c(i); File no. 1-3559, Form 10-Q for the quarter ended
June 30, 1994-Exhibit 4(a); File No. 1-3559, Form 10-Q for the quarter
ended September 30, 1994---Exhibit 4(a); Form 10-K for year ended
December 31, 1994--Exhibit 4(c)(1).
4-B Indenture dated as of March 1, 1997 between Atlantic City Electric
Company and The Bank of New York filed on Form 8-K, dated March 24,
1997, File No. 1-3559--Exhibit 4(e).
4-C Indenture Supplemental dated as of March 1, 1997 to Mortgage and Deed
of Trust dated January 15, 1937 between Atlantic City Electric Company
and The Bank of New York filed on Form 8-K dated March 24, 1997, File
No 1-3559, Exhibit 4(b).
IV-2
4-D Amended and Restated Trust Agreement, dated as of October 1, 1996, by and
among Atlantic City Electric Company, as Depositor, The Bank of New York,
as Property Trustee, The Bank of New York (Delaware) as Delaware Trustee
and the Administrative Trustees Named Therein, (File No. 1-9760, Form 10-
K for year ended December 31, 1996--Exhibit No. 4f(7)).
4-E Junior Subordinated Indenture, dated as of October 1, 1996, by and
between Atlantic City Electric Company and The Bank of New York, as
Trustee, (File No. 1-9760, Form 10-K for year ended December 31, 1996--
Exhibit No. 4f(8)).
4-F Guarantee Agreement, dated as of October 1, 1996, by and between Atlantic
City Electric Company as Guarantor, and The Bank of New York as Guarantee
Trustee, (File No. 1-9760, Form 10-K for year ended December 31, 1996--
Exhibit No. 4f(9)).
4-G Amended and Restated Trust Agreement, dated as of October 1, 1998, by and
among Atlantic City Electric Company, as Depositor, The Bank of New York,
as Property Trustee, The Bank of New York (Delaware) as Delaware Trustee
and the Administrative Trustees Named Therein, filed herewith.
4-H Junior Subordinated Indenture, dated as of October 1, 1998, by and
between Atlantic City Electric Company and The Bank of New York, as
Trustee, filed herewith.
4-I Guarantee Agreement, dated as of October 1, 1998, by and between Atlantic
City Electric Company as Guarantor, and The Bank of New York as Guarantee
Trustee, filed herewith.
10-A Termination Agreement dated August 14, 1997 between Atlantic Energy, Inc.
and Michael J. Chesser. (Filed with Form 10-K for the year ended December
31, 1997, File No. 1-3559).
10-B Agreement as to ownership as tenants in common of the Salem Nuclear
Generating Station Units 1, 2, and 3, dated November 24, 1971, and of
Supplements, dated as of September 1, 1975, and as of January 26, 1977
(File No. 2-43137--Exhibit No. 5(p); File No. 2-60966--Exhibit No. 5(m);
and File No. 2-58430--Exhibit No. 5(o)).
10-C Agreement as to ownership as tenants in common of the Peach Bottom Atomic
Power Station Units 2 and 3, dated November 24, 1971 and of Supplements
dated as of September 1, 1975 and as of January 26, 1977 (File No. 2-
43137--Exhibit No. 5(o); File No. 2-60966--Exhibit No. 5(j); File No. 2-
58430--Exhibit No. 5(m)).
10-D Owners Agreement, dated April 28, 1977 between Atlantic City Electric
Company and Public Service Electric & Gas Company for the Hope Creek
Generating Station Units No. 1 and 2 (File No. 2-60966--Exhibit No.
5(v)).
10-E Amendment to Owners Agreement for Hope Creek Nuclear Generating Station,
dated as of December 23, 1981, between Atlantic City Electric Company and
Public Service Electric & Gas Company (File No. 1-3559, Form 10-K for
year ended December 31, 1983--Exhibit No. 10b(3-2)).
12-A Computation of ratio of earnings to fixed charges.
12-B Computation of ratio of earnings to fixed charges and preferred
dividends.
23 Consent Independent Accountants.
27 Financial Data Schedules.
(b) Reports on Form 8-K:
On December 7, 1998, ACE filed a report on Form 8-K under Item 5, Other
Events, regarding proposed legislation for restructuring the electric utility
industry in New Jersey.
On February 17, 1999, ACE filed a report on Form 8-K under Item 5, Other
Events, regarding the New Jersey Electric Discount and Energy Competition Act.
IV-3
ATLANTIC CITY ELECTRIC COMPANY
SCHEDULE OF OPERATING STATISTICS
FOR THE THREE YEARS ENDED DECEMBER 31, 1998
The table below sets forth selected financial and operating statistics for
ACE's electric business for the years ended December 31, 1998, 1997, and 1996.
1998 1997 1996
---- ---- ----
Electricity generated and purchased (MWH):
Generated................................. 5,499,473 4,664,548 4,775,306
Purchased................................. 3,881,906 5,409,378 5,905,566
Interchange deliveries.................... (86,432) (793,102) (1,006,516)
---------- ---------- ----------
Total system output for load............. 9,294,947 9,280,824 9,674,356
========== ========== ==========
Electric sales (MWH):
Residential............................... 3,544,048 3,454,705 3,587,352
Commercial................................ 3,724,853 3,538,414 3,493,694
Industrial................................ 1,308,826 1,253,347 1,214,005
Resale.................................... 404,883 317,824 811,467
Other sales, losses and miscellaneous
system uses (1).......................... 312,337 716,534 567,838
---------- ---------- ----------
Total disposition of energy.............. 9,294,947 9,280,824 9,674,356
========== ========== ==========
Electric operating revenue (thousands):
Residential............................... $ 435,710 $ 446,917 $ 448,738
Commercial................................ 378,777 382,812 369,364
Industrial................................ 108,042 110,469 105,734
Resale.................................... 4,513 7,949 19,052
Miscellaneous revenues (2)................ 7,053 24,685 12,065
---------- ---------- ----------
Total service territory.................. 934,095 972,832 954,953
Interchange deliveries.................... 69,161 23,657 27,539
Merchant revenues (3)..................... 31,638 72,045 1,868
---------- ---------- ----------
Total electric revenues.................. $1,034,894 $1,068,534 $ 984,360
========== ========== ==========
Number of customers (end of period):
Residential............................... 429,720 425,036 420,499
Commercial................................ 57,499 56,816 55,580
Industrial................................ 1,003 1,023 1,013
Resale.................................... -- -- --
Other..................................... 522 523 519
---------- ---------- ----------
Total customers (4)...................... 488,744 483,398 477,611
========== ========== ==========
- --------
(1) Includes unbilled sales.
(2) Includes unbilled revenues and other miscellaneous revenues.
(3) Offsystem and competitive sales.
(4) Service territory only.
IV-4
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) 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, on March 26,
1999.
Atlantic City Electric Company
(Registrant)
/s/ John C. van Roden
By: _________________________________
(John C. van Roden, Senior Vice
President and Chief Financial
Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
Registrant and in the capacities indicated, on March 26, 1999.
Signature Title
/s/ Howard E. Cosgrove Chairman of the Board and
_____________________________________ Chief Executive Officer
(Howard E. Cosgrove)
/s/ John C. van Roden Senior Vice President and
_____________________________________ Chief Financial Officer
(John C. van Roden)
/s/ James P. Lavin Controller and Chief
_____________________________________ Accounting Officer
(James P. Lavin)
/s/ Meredith I. Harlacher, Jr. Director
_____________________________________
(Meredith I. Harlacher, Jr.)
/s/ Thomas S. Shaw Director
_____________________________________
(Thomas S. Shaw)
/s/ Barry R. Elson Director
_____________________________________
(Barry R. Elson)
/s/ Barbara S. Graham Director
_____________________________________
(Barbara S. Graham)
IV-5