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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, 1999
or
[_]TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
Commission file number 1-13895
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CONECTIV
(Exact name of registrant as specified in its charter)
Delaware 51-0377417
(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
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Common stock, $0.01 par value New York Stock Exchange
Class A common stock, $0.01 par value New York Stock Exchange
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 re-
quired 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 reg-
istrant 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 the 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. [_]
The aggregate market value of Conectiv common stock and Conectiv Class A
common stock held by non-affiliates as of December 31, 1999, was $1,617.1 mil-
lion based on the New York Stock Exchange Composite Transaction closing pric-
es.
The number of shares outstanding of each class of Conectiv's common stock,
as of the latest practicable date, was as follows:
Class Outstanding at January 31, 2000
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Common stock, $0.01 par value 86,149,969 shares
Class A common stock, $0.01 par value 5,742,315 shares
Documents Incorporated by Reference
Part of Form 10-K Documents Incorporated by Reference
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III Portions of the Definitive Proxy Statement for the Annual Meeting of Stockholders
of Conectiv held March 28, 2000, which Definitive Proxy Statement was filed
with the Securities and Exchange Commission on February 22, 2000.
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TABLE OF CONTENTS
Page
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PART I
Item 1. Business
Overview............................................................... I-1
Power Delivery......................................................... I-1
Energy................................................................. I-2
Telecommunications..................................................... I-3
HVAC................................................................... I-4
Other Businesses....................................................... I-4
Business Transition.................................................... I-5
Installed Electric Capacity............................................ I-6
Pennsylvania-New Jersey-Maryland Interconnection Association........... I-7
Purchased Power........................................................ I-7
Nuclear Power Plants................................................... I-8
Fuel Supply for Electric Generation.................................... I-9
Energy Adjustment Clauses.............................................. I-10
Retail Electric and Gas Rates.......................................... I-11
Customer Billing....................................................... I-12
Electric System Outages................................................ I-12
New Jersey Demand Side Management...................................... I-12
Cost Accounting Manual/Code of Conduct................................. I-13
Affiliated Transactions................................................ I-13
Federal Decontamination & Decommissioning Fund......................... I-13
Regulated Gas Delivery and Supply...................................... I-13
Capital Spending and Financing Program................................. I-14
Environmental Matters.................................................. I-15
Executive Officers..................................................... I-17
Item 2. Properties...................................................... I-18
Item 3. Legal Proceedings............................................... I-20
Item 4. Submission of Matters to a Vote of Security Holders............. I-20
PART II
Item 5. Market for Registrant's Common Equity and Related Stockholder
Matters................................................................ II-1
Item 6. Selected Financial Data......................................... II-3
Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations.................................................. II-5
Item 7A. Quantitative and Qualitative Disclosures About Market Risk..... II-24
Item 8. Financial Statements and Supplementary Data..................... II-26
Item 9. Changes in and Disagreements with Accountants on Accounting and
Financial Disclosure................................................... II-74
PART III
Item 10. Directors and Executive Officers of the Registrant............. III-1
Item 11. Executive Compensation......................................... III-1
Item 12. Security Ownership of Certain Beneficial Owners and
Management............................................................. III-1
Item 13. Certain Relationships and Related Transactions................. III-1
PART IV
Item 14. Exhibits, Financial Statement Schedules, and Reports on Form
8-K.................................................................... IV-1
Signatures.............................................................. IV-8
i
PART I
ITEM 1. BUSINESS
Overview
On March 1, 1998, Conectiv became a public utility holding company after a
series of merger transactions involving Delmarva Power & Light Company (DPL),
Atlantic Energy, Inc. (Atlantic), Conectiv, Inc., and DS Sub, Inc. (the Merg-
er). As a result of the Merger, Atlantic ceased to exist and DPL, Atlantic
City Electric Company (ACE), and the nonutility subsidiaries formerly held
separately by DPL and Atlantic became wholly-owned subsidiaries of Conectiv.
For additional information about the Merger, refer to Note 4 to the Consoli-
dated Financial Statements included in Item 8 of Part II. As used in this doc-
ument, references to Conectiv may mean the activities of one or more subsidi-
aries.
DPL and ACE are public utilities which supply and deliver electricity to
their customers. DPL also supplies and delivers natural gas to its customers.
These businesses are weather sensitive and seasonal because sales of electric-
ity are usually higher during the summer months due to air conditioning and
natural gas sales are usually higher in the winter when gas is used for space-
heating.
At December 31, 1999, Conectiv had 4,847 employees, including 1,872 employ-
ees represented by labor organizations. At December 31, 1999, 1,506 of
Conectiv's 4,847 employees worked in the heating, ventilation, and cooling
(HVAC) and telecommunications businesses of Conectiv subsidiaries.
Conectiv is a registered holding company under the Public Utility Holding
Company Act of 1935, as amended (PUHCA). PUHCA imposes certain restrictions on
the operations of registered holding companies and their subsidiaries. Pursu-
ant to PUHCA regulations, Conectiv formed a subsidiary service company,
Conectiv Resource Partners, Inc. (CRP) in 1998. CRP provides a variety of sup-
port services to Conectiv subsidiaries, and its employees are primarily former
DPL and ACE employees. The costs of CRP are directly assigned and allocated to
the Conectiv subsidiaries using CRP's services, including DPL and ACE.
Certain aspects of Conectiv's electric utility businesses are subject to
regulation by the Delaware and Maryland Public Service Commissions (DPSC and
MPSC, respectively), the New Jersey Board of Public Utilities (NJBPU), the
Virginia State Corporation Commission (VSCC), and the Federal Energy Regula-
tory Commission (FERC). Retail gas sales are subject to regulation by the
DPSC. Excluding off-system sales not subject to price regulation, the percent-
age of electric and gas utility operating revenues regulated by each regula-
tory commission for the year ended December 31, 1999, was as follows: NJBPU-
46.3%; DPSC-36.3%; MPSC-13.2%; VSCC-1.3%; and FERC-2.9%.
The sources of Conectiv's 1999 consolidated revenues were as follows: regu-
lated (subject to price regulation) electricity sales-57.4%; non-regulated
(not subject to price regulation) electricity sales-8.3%; regulated gas sales-
3.1%; non-regulated gas sales-18.7%; and other services-12.5%. Revenues from
"other services" include revenues earned from nonutility businesses such as
telecommunications, HVAC, petroleum sales, and other activities. In 1999, the
regulated retail electricity delivery and supply businesses provided most of
Conectiv's earnings. In 1999, Conectiv's consolidated regulated electric re-
tail revenues were earned from the following customer classes: residential-
46.2%; commercial-38.5%; industrial-14.4%; and other-0.9%.
For financial information concerning Conectiv's business segments, see Note
25 to Conectiv's 1999 Consolidated Financial Statements included in Item 8 of
Part II. The operations of Conectiv's business segments are discussed below.
Power Delivery
The Power Delivery business segment is responsible for the transmission and
distribution of electricity and natural gas to customers within the service
territories of DPL and ACE. Rates charged to DPL's customers for
I-1
delivery services are subject to regulation primarily by the DPSC, MPSC, and
VSCC. Rates charged to ACE's customers for electricity delivery service are
subject to regulation primarily by the NJBPU.
DPL and ACE deliver electricity within their service areas to approximately
955,000 customers through their respective transmission and distribution sys-
tems and also supply electricity to most of their electricity delivery custom-
ers. DPL has about 462,600 customers in its service area and ACE has about
492,400 customers in its service area. DPL's regulated electric service area
has a population of approximately 1.2 million and covers an area of about
6,000 square miles on the Delmarva Peninsula (Delaware and portions of Mary-
land and Virginia). ACE's regulated service area is located in the southern
one-third of New Jersey, covers an area of about 2,700 square miles, and has a
population of approximately 0.9 million.
DPL delivers natural gas through its gas transmission and distribution sys-
tems to approximately 107,300 customers in a service territory that covers
about 275 square miles in northern Delaware and has a population of approxi-
mately 0.5 million.
As discussed below, the electric utility businesses of DPL and ACE were re-
structured in 1999 pursuant to legislation enacted in Delaware, Maryland, and
New Jersey and orders issued by the DPSC, MPSC, and NJBPU. All customers in
ACE's service area could choose an alternative electricity supplier beginning
August 1, 1999. Some of DPL's customers could choose an alternative electric-
ity supplier effective October 1, 1999, and by October 1, 2000, about 96% of
DPL's customers will be able to choose an alternative electricity supplier.
Some of DPL's natural gas customers can currently choose an alternative sup-
plier. The electricity delivered by Power Delivery may be supplied to custom-
ers by alternative suppliers, DPL or ACE; gas delivered may be supplied to
customers by alternative suppliers or DPL. Delivery services are structured
into various forms of price regulated offers, some including energy supply, so
that customers may choose the combination that provides the best value. As the
electric utility industry evolves and restructuring of electricity supply is
implemented, there will be opportunities to serve new customers such as inter-
mediate marketers, wholesalers, bundled services providers, and energy service
companies.
Energy
DPL and ACE supply electricity to customers in their service areas with
power purchased from other suppliers and electricity generated by their power
plants. DPL also supplies natural gas to its customers in northern Delaware
under regulated tariffs. The transition to market pricing and terms of service
for supplying electricity to customers in the regulated service areas of DPL
and ACE began in 1999. In the latter half of 1999, public utility regulatory
commissions issued orders to DPL and ACE which restructured the electricity
supply businesses of DPL and ACE. By October 1, 2000, all of DPL's Delaware
and Maryland customers (approximately 96% of DPL's customers) may choose an
alternative electricity supplier. Effective August 1, 1999, all of ACE's cus-
tomers could choose an alternative electricity supplier. Among other things,
the electric restructuring orders provided for decreases in customer electric
rates, recovery of stranded costs, securitization of ACE's stranded costs, and
the regulatory treatment of any gain or loss arising from the divestiture of
electric power plants. For information about restructuring the electricity
supply business of DPL and ACE, see Notes 1, 6, 9, and 15 to the Consolidated
Financial Statements, included in Item 8 of Part II, and "Electric Utility In-
dustry Restructuring" within Management's Discussion and Analysis of Financial
Condition and Results of Operations (MD&A), included in Item 7 of Part II.
As discussed under "Deregulated Generation and Power Plant Sales" within the
MD&A, included in Item 7 of Part II, Conectiv is realigning the mix of elec-
tric generating plants owned by its subsidiaries. Conectiv expects that, in
the future, the electric generating plants owned by its subsidiaries will be
primarily "mid-merit" units. The kilowatt-hour (kWh) output of mid-merit units
can be increased or decreased quickly on an economic basis. Mid-merit plants
also typically have relatively low fixed operating and maintenance costs, can
use different fuel types, and are generally operated when demand rises and
electricity prices are higher.
I-2
In conjunction with Conectiv's mid-merit strategy, DPL and ACE entered into
agreements to sell their nuclear and non-strategic baseload fossil electric
generating plants (2,589 megawatts of capacity), as discussed under "Installed
Electric Capacity" in Part I and in Note 13 to the Consolidated Financial
Statements included in Item 8 of Part II. After these units are sold, Conectiv
will have approximately 1,900 megawatts (MW) of generating capacity, excluding
new mid-merit units being constructed. Conectiv is constructing new mid-merit
electric generating units seeking to establish a leading position in the mid-
merit generation market for the region served by the PJM. Conectiv's invest-
ment in mid-merit generation could ultimately grow to $2 billion to $3 bil-
lion. Conectiv is currently constructing a mid-merit electric power plant com-
prised of three combustion turbines, waste heat recovery boilers, and a steam
turbine (combined cycle unit). The combined cycle unit will have 550 MW of ca-
pacity, cost approximately $300 million, and is expected to be phased into
service from the third quarter of 2001 to the third quarter of 2002. In addi-
tion, Conectiv is beginning construction of another 550 MW combined cycle unit
($300 million estimated cost) which is expected to be phased into service over
a twelve month period starting in early- to mid-2002. The expected installa-
tion dates of the combined cycle units could change depending on whether con-
struction proceeds on schedule, permits and licenses are obtained as planned,
and other factors. Management is also currently reviewing other potential al-
ternatives for adding to Conectiv's mid-merit electric generating units.
In December 1999, DPL and ACE filed an application with the FERC for ap-
proval of the transfer to other Conectiv subsidiaries of the electric generat-
ing plants which are not being sold. Through the planned sales and transfers
of the electric generating units of DPL and ACE, the principal businesses of
DPL and ACE will be the transmission and distribution of energy, as envisioned
by legislation enacted during 1999 which restructured the electric utility in-
dustries in Delaware, Maryland and New Jersey. The production of electricity
will be conducted by the Conectiv subsidiaries receiving the transferred elec-
tric generating units, which are also expected to assume the non-regulated
electricity and gas trading activities currently conducted by DPL. For pro
forma information concerning the expected sale of the nuclear and non-strate-
gic baseload fossil electric generating plants, see Exhibit 99 to this Report
on Form 10-K.
DPL currently trades electricity and gas, and sells electricity and gas in
bulk in markets which are not subject to price regulation. DPL also sells
electricity and gas in competitive retail markets (including Delaware, Mary-
land, and New Jersey) where customers may choose an electric supplier other
than the local utility responsible for delivery. ACE sells the electricity
output of certain deregulated power plants in markets which are not price reg-
ulated. For additional information concerning these activities for DPL and
ACE, see Note 11 to the Consolidated Financial Statements included in Item 8
of Part II.
Other "Energy" businesses of Conectiv's subsidiaries include operation and
construction of thermal energy systems, power plant operating services, in-
vestments in electric co-generation projects, custom energy solutions, and
sales of petroleum products.
Telecommunications
Conectiv Communications, Inc. (CCI) is a competitive local exchange carrier
(CLEC) providing local, regional, and long distance voice and data services to
business and residential customers in Delaware, Pennsylvania, New Jersey, and
Maryland. CCI owns and operates a fiber optic network of more than 730 route
miles, and has installed its equipment in 62 Bell Atlantic central offices in
order to provide facilities-based services through a Nortel DMS-500 switch. In
the areas where CCI does not yet have its own facilities, CCI resells Bell At-
lantic local and Frontier long distance services.
In June 1999, CCI purchased an Internet service provider which offers dedi-
cated and dial-up Internet service, consulting, data security, and web servic-
es. This acquisition combined with CCI's DSL (digital subscriber line--a high
speed Internet connection) service, enables CCI to provide end-to-end Internet
service.
CCI had sold about 75,000 access line equivalents as of December 31, 1999,
in comparison to 32,000 access line equivalents as of December 31, 1998. CCI
sold fewer access lines in 1999 than originally planned due to longer than ex-
pected customer provisioning intervals (the period from signing up a new cus-
tomer to the start of
I-3
service) and lower than anticipated customer credit quality. In its efforts to
reduce provisioning intervals and increase customer satisfaction, during the
third quarter of 1999, CCI engaged in extensive negotiations with Bell Atlan-
tic regarding the terms and conditions for interconnection of the CCI and Bell
Atlantic networks and CCI's access to elements of Bell Atlantic's network as
required by federal law. In January 2000, CCI and Bell Atlantic reached agree-
ment on the terms of new interconnection agreements, which will apply through-
out Bell Atlantic's region and will continue in effect until early 2002. These
agreements are subject to regulatory approval in each state.
During the fourth quarter of 1999, Conectiv announced the appointment of a
30-year veteran of the telecommunications industry as the new president of
CCI.
As discussed below under "Business Transition," on March 22, 2000, Conectiv
announced plans to find a strategic partner in the telecommunications business
and increase focus on business markets and Internet related data services.
CCI has general tariffs on file in Delaware, Pennsylvania, New Jersey, and
Maryland, which detail the pricing and descriptions of each service offering.
These tariffs are based on a market pricing system rather than the traditional
cost-of-service model. Tariff filings have also been made with the Federal
Communications Commission for the provision of domestic and international long
distance services.
HVAC
Conectiv Services Inc. (CSI) is a full-service HVAC business operating in
the Mid-Atlantic region. CSI provides commercial customers with mechanical
HVAC/piping construction and installation, design services, sheet metal fabri-
cation, refrigeration services, preventive maintenance and repair services.
CSI offers residential services such as HVAC installation, maintenance, repair
and related plumbing services. The regional HVAC and plumbing industry is
highly competitive, fragmented, and rapidly consolidating. The sales and earn-
ings of the HVAC businesses are affected by construction cycles and weather
conditions.
As discussed below under "Business Transition," on March 22, 2000, Conectiv
announced plans to sell CSI.
Other Businesses
As discussed in Note 7 to the Consolidated Financial Statements, an indirect
Conectiv subsidiary holds a limited partner interest in Enertech Capital Part-
ners, L.P. (Enertech). Enertech is a venture capital fund that invests in en-
ergy-related technology and Internet service companies. Enertech's investments
include, among others, essential.com, Capstone Turbine Corporation, Coastal
Security Systems, Inc., Extant, Inc., Sagemaker and Whisper Communications,
Inc. Due to the nature of Enertech's investments, its earnings may be volatile
from period to period.
I-4
Business Transition
As discussed above, Conectiv's businesses have changed due to the restructur-
ing of the electric utility industry, planned sales of electric generating
plants, implementation of the "mid-merit" strategy, and other factors. Accord-
ingly, past results are not an indication of future business prospects or fi-
nancial results.
On March 22, 2000, Conectiv announced plans to (1) Expand Conectiv's new
sources of mid-merit generating capacity as discussed above; (2) Find a strate-
gic partner in the telecommunications business and increase focus on business
markets and Internet related data services; and (3) Sell CSI and the thermal
energy business of Conectiv Thermal Systems, Inc. (CTS). On a combined basis,
the operations of CSI and CTS for 1999 resulted in a net after-tax loss of $8.7
million, excluding the special charges discussed in Note 5 to the Consolidated
Financial Statements included in Item 8 of Part II.
These changes and other on-going business developments will cause the future
operating results of Conectiv's businesses to differ from the past. Operating
earnings may decrease temporarily as Conectiv exits from the regulated elec-
tricity production business and ramps up mid-merit generation and other busi-
nesses. In the future, Conectiv's operating earnings may also be more volatile
and are expected to be affected by the following factors.
. The return earned on the proceeds from the expected sale of power plants
compared to returns earned on such power plants prior to their sale--
management expects that the aggregate proceeds from the sale of the
electric generating plants will be used for debt repayment, repurchases
of common stock and new investments that fit with Conectiv's strategies,
including expansion of the mid-merit generation business;
. The performance and operating results of deregulated power plants, which
previously were subject to rate regulation;
. The amount of DPL's actual energy costs compared to the amounts included
in its customer rates for supplying electricity under default service,
as discussed in Note 9 to the Consolidated Financial Statements;
. Conectiv's ability to achieve cost reductions and streamline operations;
. The amount of income from investments, including Enertech; and
. The level of operating losses (or income) generated by nonutility busi-
nesses.
I-5
Installed Electric Capacity
Capacity is the capability to produce electric power, typically from owned
generation or third-party purchase contracts, and differs from the electric en-
ergy markets, which trade the actual energy being generated. The MW of net in-
stalled summer electric generating capacity available to DPL and ACE to serve
their peak loads as of December 31, 1999, are presented below. The net generat-
ing 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. See Item 2,
Properties, for additional information concerning electric generating units.
Megawatts of Capacity
-------------------------
Consolidated
Sources of Capacity DPL ACE Conectiv
------------------- ----- ----- ------------
Coal-fired generating units..................... 1,153 471 1,624
Oil-fired generating units...................... 598 241 839
Combustion turbines/combined cycle generating
units.......................................... 674 524 1,198
Nuclear generating units........................ 328 380 708
Diesel units.................................... 23 9 32
----- ----- -----
Conectiv-owned generating capacity.............. 2,776 1,625 4,401
Customer-owned capacity......................... 105 -- 105
Long-term purchased capacity.................... 243 708 951
Short-term purchased (sold) capacity............ 218 (11) 207
----- ----- -----
Total........................................... 3,342 2,322 5,664
===== ===== =====
As discussed in Note 13 to the Consolidated Financial Statements, included in
Item 8 of Part II, DPL and ACE have entered into agreements for the sale of
electric generating units, listed below, which are included in the table of in-
stalled capacity shown above. After the sale of these units, DPL and ACE will
purchase more electricity to supply customers in their service areas. See "Pur-
chased Power" for additional information.
Megawatts of Capacity
-------------------------
Consolidated
Electric Generating Units Expected to be sold DPL ACE Conectiv
--------------------------------------------- ----- ----- ------------
Coal fired generating units...................... 894 471 1,365
Oil-fired generating units....................... 153 295* 448
Combustion turbines & diesel units............... 37 31 68
Nuclear generating units......................... 328 380 708
----- ----- -----
1,412 1,177 2,589
===== ===== =====
- --------
* Includes 54 MW which is excluded from installed capacity for a generating
unit which currently is not being dispatched.
As members of the Pennsylvania-New Jersey-Maryland Interconnection Associa-
tion (PJM), DPL and ACE are obligated to maintain capacity levels based on
their allocated shares of estimated aggregate PJM capacity requirements. (The
PJM is discussed below.) DPL and ACE periodically update their forecasts of
peak demand and re-evaluate resources available to supply projected growth.
More capacity will be purchased after the sale of the nuclear and non-strategic
power plants, which have 2,589 MW of capacity.
I-6
DPL's regulated peak load in 1999 was 3,255 MW on July 5, a 5.5% increase
from DPL's previous historical peak demand of 3,085 MW which occurred on July
23, 1998. ACE experienced its highest historical peak demand of 2,329 MW on
July 5, 1999, which was 7.7% above the previous peak demand of 2,162 MW re-
corded on July 22, 1998. DPL and ACE met their 20% reserve margin obligations
to the PJM in 1999. To meet their PJM reserve obligations subsequent to the di-
vestiture of their power plants, DPL and ACE will purchase capacity from
sources that may include other Conectiv subsidiaries, other utilities, and the
PJM.
Pennsylvania-New Jersey-Maryland Interconnection Association
As members of the PJM, DPL's and ACE's generation and transmission facilities
are operated on an integrated basis with other electricity suppliers in Penn-
sylvania, New Jersey, Maryland, and the District of Columbia, and are intercon-
nected with other major utilities in the United States. This power pool im-
proves the reliability and operating economies of the systems in the group and
provides capital economies by permitting shared reserve requirements. The PJM's
installed capacity as of December 31, 1999, was 57,588 MW. The PJM's peak de-
mand during 1999 was 51,600 MW on July 6, which resulted in a summer reserve
margin of 10.4% (based on installed capacity of 56,944 MW on that date).
The PJM operates a centralized capacity credit market, enabling participants
to procure or sell surplus capacity to meet reliability obligations within the
PJM region.
The PJM Operating Agreement allows bids to sell electricity (energy) received
from generation located within the PJM control area. Transactions that are bid
into the PJM pool are capped at $1,000 per megawatt hour. All power providers
are paid the locational marginal price (LMP) set through power providers' bids.
The LMP will be higher in congested areas reflecting the price bids of those
higher cost generating units that are dispatched to supply demand and alleviate
the transmission constraint. Furthermore, in the event that all available gen-
eration within the PJM control area is insufficient to satisfy demand, the PJM
may institute emergency purchases from adjoining regions. The cost of such
emergency purchases is not subject to any PJM price cap.
Purchased Power
In Delaware and Maryland, DPL is the electricity supplier for customers who
do not choose an alternative electricity supplier, or the "default service"
provider. Upon completion of the divestiture of DPL's electric generating
plants, DPL will supply default service customers entirely with purchased pow-
er. As discussed in Note 13 to the Consolidated Financial Statements included
in Item 8 of Part II, the terms of DPL's power plant sale agreement with NRG
Energy, Inc. provide for DPL to purchase from NRG Energy, Inc. 500 megawatt-
hours of firm electricity per hour from completion of the sale through December
31, 2005. DPL currently purchases from PECO Energy Company (PECO) 243 MW of ca-
pacity and energy, which increases to 279 MW by 2006 when the contract expires.
Recently, DPL entered into another agreement with PECO to purchase 350 MW of
capacity and energy from March 2000 to February 2003. Subsequent to the divest-
iture of DPL's electric generating plants, management expects that these con-
tracts with NRG Energy, Inc. and PECO will satisfy approximately 80% of DPL's
forecasted average energy requirements. DPL also contracts with other electric
suppliers on an as needed basis for capacity and energy.
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 had long-term contracts with four IPPs for the purchase of 659 MW
of capacity and energy through December 28, 1999. On December 28, 1999, ACE
paid $228.5 million to terminate its 116 MW contract with Pedricktown Co-gener-
ation Limited Partnership, which was one of the four IPPs. For additional in-
formation concerning the contract termination, including expected recovery of
the termination payment from customers, see Note 10 to the Consolidated Finan-
cial Statements included in Item 8 of Part II.
I-7
ACE's NJBPU-approved IPP contracts as of December 31, 1999 are listed below.
Fuel MW Date of
Project Location Type Capacity Commercial Operation
---------------- ----------- -------- --------------------
Chester, Pennsylvania.............. solid waste 75 September 1991
Carney's Point, New Jersey......... coal 249 March 1994
Logan Township, New Jersey......... coal 219 September 1994
---
Total........................... 543
===
ACE is also currently purchasing 125 MW of capacity and energy from PECO un-
der a contract which ends May 31, 2000. ACE also contracts with other electric
suppliers on an as-needed basis for the purchase of short-term capacity and en-
ergy.
Effective August 1, 1999, under Basic Generation Service (BGS), ACE supplies
electricity to retail customers in its service area who have not chosen an al-
ternative electricity supplier. ACE will supply the BGS load requirement with
power purchased under the contracts shown above and the output generated by
certain units to be divested (prior to divestiture of the units). ACE will pur-
chase power through a competitive bidding process for any BGS supply require-
ment greater than the output from certain generation units to be divested and
the power purchased from the nonutility suppliers. Upon completion of the di-
vestiture of ACE's electric generating plants, ACE will supply BGS entirely
with purchased power.
Nuclear Power Plants
DPL and ACE have entered into agreements for the sale of their ownership in-
terests in nuclear power plants to PSEG Power LLC (a subsidiary of Public Serv-
ice Enterprise Group) and PECO. Upon completion of the sales, DPL and ACE will
transfer their respective nuclear decommissioning trust funds to the purchas-
ers, who will assume full responsibility for the decommissioning of Peach Bot-
tom Atomic Power Station (Peach Bottom), Salem Nuclear Generating Station (Sa-
lem), and Hope Creek Nuclear Generating Station (Hope Creek). The sales are
subject to various federal and state regulatory approvals and are expected to
be completed by the third quarter of 2000. For additional information, see Note
13 to the Consolidated Financial Statements included in Item 8 of Part II.
DPL's nuclear capacity is provided by Peach Bottom Units 2 and 3 and by Salem
Units 1 and 2. ACE's nuclear capacity is provided by Peach Bottom, Salem, and
Hope Creek. Peach Bottom is located in York County, Pennsylvania, is operated
by PECO, and has a summer capacity of 2,186 MW. Public Service Electric and Gas
(PSE&G) operates Salem and Hope Creek, which are located adjacent to each other
in Salem County, New Jersey, and have summer capacities of 2,212 MW and 1,031
MW, respectively.
DPL's and ACE's share of MW capacity and ownership interest in the nuclear
power plants are shown below.
Consolidated
Plant DPL ACE Conectiv
----- ---- ---- ------------
Peach Bottom
Share of MW....................................... 164 164 328
Ownership %....................................... 7.51% 7.51% 15.02%
Salem
Share of MW....................................... 164* 164* 328
Ownership %....................................... 7.41% 7.41% 14.82%
Hope Creek
Share of MW....................................... -- 52 52
Ownership %....................................... -- 5.00% 5.00%
- --------
* Excludes DPL's and ACE's interest in the combustion turbine at Salem.
I-8
The ownership interests of DPL and ACE in nuclear power plants provided ap-
proximately 13% of Conectiv's total installed capacity as of December 31,
1999. See Note 12 to Conectiv's 1999 Consolidated Financial Statements, in-
cluded in Item 8 of Part II, for information about its investment in jointly-
owned generating stations.
The operation of nuclear generating units is regulated by the Nuclear Regu-
latory Commission (NRC). Such regulation requires that all aspects of plant
operations be conducted in accordance with NRC safety and environmental re-
quirements 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 capaci-
ties. For a discussion about the disposal of nuclear fuel, see "Nuclear," un-
der "Fuel Supply for Electric Generation."
For information concerning funding DPL's and ACE's shares of the estimated
future cost of decommissioning the Salem, Hope Creek, and Peach Bottom nuclear
reactors, see Note 14 to the Consolidated Financial Statements included in
Item 8 of Part II.
For information about lawsuits seeking to recover damages for the costs of
replacing the steam generators at Salem, see Item 3, Legal Proceedings.
Fuel Supply for Electric Generation
DPL's and ACE's electric generating capacity by fuel type are shown under
"Installed Electric Capacity." To facilitate the purchase of adequate amounts
of fuel, DPL and ACE contract with various suppliers of coal, oil, and natural
gas on both a long- and short-term basis. DPL's long-term coal contracts gen-
erally contain provisions for periodic and limited price adjustments, which
are based on current market prices. Oil and natural gas contracts generally
are of shorter term with prices determined by market-based indices.
DPL's and ACE's obligations for coal, oil, and gas supply contracts related
to the fossil fuel-fired electric generating units to be sold are expected to
be assumed by NRG Energy, Inc., the party which has agreed to purchase the
fossil fuel-fired plants. Under the sales agreements for DPL's and ACE's in-
terests in nuclear generating units, DPL and ACE will receive proceeds for the
book value of the nuclear fuel inventories, which are expected to be used to
liquidate DPL's and ACE's obligations for the lease of the nuclear fuel inven-
tories.
Coal
Conectiv's coal fired generation includes DPL's wholly-owned Edge Moor Units
3 and 4 and the Indian River Station, and ACE's wholly-owned B.L. England
Units 1 and 2 and Deepwater Unit 6. Coal is also the fuel source for the Key-
stone and Conemaugh generating plants, in which DPL and ACE have ownership in-
terests. During 1999, 30% of DPL's coal supply was purchased under contracts
of less than three years in duration, 51% under long-term contracts (up to ten
years), and the balance on the spot market. During 1999, 51% of ACE's coal
supply was purchased under long-term contracts (up to ten years) and the bal-
ance was purchased on the spot market. Approximately 41% and 82% of DPL's and
ACE's respective projected coal requirements are expected to be provided under
supply contracts. DPL and ACE do not anticipate any difficulty in obtaining
adequate amounts of coal.
Oil
Currently, 100% of the residual oil used in DPL's Edge Moor Unit 5 is pur-
chased on a spot basis. Natural gas is used when economically feasible. A two-
year residual oil supply contract that expires in 2001 provides
I-9
90% to 100% of the fuel supply requirements for DPL's Vienna Generating Sta-
tion (Vienna). Any amount over 90% of Vienna's requirements may be purchased
in the spot market. All of the residual oil used in ACE's B.L. England Unit 3
and Deepwater Unit 1 and all of the distillate oil supply for ACE's combustion
turbines is purchased on a spot basis.
Gas
Natural gas is the primary fuel for the three combustion turbines at DPL's
Hay Road site and a secondary fuel for DPL's Edge Moor Units 3, 4, and 5. Nat-
ural gas for these DPL generating units is purchased on a firm or interrupti-
ble basis from suppliers such as marketers, producers, and utilities. The sec-
ondary fuel for DPL's Hay Road combustion turbines is low-sulfur diesel fuel,
which is purchased in the spot market. Six of ACE's combustion turbines use
natural gas as a primary fuel source and ACE's Deepwater Units 1 and 6 use
natural gas as secondary fuel. Natural gas for ACE's gas-fired generating
units is primarily purchased from the local gas distribution company on a firm
basis and is also purchased from other suppliers such as marketers, producers,
and utilities. Natural gas is delivered to both DPL and ACE through the inter-
state pipeline system under a mix of long-term firm, short-term firm, and in-
terruptible contracts.
Nuclear
PSE&G has informed DPL and ACE that it has several long-term contracts with
uranium ore operators, converters, enrichers and fabricators to meet the cur-
rently projected fuel requirements for Salem. PSE&G has also informed ACE that
it has similar contracts to satisfy the fuel requirements of Hope Creek. DPL
and ACE have also been advised by PECO that it has contracts similar to
PSE&G's 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.
After spent fuel is removed from a nuclear reactor, it is placed in tempo-
rary storage for cooling in a spent fuel pool at the nuclear station site. Un-
der the Nuclear Waste Policy Act of 1982 (NWPA), the federal government en-
tered into contracts with utilities operating nuclear power plants for trans-
portation and ultimate disposal of spent nuclear fuel and high level radioac-
tive waste. However, no permanent government-owned and operated repositories
are in service or under construction. The United States Department of Energy
(DOE) has stated that it would not be able to open a permanent, high level nu-
clear 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 DPL and 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 un-
til 2008. PECO has advised DPL and 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 DPL and ACE that it is constructing an on-site dry storage
facility, which is expected to be operational in 2000, to provide additional
storage capacity.
Energy Adjustment Clauses
As a result of electric utility industry restructuring, energy adjustments
in DPL's Delaware regulated retail electric tariffs were eliminated effective
October 1, 1999, and energy adjustments in DPL's Maryland regulated retail
electric tariffs are to be eliminated effective June 30, 2000. The energy ad-
justment clauses provided for collection from customers of fuel costs and pur-
chased energy costs. In Virginia, DPL proposed to the VSCC that the energy ad-
justment clause be discontinued in 2000. Earnings volatility may increase due
to elimination of DPL's energy adjustment clauses.
I-10
A gas cost rate clause provides for the recovery of gas costs through regu-
lated tariffs from DPL's regulated gas customers. Gas costs for regulated, on-
system customers are charged to operations based on costs billed to customers
under the gas cost rate clause. Any under-collection or over-collection of gas
costs in a current period is generally deferred. Customers' rates are adjusted
periodically to reflect amounts actually paid by DPL for purchased gas.
Through July 31, 1999, ACE's tariffs for its electric customers included en-
ergy adjustments for fuel costs, purchased energy costs, and capacity pur-
chased from nonutility electricity suppliers. Effective August 1, 1999,
through various components of regulated rates, the rates charged to ACE's BGS
customers for electricity supply, include ACE's fuel costs, purchased energy
costs, and capacity purchased from nonutility electricity suppliers. Under the
terms of the NJBPU's Summary Order concerning restructuring ACE's electricity
business, ACE's regulatory liability for over-recovered energy supply costs as
of July 31, 1999 is to be offset by any subsequent under-recoveries of BGS and
certain other costs. Similarly, any over-recoveries will increase the regula-
tory liability. Customer rates are to be adjusted for any deferred balance re-
maining after the initial four-year transition period which began August 1,
1999.
Retail Electric and Gas Rates
Changes in DPL's and ACE's customer rates other than those related to the
energy adjustment clauses are discussed below. Changes in customer rates due
to the electric and gas energy adjustment clause generally do not affect earn-
ings.
Effective October 1, 1999, DPL's Delaware residential electric rates were
reduced 7.5% in connection with the restructuring of the Delaware electric
utility industry. Also, electric rates in effect on October 1, 1999 are to re-
main unchanged for four years for Delaware residential customers and three
years for Delaware non-residential customers. Management estimates that the
initial 7.5% Delaware residential rate reduction will reduce revenues by ap-
proximately $17.5 million (on an annualized basis, assuming fiscal year 1998
sales and revenues).
A 7.5% reduction in DPL's Maryland residential electric rates is scheduled
for July 1, 2000, in connection with the restructuring of the Maryland elec-
tric utility industry. Also, the electric rates which become effective on July
1, 2000 are to remain unchanged for four years for Maryland residential cus-
tomers and three years for Maryland non-residential customers. Management es-
timates that the initial 7.5% Maryland residential rate reduction will reduce
revenues by approximately $12.5 million (on an annualized basis, assuming fis-
cal year 1998 sales and revenues).
DPL has proposed a 2.6% (approximately $0.7 million on an annual basis) rev-
enue decrease for Virginia electric retail customers by the completion of the
divestiture of DPL's electric generating plants.
In connection with restructuring the electric utility industry in New Jer-
sey, the NJBPU directed ACE to implement a 5% aggregate rate reduction effec-
tive August 1, 1999. ACE also must implement at least an additional 2% rate
reduction by January 1, 2001. By August 1, 2002, rates must be reduced by 10%
from the rates which were in effect as of April 30, 1997. Management estimates
that the initial rate reduction effective August 1, 1999, will reduce revenues
by approximately $50 million (on an annualized basis, assuming fiscal year
1998 sales and revenues). Since an estimated $25 million of the revenue reduc-
tion resulted from the energy component of ACE's regulated revenues previously
exceeding related energy costs, this portion of the revenue reduction should
not affect earnings.
In accordance with the terms included in regulatory commissions' orders
which approved the Merger, ACE and DPL phased in reductions in electric and
gas retail customer rates. ACE's total Merger-related electric 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; (2) $9.9 million effective March 1, 1998, and
(3) $0.8 million effective January 1, 1999. DPL's total Merger-related rate
decrease of $13.0 million
I-11
was phased in as follows: (1) $11.5 million effective March 1, 1998, (2) $1.1
million effective March 1, 1999, and (3) $0.4 million effective October 1,
1999.
For information concerning lower New Jersey customer rates due to corre-
sponding New Jersey tax reductions, see Note 3 to the Consolidated Financial
Statements included in Item 8 of Part II.
For additional information concerning the impact of electric utility indus-
try restructuring on customer rates, see Note 9 to the Consolidated Financial
Statements included in Item 8 of Part II.
Customer Billing
In December 1999, a new customer billing system was installed, among other
reasons, to accommodate the unbundled utility bills required by electric util-
ity industry restructuring. As is the case with any complex billing system
changeover, errors have occurred, which Conectiv is in the process of resolv-
ing. On March 14, 2000, the DPSC initiated a proceeding in which billing sys-
tem and related customer service issues are to be reviewed. Although billing
system implementation problems may potentially affect future revenues and cash
flows, management currently does not expect such problems to materially affect
Conectiv's results of operations or financial position.
Electric System Outages
After customers experienced electric service outages in early-July 1999 dur-
ing an extended period of hot and humid weather and high demand for electrici-
ty, (i) the NJBPU initiated an investigation of outages occurring in the serv-
ice territories of ACE and other New Jersey electric utilities; (ii) the DPSC
initiated an investigation of outages occurring in DPL's Delaware service ter-
ritory (as well as an examination of post-Merger DPL customer service levels);
and (iii) the MPSC initiated an investigation of outages occurring in the
service territories of DPL and other Maryland electric utilities. ACE and DPL
have responded to, and expect to continue to respond to, information requests
during the pendency of these investigations.
In November 1999, the NJBPU expanded its July outage investigation to in-
clude a general reliability investigation of ACE and all other New Jersey
utilities.
In a separate but related proceeding, the NJBPU has convened an Electric
Distribution Service Reliability and Quality Standards working group to draft
performance standards for the electric and gas transmission and distribution
systems of New Jersey utilities. Performance standards are expected to be es-
tablished by late-2000.
On October 13, 1999, the DPSC initiated a formal proceeding to investigate
the adequacy of DPL's facilities and services, including the remedies and in-
centives (if any) to be imposed or offered, respectively, to ensure the con-
tinued adequacy of DPL's facilities and services. That proceeding also will
consider the effects (if any) of electric industry restructuring in Delaware
on the reliability of electric service. DPL is actively involved in defending
actions taken (including rotating load-shedding) during early-July 1999 and
explaining its view that electric industry restructuring is unlikely to affect
DPL's electric system reliability. This DPSC proceeding is scheduled to con-
clude by May 2000.
On November 4-5, 1999, the MPSC held hearings on outages occurring during
1999 in the service territories of DPL and other Maryland utilities.
New Jersey Demand Side Management
The NJBPU adopted rules in 1991 to encourage utilities to offer demand side
management (DSM) and conservation services. The Electric Discount and Energy
Competition Act, enacted February 9, 1999 in New Jersey, requires the continu-
ation of these energy efficiency programs and the initiation of renewable en-
ergy programs, the costs of which are to be recovered through a societal bene-
fits charge to electric and gas customers
I-12
of New Jersey public utilities. On June 9, 1999, the NJBPU initiated the Com-
prehensive Resource Analysis (CRA) proceeding causing a comprehensive resource
analysis of energy programs to be undertaken including the re-evaluation of
existing DSM programs and the incorporation of new energy efficiency and re-
newable energy programs. A key issue in the CRA proceeding is the determina-
tion of the appropriate level of funding for energy efficiency and renewable
energy programs on a statewide basis. Hearings were conducted in November 1999
and a record was established that would permit the NJBPU to render decisions
for each New Jersey utility in lieu of settlements, if necessary. ACE filed
its proposed CRA plan with the NJBPU on August 23, 1999. A decision by the
NJBPU is expected in 2000.
Cost Accounting Manual/Code of Conduct
Conectiv and its subsidiaries have cost allocation and direct charging mech-
anisms in place to prevent cross-subsidization of competitive activities by
regulated utility activities. DPL and ACE are also subject to various Codes of
Conduct that affect the relationship between their regulated activities and
the unregulated activities that they or other Conectiv subsidiaries perform.
In general, these Codes of Conduct limit information obtained through utility
activities from being disseminated to employees engaged in non-regulated ac-
tivities, and restrict or prohibit sales leads, joint sales calls, joint pro-
motions, and the use of the same telephone numbers for regulated and unregu-
lated activities. There are ongoing regulatory proceedings affecting both DPL
and ACE that could result in modifications to the existing Codes of Conduct,
which modifications could adversely impact the way Conectiv's subsidiaries are
organized and Conectiv's ability to capture economies of common management and
to deploy resources efficiently.
Affiliated Transactions
Certain types of transactions between DPL and ACE and their affiliates may
require the prior approval of the VSCC and the NJBPU.
On March 15, 2000, the NJBPU adopted Interim Affiliate Relations, Fair Com-
petition and Accounting Standards and Related Reporting Requirements (Interim
Standards). These Interim Standards will remain in effect for no longer than
18 months, until final standards are issued by the NJBPU. Management is cur-
rently reviewing the Interim Standards.
Federal Decontamination & Decommissioning Fund
The Energy Policy Act of 1992 provided for creation of a Decontamination &
Decommissioning (D&D) Fund to pay for the future clean-up of DOE gaseous dif-
fusion enrichment facilities. Domestic utilities and the federal government
are required to make payments to the D&D Fund until 2008 or $2.25 billion, ad-
justed annually for inflation, is collected. The liability accrued for DPL's
and ACE's shares of the D&D Fund was $9.7 million as of December 31, 1999. The
terms of agreements for the sales of DPL's and ACE's interests in the nuclear
power plants provide for the buyers of the plants to assume the amount of this
liability which exists at the time the sales are completed.
Regulated Gas Delivery and Supply
DPL's large and medium volume commercial and industrial customers may pur-
chase gas from DPL, or directly from other suppliers and make arrangements for
transporting gas purchased from these suppliers to the customers' facilities.
DPL's transportation customers pay a fee, which may be either fixed or negoti-
ated, for the use of DPL's gas transmission and distribution facilities.
On November 1, 1999, DPL instituted a pilot program to provide transporta-
tion service and a choice of gas suppliers to a group of retail customers. The
program was open to 15% of residential and 15% of small commercial customers.
Approximately 40% of residential and 80% of small commercial customers who
were eligible for the program actually enrolled. The pilot program will be in
effect until October 30, 2001.
I-13
DPL purchases gas supplies from marketers and producers under spot market,
short-term, and long-term agreements. As shown in the table below, DPL's maxi-
mum 24-hour system capability, including natural gas purchases, storage deliv-
eries, and the emergency sendout capability of its peak shaving plant, is
190,416 Mcf (thousand cubic feet).
Number of Expiration Daily
Contracts Dates Mcf
--------- ---------- -------
Supply......................................... 1 2001 9,180
Transportation................................. 5 2001-2016 86,152
Storage........................................ 6 2000-2013 50,084
Local Peak Shaving (emergency capability)...... 45,000
-------
Total........................................ 190,416
=======
DPL experienced an all-time daily peak in combined firm sales and transpor-
tation sendout of 158,810 Mcf on January 17, 1997. DPL's peak shaving plant
liquefies, stores, and re-gasifies natural gas in order to provide supplemen-
tal gas in the event of pipeline supply shortfalls or system emergencies.
In 1998, DPL implemented a DPSC-approved gas price hedging/risk management
program with respect to gas supply for regulated customers. The program seeks
to limit exposure to commodity price uncertainty. Costs and benefits of the
program are included in the gas cost rate clause, resulting in no effect on
DPL's earnings.
Capital Spending and Financing Program
For financial information concerning Conectiv's capital spending and financ-
ing program, refer to "Liquidity and Capital Resources" in the MD&A included
in Item 7 of Part II, and Notes 16 to 19 to the 1999 Consolidated Financial
Statements, included in Item 8 of Part II.
Conectiv's ratios of earnings to fixed charges under the Securities and Ex-
change Commission (SEC) Method for 1995-1999 are shown below.
Year Ended December 31,
------------------------
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Ratio of Earnings to Fixed Charges (SEC Method)... 1.98 2.38 2.63 2.83 2.92
Under the SEC Method, earnings, including Allowance For Funds Used During
Construction, are income before extraordinary item plus income taxes and fixed
charges, less capitalized interest. Fixed charges include gross interest ex-
pense, the estimated interest component of rentals, and preferred stock divi-
dend requirements of subsidiaries. Preferred stock dividend requirements for
purposes of computing the ratio have been increased to an amount representing
the pre-tax earnings which would be required to cover such dividend require-
ments.
DPL's ratios of earnings to fixed charges and earnings to fixed charges and
preferred stock dividends under the SEC Methods for 1995-1999 are shown below.
Year Ended December 31,
------------------------
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Ratio of Earnings to Fixed Charges (SEC Method)... 3.65 2.92 2.83 3.33 3.54
Ratio of Earnings to Fixed Charges and Preferred
Stock Dividends (SEC Method)..................... 3.37 2.72 2.63 2.83 2.92
ACE's ratios of earnings to fixed charges and earnings to fixed charges and
preferred stock dividends under the SEC Methods for 1995-1999 are shown below.
Year Ended December 31,
------------------------
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Ratio of Earnings to Fixed Charges (SEC Method)... 2.57 1.66 2.84 2.59 3.19
Ratio of Earnings to Fixed Charges and Preferred
Stock Dividends (SEC Method)..................... 2.44 1.55 2.58 2.16 2.43
I-14
Environmental Matters
Conectiv's subsidiaries are 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 construction projects and the operation of ex-
isting facilities. Conectiv has incurred, and expects to continue to incur,
capital expenditures and operating costs because of environmental considera-
tions and requirements. Conectiv has a continuing program to assure compliance
with the environmental standards adopted by various regulatory authorities.
Included in Conectiv's forecasted capital requirements are construction ex-
penditures for compliance with environmental regulations, which are estimated
to be $13 million in 2000.
Air Quality Regulations
The federal Clean Air Act requires utilities and other industries to signif-
icantly 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 electric generating units by 1995
(Phase I) and required other electric generating units to begin reducing
SO\\2\\ and NOx emissions in the year 2000 (Phase II). Phase I emission reduc-
tion requirements have been achieved by the jointly-owned Conemaugh generating
station and ACE's B.L. England Units 1 and 2. The remainder of the wholly- and
jointly-owned fossil-fuel units of DPL and ACE are required to comply with
Phase II emission limits.
The facilities of DPL and ACE also must 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). To comply with RACT regulations, DPL has installed
low NOx burner technology on six of its generating units. DPL filed its RACT
compliance program in accordance with regulatory requirements but the program
has not yet received final regulatory approvals from Delaware and Maryland.
The New Jersey Department of Environmental Protection (NJDEP) has approved
ACE's RACT compliance plan.
Additional "post-RACT" NOx emission regulations are being pursued by states
in the NOTR. Delaware implemented post-RACT NOx control regulations requiring
attainment of summer seasonal emission reductions of up to 65% below 1990 lev-
els by May 1999 through reduced emissions or the procurement of NOx emission
allowances. In 1999, DPL complied with these post-RACT requirements. DPL's
post-RACT compliance plan for its Delaware generating units includes capital
expenditures of approximately $12 million. In New Jersey, post-RACT NOx con-
trol regulations require attainment of summer seasonal emission reductions, of
up to 65% below 1990 levels by May 1999 and 90% by 2003. ACE complied with
post-RACT requirements in 1999. ACE anticipates spending approximately $5 mil-
lion to $8 million over the next five years to achieve compliance with New
Jersey's post-RACT NOx regulations.
In addition to the above requirements, the United States Environmental Pro-
tection 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 the USEPA, the ACE facilities will most
likely achieve compliance with the USEPA requirement by 2003. Because Delaware
has not yet promulgated regulations to implement the reductions that the USEPA
has mandated by 2003, DPL currently cannot determine the additional operating
and capital costs that will be incurred to comply with these initiatives.
In July 1997, the USEPA adopted new federal air quality standards for par-
ticulate matter and ozone. The new particulate matter standard addresses fine
particulate matter. Attainment of the fine particulate matter standard may re-
quire reductions in NOx and SO\\2\\. However, under the time schedule an-
nounced by the USEPA, particulate matter non-attainment areas will not be des-
ignated until 2002 and control measures to meet this standard will not be
identified until 2005.
I-15
In 1999, the USEPA requested data from a number of electric utilities re-
garding older coal fired units in order to determine compliance with the regu-
lations for the Prevention of Significant Deterioration of Air Quality (PSD).
Based on the collected data, the U.S. Justice Department, on behalf of the
USEPA, filed seven lawsuits against electric utility companies in the Midwest
and South on November 3, 1999. On February 23, 2000, ACE received a request
for data from the USEPA and NJDEP on coal-fired operations at the Deepwater
and B.L. England electric generating stations. At this time it is not possible
to predict the impact of this request, if any, on Deepwater or B.L. England
operations.
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 envi-
ronmental regulatory agencies specify effluent limitations, monitoring re-
quirements, 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.
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. The
NJPDES permit for the B.L. England station expired in December 1999, but con-
tinues in effect because application for renewal was submitted, as required,
in June 1999. Both plants are permitted to continue operations under these
permits.
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 adopt regulations in determining whether cooling water intake
structures represent the best technology available for minimizing adverse en-
vironmental impacts. As part of its efforts to develop regulations, the USEPA
has requested information from ACE and DPL regarding current intake structure
design. Final action on the proposed regulations is required in 2001.
In reviewing DPL's applications to renew NPDES permits, DNREC has required
DPL to update earlier studies to determine if Indian River and Edge Moor power
plants are still in compliance with the Clean Water Act. Studies assessing
thermal water quality standards compliance were completed in 1999 and studies
assessing impacts of the cooling water intake structures will be completed in
2000. A report of the results of the thermal impact studies will be completed
in May 2000. If the studies indicate an adverse environmental impact, then up-
grades to the intake structures and/or environmental enhancement projects to
offset adverse impacts may be required. Impact studies would cost up to $2
million per plant. Costs for intake structure upgrades and enhancement pro-
jects would range from approximately $1 million if little adverse impact is
found, to $45 million if cooling towers are required, which DPL considers to
be an unlikely potential outcome.
Hazardous Substances
The nature of the electric and gas utility businesses results in the produc-
tion or handling of various by-products and substances which may contain sub-
stances 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 autho-
rize governmental agencies to compel responsible parties to clean up certain
abandoned or uncontrolled hazardous waste sites. Conectiv's exposure is mini-
mized by adherence to environmental standards for Conectiv-owned facilities
and through a waste disposal contractor screening and audit process.
In December 1999, DPL discovered an oil leak at the Indian River power
plant. DPL took action to determine the source of the leak and cap it, contain
the oil to minimize impact to a nearby waterway and began recovering oil from
the soil. DPL is in the process of determining the extent of the leak, design-
ing an oil
I-16
recovery/remediation system, and estimating the costs to remediate the site.
DPL is working together with regulatory agencies and may be subject to mone-
tary penalties. Management cannot predict the outcome of this matter.
As of December 31, 1999, Conectiv's other accrued liabilities included $3
million for clean-up and other potential costs related to federal and state
superfund sites. Conectiv does not expect such future costs to have a material
effect on Conectiv's financial position or results of operations.
Executive Officers
The names, ages, and positions of all of the executive officers of Conectiv
as of December 31, 1999, are listed below, along with their business experi-
ences 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 Conectiv
(As of December 31, 1999)
Name, Age and Position Business Experience During Past 5 Years
---------------------- ---------------------------------------
Howard E. Cosgrove, 56....... Elected 1998 as Chairman of the Board and Chief
Chairman of the Board, Executive Officer of Conectiv, Delmarva Power &
President and Light Company, and Atlantic City Electric
Chief Executive Officer Company. Elected 1992 as Chairman of the Board,
President and Chief Executive Officer and
Director of Delmarva Power & Light Company.
Barry R. Elson, 58........... 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, 52........... 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 of Delmarva Power & Light
Company.
John C. van Roden, 50........ Elected 1998 as Senior Vice President and Chief
Senior Vice President and Financial Officer of Conectiv, Delmarva Power &
Chief Financial Officer Light Company, and Atlantic City Electric
Company and Director of 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.
(continued on following page)
I-17
Executive Officers of Conectiv (continued)
Name, Age and Position Business Experience During Past 5 Years
---------------------- ---------------------------------------
Barbara S. Graham, 51........ Elected 1999 as Senior Vice President of
Senior Vice President Conectiv , Delmarva Power & Light Company, and
Atlantic City Electric Company and Director of
Delmarva Power & Light Company and Atlantic City
Electric Company. Elected 1998 as Senior Vice
President 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 of
Delmarva Power & Light Company.
James P. Lavin, 52........... 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.
ITEM 2. PROPERTIES
Substantially all utility plant and properties of DPL and ACE are subject to
liens of the Mortgages under which First Mortgage Bonds are issued.
The electric properties of DPL and ACE are located in New Jersey, Delaware,
Maryland, Virginia, and Pennsylvania. The following table sets forth the net
installed summer electric capacity available to DPL and ACE to serve their
peak loads as of December 31, 1999.
Net Installed
Capacity
Station Location (kilowatts)
------- -------- -------------
Coal-Fired
Edge Moor.......... Wilmington, DE...................... 260,000
Indian River....... Millsboro, DE....................... 767,000
B L England........ Beesley's Pt., NJ................... 284,000
Conemaugh.......... New Florence, PA.................... 128,000(A)
Keystone........... Shelocta, PA........................ 105,000(A)
Deepwater.......... Pennsville, NJ...................... 80,000
---------
1,624,000
---------
Oil-Fired
Edge Moor.......... Wilmington, DE...................... 445,000
B L England........ Beesley's Pt., NJ................... 155,000
Vienna............. Vienna, MD.......................... 153,000
Deepwater.......... Pennsville, NJ...................... 86,000(B)
---------
839,000
---------
(continued on following page)
I-18
Net Installed
Capacity
Station Location (kilowatts)
------- -------- -------------
Combustion
Turbines/Combined Cycle
Hay Road.............. Wilmington, DE...................... 511,000
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
Christiana............ Wilmington, DE...................... 45,000
Deepwater............. Pennsville, NJ...................... 19,000
Edge Moor............. Wilmington, DE...................... 13,000
Madison Street........ Wilmington, DE...................... 11,000
West.................. Marshallton, DE..................... 15,000
Delaware City......... Delaware City, DE................... 16,000
Indian River.......... Millsboro, DE....................... 17,000
Vienna................ Vienna, MD.......................... 17,000
Tasley................ Tasley, VA.......................... 26,000
Salem................. Lower Alloways Creek Twp., NJ....... 6,000(A)
---------
1,198,000
---------
Nuclear
Peach Bottom.......... Peach Bottom Twp., PA............... 328,000(A)
Salem................. Lower Alloways Creek Twp., NJ....... 328,000(A)
Hope Creek............ Lower Alloways Creek Twp., NJ....... 52,000(A)
---------
708,000
---------
Diesel Units
Crisfield............. Crisfield, MD....................... 10,000
Bayview............... Bayview, VA......................... 12,000
B L England........... Beesley's Pt., NJ................... 8,000
Keystone.............. Shelocta, PA........................ 700(A)
Conemaugh............. New Florence, PA.................... 800(A)
---------
31,500
---------
Subtotal--Conectiv-Owned Generating Capacity............... 4,400,500
---------
Customer-
Owned Capacity......... Delaware City, DE................... 105,000(C)
Long-term Capacity Purchases................................. 950,500
Short-term Capacity Purchases................................ 207,300
---------
Total...................................................... 5,663,300
=========
- --------
(A) DPL and ACE portion of jointly-owned plants.
(B) Excludes 54,000 kilowatts for a generating unit currently not being dis-
patched.
(C) Represents capacity owned by a refinery customer of DPL which is available
to DPL to serve its peak load.
On a combined basis, the electric transmission and distribution systems of
DPL and ACE include 2,622 transmission poleline miles of overhead lines, 5
transmission cable miles of underground cables, 16,350 distribution poleline
miles of overhead lines, and 6,738 distribution cable miles of underground ca-
bles.
I-19
DPL has a liquefied natural gas plant located in Wilmington, Delaware, with
a storage capacity of 3.045 million gallons and an emergency sendout capabil-
ity of 45,000 Mcf per day. DPL also owns five natural gas city gate stations
at various locations in its gas service territory. These stations have a total
sendout capacity of 200,000 Mcf per day.
The following table sets forth DPL's gas pipeline miles:
Transmission Mains.................................................. 114*
Distribution Mains.................................................. 1,573
Service Lines....................................................... 1,155
- --------
* Includes 11 miles of joint-use gas pipeline that is used 10% for gas opera-
tions and 90% for electric operations.
DPL, ACE, and other Conectiv subsidiaries also own and occupy a number of
properties and buildings that are used for office, service, and other purpos-
es.
ITEM 3. LEGAL PROCEEDINGS
As previously reported, on February 27, 1996, the co-owners of Salem, in-
cluding ACE and DPL, filed a complaint in the United States District Court for
New Jersey against Westinghouse Electric Corporation (Westinghouse), the de-
signer 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 In-
fluenced 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 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. Following oral argument before the
Court of Appeals for the Third Circuit, Westinghouse and Public Service Elec-
tric and Gas, on behalf of the co-owners, negotiated a settlement of the liti-
gation. The federal and state cases have been dismissed with prejudice.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matter was submitted during the fourth quarter of the fiscal year covered
by this report to a vote of the security holders of Conectiv (the holding com-
pany), through the solicitation of proxies or otherwise.
I-20
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
Conectiv common stock and Conectiv Class A common stock are listed on the
New York Stock Exchange.
As of December 31, 1999, there were 66,299 holders of Conectiv's common
stock and 30,523 holders of Conectiv's Class A common stock.
Conectiv common stock(1)
------------------------
1999 1998
------------------------- ----------------------------
Price Price
Dividend --------------- Dividend ------------------
Declared High Low Declared High Low
--------- ------- ------- --------- -------- ---------
First Quarter........... $0.38 1/2 $24 3/8 $19 3/8 $0.38 1/2 $22 3/4 $20 7/8
Second Quarter.......... 0.22 25 1/2 19 3/8 0.38 1/2 22 9/16 19 7/8
Third Quarter........... 0.22 25 1/4 19 0.38 1/2 23 1/4 19 11/16
Fourth Quarter.......... 0.22 20 3/4 16 1/4 0.38 1/2 24 1/2 21 7/8
Conectiv Class A common
stock(2)
-----------------------
1999 1998
--------------------------- --------------------------
Price Price
Dividend ------------------ Dividend -----------------
Declared High Low Declared High Low
-------- --------- -------- -------- ------- ---------
First Quarter........... $0.80 $40 $34 7/8 $0.80 $34 1/2 $29 9/16
Second Quarter.......... 0.80 42 1/4 34 3/8 0.80 36 7/8 31 11/16
Third Quarter........... 0.80 43 37 5/16 0.80 37 3/8 34
Fourth Quarter.......... 0.80 40 13/16 26 1/2 0.80 39 7/8 35 3/8
- --------
(1) The 1998 common stock price represents DPL for January and February, and
Conectiv for March through December, based on the March 1, 1998 Merger
date.
(2) Conectiv Class A common stock began trading March 3, 1998.
Stock Stock Symbol
Conectiv common stock CIV (New York Stock Ex-
Conectiv Class A common change)
stock CIV A (New York Stock Ex-
change)
DIVIDENDS ON COMMON STOCK
Conectiv announced on May 11, 1999 that it intended to reduce the dividends
on common stock to a targeted payout ratio of 40% to 60% of earnings per aver-
age share of common stock outstanding. Conectiv's Board of Directors declared
a quarterly dividend per share of common stock of $0.385 for the first quarter
of 1999, and $0.22 per share in the second, third, and fourth quarters of
1999, or a total of $1.045 in 1999 which represented approximately 55% of the
$1.89 of earnings per average share of common stock outstanding adjusted to
exclude the special and extraordinary charges discussed in Notes 5 and 6 to
the Consolidated Financial Statements, included in Item 8 of Part II.
DIVIDENDS ON CLASS A COMMON STOCK
As previously disclosed, Conectiv's Board of Directors intends that the
quarterly dividend on shares of Class A common stock will remain $0.80 per
share ($3.20 annualized rate) until March 31, 2001 (the "Initial Period"),
subject to declaration by Conectiv's Board of Directors and the obligations of
Conectiv's Board of Directors to consider the financial condition and regula-
tory environment of Conectiv and its subsidiaries and the results of opera-
tions of Conectiv and its subsidiaries; and also subject to the limitations
under applicable law and the provisions of Conectiv's Restated Certificate of
Incorporation.
II-1
Conectiv intends, following the Initial Period, subject to declaration by
Conectiv's Board of Directors and the obligation of the Board of Directors to
consider the financial condition and regulatory environment of Conectiv and
its subsidiaries and the results of operations of Conectiv and its subsidiar-
ies, to pay annual dividends on the Class A common stock in an aggregate
amount equal to (1) 90% of "Company Net Income Attributable to the Atlantic
Utility Group" (as defined in the Restated Certificate) multiplied by (2) the
Outstanding Atlantic Utility Fraction. The Outstanding Atlantic Utility Frac-
tion, as defined in Conectiv's Restated Certificate of Incorporation, repre-
sents the proportionate interest of the Class A common stock in the equity
value of the Atlantic Utility Group (and the percentage of "Company Net Income
Attributable to the Atlantic Utility Group" which is applicable to Class A
common stock). The Outstanding Atlantic Utility Fraction was 27.3% as of De-
cember 31, 1999 and 30.0% as of December 31, 1998. Notwithstanding Conectiv's
intention with respect to dividends on the Class A common stock following the
Initial Period, if and to the extent that the annual dividends paid on the
Class A common stock during the Initial Period exceed 100% of the earnings of
the Atlantic Utility Group that were applicable to the Class A common stock
during such period, Conectiv's Board of Directors may consider such fact in
determining the appropriate annual dividend rate on the Class A common stock
following the Initial Period. Dividends declared per share of Class A common
stock were $3.20 for 1999 and $3.20 for 1998. In comparison, earnings exclud-
ing special charges and the extraordinary item which were applicable to Class
A common stock were $1.44 in 1999 and $1.82 in 1998.
Management does not expect that earnings attributable to the Atlantic Util-
ity Group that are applicable to the shares of Class A common stock will be
sufficient to cover dividends on the Class A common stock during the remainder
of the Initial Period.
DIVIDEND RESTRICTION
Under the Public Utility Holding Company Act of 1935, as amended, Conectiv
may not pay dividends on the shares of common stock and Class A common stock
from an accumulated deficit or paid-in-capital without approval of the SEC. As
of December 31, 1999, Conectiv had an accumulated deficit of $36.5 million. In
January 2000, the SEC approved payment of the dividends declared by Conectiv
on its common stock and Class A common stock in December 1999. Conectiv ex-
pects to have retained earnings sufficient to offset dividends declared on
shares of common stock and Class A common stock beginning in the third quarter
of 2000, when the sale of the electric generating units discussed in Note 13
to the Consolidated Financial Statements, included in Item 8 of Part II, is
expected to be completed. There can be no assurances, however, that the sales
of the electric generating units will be completed, or that any gain will be
realized from such sales of the electric generating units. In any event,
Conectiv expects to receive the necessary SEC approvals during 2000 for the
quarterly payment of dividends on shares of its common stock and Class A com-
mon stock.
II-2
CONECTIV
ITEM 6. SELECTED FINANCIAL DATA
Year Ended December 31,
--------------------------------------------------------------------------
1999 1998(1) 1997 1996 1995
----------- ----------- ----------- ----------- -----------
(Dollars in Thousands, Except Per Share Amounts)
Operating Results and
Data
Operating Revenues...... $ 3,744,897 $ 3,071,606 $ 1,415,367 $ 1,168,664 $ 1,055,725
Operating Income........ $ 345,589(2) $ 386,915(2) $ 226,294 $ 250,389 $ 254,425
Income Before
Extraordinary Item..... $ 113,578(2) $ 153,201(2) $ 101,218(3) $ 107,251 $ 107,546
Extraordinary Item, Net
of Income Taxes(4)..... $ (311,718) -- -- -- --
Net Income (Loss)....... $ (198,140)(2) $ 153,201(2) $ 101,218(3) $ 107,251 $ 107,546
On System Electric Sales
(kWh 000)(5)........... 22,418,459 20,687,653 13,231,766 12,925,716 12,310,921
On System Gas Sold and
Transported (mcf 000).. 23,461 21,587 22,855 22,424 21,371
Common Stock Information
Basic and Diluted
Earnings (Loss)
Applicable to:
Common Stock
Income Before
Extraordinary Item.... $ 106,639(6) $ 141,292(6) $ 101,218(3) $ 107,251 $ 107,546
Extraordinary Item, Net
of Income Taxes(4).... (295,161) -- -- -- --
----------- ----------- ----------- ----------- -----------
Total................. $ (188,522) $ 141,292 $ 101,218 $ 107,251 $ 107,546
----------- ----------- ----------- ----------- -----------
Class A Common Stock
Income Before
Extraordinary Item.... $ 6,939(7) $ 11,909 -- -- --
Extraordinary Item, Net
of Income Taxes(4).... (16,557) -- -- -- --
----------- ----------- ----------- ----------- -----------
Total................. $ (9,618) $ 11,909 -- -- --
----------- ----------- ----------- ----------- -----------
Earnings (Loss) Per
Share of:
Common Stock
Before Extraordinary
Item.................. $ 1.14(6) $ 1.50(6) $ 1.66(3) $ 1.77 $ 1.79
Extraordinary Item(4).. (3.16) -- -- -- --
----------- ----------- ----------- ----------- -----------
Total................. $ (2.02) $ 1.50 $ 1.66 $ 1.77 $ 1.79
----------- ----------- ----------- ----------- -----------
Class A Common Stock
Before Extraordinary
Item.................. $ 1.14(7) $ 1.82 -- -- --
Extraordinary Item(4).. (2.71) -- -- -- --
----------- ----------- ----------- ----------- -----------
Total................. $ (1.57) $ 1.82 -- -- --
----------- ----------- ----------- ----------- -----------
Dividends Declared Per
Share of:
Common Stock........... $ 1.045 $ 1.54 $ 1.54 $ 1.54 $ 1.54
Class A Common Stock... $ 3.20 $ 3.20 -- -- --
Average Shares
Outstanding (000):
Common Stock........... 93,320 94,338 61,122 60,698 60,217
Class A Common Stock... 6,110 6,561 -- -- --
Year-End Stock Price:
Common Stock........... $ 16 13/16 $ 24 1/2 $ 23 1/16 $ 20 3/8 $ 22 3/4
Class A Common Stock... $ 29 5/8 $ 39 1/2 -- -- --
Book Value Per Common
Share(8)............... $ 12.38 $ 17.21 $ 15.59 $ 15.41 $ 15.20
Return on Average Common
Stockholders'
Equity(9).............. 8.0% 8.3% 10.6% 11.4% 11.7%
Capitalization
Common Stockholders'
Equity................. $ 1,138,173 $ 1,843,161 $ 954,496 $ 934,913 $ 923,440
Preferred Stock of
Subsidiaries:
Not Subject to
Mandatory Redemption.. 95,933 95,933 89,703 89,703 168,085
Subject to Mandatory
Redemption............ 188,950 188,950 70,000 70,000 --
Variable Rate Demand
Bonds (VRDB)(10)....... 158,430 125,100 71,500 85,000 86,500
Long-Term Debt.......... 2,124,898 1,746,562 983,672 904,033 853,904
----------- ----------- ----------- ----------- -----------
Total Capitalization
with VRDB.............. $ 3,706,384 $ 3,999,706 $ 2,169,371 $ 2,083,649 $ 2,031,929
=========== =========== =========== =========== ===========
Other Information
Total Assets............ $ 6,138,462 $ 6,087,674 $ 3,015,481 $ 2,931,855 $ 2,866,685
Long-Term Capital Lease
Obligation............. $ 30,395 $ 36,603 $ 19,877 $ 20,552 $ 20,768
Capital Expenditures.... $ 320,395 $ 224,831 $ 156,808 $ 165,595 $ 142,833
- --------
(1) As discussed in Note 4 to the Consolidated Financial Statements, Delmarva
Power & Light Company (DPL) and Atlantic City Electric Company (ACE) be-
came wholly-owned subsidiaries of Conectiv (the Merger) on March 1, 1998.
The Merger was accounted for under the purchase method of accounting,
with DPL as the acquirer. Accordingly, the 1998 Consolidated Statement of
Income includes 10 months of operating results for ACE and other former
subsidiaries of Atlantic Energy, Inc.
II-3
(2) Special Charges, as discussed in Note 5 to the Consolidated Financial
Statements, decreased operating income, income before extraordinary item,
and net income by $105.6 million, $71.6 million, and $71.6 million, re-
spectively, in 1999, and operating income, income before extraordinary
item, and net income by $27.7 million, $16.8 million and $16.8 million,
respectively in 1998.
(3) In 1997, the gain on the sale of a landfill and waste-hauling company in-
creased income before extraordinary item, net income and earnings per
common share by $13.7 million, $13.7 million, and $0.22, respectively.
(4) As discussed in Note 6 to the Consolidated Financial Statements, the ex-
traordinary item resulted from the restructuring of the electric utility
industry.
(5) Excludes interchange deliveries.
(6) Special Charges, as discussed in Note 5 to the Consolidated Financial
Statements, decreased income before extraordinary item applicable to
Conectiv common stock by $69.7 million ($0.75 per share) in 1999 and
$16.8 million ($0.18 per share) in 1998.
(7) Special Charges, as discussed in Note 5 to the Consolidated Financial
Statements, decreased income before extraordinary item applicable to
Conectiv Class A common stock by $1.9 million ($0.30 per share) in 1999.
(8) Conectiv common stock and Conectiv Class A common stock have the same
book value per common share.
(9) Before extraordinary item in 1999.
(10) Although Variable Rate Demand Bonds are classified as current liabili-
ties, management intends to use the bonds as a source of long-term fi-
nancing, as discussed in Note 19 to the Consolidated Financial State-
ments.
II-4
CONECTIV
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
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 dis-
closures without the threat of litigation, provided those statements are iden-
tified as forward-looking and are accompanied by meaningful, cautionary state-
ments 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 manage-
ment's beliefs as well as assumptions made by and information currently avail-
able to management. When used herein, the words "intend," "will," "antici-
pate," "estimate," "expect," "believe," 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: the effects of deregulation of energy supply and the unbundling
of delivery services; the ability to enter into purchased power agreements on
terms acceptable to Conectiv; market demand and prices for energy, capacity,
and fuel; weather variations affecting energy usage; operating performance of
power plants; an increasingly competitive marketplace; results of any asset
dispositions; sales retention and growth; federal and state regulatory ac-
tions; future litigation results; costs of construction; operating restric-
tions; increased costs and construction delays attributable to environmental
regulations; nuclear decommissioning and the availability of reprocessing and
storage facilities for spent nuclear fuel; and credit market concerns.
Conectiv undertakes no obligation to publicly update or revise any forward-
looking statements, whether as a result of new information, future events or
otherwise. The foregoing list of factors pursuant to the Litigation Reform Act
should not be construed as exhaustive or as any admission regarding the ade-
quacy of disclosures made prior to the effective date of the Litigation Reform
Act.
OVERVIEW
Conectiv was formed on March 1, 1998 (the Merger), through an exchange of
common stock with Delmarva Power & Light Company (DPL) and Atlantic Energy,
Inc. (Atlantic). Conectiv's two largest subsidiaries, DPL and Atlantic City
Electric Company (ACE), generate, purchase and sell electricity. DPL also sup-
plies and transports gas to its customers. Conectiv also has subsidiaries with
nonutility businesses which include local and long-distance telephone servic-
es, other telecommunication services; heating, ventilation, and air condition-
ing (HVAC) construction and services; and various other businesses.
As used in this document, references to Conectiv may mean the activities of
one or more subsidiary companies.
Under the purchase method of accounting, with DPL as the acquirer, the Con-
solidated Statements of Income include the results of operations for ACE and
formerly Atlantic-owned nonutility businesses from March 1, 1998 and thereaf-
ter. See Note 4 to the Consolidated Financial Statements for additional infor-
mation concerning the Merger.
II-5
COMMON STOCK EARNINGS SUMMARY
1999 1998 1997
-------- -------- --------
(Dollars in Millions,
Except Per Share Amounts)
After-tax contribution to earnings (loss)
applicable to common stock
Income excluding Special Charges and
Extraordinary Item............................ $ 176.3 $ 158.1 $ 101.2
Special Charges................................ (69.7) (16.8) --
-------- -------- --------
Income Before Extraordinary Item................. 106.6 141.3 101.2
Extraordinary Item............................... (295.1) -- --
-------- -------- --------
Earnings (loss) applicable to common stock....... $ (188.5) $ 141.3 $ 101.2
======== ======== ========
Average shares of common stock outstanding
(000)........................................... 93,320 94,338 61,122
-------- -------- --------
After-tax contribution to earnings (loss) per
average share of common stock
Income excluding Special Charges and
Extraordinary Item............................ $ 1.89 $ 1.68 $ 1.66
Special Charges................................ (0.75) (0.18) --
-------- -------- --------
Earnings (loss) per average share of common
stock:
Before Extraordinary Item...................... 1.14 1.50 1.66
Extraordinary Item............................. (3.16) -- --
-------- -------- --------
Earnings (loss) per average share of common
stock........................................... $ (2.02) $ 1.50 $ 1.66
======== ======== ========
For 1999, Conectiv reported a net loss applicable to common stock of $188.5
million, or a loss of $2.02 per average common share (93,320,000 average com-
mon shares). The net loss resulted from (i) a $295.1 million extraordinary
charge applicable to common stock ($3.16 per average share of common stock)
for discontinuing the application of Statement of Financial Accounting Stan-
dards (SFAS) No. 71, "Accounting for the Effects of Certain Types of Regula-
tion," (SFAS No. 71) to DPL's and ACE's electricity supply businesses because
of deregulation, and (ii) $69.7 million of special charges applicable to com-
mon stock ($0.75 per average share of common stock) primarily for write-downs
of investments in non-utility businesses and accrued employee separation
costs. For 1998, earnings applicable to common stock were $141.3 million, or
$1.50 per average share of common stock (94,338,000 average common shares),
after special charges of $16.8 million ($0.18 per average common share). For
additional information concerning special charges, see Note 5 to the Consoli-
dated Financial Statements and the "Special Charges" caption within "Manage-
ment's Discussion and Analysis of Financial Condition and Results of Opera-
tions" (MD&A). For additional information concerning deregulation and the ex-
traordinary charge to earnings, see Notes 1, 6, 9 and 15 to the Consolidated
Financial Statements and the "Electric Utility Industry Restructuring" section
within the MD&A. As discussed in Note 9 to the Consolidated Financial State-
ments, ACE's portion of the extraordinary charge was based on a Summary Order
issued by the New Jersey Board of Public Utilities (NJBPU) which addressed
stranded costs, unbundled rates, and other matters related to restructuring.
The NJBPU is to issue a more detailed order at a later date. If the NJBPU's
final detailed order were to differ materially from the Summary Order, then
the extraordinary charge could change.
Excluding the extraordinary and special charges to earnings, earnings appli-
cable to common stock were $176.3 million, or $1.89 per average common share,
for 1999 compared to $158.1 million, or $1.68 per average common share, for
1998. The $0.21 increase in earnings per average share of common stock in-
cluded a $0.06 per share increase from the net effect of purchasing 12.8 mil-
lion outstanding shares of Conectiv common stock in June 1999 (the Offer), as
discussed in Note 16 to the Consolidated Financial Statements, a $0.06 per
share increase from utility operations, and a $0.09 per share increase from
non-regulated investments and operations. The operating results of regulated
utility operations improved mainly due to higher retail electric and gas
sales, which benefited from the effects of weather, partly offset by electric
rate decreases and higher operating expenses. The $0.09 per share net improve-
ment in non-regulated investments and operations includes $0.27 per share in
1999 from equity in earnings of the Enertech venture capital fund (as dis-
cussed in Note 7 to the
II-6
Consolidated Financial Statements) and a $0.05 per share lower loss from HVAC
operations. These improvements were partially offset by the prior year equity
in earnings of a nonutility generation joint venture ($0.11 per share) and a
$0.12 per share higher net loss from Conectiv's other nonutility businesses,
primarily attributed to the telecommunications business which incurred higher
expenses to gain new customers and expand operations. Excluding the equity in
earnings of the venture capital fund in 1999 and the nonutility generation
joint venture in 1998, the operations of non-regulated businesses resulted in
a net loss after taxes of approximately $44 million in 1999 compared to a net
loss of $38 million in 1998.
Excluding the special charges to earnings, earnings applicable to common
stock were $158.1 million, or $1.68 per average common share (94,338,000 aver-
age common shares), for 1998 compared to $101.2 million, or $1.66 per average
common share (61,122,000 average common shares) for 1997. The net effect of
the higher number of average common shares due to the Merger on the variance
in earnings per share was essentially neutral since the dilution resulting
from the additional common shares was offset by the net earnings contributed
by the former Atlantic companies. The $0.02 increase in earnings per common
share (as adjusted) was primarily attributed to 2.5% higher DPL retail elec-
tric kilowatt-hour (kWh) sales and lower DPL utility operating and maintenance
expenses, offset substantially by the 1997 gain on sale of a landfill and
waste-hauling company ($0.22 per share) and higher operating losses of non-
regulated businesses.
DIVIDENDS ON COMMON STOCK
Conectiv announced on May 11, 1999 that it intended to reduce the dividends
on common stock to a targeted payout ratio of 40% to 60% of earnings per aver-
age share of common stock outstanding. Conectiv's Board of Directors declared
a quarterly dividend per share of common stock of $0.385 for the first quarter
of 1999, and $0.22 per share in the second, third, and fourth quarters of
1999, or a total of $1.045 in 1999 which represented approximately 55% of the
$1.89 of earnings per average share of common stock outstanding adjusted to
exclude the special and extraordinary charges discussed in Notes 5 and 6 to
the Consolidated Financial Statements.
CLASS A COMMON STOCK EARNINGS SUMMARY
After Tax Earnings (Loss) Earnings (Loss) Per
Applicable to Average
Class A Common Stock Class A Common Share
-------------------------- ----------------------
1999 1998 1999 1998
------------ ------------ ---------- ----------
(Dollars in Millions, Except Per Share
Amounts)
Income excluding Special
Charges and Extraordinary
Item........................ $ 8.8 $ 11.9 $ 1.44 $ 1.82
Special Charges.............. (1.9) -- (0.30) --
------------ ------------ ---------- ---------
Income Before Extraordinary
Item........................ 6.9 11.9 1.14 1.82
Extraordinary Item........... (16.5) -- (2.71) --
------------ ------------ ---------- ---------
Earnings (loss) applicable to
Class A common stock........ $ (9.6) $ 11.9 $ (1.57) $ 1.82
============ ============ ========== =========
Average shares of Class A
common Stock outstanding
(000)....................... 6,110 6,561
------------ ------------
For 1999, the net loss applicable to Class A common stock was $9.6 million,
or $1.57 per average share of Class A common stock. Excluding the $16.5 mil-
lion extraordinary charge (due to deregulation of the electricity supply busi-
ness of ACE as discussed in Notes 1, 6, 9, and 15 to the Consolidated Finan-
cial Statements) and $1.9 million of special charges applicable to Class A
common stock, earnings applicable to Class A common stock were $8.8 million,
or $1.44 per average share of Class A common stock, for 1999 compared to $11.9
million, or $1.82 per average share of Class A common stock, for 1998. The
$0.38 decrease in earnings per average share
II-7
of Class A common stock (excluding the extraordinary item and special charges)
was mainly due to higher fourth quarter operating expenses for ACE's electric-
ity delivery and generation businesses and the customer rate decreases which
became effective on August 1, 1999 due to restructuring of the electric util-
ity industry in New Jersey.
Earnings applicable to Class A common stock are equal to a percentage of
"Company Net Income Attributable to the Atlantic Utility Group," which is
earnings of the Atlantic Utility Group (AUG) less $40 million per year. The
Atlantic Utility Group (AUG) includes the assets and liabilities of the elec-
tric generation, transmission, and distribution businesses of ACE which ex-
isted on August 9, 1996 and were regulated by the NJBPU. The earnings of the
AUG will continue to be affected by the implementation of the Summary Order in
New Jersey, including the related rate decreases. (See Note 9 to the Consoli-
dated Financial Statements for information concerning the Summary Order.) The
planned sales of most of ACE's electric generating plants (discussed under
"Deregulated Generation and Power Plant Sales") are expected to decrease the
earnings capacity of the AUG. The extent of the decrease in earnings capacity
will be affected by how the proceeds from the sales of the generating plants
are utilized, which has not yet been finalized by Conectiv's management and
Board of Directors. On January 19, 2000, Conectiv announced that it expects to
use the proceeds for debt repayment, repurchases of common stock and new in-
vestments that fit with Conectiv's strategies, including expansion of the mid-
merit generation business (which is discussed under "Deregulated Generation
and Power Plant Sales"). Under certain circumstances, the percentage of "Com-
pany Net Income Attributable to the Atlantic Utility Group" applicable to
Class A common stock may be adjusted. The electric generating plants of ACE
which are not sold to third parties are expected to be transferred to another
Conectiv subsidiary; such transfer would not affect the earnings of the AUG or
the percentage of "Company Net Income Attributable to the Atlantic Utility
Group" applicable to Class A common stock because the transferred electric
generating plants would remain part of the AUG.
DIVIDENDS ON CLASS A COMMON STOCK
As previously disclosed, Conectiv's Board of Directors intends that the
quarterly dividend on shares of Class A common stock will remain $0.80 per
share ($3.20 annualized rate) until March 31, 2001 (the "Initial Period"),
subject to declaration by Conectiv's Board of Directors and the obligations of
Conectiv's Board of Directors to consider the financial condition and regula-
tory environment of Conectiv and its subsidiaries and the results of opera-
tions of Conectiv and its subsidiaries; and also subject to the limitations
under applicable law and the provisions of Conectiv's Restated Certificate of
Incorporation.
Conectiv intends, following the Initial Period, subject to declaration by
Conectiv's Board of Directors and the obligation of the Board of Directors to
consider the financial condition and regulatory environment of Conectiv and
its subsidiaries and the results of operations of Conectiv and its subsidiar-
ies, to pay annual dividends on the Class A common stock in an aggregate
amount equal to (1) 90% of "Company Net Income Attributable to the Atlantic
Utility Group" (as defined in the Restated Certificate) multiplied by (2) the
Outstanding Atlantic Utility Fraction. The Outstanding Atlantic Utility Frac-
tion, as defined in Conectiv's Restated Certificate of Incorporation, repre-
sents the proportionate interest of the Class A common stock in the equity
value of the AUG (and the percentage of "Company Net Income Attributable to
the Atlantic Utility Group" which is applicable to Class A common stock). The
Outstanding Atlantic Utility Fraction was 27.3% as of December 31, 1999 and
30.0% as of December 31, 1998. Notwithstanding Conectiv's intention with re-
spect to dividends on the Class A common stock following the Initial Period,
if and to the extent that the annual dividends paid on the Class A common
stock during the Initial Period exceed 100% of the earnings of the AUG that
were applicable to the Class A common stock during such period, Conectiv's
Board of Directors may consider such fact in determining the appropriate an-
nual dividend rate on the Class A common stock following the Initial Period.
Dividends declared per share of Class A common stock were $3.20 for 1999 and
$3.20 for 1998. In comparison, earnings excluding special charges and the ex-
traordinary item which were applicable to Class A common stock were $1.44 in
1999 and $1.82 in 1998.
Management does not expect that earnings attributable to the AUG that are
applicable to the shares of Class A common stock will be sufficient to cover
dividends on the Class A common stock during the remainder of the Initial Pe-
riod.
II-8
ELECTRIC UTILITY INDUSTRY RESTRUCTURING
During the latter half of 1999, as discussed in Notes 1, 6, 9, and 15 to the
Consolidated Financial Statements, the NJBPU issued an order to ACE, and the
DPSC and MPSC issued orders to DPL, concerning restructuring the electricity
supply businesses of ACE and DPL, respectively. Based on these orders, ACE and
DPL determined that the requirements of SFAS No. 71 no longer applied to their
electricity supply businesses as of August 1, 1999 and September 30, 1999,
respectively. As a result, ACE and DPL discontinued applying SFAS No. 71 and
applied the requirements of SFAS No. 101, "Regulated Enterprises--Accounting
for the Discontinuation of Application of FASB Statement No. 71" (SFAS No.
101) and Emerging Issues Task Force (EITF) Issue No. 97-4, "Deregulation of
the Pricing of Electricity--Issues Related to the Application of FASB State-
ments No. 71 and No. 101" (EITF 97-4), which among other things, resulted in
an extraordinary charge to earnings of $311.7 million, net of $188.3 million
of income taxes.
Implementation Dates
The table below shows when DPL's Delaware and Maryland and ACE's New Jersey
retail electric customers may choose an alternative supplier. The Virginia
Electric Utility Restructuring Act, signed into law on March 29, 1999, phases-
in retail electric competition beginning January 1, 2002.
State Customer Group Effective Date for Choice
- ----- -------------- -------------------------
New Jersey.............. All customers August 1, 1999
Delaware................ Customers with peak loads of 1,000 kilowatts or
more October 1, 1999
Delaware................ Customers with peak loads of 300 kilowatts or
more January 15, 2000
Delaware................ All other Delaware retail electric customers October 1, 2000
Maryland................ All customers July 1, 2000
Revenue Reductions
Pursuant to the electric utility restructuring orders issued by the NJBPU,
DPSC, and MPSC, electric rate decreases became effective, or are scheduled to
become effective, as shown in the table below.
Estimated Annualized
State Revenue Decrease(1) Effective Date
- ----- -------------------- ---------------
New Jersey................................ $50.0 million(2) August 1, 1999
Delaware.................................. $17.5 million(3) October 1, 1999
Maryland.................................. $12.5 million(3) July 1, 2000
- --------
(1) Estimated based on 1998 fiscal year sales and revenues.
(2) Represents a 5% rate reduction. Approximately $25 million of the estimated
$50 million decrease in ACE's New Jersey electric revenues is for the en-
ergy component of ACE's electric revenues which had been greater than the
related energy costs. Thus, $25 million of this estimated revenue decrease
should not affect earnings. An additional two percent rate reduction is
required by January 1, 2001, and by August 1, 2002, rates must be ten per-
cent lower than the rates which were in effect April 30, 1997.
(3) Represents a 7.5% reduction in residential rates, which are held constant
for four years. Non-residential rates are held constant for three years.
Regulatory Implications on Sales of Electric Generating Plants
Under the NJBPU's Summary Order, any gain or loss realized upon the sale of
ACE's electric generating plants (other than the Deepwater plant and combus-
tion turbines owned by ACE) will affect the amount of ACE's recoverable
stranded costs. Accordingly, any gain or loss realized by ACE on the sale of
these plants would not affect future earnings. Any loss on a sale within three
years of the Deepwater plant and combustion turbines owned by ACE, which began
operating on a deregulated basis effective August 1, 1999, cannot be recovered
from ACE's customers. ACE's agreement for the sale of electric generating
units to NRG Energy, Inc. includes
II-9
the sale of the 239 megawatts (MW) Deepwater plant at a loss which was re-
corded in the fourth quarter of 1999 as an adjustment to the extraordinary
item initially estimated and recorded in the third quarter of 1999.
Under the DPSC's and MPSC's electric restructuring orders, any gain or loss
realized on the sale of DPL's electric generating plants will affect net in-
come to the extent the net selling proceeds differ from the plants' net book
value, as adjusted for any impairment write-downs recorded in 1999. Based on
the existing agreements for the sale of electric generating units of DPL and
ACE with 2,588.5 MW of capacity, as discussed below under "Deregulated Genera-
tion and Power Plant Sales," and the expected financial effects of the re-
structuring orders, management expects to recognize a net gain in earnings of
approximately $140 million to $150 million when DPL completes the sale of its
electric generating plants which were not impaired from deregulation. There
can be no assurances, however, that the sales of DPL's and ACE's electric gen-
erating plants will be completed pursuant to the agreements, or that any gain
will be realized from such sales of electric generating plants.
Stranded Cost Recovery and Securitization
The NJBPU's Summary Order provides ACE the opportunity to recover 100% of
the net stranded costs related to certain generation units to be divested and
the stranded costs associated with power purchased from nonutility generators
(NUGs). The Summary Order also permits securitization of 100% of the net
stranded costs of certain generation units to be divested and the costs to ef-
fect potential NUG contract buyouts or buydowns. Securitization is expected to
occur through a special purpose entity which will issue bonds secured by the
right to collect stranded costs from customers. Stranded costs, net of taxes,
will be collected from customers through a transition bond charge and the in-
come tax expense associated with the revenues from stranded cost recovery will
be collected from customers through a separate market transition charge. As of
December 31, 1999, the balance for ACE's pre-tax recoverable stranded costs
was $988.3 million, which includes the stranded costs estimated and recorded
as a result of discontinuing the application of SFAS No. 71 and the $228.5
million payment to terminate a NUG contract (see "Renegotiation of Purchased
Power Contracts"). ACE's amount of recoverable stranded costs remains subject
to adjustment based on the actual gains and losses realized on the sale of
certain electric generating plants, additional buyouts or buydowns of NUG con-
tracts, the NJBPU's final restructuring order, and the final amount determined
to be recoverable through customer rates under the New Jersey Act.
Based on the $24 million of after-tax stranded cost recovery that the DPSC
and MPSC restructuring orders provided for, DPL recorded recoverable stranded
costs on a pre-tax basis of $44.3 million in the third quarter of 1999 ($41.8
million as of December 31, 1999). Although only partial stranded cost recovery
was provided for by the DPSC's and MPSC's restructuring orders, any gain that
may be realized on the sale of DPL's electric generating units which were not
impaired by deregulation will increase future earnings.
The $1.0 billion of pre-tax recoverable stranded costs on the consolidated
balance sheet as of December 31, 1999 represents amounts expected to be col-
lected from regulated delivery customers for stranded costs which resulted
from deregulation of the electricity supply business. The $1.0 billion balance
is net of amounts amortized and includes the $228.5 million NUG contract ter-
mination payment, with the remaining balance arising from the write-down of
property, plant and equipment and recognition of certain liabilities in con-
junction with discontinuing the application of SFAS No. 71 due to deregulation
of the electricity supply business.
Basic Generation Service and Default Service
Through July 31, 2002, under New Jersey's Basic Generation Service (BGS),
ACE is obligated to supply electricity to customers who do not choose an al-
ternative electricity supplier. As the BGS supplier, ACE's BGS rates are de-
signed to recover its costs, and, except for the above-market portions of NUG
power and the costs of certain of ACE's power plants which are recovered
through a separate non-bypassable Net NUG Charge and Market Transition Charge,
respectively, are included in regulated delivery rates. In accordance with the
NJBPU's Summary Order, ACE defers the difference between such costs incurred
and the related revenues. ACE's customer rates are to be adjusted for any de-
ferred balance remaining after the initial four-year transition period that
began August 1, 1999.
II-10
DPL is obligated to supply electricity to customers who do not choose an al-
ternative electricity supplier for three or four years (depending on customer
class) after October 1, 1999 in Delaware and July 1, 2000 in Maryland. After
October 1, 1999 in Delaware and July 1, 2000 in Maryland, Conectiv's earnings
will be affected to the extent that DPL's actual energy costs vary from the
amounts included in its customer rates.
Shopping Credits
Customers who choose an alternative electricity supplier receive a credit to
their bill, or a shopping credit, which generally represents the cost of elec-
tricity supply and transmission service. System-average shopping credits for
the first three to four years (depending on the state and/or customer group)
after customer choice begins, have been initially estimated to range from 5.27
to 5.48 cents per kWh for ACE's New Jersey customers, from 4.736 to 4.740
cents per kWh for DPL's Delaware customers, and from 5.302 to 5.307 cents per
kWh for DPL's Maryland customers.
Earnings Impact
The restructuring of the electric utility industry has changed Conectiv's
business. The planned sales of electric generating plants and implementation
of the "mid-merit" strategy, which are discussed under "Deregulated Generation
and Power Plant Sales," will also result in changes to Conectiv's existing
businesses. Accordingly, past results are not an indication of future business
prospects or financial results.
On March 22, 2000, Conectiv announced plans to (1) Expand Conectiv's new
sources of mid-merit generating capacity as discussed under "Deregulated Gen-
eration and Power Plant Sales"; (2) Find a strategic partner in the telecommu-
nications business and increase focus on business markets and Internet related
data services; and (3) Sell the HVAC and thermal energy businesses. On a com-
bined basis, the operations of HVAC and thermal energy for 1999 resulted in a
net after-tax loss of $8.7 million, excluding the special charges discussed in
Note 5 to the Consolidated Financial Statements.
These changes and other on-going business developments will cause the future
operating results of Conectiv's business to differ from the past. Operating
earnings may decrease temporarily as Conectiv exits from the regulated elec-
tricity production business and ramps up mid-merit generation and other busi-
nesses. In the future, Conectiv's operating earnings may also be more volatile
and are expected to be affected by the following factors.
. The return on the proceeds from the expected sale of power plants com-
pared to returns earned on such power plants prior to their sale--man-
agement expects that the aggregate proceeds from the sale of the elec-
tric generating plants will be used for debt repayment, repurchases of
common stock and new investments that fit with Conectiv's strategies,
including expansion of the mid-merit generation business;
. The performance and operating results of deregulated power plants, which
previously were subject to rate regulation;
. The amount of DPL's actual energy costs compared to the amounts included
in its customer rates for default service; and
. Conectiv's ability to achieve cost reductions and streamline operations.
. The amount of income from investments, including Enertech; and
. The level of operating losses (or income) generated by nonutility busi-
nesses.
The sole source of earnings applicable to Class A common stock is the AUG,
which currently consists of the electric generation, transmission and distri-
bution business of ACE. Earnings applicable to Conectiv common stock result
from all the businesses and subsidiaries of Conectiv, including the regulated
utility business of ACE. ACE's earnings, including any changes in ACE's earn-
ings due to deregulation or other factors, have a signifi-
II-11
cantly greater impact on the earnings per share of Class A common stock in
comparison to the impact on earnings per share of Conectiv's common stock.
Renegotiation of Purchased Power Contracts
ACE has had four NJBPU-approved long-term contracts with NUGs providing for
the purchase by ACE of energy and capacity from such NUGs. Such contracts were
entered into in the late 1980s, and purchases commenced in the early 1990s.
The New Jersey Electric Discount and Energy Competition Act (New Jersey Act)
provides for, among other things, the recognition by the NJBPU of the costs of
buydowns or buyouts of such contracts as stranded costs. The New Jersey Act
further provides for the financing and recovery of such costs by the given
utility, subject to certain conditions and to approval by the NJBPU. As dis-
cussed below, ACE and one of the four NUGs have terminated one of the long-
term power purchase contracts. ACE continues to negotiate buyouts and buydowns
of the remaining contracts. The financial commitments associated with such
buyouts and buydowns could be substantial. Management cannot currently predict
the ultimate outcome of contract buyout and buydown negotiations or the costs
associated therewith. There can be no assurances, moreover, that the NJBPU
will approve the arrangements that may be successfully negotiated by the par-
ties, or arrangements for the interim and/or long-term financing of amounts
(including, but not limited to, the issuance of transition bonds). The ability
of ACE to issue transition bonds would depend not only upon approval of the
NJBPU, but also the condition of the relevant capital markets at the times of
the offerings.
On May 7, 1999, ACE and a NUG, with which ACE has a long-term power purchase
contract, signed a letter of intent (LOI) relating to a transaction that could
have led to the termination of such contract. The transaction contemplated by
the LOI would have involved the establishment of a new, substitute long-term
power contract between the NUG and a third party; and the payment by ACE to
the NUG of a termination amount. ACE and the NUG received proposals from vari-
ous prospective purchasers, but were unable to establish mutually agreeable
arrangements to proceed with the transaction. Subsequently, ACE and the NUG
have been engaged in negotiations to achieve an alternative restructuring of
the purchase power contract. Such alternative restructuring, if successfully
negotiated, would be subject to the receipt of various corporate and regula-
tory approvals.
On November 10, 1999, the NJBPU issued an Order approving ACE's proposal to
terminate a NUG contract under which ACE purchased energy and 116 MW of capac-
ity from a partnership (Pedricktown Co-generation Limited Partnership) owned
50% by other Conectiv subsidiaries. The NJBPU Order also provided that ACE is
entitled to recover from customers the contract termination payment of $228.5
million, together with reasonable and prudently incurred transaction costs and
interim financing costs as specified therein. The NJBPU Order also found that
the termination payment and related transaction costs are eligible for long-
term financing through the issuance of transition bonds (securitization). On
December 28, 1999, ACE paid $228.5 million to terminate the contract and bor-
rowed funds from a credit facility that ACE had arranged to finance the con-
tract termination payment. The contract termination payment and related costs
are classified as "Recoverable Stranded Costs" on the balance sheet as of De-
cember 31, 1999. ACE's customer rates were reduced by about 1% (approximately
$11 million of revenues on an annualized basis) effective January 1, 2000 as a
result of the net savings expected to result from the contract termination.
ACE anticipates that securitization will ultimately be used to finance the
stranded costs associated with the buyout or buydown of its NUG contracts (in-
cluding the buyout described above), along with stranded costs determined in
connection with the planned divestiture of certain of ACE's generating units.
As noted above, there can be no assurances that the NJBPU will approve the is-
suance of transition bonds for such costs or that ACE will be able to issue
and sell any such bonds.
Deregulated Generation and Power Plant Sales
Conectiv is changing the mix of the types of electric generating plants it
owns in conjunction with implementing its asset-backed, "merchant" strategy
focusing on "mid-merit" electric generating plants. Mid-merit electric gener-
ating plants can quickly increase or decrease their kWh output level on an
economic basis. Mid-
II-12
merit plants typically have relatively low fixed operating and maintenance
costs and also can use different types of fuel. These plants are generally op-
erated during times when demand for electricity rises and prices are higher.
As discussed below, DPL and ACE have entered into agreements to sell their nu-
clear and non-strategic baseload fossil electric generating plants. Baseload
electric generating plants run almost continuously to supply the base level of
demand for electricity, or the minimum demand level which generally always ex-
ists on an electrical system. In a deregulated electricity supply market, man-
agement expects that mid-merit electric generating plants will be more profit-
able and provide higher returns on invested capital than baseload electric
generating plants.
Under the NJBPU's Summary Order, the kWh output from the Deepwater plant
(which is included in the generating units of ACE to be sold) and combustion
turbines owned by ACE is not dedicated to supplying BGS customers, but instead
is being operated on a deregulated basis, effective August 1, 1999. Effective
October 1, 1999, the Delaware portion (approximately 59%) of DPL's electric
generating plants was deregulated and the plants' kWh output may, at DPL's op-
tion, be sold in deregulated markets or used to supply default service custom-
ers in Delaware. Similarly, effective July 1, 2000, the Maryland portion (ap-
proximately 30%) of DPL's electric generating plants is deregulated and the
plants' kWh output may, at DPL's option, be sold in deregulated markets or
used to supply default service customers in Maryland.
Conectiv is constructing new mid-merit electric generating units seeking to
establish a leading position in the mid-merit generation market for the region
served by the PJM. Conectiv's investment in mid-merit generation could ulti-
mately grow to $2 billion to $3 billion. Conectiv is currently constructing a
new mid-merit, electric power plant in northern Delaware comprised of three
combustion turbines, waste heat recovery boilers and a steam turbine (combined
cycle unit). Assuming all permits and licenses are obtained, the new mid-merit
power plant will be installed on the site which currently includes the Hay
Road combined cycle unit and the Edge Moor power plant. The new mid-merit
power plant is expected to cost approximately $300 million and have a capacity
of approximately 550 MW. The three new combustion turbine units are expected
to be installed by the third quarter of 2001 and the waste heat recovery
boiler and steam turbine is expected to be installed by the third quarter of
2002. In addition, Conectiv is beginning construction of another 550 MW com-
bined cycle unit ($300 million estimated cost) which is expected to be phased
into service over a twelve month period starting in early-to mid-2002. The ex-
pected installation dates of the combined cycle units could change depending
on whether construction proceeds on schedule, permits and licenses are ob-
tained as planned, and other factors. Management is also currently reviewing
other potential alternatives for adding to Conectiv's mid-merit electric gen-
erating units.
On September 30, 1999, Conectiv announced that DPL and ACE reached agree-
ments to sell their ownership interests in nuclear plants, representing 714 MW
of capacity, to PSEG Power LLC and PECO Energy Company (PECO). The aggregate
sales price of $20 million, less selling costs, was used as the fair value of
the nuclear plants in determining the amount of impairment that resulted from
deregulation and the amount of the write down of DPL's and ACE's investments
in nuclear plants that was recorded in 1999. Upon completion of the sale, DPL
and ACE will transfer their respective nuclear decommissioning trust funds to
the purchasers, and PSEG Power LLC and PECO will assume full responsibility
for the decommissioning of Peach Bottom, Salem, and Hope Creek. The sales are
subject to various federal and state regulatory approvals and are expected to
close by the third quarter of 2000.
On January 19, 2000, Conectiv announced that DPL and ACE reached agreements
to sell wholly- and jointly-owned fossil units which have a total capacity of
1,874.5 MW and a net book value of $422.6 million as of December 31, 1999 (net
of the write downs recorded as a result of deregulation) to NRG Energy, Inc.,
a subsidiary of Northern States Power Company for $800 million. The sales are
subject to various federal and state regulatory approvals and are expected to
be completed during the third quarter of 2000. Management expects that the ag-
gregate proceeds from the sale of the electric generating plants will be used
for debt repayment, repurchases of common stock and new investments that fit
with Conectiv's strategies, including expansion of the mid-merit generation
business.
Upon completion of the divestiture of DPL's electric generating plants, DPL
will supply default service customers entirely with purchased power. The terms
of DPL's power plant sale agreement with NRG Energy, Inc. provide for DPL to
purchase from NRG Energy, Inc. 500 megawatt-hours of firm electricity per hour
from completion of the sale through December 31, 2005. DPL currently purchases
from PECO 243 MW of capacity and energy, which increases to 279 MW by 2006
when the contract expires. Recently, DPL entered into another
II-13
agreement with PECO to purchase 350 MW of capacity and energy from March 2000
to February 2003. Subsequent to the divestiture of DPL's electric generating
plants, management expects that these contracts with NRG Energy, Inc. and PECO
will satisfy approximately 80% of DPL's forecasted average energy require-
ments. DPL also contracts with other electric suppliers on an as needed basis
for capacity and energy.
Based on the terms of the restructuring orders issued by the DPSC and MPSC
and DPL's sales agreement with NRG Energy, Inc., management expects to recog-
nize a net gain in earnings of approximately $140 million to $150 million when
DPL completes the sale of its electric generating plants which were not im-
paired from deregulation. There can be no assurances, however, that the sales
of DPL's, or ACE's, electric generating plants will be completed pursuant to
the agreements, or that any gain will be realized from such sales of electric
generating plants.
The electric generating units which are not sold (approximately 1,900 MW of
capacity) are expected to be transferred to nonutility electric generation
subsidiaries during 2000. The 1,100 MW of capacity for the combined cycle
units being installed over the next several years will also be owned by a non-
utility electric generation Conectiv subsidiary.
Due to the expected sale of power plants, more electric capacity and energy
is expected to be purchased in the future. However, upon the sale of the elec-
tric generating plants, Conectiv's depreciation, fuel, operating, and mainte-
nance expenses for these plants will end. Also, to the extent the sales pro-
ceeds are used to pay off securities which had financed the plants, financing
costs will also decrease.
For pro forma information concerning the expected sale of power plants, see
Exhibit 99 to this Report on Form 10-K.
Both ACE's and DPL's mortgage indentures require that the electric generat-
ing plants being divested be released from the liens of the respective mort-
gages. These assets may be released with a combination of cash, bondable prop-
erty additions and credits representing previously issued and retired first
mortgage bonds. Both ACE and DPL have sufficient bondable property additions
and retired first mortgage bonds to release such assets at fair values.
OPERATING REVENUES
Electric Revenues
The table below shows the amounts of electric revenues earned which are sub-
ject to price regulation (Regulated) and which are not subject to price regu-
lation (Non-regulated). "Regulated electric revenues" include revenues for de-
livery (transmission and distribution) service and electricity supply service
within DPL's and ACE's service areas. DPL's default service and ACE's BGS are
subject to price regulation during the transition to retail competition.
"Non-regulated electric revenues" result primarily from electricity trading
activities, bulk sales of electricity including sales of output from
deregulated electric generating plants, and competitive retail sales. Conectiv
actively participates in the wholesale energy markets to support wholesale
utility and competitive retail marketing activities. Energy market
participation results in exposure to commodity market risk when, at times, net
open energy commodity positions are created or allowed to continue. To the
extent that Conectiv has net open positions, controls are in place that are
intended to keep risk exposures within certain management approved risk
tolerance levels.
1999 1998 1997
-------- -------- --------
(Dollars in millions)
Regulated electric revenues...................... $2,150.1 $1,918.2 $ 989.5
Non-regulated electric revenues.................. 309.9 285.5 102.6
-------- -------- --------
Total electric revenues.......................... $2,460.0 $2,203.7 $1,092.1
======== ======== ========
II-14
For 1999 compared to 1998, "Regulated electric revenues" increased by $231.9
million, from $1,918.2 million for 1998 to $2,150.1 million for 1999. The
$231.9 million increase was primarily due to a $163.5 million increase for two
additional months of ACE's revenues in the current reporting period, with the
remaining $68.4 million net increase comprised of the following items: (a) an
$81.4 million revenue increase from a 2.8% increase in retail kWh sold (due to
the effects of weather and a 1.2% increase in the number of customers) and
higher billings of certain services related to the electricity delivery busi-
ness, (b) a $27.6 million decrease from retail rate decreases, primarily due
to the New Jersey and Delaware 1999 rate decreases for electric utility indus-
try restructuring, and (c) a $14.6 million increase in interchange/resale rev-
enues primarily from revenues for transmission network usage and system con-
gestion. The effect on consolidated electric revenues of customers choosing an
alternative electricity supplier due to implementation of electric utility in-
dustry restructuring did not have a material effect on total electric revenues
in 1999.
"Non-regulated electric revenues" increased by $24.4 million in 1999, from
$285.5 million for 1998 to $309.9 million for 1999. The $24.4 million increase
was mainly due to higher bulk sales of electricity, including sales to compet-
itive retail aggregators, partially offset by lower electricity trading vol-
umes. Higher competitive retail electricity sales in Pennsylvania and revenues
from ACE's deregulated electric generating units also contributed to the in-
crease.
For 1998 compared to 1997, "Regulated electric revenues" increased by $928.7
million, from $989.5 million for 1997 to $1,918.2 million for 1998. The $928.7
million increase was primarily due to an $863.6 million increase from the ten
months of ACE's "Regulated electric revenues" included in consolidated 1998
revenues due to the Merger. The remaining $65.1 million increase was mainly
due to higher DPL interchange delivery revenues which did not significantly
impact operating income due to low gross margins. Additional DPL "Regulated
electric revenues" due to a 2.5% kWh sales increase were offset by the impact
of the Merger-related customer rate decrease ($10.7 million for DPL) and lower
average rates for the energy-portion of revenues ($15.3 million). Prior to
electric utility industry restructuring, the energy portion of revenues gener-
ally did not affect operating income, as discussed under "Energy Supply Costs"
in Note 1 to the Consolidated Financial Statements. DPL's 2.5% kWh sales in-
crease was primarily due to favorable economic conditions and 1.6% customer
growth.
"Non-regulated electric revenues" increased by $182.9 million in 1998, from
$102.6 million for 1997 to $285.5 million for 1998 mainly due to higher elec-
tricity trading volumes by DPL.
In December 1999, a new customer billing system was installed to accommodate
the unbundled utility bills required by electric utility industry restructur-
ing. As is the case with any complex billing system changeover, errors have
occurred, which Conectiv is in the process of resolving. On March 19, 2000,
the DPSC initiated a proceeding in which billing system and related customer
service issues are to be reviewed. Although billing system implementation
problems may potentially affect future revenues and cash flows, management
currently does not expect such problems to materially affect Conectiv's re-
sults of operations or financial position.
Gas Revenues
DPL earns gas revenues from on-system sales which generally are subject to
price regulation, off-system trading and sales of natural gas which are not
subject to price regulation, and from the transportation of gas for customers.
The table below shows the amounts of gas revenues earned which are subject to
price regulation (Regulated) and which are not subject to price regulation
(Non-regulated).
1999 1998 1997
------- ------- -------
(Dollars in millions)
Regulated gas revenues.............................. $ 117.2 $ 106.7 $ 117.2
Non-regulated gas revenues.......................... 699.0 428.4 86.9
------- ------- -------
Total gas revenues.................................. $ 816.2 $ 535.1 $ 204.1
======= ======= =======
II-15
The primary factor affecting fluctuations in "Regulated gas revenues" is
winter weather's impact on residential customers' gas usage levels in heating
their homes. Mild winter weather in early 1998 resulted in less cubic feet of
gas sold to residential customers and lower revenues than in 1999 or in 1997.
As a percent of gross revenues, the gross margin earned from "Non-regulated
gas revenues" in excess of related purchased gas costs is much lower than the
gross margin earned from "Regulated gas revenues," since rates charged to reg-
ulated gas customers include amounts for recovery of the cost of gas delivery
systems and services. "Non-regulated gas revenues" increased by $270.6 million
in 1999 and by $341.5 million in 1998 primarily due to higher volumes of natu-
ral gas traded.
Other Services Revenues
Other service revenues were comprised of the following:
1999 1998 1997
------- ------- -------
(Dollars in millions)
Fuel oil and gasoline............................... $ 201.4 $ 140.6 $ --
HVAC................................................ 134.9 94.9 64.9
Telecommunications.................................. 36.2 10.6 1.7
Thermal systems..................................... 26.1 22.0 --
Operation of power plants........................... 32.8 26.0 23.5
Solutions*.......................................... 23.4 11.8 --
Other............................................... 13.9 26.9 29.1
------- ------- -------
Total............................................... $ 468.7 $ 332.8 $ 119.2
======= ======= =======
- --------
* Custom energy-related products and services
As shown above, "Other Services Revenues" increased by $135.9 million in
1999, from $332.8 million in 1998 to $468.7 million in 1999. The $135.9 mil-
lion increase was primarily due to an additional three months of revenues from
a business acquired by Conectiv in March 1998 which distributes fuel oil and
gasoline, additional acquisitions of HVAC service businesses, and expansion of
Conectiv's telecommunications and Solutions businesses. In 1998, "Other Serv-
ices Revenues" increased by $213.6 million mainly due to the acquisition of a
fuel oil and gasoline distributor, additional acquisitions of HVAC businesses,
revenues from the district heating and cooling business of Conectiv Thermal
Systems, Inc., and start-up of Conectiv's telecommunications and Solutions
businesses.
As shown above, telecommunications revenues from Conectiv Communications,
Inc. (CCI) grew by $25.6 million in 1999 and $8.9 million in 1998. Among other
services, CCI offers customers local and long-distance phone service, a re-
gional calling plan, and a plan for calls within the United States. CCI had
sold about 75,000 access line equivalents as of December 31, 1999 in compari-
son to 32,000 access line equivalents as of December 31, 1998. CCI sold fewer
access lines in 1999 than originally planned due to longer than expected cus-
tomer provisioning intervals (the period from signing up a new customer to the
start of service) and lower than anticipated customer credit quality. In its
efforts to reduce provisioning intervals and increase customer satisfaction,
during the third quarter of 1999, CCI engaged in extensive negotiations with
Bell Atlantic regarding the terms and conditions for interconnection of the
CCI and Bell Atlantic networks and CCI's access to elements of Bell Atlantic's
network as required by federal law. In January 2000, CCI and Bell Atlantic
reached agreement on the terms of new interconnection agreements, which will
apply throughout Bell Atlantic's region and will continue in effect until
early 2002. These agreements will be subject to regulatory approval in each
state.
In June 1999, CCI purchased an Internet service provider which offers dedi-
cated and dial-up Internet service, consulting, data security, and web servic-
es. This acquisition combined with CCI's DSL (digital subscriber line--a high
speed Internet connection) service, enables CCI to provide end-to-end Internet
service.
II-16
During the fourth quarter of 1999, Conectiv announced the appointment of a
30-year veteran of the telecommunications industry as the new president of
CCI.
As discussed under "Earnings Impact" within the "Electric Utility Industry
Restructuring" section of the MD&A, on March 22, 2000, Conectiv announced
plans to find a strategic partner in the telecommunications business and in-
crease focus on business markets and Internet related data services. Conectiv
also announced plans to sell its HVAC and thermal energy businesses.
OPERATING EXPENSES
Electric Fuel and Purchased Power
Electric fuel and purchased power increased $76.5 million in 1999 mainly due
to $50.3 million of expenses associated with the additional two months of
ACE's operations in the current period. The remaining $26.2 million increase
resulted primarily from higher average energy costs per kWh, reflecting addi-
tional costs for the prolonged periods of high peak demands during the summer
of 1999. Lower energy expenses recorded pursuant to regulated energy adjust-
ment clauses (discussed under "Energy Supply Costs" in Note 1 to the Consoli-
dated Financial Statements) mitigated the increase.
Electric fuel and purchased power increased $459.2 million in 1998. Inclu-
sion of ACE's operations in the consolidated financial statements beginning
March 1, 1998 accounted for $254.8 million of the increase, and the remaining
increase was due to more energy supplied for greater volumes of electricity
sold off-system and within DPL's service territory.
Gas Purchased
Primarily due to larger volumes of gas purchased for resale off-system, gas
purchased increased $268.6 million in 1999 and $333.4 million in 1998.
Other Services' Cost of Sales
Other services' cost of sales increased by $111.6 million in 1999 and $178.1
million in 1998 principally due to increased volumes of fuel oil and gasoline
sold and higher volumes of HVAC services provided.
Purchased Electric Capacity
In 1999, purchased electric capacity increased $33.8 million due to $28.0
million for the two additional months of ACE's operations in 1999 and higher
capacity requirements associated with energy supplied within and outside of
DPL's and ACE's regulated service territories. Purchased electric capacity
costs increased $154.2 million in 1998 primarily due to ACE's purchased elec-
tric capacity costs which are recovered through regulated customer rates.
Special Charges
As discussed in Note 5 to the Consolidated Financial Statements, special
charges of $105.6 million before taxes ($71.6 million after taxes) were re-
corded in the third quarter of 1999 as a result of (a) a decline in the esti-
mated residual values of assets leased through leveraged lease arrangements
($43.7 million before taxes, or $26.7 million after taxes), (b) costs for 160
employee separations (80 of which have occurred) expected within the next year
($10.9 million before taxes, or $6.5 million after taxes), (c) a write-down of
the goodwill associated with HVAC businesses ($35.6 million before taxes, or
$29.1 million after taxes) and (d) additional costs related to the Merger, im-
pairments of certain other assets, and other items ($15.4 million before tax-
es, or $9.3 million after taxes). The special charges decreased 1999 earnings
per Conectiv common share by $0.75 and earnings per Conectiv Class A common
share by $0.30.
Conectiv's operating results for 1998 include special charges of $27.7 mil-
lion before taxes ($16.8 million after taxes, or $0.18 per Conectiv common
share) for the cost of DPL employee separations associated with the Merger-re-
lated workforce reduction and other Merger-related costs. The 1998 employee
separation, relocation, and other Merger-related costs for Atlantic and its
former subsidiaries were capitalized as costs of the Merger.
II-17
Operation and Maintenance Expenses
After excluding the $35.5 million of operation and maintenance expenses at-
tributed to the two additional months of ACE's operations in 1999, operation
and maintenance expenses increased by $67.0 million in 1999. This increase was
attributed to $28.2 million of increased costs associated with operating and
expanding Conectiv's telecommunications business, a $23.9 million increase for
the electric delivery business including higher customer care expenses, and a
$14.9 million increase largely due to higher electric power plant expenses.
Operation and maintenance expenses increased by $200.6 million in 1998, from
$331.8 million in 1997 to $532.4 million in 1998. The increase was primarily
due to $191.0 million of operation and maintenance expenses of the former At-
lantic-owned companies included in consolidated operating results for 1998 as
a result of the Merger. The remaining $9.6 million increase was due to a $54.9
million increase for expansion of telecommunication, HVAC, and other nonutil-
ity businesses, substantially offset by lower utility operating expenses.
Utility operating expenses decreased in 1998 due to fewer employees and the
absence of the re-start activities at the Salem nuclear power plant in 1997.
Depreciation and Amortization
After excluding the two additional months of operating results of ACE and
other former Atlantic-owned businesses in 1999, depreciation and amortization
expense increased $10.8 million in 1999. This increase was primarily due to
depreciation of new computer networks and other shared infrastructure assets,
as well as increased depreciation for non-regulated businesses due to expan-
sion of the telecommunications and HVAC businesses. Depreciation and amortiza-
tion expense increased in 1998 mainly due to the ten months of 1998 operating
results of the former Atlantic-owned companies consolidated as a result of the
Merger. Also, $6.2 million of goodwill from the Merger was amortized in 1998,
which contributed to the increase.
Taxes Other Than Income Taxes
The $13.7 million increase in taxes other than income taxes for 1999 was
principally due to higher revenues and inclusion of the two additional months
of operating results of ACE and other former Atlantic-owned businesses in
1999. Taxes other than income taxes increased in 1998 mainly due to the ten
months of 1998 operating results for the former Atlantic-owned companies con-
solidated as a result of the Merger.
OTHER INCOME
Other income increased $34.2 million in 1999 due to the following items: (a)
a $42.1 million ($24.9 million after-taxes or $0.27 per share of common stock)
increase from 1999 equity in earnings of the Enertech venture capital fund;
(b) a $17.7 million ($10.6 million after-taxes or $0.11 per share of common
stock) decrease due to the 1998 equity in earnings of a nonutility generation
joint venture; and (c) a $9.8 million increase due to the 1998 write-off of a
non-utility investment, 1999 interest income related to a successful tax ap-
peal, two additional months of ACE's operating results in 1999, and implemen-
tation of mark-to-market accounting for energy trading activities in January
1999. Due to the nature of Enertech's investments, which include Internet
service companies, its earnings may be volatile from period to period.
Other income for 1997 includes a $22.9 million pre-tax gain ($13.7 million
after-taxes or $0.22 per common share) on the sale of the Pine Grove landfill
and related waste-hauling operations.
FINANCING COSTS
Financing costs reflected in the Consolidated Statements of Income include
interest charges, allowance for funds used during construction (AFUDC), and
preferred stock dividend requirements of subsidiaries.
After excluding the financing costs from the two additional months of oper-
ating results of ACE and other former Atlantic-owned businesses included in
1999, financing costs increased $21.2 million in 1999 due to
II-18
approximately $12.6 million of interest expense from debt financing for the
Offer, a $2.5 million gain in 1998 on the redemption of preferred stock, and a
$6.1 million net increase in interest expense mainly from financing nonutility
businesses.
After excluding increases attributed to the operating results of ACE and
former Atlantic-owned nonutility subsidiaries for 1998, financing costs in-
creased $7.0 million in 1998 mainly due to financing requirements associated
with investments in new nonutility businesses.
INCOME TAXES
The effective income tax rate on "Income Before Income Taxes and Extraordi-
nary Item" increased in 1999 primarily due to the write-off of goodwill (as
discussed in Note 5 to the Consolidated Financial Statements), which is only
partly deductible for income tax purposes, and higher state income tax ex-
penses. See Note 3 to the Consolidated Financial Statements for a reconcilia-
tion of the amount computed by multiplying "income before income taxes and ex-
traordinary item" by the federal statutory rate to income tax expense on oper-
ations.
NEW ACCOUNTING PRONOUNCEMENTS
In June 1999, the Financial Accounting Standards Board (FASB) issued SFAS
No. 137, "Accounting for Derivative Instruments and Hedging Activities--Defer-
ral of the Effective Date of FASB Statement No. 133," which delays the re-
quired implementation date for SFAS No. 133, "Accounting for Derivative In-
struments and Hedging Activities," until all fiscal quarters of all fiscal
years beginning after June 15, 2000. Reporting entities may elect to adopt
SFAS No. 133 prior to the required implementation date. SFAS No. 133 estab-
lishes accounting and reporting standards for derivative instruments and for
hedging activities. Conectiv has not yet adopted SFAS No. 133 and currently
cannot determine the effect that SFAS No. 133 will have on its financial
statements.
YEAR 2000
Conectiv experienced no material operational problems, loss of revenues or
impact on customers in any of its businesses and is not aware of any material
claims made or to be made by or against Conectiv or any of its subsidiaries as
a result of the Year 2000 issue around either the rollover from 1999 to 2000
or the Year 2000 Leap Year issue on February 29, 2000.
The Year 2000 issue was 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 have been unable to
interpret dates during and beyond the year 1999, which could have caused a
system failure or other computer errors, leading to disruption of operations.
A project team, originally started in 1996 by ACE, managed Conectiv's response
to this situation. A Conectiv corporate officer, reporting directly to the
Chief Executive Officer, coordinated all Year 2000 activities. Conectiv met
substantial challenges in identifying and correcting the computer and embedded
systems critical to generating and delivering power, delivering natural gas
and providing other services to customers.
The project team used a phased approach to managing its activities. The
first phase was inventory and assessment of all systems, equipment, and
processes. Each identified item was given a criticality rating of high, medium
or low. Those items rated as high or medium were then subject to the second
phase of the project. The second phase--determining and implementing correc-
tive action for the identified systems, equipment and processes--concluded
with a test of the unit being remediated. The third phase involved system
testing and compliance certification.
Overall, Conectiv's Year 2000 Project covered 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 were es-
sential for continued operations and customer response across Conectiv's sev-
eral businesses;
II-19
these were regarded as "mission critical." The Year 2000 Project team focused
on these 21 systems, with work on the other systems continuing based on their
relative importance to Conectiv's businesses.
At the time of the change from 1999 to 2000, 100% of all inventory and as-
sessment, corrective action/unit testing and system testing/compliance work
was complete on the mission critical systems. For the balance of the high and
medium criticality systems, 99% of this work was complete.
Additionally, Conectiv developed and tested contingency plans in the event
that Year 2000 outages occurred, which they did not. Contingency plans were in
place for all mission critical systems and were coordinated into a detailed
overall Year 2000 restoration plan under the direction of a senior-level engi-
neering and operations manager. Contingency plans were also developed for non-
mission critical systems. The Year 2000 plans built on Conectiv's existing ex-
pertise in service restorations. Conectiv also coordinated these efforts with
state and local emergency management agencies. Conectiv followed this approach
for both the change from 1999 to 2000 and for the Leap Year issue.
Further, Conectiv participated in two industry-wide drills sponsored by the
North American Electric Reliability Council ("NERC") and conducted its own in-
ternal drills. All of these drills were exercises only and did not result in
service interruptions.
Distribution of electricity is dependent on the overall reliability of the
electric grid. ACE and DPL cooperated with NERC and the PJM Interconnection in
Year 2000 remediation, contingency planning and restoration planning efforts.
As requested by NERC, ACE and DPL filed their Year 2000 Readiness Statement
with NERC stating that as of June 30, 1999, 96% of work on mission critical
systems had been completed. The remaining 4% of work constituted three excep-
tions to full readiness status and were reported to NERC in the regular
monthly filing made on June 30, 1999. On the basis of Conectiv's filings, NERC
designated Conectiv as "Ready with Limited Exceptions." NERC regarded excep-
tions as "limited" only if they did "not pose a measurable risk to reliable
electric operations into the Year 2000." All three exceptions were completed
prior to the change from 1999 to 2000.
Conectiv also contacted vendors and service providers to review their Year
2000 efforts. Many aspects of Conectiv's businesses are dependent on third
parties. For example, fuel suppliers must be able to provide coal or gas for
DPL or ACE to generate electricity.
Conectiv incurred approximately $16 million in costs for the Year 2000 Proj-
ect through year-end 1999. Management anticipates approximately $1 million to
$2 million in 2000 expenses, including those already incurred for the period
around the change from 1999 to 2000. Project costs do not include significant
expenditures covering new systems, such as Conectiv's SAP business, financial
and human resources management systems, an energy control system, and a cus-
tomer information system. While these new systems effectively remediated Year
2000 problems in the systems they replaced, Conectiv is not reporting the ex-
penditures on these systems in its costs for the Year 2000 Project, because
the new systems were installed principally for other reasons. The total cost
of these other projects over several years exceeds $87 million.
During July 1999, President Clinton signed the Year 2000 litigation reform
bill, known as the "Y2K Act." The Y2K Act provides some new partial liability
and damages protections to defendants in Year 2000 failure-related cases. It
also establishes new litigation procedures that plaintiffs and defendants must
follow. In general, the Y2K Act provides a pre-litigation notice period, pro-
portionate liability among defendants in Year 2000 cases, a requirement that
plaintiffs mitigate damages from Year 2000-related failures, and federal court
jurisdiction for Year 2000 claims. The law covers many types of civil actions
that allege harm or injury related to an actual or potential Year 2000-related
failure, or a claim or defense arising or related to such a failure. The Y2K
Act does not, however, cover civil actions for personal injury or wrongful
death or most actions brought by a government entity acting in a regulatory,
supervisory or enforcement capacity. The law governs actions brought after
January 1, 1999 for a Year 2000-related failure occurring before January 1,
2003. Although the Y2K Act will not afford
II-20
Conectiv complete protection from Year 2000-related claims, it should help
limit any liability related to any Year 2000-related failures. Conectiv cannot
predict the extent to which such liability will be limited by the Y2K Act.
Even though the critical dates occurred with no material operational prob-
lems, loss of revenues or impact on customers in any of its businesses,
Conectiv will not with certainty be able to determine whether there may be
Year 2000-related claims against Conectiv for some time. Conectiv does not be-
lieve at this time that there are any material Year 2000-related claims that
it will make against vendors or suppliers but this evaluation is on-going.
LIQUIDITY AND CAPITAL RESOURCES
General
Conectiv's primary sources of capital are internally generated funds (net
cash provided by operating activities less common dividends) and external
financings. Additionally, restructuring the electric utility industry has cre-
ated new opportunities for raising capital. As discussed under "Deregulated
Generation and Power Plant Sales," Conectiv plans to sell electric generating
units with 2,588.5 MW of capacity in 2000 for approximately $820 million, be-
fore certain adjustments and selling expenses. As discussed under "Stranded
Cost Recovery and Securitization," capital is also expected to be raised
through the securitization of ACE's stranded costs, subsequent to ACE's appli-
cation to the NJBPU for approval of such securitization. Capital requirements
generally include construction expenditures for the electric and gas delivery
businesses, construction expenditures for electric generating units, expansion
of new businesses such as telecommunications and HVAC, and repayment of debt
and equity securities and capital lease obligations.
Cash Flows From Operating Activities
In 1999, the $310.2 million of net cash provided by operating activities was
reduced by the net $146.3 million net cash outflow from (a) a $228.5 million
payment by ACE (included in "Recoverable stranded costs" on the December 31,
1999 balance sheet) to terminate a contract for purchasing electricity from a
NUG in which other Conectiv subsidiaries have a 50% interest, and (b) an $82.2
million distribution related to the contract termination which was received by
the Conectiv subsidiaries with an ownership interest in the NUG. The distribu-
tion was primarily the result of a gain realized by the NUG from the contract
termination; Conectiv's subsidiaries' $70.8 million share of the NUG's gain
was deferred and is classified as "Deferred gain on termination of purchased
energy contract" on the December 31, 1999 balance sheet. Excluding the $146.3
million reduction in 1999 net cash provided by operating activities due to
termination of the NUG contract, operating activities provided a net cash in-
flow of $456.5 million in 1999, or an $84.2 million increase in comparison to
the $372.3 million of net cash provided by operating activities in 1998. This
increase was primarily due to $45 million of cash distributions received from
Enertech in 1999 and two additional months of ACE's operations included in the
consolidated 1999 financial statements. Net cash inflows from 1998 operating
activities increased by $155.3 million in comparison to 1997 mainly due to
cash flow provided by ACE's operations (from March 1998 to December 1998) as a
result of the Merger, partly offset by more cash used by the operations of
Conectiv's new businesses.
After removing the $146.3 million net use of cash for the 1999 NUG contract
termination and subtracting common dividend payments from operating activi-
ties' net cash inflows, internally generated funds were $321.3 million in
1999, $218.2 million in 1998, and $123.2 million in 1997. Internally generated
funds provided 100%, 97%, and 79% of the cash required for capital expendi-
tures in 1999, 1998, and 1997, respectively.
As of December 31, 1999, Conectiv had taxes receivable of $15.7 million due
to an expected current tax benefit from the deferred NUG contract buyout pay-
ment. The items included in the special and extraordinary charges to earnings
generally were not currently deductible for income tax purposes, but instead
resulted in a deferred tax benefit.
II-21
The $46.4 million current liability for deferred energy supply costs as of
December 31, 1999 is for ACE's electricity supply business, which will de-
crease to the extent there are any under-recoveries of BGS and certain other
costs. ACE's customers rates are to be adjusted for the deferred balance which
remains as of July 31, 2003.
The liabilities accrued for "Above-market purchased energy contracts and
other electric restructuring liabilities" resulted from the extraordinary
charge to earnings discussed in Note 6 to the Consolidated Financial State-
ments and did not affect cash flows in 1999.
Cash Flows From Investing Activities
The amount of cash used for business acquisitions (net of cash acquired) was
$17.1 million in 1999, $2.6 million in 1998, and $32.0 million in 1997. In
1999, business acquisitions were primarily for HVAC businesses, and also in-
cluded CCI's purchase of an Internet service company. In 1998, business acqui-
sition expenditures were net of $34.5 million of cash acquired in the Merger.
The 1998 nonutility businesses acquired by Conectiv included HVAC businesses,
a fuel oil distributor, and a gas marketer. Business acquisition expenditures
in 1997 resulted primarily from the purchase of HVAC businesses and direct
Merger costs.
Capital expenditures in 1999 were $320.4 million, a $95.6 million increase
from 1998. The $95.6 million increase in capital expenditures was primarily
due to construction of a new customer service center, higher expenditures for
computer networks, customer service systems, and other shared infrastructure
assets, and expansion of CCI's telecommunications system. In 1998, capital ex-
penditures increased to $224.8 million from $156.8 million in 1997 mainly due
to ACE's utility capital expenditures from March 1998 to December 1998.
"Investments in partnerships" of $23.6 million in 1999 and $28.6 million in
1998 were primarily due to Conectiv Thermal Systems, Inc.'s share of funding
for construction of the "Venetian" project in Las Vegas, Nevada, and invest-
ments in Enertech.
Cash Flows From Financing Activities
The $27.5 million balance of dividends payable as of December 31, 1999 in
comparison to the $47.7 million balance as of December 31, 1998, primarily re-
flects lower dividends declared per share of common stock ($0.22 compared to
$0.385) and decreases of 12.8 million and 0.8 million in the number of shares
outstanding of common stock and Class A common stock, respectively, due to the
Offer.
Common dividend payments were $135.1 million in 1999, $154.1 million in
1998, and $93.8 million in 1997. The decrease in common dividends paid in 1999
was due to lower common dividends declared per share of common stock ($1.045
in 1999 compared to $1.54 in 1998) and fewer shares outstanding of common
stock and Class A common stock due to the Offer. Common dividend payments in-
creased in 1998 due to common stock issued to Atlantic stockholders in con-
junction with the Merger.
Under the Public Utility Holding Company Act of 1935, as amended, Conectiv
may not pay dividends on the shares of common stock and Class A common stock
from an accumulated deficit or paid-in-capital without SEC approval. As of De-
cember 31, 1999, Conectiv had an accumulated deficit of $36.5 million. In Jan-
uary 2000, the SEC approved payment of the dividends declared by Conectiv on
its common stock and Class A common stock in December 1999. Conectiv expects
to have retained earnings sufficient to offset dividends declared on shares of
common stock and Class A common stock beginning in the third quarter of 2000,
when the sale of the electric generating units discussed in Note 13 to the
Consolidated Financial Statements is expected to be completed. There can be no
assurances, however, that the sales of the electric generating units will be
completed, or that any gain will be realized from such sales of the electric
generating units. In any event, Conectiv expects to receive the necessary SEC
approvals during 2000 for the quarterly payment of dividends on shares of its
common stock and Class A common stock.
II-22
For the three-year period including 1997 to 1999, the net financing result-
ing from issuances of securities and purchases/redemptions of securities is
summarized below:
Common Preferred Long-term
Stock Stock Debt*
------- --------- ---------
(Millions of Dollars)
Issuances....................................... $ 17.9 $ 25.0 $ 711.0
Purchases & Redemptions......................... (410.9) (33.8) (363.6)
------- ------ -------
Net............................................. $(393.0) $ (8.8) $ 347.4
======= ====== =======
- --------
* Includes $33.33 million of variable rate demand bonds issued in 1999, and
$1.8 million of variable rate demand bonds redeemed in 1997.
As shown in the above table, during 1997 to 1999, common stock and preferred
stock financing activities used capital in the amounts of $393.0 million and
$8.8 million, respectively, and long-term debt financing activities provided
$347.4 million of capital. In addition, net short-term debt financing activi-
ties provided $383.8 million of capital during 1997 to 1999.
Most of the common stock financing activity during the three year period re-
sulted from a $361.4 million use of cash for the Offer in June of 1999, which
reduced the number of shares of common stock and Class A common stock out-
standing by 12.8 million and 0.8 million, respectively. Conectiv also pur-
chased 2.2 million shares of its common stock for $42.7 million under a buy
back program in 1998 and 1999. On January 19, 2000, Conectiv announced that
its Board of Directors approved the open market purchase of up to an addi-
tional 5 million shares of common stock.
In 1998, $25 million of 7 3/8% preferred stock was issued through a subsidi-
ary and $33.8 million (average dividend rate of 5.5%) of preferred stock of
subsidiaries was purchased. A gain of $2.5 million was realized on the pur-
chase of preferred stock of subsidiaries in 1998 and is reflected in the 1998
Consolidated Statement of Income as a reduction of preferred dividends.
Long-term debt issued during 1997 to 1999 amounted to $677.7 million, which
included the $228.5 million bank loan for interim financing of ACE's December
1999 NUG termination payment, $250 million of 6.73% Medium Term Notes issued
in May 1999 in connection with the Offer, and $199.2 million of 6.6% to 7.72%
Medium Term Notes issued during 1997 and 1998. Redemptions and purchases of
long-term debt during 1997 to 1999 amounted to $361.8 million, which included
$158.2 million in 1998 for the nonutility revolving credit facilities of At-
lantic and its former subsidiaries, $91.0 million in 1998 and 1999 of Medium
Term Notes with a 7.0% average interest rate, $43.9 million in 1997 and 1999
of First Mortgage Bonds with a 6.6% average interest rate, and $68.7 million
during 1997 to 1999 of other debt with an average interest rate of 7.4%.
During 1997 to 1999, short-term debt financing provided a net $383.8 million
source of funds. Conectiv had $579.7 million of short-term debt outstanding as
of December 31, 1999, an increase of $203.6 million from the $376.1 million
balance as of December 31, 1998. Short-term debt outstanding increased in 1999
primarily due to financing part of the common stock purchased pursuant to the
Offer and funding the expansion of CCI's telecommunications business. In 1998,
short-term debt was issued to refinance $158.2 million of nonutility revolving
credit facilities of Atlantic and its former subsidiaries, and to finance non-
utility business expansions and acquisitions. On a consolidated basis,
Conectiv had $1.05 billion in short-term credit lines as of December 31, 1999,
of which $273 million was available for borrowing.
Conectiv's capital structure including short-term debt and current maturi-
ties of long-term debt, expressed as a percentage of total capitalization, is
shown below as of December 31, 1999, and December 31, 1998.
December 31, December 31,
1999 1998
------------ ------------
Common stockholders' equity...................... 26.2% 41.4%
Preferred stock of subsidiaries.................. 6.6% 6.4%
Long-term debt and variable rate demand bonds.... 52.7% 42.0%
Short-term debt and current maturities of long-
term debt....................................... 14.5% 10.2%
II-23
Common stockholders' equity reflects a decrease as a percent of total capi-
talization, and long-term debt and short-term debt reflect an increase as a
percent of total capitalization, due to the special and extraordinary charges
recorded in 1999 and financing the purchase of common stock pursuant to the
Offer by issuing long-term debt and short-term debt. Long-term debt as a per-
cent of total capitalization reflects an additional increase due to financing
the $228.5 million NUG termination contract payment.
On December 14, 1999, the SEC approved Conectiv's request regarding the fol-
lowing financing matters: (a) The authorized short-term debt borrowing capac-
ity of Conectiv (the holding company) and DPL was increased from a total of
$800 million to a total of $1.3 billion and (b) Conectiv was authorized to is-
sue securities as long as consolidated common equity as a percent of total
capitalization (common equity ratio) is 20% or higher. Conectiv also requested
SEC approval for the following financing matters: (a) The issuance of up to
$500 million of additional long-term debt by Conectiv (the holding company),
which would bring the total amount of authorized Conectiv long-term debt to $1
billion, of which $250 million has been issued. Proceeds from the additional
long-term debt would be used to pay down short term debt; and (b) The authori-
zation to use proceeds from the issuance of securities for investments in a
Conectiv subsidiary that will own contractual rights for non-utility, combus-
tion turbine generating facilities. The SEC has currently "reserved jurisdic-
tion" over these requests, which requires additional information to be filed
by Conectiv prior to any SEC authorization.
On September 28, 1999, the parties to the agreements for Conectiv's $800
million short-term credit facilities agreed to an amendment permitting a ratio
of total indebtedness to total capitalization of 70% through December 31,
2000. As of December 31, 1999, the ratio of total indebtedness to total capi-
talization computed in accordance with the terms of the credit agreements,
which allow for an adjustment to increase common equity by the amount of the
extraordinary item, was 63.5%.
Forecasted Capital Requirements
Management expects capital requirements, excluding securities redemptions,
to range from approximately $375 million to $400 million for 2000. These capi-
tal requirements are primarily for the expansion of Conectiv's mid-merit gen-
eration strategy (including about $130 million for the combined cycle units),
transmission and distribution improvements, telecommunications, and other
businesses. Beyond 2000, Conectiv's commitments for capital expenditures in-
clude approximately $460 million for the 1,100 MW of capacity expected to be
installed during 2001-2003 for the combined cycle units. Capital requirements
beyond 2000 are also expected to include approximately $125 million to $150
million per year for capital expenditures related to DPL's and ACE's delivery
businesses. The forecasted amounts are subject to change due to changes in
business plans, construction scheduling, permitting, and other factors.
Scheduled maturities of long-term debt over the next five years are as fol-
lows: 2000--$48.9 million; 2001--$100.8 million; 2002--$370.6 million; 2003--
$212.8 million; 2004--$154.7 million. These amounts include $57.1 million in
2001 and $171.4 million in 2002 for repayment of $228.5 million borrowed in
December 1999 to finance ACE's NUG contract termination payment, which is ex-
pected to be refinanced by issuing bonds securitized by ACE's stranded cost
recovery. Capital requirements for the redemption of securities also include
$11.5 million in 2001, $11.5 million in 2002, and $1.0 million in 2003 for
sinking fund requirements of ACE's preferred stock.
Management expects to fund Conectiv's future capital requirements from in-
ternally generated funds, external financings (including securitization of
stranded costs), and proceeds from the sales of the electric generating units.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The following discussion contains "forward looking statements." These pro-
jected results have been prepared based upon certain assumptions considered
reasonable given the information currently available to Conectiv. Neverthe-
less, because of the inherent unpredictability of interest rates, equity mar-
ket prices, and energy commodity prices as well as other factors, actual re-
sults could differ materially from those projected in
II-24
such forward-looking information. For a description of Conectiv's significant
accounting policies associated with these activities see Notes 1 and 11 to the
Consolidated Financial Statements.
Interest Rate Risk
Conectiv is subject to the risk of fluctuating interest rates in the normal
course of business. Conectiv manages interest rates through the use of fixed
and, to a lesser extent, variable rate debt. As of December 31, 1999, a hypo-
thetical 10% change in interest rates would result in a $4.3 million change in
interest costs and earnings before taxes related to short-term and variable
rate debt.
Equity Price Risk
ACE and DPL maintain trust funds, as required by the Nuclear Regulatory Com-
mission, to fund certain costs of nuclear decommissioning (See Note 14 to the
Consolidated Financial Statements). These funds are invested primarily in do-
mestic and international equity securities, fixed-rate, fixed income securi-
ties, and cash and cash equivalents. By maintaining a portfolio that includes
long-term equity investments, ACE and DPL are maximizing the returns to be
utilized to fund nuclear decommissioning costs. However, the equity securities
included in ACE's and DPL's portfolios are exposed to price fluctuations in
equity markets, and the fixed-rate, fixed income securities are exposed to
changes in interest rates. ACE and DPL actively monitor their portfolios by
benchmarking the performance of their investments against certain indexes and
by maintaining, and periodically reviewing, established target asset alloca-
tion percentages of the assets in their trusts. Because the accounting for nu-
clear decommissioning recognizes that costs are recovered through electric
rates, fluctuations in equity prices and interest rates do not affect the
earnings of ACE and DPL.
Commodity Price Risk
Conectiv is exposed to the impact of market fluctuations in the price and
transportation costs of natural gas, electricity, and petroleum products.
Conectiv engages in commodity hedging activities to minimize the risk of mar-
ket fluctuations associated with the purchase and sale of energy commodities
(natural gas, petroleum and electricity). Some hedging activities are con-
ducted using energy derivatives (futures, option, and swaps). The remainder of
Conectiv's hedging activity is conducted by backing physical transactions with
offsetting physical positions. The hedging objectives include the assurance of
stable and known minimum cash flows and the fixing of favorable prices and
margins when they become available. Conectiv also engages in energy commodity
trading and arbitrage activities, which expose Conectiv to commodity market
risk when, at times, Conectiv creates net open energy commodity positions or
allows net open positions to continue. To the extent that Conectiv has net
open positions, controls are in place that are intended to keep risk exposures
within management-approved risk tolerance levels.
Conectiv uses a value-at-risk model to assess the market risk of its elec-
tricity, gas, and petroleum commodity activities. The model includes fixed
price sales commitments, physical forward contracts, and commodity derivative
instruments. Value at risk represents the potential gain or loss on instru-
ments or portfolios due to changes in market factors, for a specified time pe-
riod and confidence level. Conectiv estimates value-at-risk across its power,
gas, and petroleum commodity business using a delta-normal variance/covariance
model with a 95 percent confidence level and assuming a five-day holding peri-
od. At December 31, 1999, Conectiv's calculated value at risk with respect to
its commodity price exposure was approximately $4.0 million including genera-
tion activities and $0.8 million excluding generation activities. At December
31, 1998, Conectiv's calculated value at risk with respect to its commodity
price exposure was approximately $0.7 million excluding generation activities;
and there was no value at risk for generation activities.
II-25
CONECTIV
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
REPORT OF MANAGEMENT
Management is responsible for the information and representations contained
in Conectiv's consolidated financial statements. Our consolidated financial
statements have been prepared in conformity with accounting principles gener-
ally accepted in the United States, based upon currently available facts and
circumstances and management's best estimates and judgments of the expected
effects of events and transactions.
Conectiv 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 auditing standards generally accepted in the
United States which include a review of selected internal controls to deter-
mine the nature, timing, and extent of audit tests to be applied.
The 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 of Directors 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, President Senior Vice President and Chief Finan-
and Chief Executive Officer cial Officer
February 7, 2000
II-26
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors
Conectiv
Wilmington, Delaware
In our opinion, the accompanying consolidated financial statements listed in
the accompanying index appearing under Item 14(a)(1) on page IV-I present
fairly, in all material respects, the financial position of Conectiv and sub-
sidiary companies at December 31, 1999 and 1998, and the results of their op-
erations and their cash flows for each of the three years in the period ended
December 31, 1999 in conformity with accounting principles generally accepted
in the United States. In addition, in our opinion, the financial statement
schedules listed in the accompanying index appearing under Item 14(a)(2) on
pages IV-I to IV-6 present fairly, in all material respects, the information
set forth therein when read in conjunction with the related consolidated fi-
nancial statements. These financial statements and financial statement sched-
ules are the responsibility of Conectiv's management; our responsibility is to
express an opinion on these financial statements and financial statement
schedules based on our audits. We conducted our audits of these statements in
accordance with auditing standards generally accepted in the United States,
which require that we plan and perform the audit to obtain reasonable assur-
ance 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 princi-
ples used and significant estimates made by management, and evaluating the
overall financial statement presentation. We believe that our audits provide a
reasonable basis for the opinion expressed above.
/s/ PricewaterhouseCoopers LLP
PricewaterhouseCoopers LLP
Philadelphia, Pennsylvania
February 7, 2000
II-27
CONECTIV
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31,
----------------------------------
1999 1998 1997
---------- ---------- ----------
(Dollars in Thousands,
Except Per Share Amounts)
OPERATING REVENUES
Electric.................................. $2,459,970 $2,203,748 $1,092,144
Gas....................................... 816,245 535,082 204,057
Other services............................ 468,682 332,776 119,166
---------- ---------- ----------
3,744,897 3,071,606 1,415,367
---------- ---------- ----------
OPERATING EXPENSES
Electric fuel and purchased power......... 952,348 875,816 416,640
Gas purchased............................. 754,990 486,411 153,027
Other services' cost of sales............. 374,918 263,319 85,192
Purchased electric capacity............... 216,444 182,676 28,470
Special charges........................... 105,648 27,704 --
Operation and maintenance................. 634,966 532,419 331,770
Depreciation and amortization............. 271,348 241,420 136,340
Taxes other than income taxes............. 88,646 74,926 37,634
---------- ---------- ----------
3,399,308 2,684,691 1,189,073
---------- ---------- ----------
OPERATING INCOME........................... 345,589 386,915 226,294
---------- ---------- ----------
OTHER INCOME
Allowance for equity funds used during
construction............................. 2,461 2,609 1,337
Other income.............................. 68,420 34,251 36,322
---------- ---------- ----------
70,881 36,860 37,659
---------- ---------- ----------
INTEREST EXPENSE
Interest charges.......................... 182,821 153,644 83,398
Allowance for borrowed funds used during
construction and capitalized interest.... (5,639) (4,213) (2,996)
---------- ---------- ----------
177,182 149,431 80,402
---------- ---------- ----------
PREFERRED STOCK DIVIDEND REQUIREMENTS OF
SUBSIDIARIES.............................. 19,894 15,326 10,178
---------- ---------- ----------
INCOME BEFORE INCOME TAXES AND
EXTRAORDINARY ITEM........................ 219,394 259,018 173,373
INCOME TAXES, EXCLUDING INCOME TAXES
APPLICABLE TO
EXTRAORDINARY ITEM........................ 105,816 105,817 72,155
---------- ---------- ----------
INCOME BEFORE EXTRAORDINARY ITEM........... 113,578 153,201 101,218
EXTRAORDINARY ITEM (NET OF INCOME TAXES OF
$188,254)................................. (311,718) -- --
---------- ---------- ----------
NET INCOME (LOSS).......................... $ (198,140) $ 153,201 $ 101,218
========== ========== ==========
EARNINGS (LOSS) APPLICABLE TO:
Common stock
Income before extraordinary item.......... $ 106,639 $ 141,292 $ 101,218
Extraordinary item, net of income taxes... (295,161) -- --
---------- ---------- ----------
Total.................................... $ (188,522) $ 141,292 $ 101,218
========== ========== ==========
Class A common stock
Income before extraordinary item.......... $ 6,939 $ 11,909 --
Extraordinary item, net of income taxes... (16,557) -- --
---------- ---------- ----------
Total.................................... $ (9,618) $ 11,909 --
========== ========== ==========
AVERAGE SHARES OUTSTANDING (000)
Common stock.............................. 93,320 94,338 61,122
Class A common stock...................... 6,110 6,561 --
EARNINGS (LOSS) PER AVERAGE SHARE, BASIC
AND DILUTED
Common stock
Before extraordinary item................. $ 1.14 $ 1.50 $ 1.66
Extraordinary item........................ (3.16) -- --
---------- ---------- ----------
Total.................................... $ (2.02) $ 1.50 $ 1.66
========== ========== ==========
Class A common stock
Before extraordinary item................. $ 1.14 $ 1.82 --
Extraordinary item........................ (2.71) -- --
---------- ---------- ----------
Total.................................... $ (1.57) $ 1.82 --
========== ========== ==========
DIVIDENDS DECLARED PER SHARE
Common stock.............................. $ 1.045 $ 1.54 $ 1.54
Class A common stock...................... $ 3.20 $ 3.20 --
See accompanying Notes to Consolidated Financial Statements.
II-28
CONECTIV
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
-------------------------------
1999 1998 1997
--------- --------- ---------
(Dollars in Thousands)
Cash Flows From Operating Activities
Net income (loss)............................ $(198,140) $ 153,201 $ 101,218
Adjustments to reconcile net income (loss)
to net cash provided by operating
activities
Deferred recoverable purchased power
contract termination payment............... (228,500) -- --
Distribution from partnership in excess of
recognized earnings........................ 70,849 -- --
Extraordinary item, net of income taxes..... 311,718 -- --
Special charges............................. 105,648 27,704 --
Depreciation and amortization............... 294,902 261,457 142,734
Allowance for equity funds used during
construction............................... (2,461) (2,609) (1,337)
Investment tax credit adjustments, net...... (5,094) (4,002) (2,560)
Deferred income taxes, net.................. 44,752 4,620 7,169
Net change in:
Accounts receivable........................ (92,952) (118,578) (53,911)
Inventories................................ (14,753) (9,691) 4,763
Prepaid New Jersey sales and excise taxes.. 22,216 (20,078) --
Accounts payable........................... 61,561 107,005 16,394
Other current assets & liabilities(1)...... (57,366) 10,296 43,708
Gain on sale of landfill and waste hauling
company.................................... -- -- (22,896)
Other, net.................................. (2,211) (37,016) (18,250)
--------- --------- ---------
Net cash provided by operating activities..... 310,169 372,309 217,032
--------- --------- ---------
Cash Flows From Investing Activities
Acquisition of businesses, net of cash
acquired.................................... (17,138) (2,590) (31,994)
Capital expenditures......................... (320,395) (224,831) (156,808)
Investments in partnerships.................. (23,570) (28,594) (1,800)
Sale of landfill and waste hauling company... -- -- 33,405
Deposits to nuclear decommissioning trust
funds....................................... (5,880) (10,676) (4,240)
Decrease in bond proceeds held in trust
funds....................................... 12,449 -- 2,002
Decrease in investment in leveraged leases... 8,242 8,027 1,640
Other, net................................... 1,826 (688) 1,022
--------- --------- ---------
Net cash used by investing activities......... (344,466) (259,352) (156,773)
--------- --------- ---------
Cash Flows From Financing Activities
Common dividends paid........................ (135,134) (154,101) (93,811)
Common stock issued.......................... 68 63 17,807
Common stock redeemed........................ (390,397) (13,232) (7,323)
Preferred securities issued.................. -- 25,000 --
Preferred securities redeemed................ -- (33,769) --
Long-term debt issued........................ 478,500 33,000 166,200
Long-term debt redeemed...................... (133,218) (200,078) (28,540)
Variable rate demand bonds issued............ 33,330 -- --
Variable rate demand bonds redeemed.......... -- -- (1,800)
Principal portion of capital lease
payments.................................... (23,554) (20,037) (6,813)
Net change in short-term debt................ 203,627 282,889 (102,671)
Cost of issuances and refinancings........... (8,570) (2,147) (4,502)
--------- --------- ---------
Net cash provided (used) by financing
activities................................... 24,652 (82,412) (61,453)
--------- --------- ---------
Net change in cash and cash equivalents....... (9,645) 30,545 (1,194)
Beginning of year cash and cash equivalents... 65,884 35,339 36,533
--------- --------- ---------
End of year cash and cash equivalents......... $ 56,239 $ 65,884 $ 35,339
========= ========= =========
- --------
(1) Other than debt and deferred income taxes classified as current.
See accompanying Notes to Consolidated Financial Statements.
II-29
CONECTIV
CONSOLIDATED BALANCE SHEETS
As of December 31,
-----------------------
1999 1998
----------- -----------
(Dollars in Thousands)
ASSETS
Current Assets
Cash and cash equivalents............................ $ 56,239 $ 65,884
Accounts receivable, net of allowances of $11,564 and
$4,743, respectively................................ 544,463 455,088
Inventories, at average cost
Fuel (coal, oil and gas)........................... 65,360 71,701
Materials and supplies............................. 58,177 73,047
Prepaid New Jersey sales and excise taxes............ -- 20,078
Deferred energy supply costs......................... 8,612 --
Other prepayments.................................... 20,295 17,278
Taxes receivable..................................... 15,674 --
Deferred income taxes, net........................... 25,175 20,796
----------- -----------
793,995 723,872
----------- -----------
Investments
Investment in leveraged leases....................... 72,161 122,256
Funds held by trustee................................ 173,247 174,509
Other investments.................................... 100,764 90,913
----------- -----------
346,172 387,678
----------- -----------
Property, Plant and Equipment
Electric generation.................................. 1,571,556 2,917,011
Electric transmission and distribution............... 2,633,375 2,539,436
Gas transmission and distribution.................... 265,708 249,383
Other electric and gas facilities.................... 405,303 363,263
Telecommunications, thermal systems, and other
property, plant, and equipment...................... 238,229 202,415
----------- -----------
5,114,171 6,271,508
Less: Accumulated depreciation....................... 2,097,529 2,522,878
----------- -----------
Net plant in service................................. 3,016,642 3,748,630
Construction work-in-progress........................ 199,390 265,593
Leased nuclear fuel, at amortized cost............... 55,983 63,328
Goodwill, net........................................ 369,468 402,836
----------- -----------
3,641,483 4,480,387
----------- -----------
Deferred Charges and Other Assets
Recoverable stranded costs........................... 1,030,049 --
Deferred recoverable income taxes.................... 93,853 184,434
Unrecovered purchased power costs.................... 28,923 48,274
Unrecovered New Jersey state excise tax.............. 22,567 35,594
Deferred debt refinancing costs...................... 21,113 44,223
Deferred other postretirement benefit costs.......... 32,479 34,978
Prepaid pension costs................................ 35,005 16,130
Unamortized debt expense............................. 28,045 27,375
License fees......................................... 23,331 24,706
Other................................................ 41,447 80,023
----------- -----------
1,356,812 495,737
----------- -----------
Total Assets........................................... $ 6,138,462 $ 6,087,674
=========== ===========
See accompanying Notes to Consolidated Financial Statements.
II-30
CONECTIV
CONSOLIDATED BALANCE SHEETS
As of December 31,
------------------------
1999 1998
----------- -----------
(Dollars in Thousands)
CAPITALIZATION AND LIABILITIES
Current Liabilities
Short-term debt.................................... $ 579,688 $ 376,061
Long-term debt due within one year................. 48,937 80,822
Variable rate demand bonds......................... 158,430 125,100
Accounts payable................................... 307,764 240,775
Taxes accrued...................................... -- 41,299
Interest accrued................................... 41,137 37,346
Dividends payable.................................. 27,545 47,743
Deferred energy supply costs....................... 46,375 15,990
Current capital lease obligation................... 28,715 28,314
Above-market purchased energy contracts and other
electric restructuring liabilities................ 41,101 --
Other.............................................. 91,353 88,341
----------- -----------
1,371,045 1,081,791
----------- -----------
Deferred Credits and Other Liabilities
Other postretirement benefits obligation........... 96,388 102,269
Deferred income taxes, net......................... 730,987 862,179
Deferred investment tax credits.................... 74,431 79,525
Regulatory liability for New Jersey income tax
benefit........................................... 49,262 --
Above-market purchased energy contracts and other
electric restructuring liabilities................ 119,704 --
Deferred gain on termination of purchased energy
contract.......................................... 70,849 --
Long-term capital lease obligation................. 30,395 36,603
Other.............................................. 47,447 50,701
----------- -----------
1,219,463 1,131,277
----------- -----------
Capitalization
Common stock: $0.01 per share par value 150,000,000
shares authorized; shares outstanding--86,173,169
in 1999, and 100,516,768 in 1998.................. 863 1,007
Class A common stock: $0.01 per share par value;
10,000,000 shares authorized; shares outstanding--
5,742,315 in 1999, 6,560,612 in 1998.............. 57 66
Additional paid-in capital--common stock........... 1,085,060 1,462,675
Additional paid-in capital--Class A common stock... 93,738 107,095
Retained earnings (Accumulated deficit)............ (36,472) 276,939
----------- -----------
1,143,246 1,847,782
Treasury shares, at cost:
167,514 shares in 1999; 185,030 shares in 1998... (3,446) (3,797)
Unearned compensation.............................. (1,627) (824)
----------- -----------
Total common stockholders' equity................ 1,138,173 1,843,161
Preferred stock of subsidiaries:
Not subject to mandatory redemption.............. 95,933 95,933
Subject to mandatory redemption.................. 188,950 188,950
Long-term debt..................................... 2,124,898 1,746,562
----------- -----------
3,547,954 3,874,606
----------- -----------
Commitments and Contingencies (Notes 21, 22 and 24)
----------- -----------
Total Capitalization and Liabilities................. $ 6,138,462 $ 6,087,674
=========== ===========
See accompanying Notes to Consolidated Financial Statements.
II-31
CONECTIV
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDERS' EQUITY
Additional
Par Value Paid-in Capital
------------------ -------------------- Retained
Common Class A Class A Earnings Unearned
Shares Common Common Common Common (Accumulated Treasury Compen-
Outstanding Stock(1) Stock Stock Stock Deficit) Stock sation Total
----------- --------- ------- ---------- -------- ------------ -------- -------- ----------
(Dollars in Thousands)
Balance as of December
31, 1996.............. 60,682,719 $ 136,765 $ -- $ 508,300 $ -- $ 293,604 $ (2,138) $(1,618) $ 934,913
Net income............. 101,218 101,218
Cash dividends declared
Common stock ($1.54
per share)........... (94,065) (94,065)
Issuance of common
stock
DRIP(2)............... 965,655 2,173 15,485 17,658
LTIP(3)............... 76,553 172 1,288 (1,360) 100
Other issuance........ 2,741 6 47 53
Reacquired common
stock................. (517,406) 230 (9,549) 2,162 (7,157)
Amortization of
unearned
compensation.......... 1,462 314 1,776
----------- --------- ---- ---------- -------- --------- -------- ------- ----------
Balance as of December
31, 1997.............. 61,210,262 139,116 -- 526,812 -- 300,757 (11,687) (502) 954,496
Net income............. 153,201 153,201
Cash dividends declared
Common stock ($1.54
per share)........... (155,302) (155,302)
Class A common stock
($3.20 per share).... (20,994) (20,994)
Issuance of common
stock
Business
acquisitions......... 488,473 9,090 9,090
LTIP and CICP(4)...... 78,381 7 (427) 1,613 (1,130) 63
Merger(5)(6).......... 45,924,284 (138,111) 66 946,804 107,095 915,854
Reacquired common
stock................. (598,862) (5) (10,947) (2,280) (13,232)
Redemption of preferred
stock................. 136 (723) (587)
Incentive compensation
Expense recognition... 309 263 572
Forfeited common
shares............... (25,158) (12) (533) 545 --
----------- --------- ---- ---------- -------- --------- -------- ------- ----------
Balance as of December
31, 1998(6)........... 107,077,380 1,007 66 1,462,675 107,095 276,939 (3,797) (824) 1,843,161
Net loss............... (198,140) (198,140)
Cash dividends declared
Common stock ($1.045
per share)........... (96,241) (96,241)
Class A common stock
($3.20 per share).... (19,030) (19,030)
Issuance of common
stock
CICP(7)............... 95,676 1 1,475 375 (1,783) 68
Reacquired common stock
Tender Offer(8)....... (13,586,512) (128) (9) (347,879) (13,357) (361,373)
Common stock
purchased............ (1,671,060) (17) (31,356) (24) (31,397)
Incentive compensation
expense............... 145 980 1,125
----------- --------- ---- ---------- -------- --------- -------- ------- ----------
Balance as of December
31, 1999(9)........... 91,915,484 $ 863 $ 57 $1,085,060 $ 93,738 $ (36,472) $ (3,446) $(1,627) $1,138,173
=========== ========= ==== ========== ======== ========= ======== ======= ==========
- -------
(1) There are 150,000,000 and 10,000,000 shares of Conectiv common stock and
Conectiv Class A common stock, respectively, which are authorized. The
common stock had a par value of $2.25 per share prior to the Merger and
$0.01 per share after the Merger on March 1, 1998.
(2) Dividend Reinvestment and Common Share Purchase Plan (DRIP)--As of Decem-
ber 31, 1999, 2,881,269 shares of Conectiv common stock remained available
under Conectiv's registration statement filed with the Securities and Ex-
change Commission for issuance of shares of Conectiv common stock through
Conectiv's dividend reinvestment plan.
(3) Long-term Incentive Plan (LTIP) of Delmarva Power & Light Company (DPL)--
includes restricted common shares granted and stock options exercised.
(4) Includes restricted common shares granted and stock options exercised un-
der DPL's LTIP and the Conectiv Incentive Compensation Plan (CICP)
(5) Conectiv common stock and Conectiv Class A common stock were issued to
former Atlantic common stockholders, and Conectiv common stock was issued
to former DPL common stockholders, pursuant to the Merger discussed in
Note 4 to the Consolidated Financial Statements.
(6) Includes 6,560,612 shares of Conectiv Class A common stock; all other
shares are Conectiv common stock.
(7) Includes restricted Conectiv common shares granted and stock options exer-
cised under the CICP.
(8) Includes 12,768,215 shares of Conectiv common stock and 818,297 shares of
Conectiv Class A common stock, and costs associated with the tender offer
discussed in Note 16 to the Consolidated Financial Statements.
(9) Includes 86,173,169 shares of Conectiv common stock and 5,742,315 shares
of Conectiv Class A common stock.
See accompanying Notes to Consolidated Financial Statements.
II-32
CONECTIV
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1. SIGNIFICANT ACCOUNTING POLICIES
Nature of Business
As discussed in Note 4 to the Consolidated Financial Statements, effective
March 1, 1998, Delmarva Power & Light Company (DPL) and Atlantic Energy, Inc.
(Atlantic) consummated a series of merger transactions (the Merger) by which
DPL and Atlantic City Electric Company (ACE) became wholly-owned subsidiaries
of Conectiv. Conectiv is a registered holding company under the Public Utility
Holding Company Act of 1935 (PUHCA).
As used in this document, references to Conectiv may mean the activities of
one or more subsidiary companies.
DPL and ACE are public utilities which supply and deliver electricity to
their customers. As discussed below, DPL also supplies and delivers natural
gas to its customers. DPL and ACE supply electricity to customers with power
purchased from other suppliers and electricity generated by their power
plants. The transition to market pricing and terms of service for supplying
electricity to customers in the regulated service areas of DPL and ACE began
in 1999. DPL and ACE also supply electricity in markets which are not subject
to price regulation. DPL and ACE deliver electricity within their service
areas to approximately 955,000 customers through their respective transmission
and distribution systems and also supply electricity to most of their elec-
tricity delivery customers. DPL's regulated electric service area is located
on the Delmarva Peninsula (Delaware and portions of Maryland and Virginia) and
ACE's regulated service area is located in the southern one-third of New Jer-
sey. On a combined basis, DPL's and ACE's regulated electric service areas en-
compass about 8,700 square miles and have a population of approximately 2.0
million.
DPL provides regulated gas service (supply and/or delivery) to approximately
107,300 customers located in a service territory that covers about 275 square
miles with a population of approximately 0.5 million in northern Delaware. DPL
also sells gas off-system and in markets which are not subject to price regu-
lation.
In December 1999, DPL and ACE filed an application with the Federal Energy
Regulatory Commission (FERC) for approval of the transfer to other Conectiv
subsidiaries of the electric generating plants remaining after the sale of
certain electric generating plants (as discussed in Note 13 to the Consoli-
dated Financial Statements). Through this planned divestiture, the principal
businesses of DPL and ACE would be the transmission and distribution of ener-
gy, as envisioned by legislation enacted during 1999 which restructured the
electric utility industry in the service areas of DPL and ACE. The production
of electricity would be conducted by the subsidiaries receiving the trans-
ferred electric generating units. See Note 9 to the Consolidated Financial
Statements for information concerning restructuring of the electric utility
industry.
"Other services," which are not subject to price regulation, are provided
primarily by Conectiv's nonutility subsidiaries and, to a lesser extent, by
DPL and ACE. The principal businesses of Conectiv's nonutility subsidiaries'
which are included in revenues from "Other services" are as follows: heating,
ventilation, and air conditioning (HVAC) construction and services; telecommu-
nications, including local and long-distance phone services; construction and
operation of thermal energy systems; power plant operations; leveraged leases;
and sales of petroleum products. Revenues from marketing non-regulated elec-
tricity and gas are included in "Electric" revenues and "Gas" revenues, re-
spectively. Earnings from investments in energy-related technology growth com-
panies which are accounted for on the equity method are included in "Other in-
come."
Regulation of Utility Operations
Certain aspects of Conectiv's utility businesses are subject to regulation
by the Delaware and Maryland Public Service Commissions (DPSC and MPSC, re-
spectively), the New Jersey Board of Public Utilities
II-33
(NJBPU), the Virginia State Corporation Commission (VSCC), and the FERC. Re-
tail gas sales are subject to regulation by the DPSC. Excluding off-system
sales not subject to price regulation, the percentage of electric and gas
utility operating revenues regulated by each regulatory commission for the
year ended December 31, 1999, was as follows: NJBPU, 46.3%; DPSC, 36.3%; MPSC,
13.2%; VSCC, 1.3%; and FERC, 2.9%.
The electric delivery businesses of DPL and ACE and the retail gas business
of DPL are subject to the requirements of Statement of Financial Accounting
Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of Regu-
lation" (SFAS No. 71). As discussed below, prior to the third quarter of 1999,
the electricity supply businesses of DPL and ACE were subject to the require-
ments of SFAS No. 71. Regulatory commissions occasionally provide for future
recovery from customers of current period expenses. When this happens, the ex-
penses are deferred as regulatory assets and subsequently recognized in the
Consolidated Statements of Income during the period the expenses are recovered
from customers. Similarly, regulatory liabilities may also be created due to
the economic impact of regulatory commissions' actions.
In the latter half of 1999, as discussed in Note 9 to the Consolidated Fi-
nancial Statements, the NJBPU issued a Summary Order to ACE, and the DPSC and
MPSC issued orders to DPL, concerning restructuring the electricity supply
businesses of ACE and DPL, respectively. These orders were issued pursuant to
the New Jersey, Delaware, and Maryland electric restructuring legislation en-
acted earlier in 1999. Based on these orders, ACE and DPL determined that the
requirements of SFAS No. 71 no longer applied to their electricity supply
businesses in the third quarter of 1999. As a result, ACE and DPL discontinued
applying SFAS No. 71 to their electricity supply businesses and applied the
requirements of SFAS No. 101, "Regulated Enterprises--Accounting for the Dis-
continuation of Application of FASB Statement No. 71" (SFAS No. 101) and
Emerging Issues Task Force (EITF) Issue No. 97-4, "Deregulation of the Pricing
of Electricity--Issues Related to the Application of FASB Statements No. 71
and No. 101" (EITF 97-4). For information concerning the extraordinary charge
to earnings which resulted from applying the requirements of SFAS No. 101 and
EITF 97-4, refer to Note 6 to the Consolidated Financial Statements.
Refer to Note 15 to the Consolidated Financial Statements for information
about regulatory assets arising from the financial effects of rate regulation.
Financial Statement Presentation
The consolidated financial statements include the accounts of Conectiv and
its majority-owned subsidiaries. All significant intercompany accounts and
transactions are eliminated in consolidation.
Ownership interests of 20% or more in entities not controlled by Conectiv
are accounted for on the equity method of accounting. Investments in entities
accounted for on the equity method are included in "Other investments" on the
Consolidated Balance Sheets. Earnings from equity method investees are in-
cluded in "Other income" in the Consolidated Statements of Income. Ownership
interests of less than 20% in other entities are accounted for on the cost
method of accounting.
Certain reclassifications of prior period data have been made to conform
with the current presentation.
Use of Estimates
The preparation of financial statements in conformity with generally ac-
cepted accounting principles 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 re-
porting period. Actual results could differ from those estimates and assump-
tions.
II-34
Revenue Recognition
DPL and ACE accrue revenues for electric and gas service rendered from the
last meter reading to the month-end which has not yet been billed to custom-
ers. Similarly, revenues from "Other services" are recognized when services
are performed or products are delivered.
Energy Supply Costs
Under "energy adjustment clauses" prior to deregulation of electricity sup-
ply, regulated electric customer rates were subject to adjustment for differ-
ences between energy costs incurred in supplying regulated customers and
amounts billed to customers for recovery of such costs. As a result, the
amount recognized in the Consolidated Statements of Income for energy costs
incurred in supplying electricity to regulated customers was adjusted to match
the amounts billed to ACE's and DPL's regulated customers. An asset was re-
corded for under-collections from customers and a liability was recorded for
over-collections from customers. Effective August 1, 1999 for ACE, and October
1, 1999 for DPL, the accounting for energy costs associated with supplying
electricity changed as discussed below.
The DPSC and MPSC electric restructuring orders discussed in Note 9 to the
Consolidated Financial Statements did not provide a rate adjustment mechanism
for any under-recovery or over-recovery of energy costs after the start of
customer choice (October 1, 1999 in Delaware and July 1, 2000 in Maryland).
Thus, effective October 1, 1999 for DPL's Delaware electricity supply business
(July 1, 2000 for DPL's Maryland electricity supply business), the practice of
deferring the difference between the amount collected in revenues for energy
costs and the amount of actual energy costs incurred was ended. As a result,
differences between DPL's energy revenues and expenses will affect earnings
and earnings volatility may increase.
As discussed under "Shopping Credits and Basic Generation Service" in Note 9
to the Consolidated Financial Statements, the electric restructuring order is-
sued by the NJBPU to ACE provides for recovery through customer rates of en-
ergy and other costs of supplying customers who do not choose an alternative
electricity supplier. Effective August 1, 1999, in recognition of these cost-
based, rate-recovery mechanisms, ACE adjusts revenues from customer billings
to the amount of the related costs incurred, including an allowed return on
electric generating plants.
The amount recognized in the Consolidated Statement of Income for the cost
of gas purchased to supply DPL's regulated gas customers is adjusted to cus-
tomer billings for such costs since customer rates are periodically adjusted
to reflect amounts actually paid by DPL for purchased gas.
Nuclear Fuel
The ownership interests of DPL and ACE in nuclear fuel at the Peach Bottom
Atomic Power Station (Peach Bottom) and the Salem Nuclear Generating Station
(Salem), and ACE's ownership interest in nuclear fuel at the Hope Creek Nu-
clear Generating Station (Hope Creek), are financed through contracts ac-
counted 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.
Energy Trading and Risk Management Activities
In June 1999, the Financial Accounting Standards Board (FASB) issued SFAS
No. 137, "Accounting for Derivative Instruments and Hedging Activities--Defer-
ral of the Effective Date of FASB Statement No. 133," which delays the re-
quired implementation date for SFAS No. 133, "Accounting for Derivative In-
struments and Hedging Activities," until all fiscal quarters of all fiscal
years beginning after June 15, 2000. Reporting entities may elect to adopt
SFAS No. 133 prior to the required implementation date. SFAS No. 133 estab-
lishes accounting and reporting standards for derivative instruments and for
hedging activities. Conectiv has not yet adopted SFAS No. 133 and currently
cannot determine the effect that SFAS No. 133 will have on its financial
statements.
II-35
On January 1, 1999, Conectiv adopted the EITF consensus EITF 98-10, "Ac-
counting for Contracts Involved in Energy Trading and Risk Management Activi-
ties" under which contracts (including derivative financial instruments) en-
tered into in connection with energy trading activities are marked to market,
with gains and losses (unrealized and realized) included in earnings. Imple-
mentation of EITF 98-10 did not have a material impact on net income. In 1997
and 1998 (prior to implementation of EITF 98-10), certain energy trading
transactions were accounted for with "hedge accounting," as discussed below.
Conectiv uses futures, options and swap agreements to hedge firm commitments
or anticipated transactions of energy commodities and also creates net open
energy commodity positions. Under hedge accounting, a derivative, at its in-
ception and on an ongoing basis, is expected to substantially offset adverse
price movements in the firm commitment or anticipated transaction that it is
hedging. Gains and losses related to qualifying hedges are deferred and are
recognized in operating results when the underlying transaction occurs. If,
subsequent to being hedged, underlying transactions are no longer likely to
occur or the hedge is no longer effective, the gains or losses on the related
derivatives are recognized currently in operating results. Gains and losses
from hedges of the cost of energy sold are reflected within the Consolidated
Statements of Income as "Electric fuel and purchased power" or "Gas pur-
chased," as appropriate for the hedged transaction. Gains and losses on hedges
of the selling price of generated electricity are recognized in revenues.
Premiums paid for options are included as current assets in the consolidated
balance sheet until they are exercised or expire. Margin requirements for
futures contracts are also recorded as current assets. Under hedge accounting,
unrealized gains and losses on all futures contracts are deferred on the con-
solidated balance sheet as either current assets or deferred credits.
The cash flows from derivatives are included in the cash flows from opera-
tions section of the cash flow statement.
Depreciation Expense
The annual provision for depreciation on utility property is computed on the
straight-line basis using composite rates by classes of depreciable property.
Accumulated depreciation is charged with the cost of depreciable property re-
tired, including removal costs less salvage and other recoveries. The rela-
tionship of the annual provision for depreciation for financial accounting
purposes to average depreciable property was 3.5% for 1999, 3.8% for 1998, and
3.7% for 1997. Depreciation expense includes a provision for Conectiv's share
of the estimated cost of decommissioning nuclear power plant reactors based on
amounts billed to customers for such costs. Refer to Note 14 to the Consoli-
dated Financial Statements for additional information on nuclear
decommissioning.
Nonutility property is generally depreciated on a straight-line basis over
the useful lives of the assets.
Income Taxes
The consolidated financial statements include two categories of income tax-
es--current and deferred. Current income taxes represent the amounts of tax
expected to be reported on Conectiv's federal and state income tax returns.
Deferred income taxes are discussed below.
Deferred income tax assets and liabilities represent the tax effects of tem-
porary differences between the financial statement and tax bases of existing
assets and liabilities and are measured using presently enacted tax rates. The
portion of Conectiv's deferred tax liability applicable to the utility opera-
tions of DPL and ACE that has not been recovered from utility customers repre-
sents income taxes recoverable in the future and is shown on the Consolidated
Balance Sheets as "Deferred recoverable income taxes." Deferred recoverable
income taxes decreased to $93.9 million as of December 31, 1999, from $184.4
million as of December 31, 1998, primarily due to deregulation of the elec-
tricity supply businesses of DPL and ACE in 1999.
II-36
Deferred income tax expense generally 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 re-
ported on the Consolidated Balance Sheets as "Deferred investment tax cred-
its." These investment tax credits are being amortized to income over the use-
ful lives of the related utility plant. Investment tax credits associated with
leveraged leases are being amortized over the lives of the related leases dur-
ing the periods in which the net investment is positive.
Deferred Debt Refinancing Costs
Prior to the third quarter of 1999, the costs of refinancing debt of the
utility businesses of DPL and ACE were deferred and amortized over the period
during which the costs are recovered in rates, which is generally the life of
the new debt. In the third quarter of 1999, the deferred costs associated with
previously refinanced debt attributed to the electric generation businesses of
DPL and ACE were written-off and charged to earnings, net of anticipated rate
recovery. Any costs incurred in the future for refinancing debt attributed to
the electric generation business for which rate recovery is not provided will
be accounted for in accordance with SFAS No. 4, "Reporting Gains and Losses
from Extinguishment of Debt," which requires such costs to be expensed.
License Fees
License fees represent the unamortized balance of amounts previously paid by
the predecessor to Conectiv Thermal Systems, Inc. (a Conectiv subsidiary) for
the right to operate heating and cooling systems of certain hotel casinos in
Atlantic City, New Jersey, over a 20-year period. These fees are classified as
License Fees on the balance sheet and are being amortized over 20 years.
Interest Expense
The amortization of debt discount, premium, and expense, including deferred
refinancing expenses associated with the regulated electric and gas transmis-
sion and distribution businesses, is included in interest expense.
Utility Plant
As discussed in Note 6 to the Consolidated Financial Statements, utility
plant which became impaired as a result of deregulation of the electric util-
ity industry is stated at fair value. The estimated fair values were based on
amounts included in agreements for the sale of certain electric generating
plants of DPL and ACE, as discussed in Note 13 to the Consolidated Financial
Statements. Utility plant which is not impaired is stated at original cost.
Utility plant is generally subject to a first mortgage lien.
Allowance for Funds Used During Construction
Allowance for Funds Used During Construction (AFUDC) is included in the cost
of regulated transmission and distribution utility plant and represents the
cost of borrowed and equity funds used to finance construction. In the Consol-
idated 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 was capitalized on utility plant construction
at the rates of 8.6% in 1999, 8.8% in 1998, and 7.5% in 1997.
Effective in the third quarter of 1999, the cost of financing the construc-
tion of electric generation plant is capitalized in accordance with SFAS No.
34, "Capitalization of Interest Cost."
II-37
Stock-based Employee Compensation
Refer to Note 16 to the Consolidated Financial Statements for Conectiv's ac-
counting policy on stock-based employee compensation.
Cash Equivalents
In the consolidated financial statements, Conectiv considers highly liquid
marketable securities and debt instruments purchased with a maturity of three
months or less to be cash equivalents.
Goodwill
Conectiv amortizes goodwill arising from business acquisitions over the
shorter of the estimated useful life or 40 years.
Leveraged Leases
Conectiv's investment in leveraged leases includes the aggregate of rentals
receivable (net of principal and interest on nonrecourse indebtedness) and es-
timated residual values of the leased equipment less unearned and deferred in-
come (including investment tax credits). Unearned and deferred income is rec-
ognized at a level rate of return during the periods in which the net invest-
ment is positive. Refer to Note 22 to the Consolidated Financial Statements
for additional information on leveraged leases.
Funds Held By Trustee
Funds held by trustee are stated at fair market value and primarily include
deposits in Conectiv's external nuclear decommissioning trusts and unexpended,
restricted, tax-exempt bond proceeds. Changes in the fair market value of the
trust funds are also reflected in the accrued liability for nuclear
decommissioning which is included in accumulated depreciation.
Earnings Per Share
Earnings per share has been computed in accordance with SFAS No. 128, "Earn-
ings Per Share." Under SFAS No. 128, basic earnings per share are computed
based on earnings applicable to common stock divided by the weighted average
number of common shares outstanding for the period. Diluted earnings per share
are computed based on earnings applicable to common stock divided by the
weighted average number of shares of common stock outstanding during the pe-
riod after giving effect to securities considered to be dilutive common stock
equivalents. The effect of dilutive common stock equivalents was not signifi-
cant, and thus, for 1999, 1998, and 1997, Conectiv's basic and diluted earn-
ings per share were the same amounts.
NOTE 2. SUPPLEMENTAL CASH FLOW INFORMATION
See the Consolidated Statement of Changes in Common Stockholders' Equity and
Note 4 to the Consolidated Financial Statements for information concerning the
issuance of Conectiv common stock and Conectiv Class A common stock in ex-
change for DPL and Atlantic common stock pursuant to the Merger in March 1998.
Cash Paid During the Year
1999 1998 1997
-------- -------- -------
(Dollars in Thousands)
Interest, net of capitalized amounts................. $164,370 $142,503 $73,211
Income taxes, net of refunds......................... $111,667 $107,755 $53,550
II-38
NOTE 3. INCOME TAXES
Conectiv files a consolidated federal income tax return which includes its
wholly-owned subsidiaries. Income taxes are allocated to Conectiv's subsidiar-
ies based upon the taxable income or loss of each subsidiary.
Components of Consolidated Income Tax Expense
1999 1998 1997
--------- -------- -------
(Dollars in Thousands)
Operations
Federal: Current.................................. $ 44,468 $ 80,408 $58,737
Deferred................................. 36,088 7,387 6,589
State: Current.................................. 21,690 24,791 8,810
Deferred................................. 8,664 (2,767) 579
Investment tax credit adjustments, net............ (5,094) (4,002) (2,560)
--------- -------- -------
105,816 105,817 72,155
--------- -------- -------
Extraordinary Item
Federal: Deferred................................. (155,702) -- --
State: Deferred................................. (32,552) -- --
--------- -------- -------
(188,254) -- --
--------- -------- -------
Total Income Tax Expense.......................... $ (82,438) $105,817 $72,155
========= ======== =======
Reconciliation of Effective Income Tax Rate
The amount computed by multiplying "Income before income taxes and extraor-
dinary item" by the federal statutory rate is reconciled below to income tax
expense on operations (which excludes amounts applicable to the extraordinary
item).
1999 1998 1997
-------------- -------------- -------------
Amount Rate Amount Rate Amount Rate
-------- ---- -------- ---- ------- ----
(Dollars in Thousands)
Statutory federal income tax
expense........................... $ 76,788 35% $ 90,656 35% $60,081 35%
Increase (decrease) due to:
State income taxes, net of
federal tax benefit............. 19,730 9 14,316 6 6,102 4
Depreciation..................... 5,915 3 5,047 2 3,569 2
Non-deductible goodwill.......... 9,536 4 2,188 1 -- --
Investment tax credit
amortization.................... (5,094) (2) (4,002) (2) (2,560) (2)
Other, net....................... (1,059) (1) (2,388) (1) 4,963 3
-------- --- -------- --- ------- ---
Total income tax expense for
operations........................ $105,816 48% $105,817 41% $72,155 42%
======== === ======== === ======= ===
II-39
Components of Deferred Income Taxes
The tax effects of temporary differences that give rise to Conectiv's net
deferred tax liability are shown below.
As of December 31,
---------------------
1999 1998
---------- ----------
(Dollars in
Thousands)
Deferred Tax Liabilities
Plant basis differences............................. $ 636,762 $ 692,780
Leveraged leases.................................... 87,669 116,481
Deferred recoverable income taxes................... 46,215 72,448
Termination of purchased energy contract............ 65,487 --
Other............................................... 134,368 132,747
---------- ----------
Total deferred tax liabilities...................... 970,501 1,014,456
---------- ----------
Deferred Tax Assets
Deferred investment tax credits..................... 32,895 36,494
Other............................................... 231,794 136,579
---------- ----------
Total deferred tax assets........................... 264,689 173,073
---------- ----------
Total deferred taxes, net............................. $ 705,812 $ 841,383
========== ==========
Valuation allowances for deferred tax assets were not material as of Decem-
ber 31, 1999 and 1998.
Effective January 1, 1998, New Jersey eliminated the Gross Receipts and
Franchise Tax paid by electric, natural gas and telecommunication public util-
ities. Utilities were subject to the state's corporate business tax beginning
in 1998. In addition, the state's existing sales and use tax was expanded to
include retail sales of electricity and gas. A transitional energy facility
assessment tax (TEFA) is being applied for a limited time to electric and nat-
ural gas utilities and is being phased out over a five-year period which began
January 1, 1999. When fully implemented, this 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.
NOTE 4. MERGER
On March 1, 1998, DPL and ACE became wholly-owned subsidiaries of Conectiv.
Before the Merger, Atlantic owned ACE, an electric utility serving the south-
ern one-third of New Jersey, and nonutility subsidiaries. As a result of the
Merger, Atlantic ceased to exist, 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 accordance with the terms of the Merger, DPL common stockholders received
one share of Conectiv common stock in exchange for each share of DPL common
stock, and Atlantic common stockholders received 0.75 of one share of Conectiv
common stock and 0.125 of one share of Conectiv Class A common stock in ex-
change for each share of Atlantic common stock. Atlantic stockholders and DPL
stockholders received 39,363,672 and 61,832,699 shares of Conectiv common
stock, respectively. Atlantic stockholders received 6,560,612 shares of
Conectiv Class A common stock. See Note 17 to the Consolidated Financial
Statements for information concerning Conectiv Class A common stock and the
apportionment of earnings between Conectiv Class A common stock and Conectiv
common stock.
The Merger was accounted for under the purchase method of accounting, with
DPL as the acquirer. In connection with the Merger, $289.0 million of goodwill
was recorded, which is being amortized over 40 years. The results of opera-
tions for ACE and the formerly Atlantic-owned nonutility subsidiaries from
March 1, 1998 and thereafter are included in the Consolidated Statements of
Income. The amount of goodwill from the Merger
II-40
amortized to expense was $7.1 million, or $0.08 per common share, in 1999, and
$6.2 million, or $0.07 per common share, in 1998.
NOTE 5. SPECIAL CHARGES
Conectiv's operating results for 1999 include "Special charges" of $105.6
million before taxes ($71.6 million after taxes), which were recorded in the
third quarter. The special charges decreased 1999 earnings per Conectiv common
share by $0.75 and earnings per Conectiv Class A common share by $0.30. The
items included in the 1999 special charges are discussed below.
(a) Declines in the estimated residual values of the airplanes and cargo
container-ships leased by certain Conectiv subsidiaries to third par-
ties under leveraged leases resulted in a write-down of the investments
in leveraged leases by $43.7 million before taxes ($26.7 million after
taxes).
(b) Approximately $10.9 million before taxes ($6.5 million after taxes) was
accrued for 160 planned employee separations (80 of which have oc-
curred) expected within the next year in conjunction with a cost reduc-
tion and productivity program.
(c) Lower actual operating cash flows than initially expected when certain
HVAC businesses were acquired caused the net book value of the HVAC
businesses to be impaired, based on SFAS No. 121, "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets To Be Dis-
posed Of" (SFAS No. 121). SFAS No. 121 requires that goodwill associ-
ated with impaired assets purchased in a business combination be elimi-
nated before reducing the carrying amounts of the other long-lived as-
sets of the purchased business. As a result, the goodwill associated
with the HVAC businesses was written-down by $35.6 million before taxes
($29.1 million after taxes).
(d) Charges for additional costs related to the Merger, impairments of cer-
tain other assets, and other items were $15.4 million before taxes
($9.3 million after taxes).
Conectiv's operating results for 1998 include "Special charges" of $27.7
million before taxes ($16.8 million after taxes, or $0.18 per Conectiv common
share) for the cost of DPL employee separations associated with the Merger-re-
lated workforce reduction and other Merger-related costs. The $27.7 million
pre-tax charge includes a net $45.5 million gain from curtailments and settle-
ments of pension and other postretirement benefits. The 1998 employee separa-
tion, relocation, and other Merger-related costs for Atlantic and its former
subsidiaries of $80.8 million before taxes, or $48.3 million after taxes, were
capitalized as costs of the Merger.
NOTE 6. EXTRAORDINARY ITEM
As discussed in Note 1 to the Consolidated Financial Statements, as a result
of electric utility restructuring orders, DPL and ACE discontinued applying
SFAS No. 71 to their electricity supply businesses in the third quarter of
1999 and applied the requirements of SFAS No. 101 and EITF 97-4. Pursuant to
the requirements of SFAS No. 101 and EITF 97-4, DPL and ACE recorded extraor-
dinary charges which, on a consolidated basis, reduced earnings by $311.7 mil-
lion, after $188.3 million of income taxes. The portion of the extraordinary
charge related to impaired assets was determined in accordance with SFAS No.
121. The extraordinary charge primarily resulted from impaired electric gener-
ating plants and certain other assets, uneconomic energy contracts, and other
effects of deregulation requiring loss recognition. The impairment amount for
electric generating plants was determined based on expected proceeds under
agreements for the sale of the electric generating plants, which are discussed
in Note 13 to the Consolidated Financial Statements. The extraordinary charge
was decreased by the regulatory asset established for the amount of stranded
costs expected to be recovered through regulated electricity delivery rates.
As discussed in Note 9 to the Consolidated Financial Statements, ACE's por-
tion of the extraordinary charge was based on the NJBPU's Summary Order and
the NJBPU is to issue a more detailed order at a later date. If the NJBPU's
final detailed order were to differ materially from the Summary Order, then
the extraordinary charge could change.
II-41
The details of the extraordinary charge are shown in the following table.
Consolidated
Items Included in Extraordinary Charge Conectiv DPL ACE
-------------------------------------- ------------ ------- -------
(Dollars in millions)
(a) The net book value of certain electric
generating stations (the nuclear plants and
certain fossil-fuel plants) and other
electric plant-related assets including
inventories were written-down due to
impairment................................. $(915.4) $(253.3) $(662.1)
(b) The net present value of water-supply
capacity from the Merrill Creek Reservoir
in excess of the electric generating
plants' requirements was expensed.......... (45.3) (41.9) (3.4)
(c) The net present value of expected losses
under uneconomic energy contracts,
primarily for the purchase of electricity
and gas at above-market prices, was
expensed................................... (100.3) (99.0) (1.3)
(d) Generation-related regulatory assets and
certain other utility assets impaired from
deregulation were written-off. Also,
various liabilities resulting from
deregulation were recorded................. (252.5) (51.5) (201.0)
(e) Regulatory assets were established for the
amount of stranded costs expected to be
recovered through regulated electricity
delivery rates............................. 813.5 44.3 769.2
------- ------- -------
Total pre-tax extraordinary charge............. (500.0) (401.4) (98.6)
Income tax benefit............................. 188.3 147.8 40.5
------- ------- -------
Total extraordinary charge, net of income
taxes....................................... $(311.7) $(253.6) $ (58.1)
======= ======= =======
NOTE 7. INVESTMENT INCOME
Enertech Capital Partners, L.P.
An indirect Conectiv subsidiary holds a limited partner interest in Enertech
Capital Partners, L.P. (Enertech). Enertech is a venture capital fund that in-
vests in energy-related technology and Internet service companies. Enertech
records its investments at fair value and includes gains and losses on changes
in the fair value of its investments in income in accordance with industry
practice. Conectiv's subsidiary accounts for its investment in Enertech on the
equity method of accounting. Conectiv's equity in earnings of Enertech was
$42.1 million ($24.9 million after-income taxes or $0.27 per common share) in
1999. The pre-tax earnings are reported as "Other income" in the Consolidated
Statement of Income. Conectiv's equity in earnings of Enertech was not signif-
icant in 1998. Due to the nature of Enertech's investments, its earnings may
be volatile from period to period.
The carrying amount of Conectiv's subsidiary's investment in Enertech was
$26.6 million as of December 31, 1999 and $15.9 million as of December 31,
1998. In 1999, Conectiv's subsidiary received $45 million of cash distribu-
tions from Enertech. In 1998, no cash distributions were received.
II-42
Summarized financial information for Enertech (in its entirety) is presented
below for the periods in which Enertech is included in Conectiv's Consolidated
Financial Statements. Conectiv's subsidiary owns a partial interest in
Enertech.
Year Ended December 31,
-----------------------
Income Statement Information 1999 1998
---------------------------- ----------- -----------
(Dollars in Thousands)
Operating Revenues(a)........................... $ 60,272 $ (2,161)
Income (Loss) Before Taxes...................... $ 58,500 $ (3,743)
--------
(a)Includes the net change in investment valuation.
As of December 31,
-----------------------
Balance Sheet Information 1999 1998
------------------------- ----------- -----------
(Dollars in Thousands)
Current assets.................................. $ 6,347 $ 2,251
Noncurrent assets............................... 38,701 18,165
----------- -----------
Total assets.................................... $ 45,048 $ 20,416
=========== ===========
Current liabilities............................. $ 7,006 $ 1,794
Partners' capital............................... 38,042 18,622
----------- -----------
Total capitalization and liabilities............ $ 45,048 $ 20,416
=========== ===========
Pine Grove Landfill
In the fourth quarter of 1997, a subsidiary of DPL sold the Pine Grove Land-
fill and a related waste-hauling company. Pre-tax proceeds received from the
sale were $34.2 million ($33.4 million net of cash sold), resulting in a pre-
tax gain of $22.9 million ($13.7 million after income taxes or $0.22 per com-
mon share).
Other
See Note 8 to the Consolidated Financial Statements for additional informa-
tion concerning investment income.
NOTE 8. SUMMARIZED FINANCIAL INFORMATION OF ENTITIES NOT CONSOLIDATED
Summarized financial information for unconsolidated entities accounted for
on the equity method (excluding Enertech, which is shown in Note 7 to the Con-
solidated Financial Statements) is presented below for the periods the uncon-
solidated entities are included in Conectiv's Consolidated Financial State-
ments. The amounts presented below are primarily attributed to unconsolidated
electric co-generation projects and are for the unconsolidated entities in
their entirety.
Year Ended December 31,
-----------------------
Income Statement Information 1999 1998 1997
---------------------------- ------- ------- -------
(Dollars in Thousands)
Operating Revenues.................................. $98,507 $99,208 $47,196
Income Before Taxes................................. $15,932 $50,077 $14,873
II-43
As of December
31,
-----------------
Balance Sheet Information 1999 1998
------------------------- -------- --------
(Dollars in
Thousands)
Current assets............................................ $ 77,404 $116,144
Noncurrent assets......................................... 225,860 235,176
-------- --------
Total assets.............................................. $303,264 $351,320
======== ========
Current liabilities....................................... $ 17,125 $ 24,195
Noncurrent liabilities.................................... 147,443 197,031
Partners' capital......................................... 138,696 130,094
-------- --------
Total capitalization and liabilities...................... $303,264 $351,320
======== ========
The carrying amount of Conectiv's subsidiaries' investments in these enti-
ties was $60.4 million as of December 31, 1999 and $62.4 million as of Decem-
ber 31, 1998. Conectiv's subsidiaries' equity in earnings of these entities
was $6.4 million in 1999, $22.2 million in 1998, and $9.1 million in 1997.
These amounts are included in "Other Income" in the Consolidated Statements of
Income. Conectiv's subsidiaries received cash distributions from these enti-
ties of $86.4 million in 1999, which includes the $82.2 million distribution
related to the purchased power contract termination discussed in Note 10 to
the Consolidated Financial Statements, and $22.2 million in 1998. In 1997,
distributions from equity method investees were insignificant.
NOTE 9. RATE MATTERS
Electric Utility Industry Restructuring
New Jersey Electric Utility Industry Restructuring
On February 9, 1999, New Jersey enacted the Electric Discount and Energy
Competition Act (the New Jersey Act) which, among other things, provided cus-
tomers of New Jersey electric utilities with a choice of electricity suppliers
beginning August 1, 1999. Pursuant to the New Jersey Act, on July 15, 1999,
the NJBPU issued a Summary Order to ACE concerning stranded costs, unbundled
rates, and other matters related to restructuring. The NJBPU stated that a
more detailed order would be issued at a later date. Management expects the
NJBPU's final order to be issued after appeals related to the NJBPU's final
order on restructuring the electric supply business of Public Service Electric
and Gas Company are resolved. The outcome of these appeals could potentially
affect the NJBPU's final order for ACE. The key provisions of the Summary Or-
der are discussed below.
Rate Decreases
In its Summary Order, the NJBPU directed ACE to implement a five percent ag-
gregate rate reduction effective August 1, 1999. ACE also must implement at
least an additional two percent rate reduction by January 1, 2001. By August
1, 2002, rates must be reduced by ten percent from the rates which were in ef-
fect as of April 30, 1997. Management estimates that the initial rate reduc-
tion effective August 1, 1999, will reduce revenues by approximately $50 mil-
lion (on an annualized basis, assuming fiscal year 1998 sales and revenues).
Since an estimated $25 million of the revenue reduction resulted from the en-
ergy component of ACE's regulated revenues previously exceeding related energy
costs, this portion of the revenue reduction should not affect earnings.
Stranded Cost Recovery and Securitization
The Summary Order provides that ACE may divest its nuclear and fossil fuel
baseload units and transfer the remaining generating units to a nonutility af-
filiated company at net book value. The NJBPU determined that ACE will have
the opportunity to recover 100% of the net stranded costs related to certain
generation units to be divested and the stranded costs associated with power
purchased from nonutility generators (NUGs), subject to
II-44
further NJBPU proceedings. The Summary Order also permits securitization of
stranded costs. Securitization is expected to occur through a special purpose
entity which will issue bonds secured by the right to collect stranded costs
from customers. The Summary Order allows securitization of (a) 100% of the net
stranded costs of certain generation units to be divested, over a period not
to exceed 15 years, and (b) 100% of the costs to effect potential NUG contract
buyouts or buydowns, over a period not to exceed the remaining term of the re-
structured contracts. The Summary Order provides for stranded costs, net of
taxes, to be collected from customers through a transition bond charge over
the securitization term. The Summary Order also provides for customers' rates
to include a separate market transition charge for recovery of the income tax
expense associated with the revenues from stranded cost recovery.
As of December 31, 1999, the balance for ACE's pre-tax recoverable stranded
costs was $988.3 million, which includes the stranded costs estimated and re-
corded as a result of discontinuing the application of SFAS No. 71 (as dis-
cussed in Note 6 to the Consolidated Financial Statements) and the $228.5 mil-
lion payment to terminate a NUG contract (as discussed in Note 10 to the Con-
solidated Financial Statements). ACE's amount of recoverable stranded costs
remains subject to adjustment based on the actual gains and losses realized on
the sale of certain electric generating plants, additional buyouts or buydowns
of NUG contracts, the NJBPU's final restructuring order, and the final amount
determined to be recoverable through customer rates under the New Jersey Act.
Shopping Credits and Basic Generation Service
The Summary Order established minimum initial shopping credits for customers
who choose an alternative electric supplier, from a system average 5.27 cents
per kilowatt-hour (kWh), effective August 1, 1999, to a system average of 5.48
cents per kWh in 2003. These shopping credits include transmission costs and
charges by ACE for Basic Generation Service (BGS) to be provided to retail
customers who do not choose another electricity supplier. ACE is obligated to
provide BGS through July 31, 2002; thereafter, the BGS supplier will be deter-
mined each year based on a competitive bidding process. In accordance with the
Summary Order, ACE will supply the BGS load requirement with power purchased
under its NUG contracts and the output generated by certain units to be di-
vested (prior to divestiture of the units). ACE will purchase power through a
competitive bidding process for any BGS supply requirement greater than the
output from certain generation units to be divested and power purchased from
NUGs.
The Summary Order established the rates charged to ACE's BGS customers for
such service, which include a component for the market-value of power pur-
chased from NUGs. The above-market portion of the cost of NUG power is to be
collected through a non-bypassable Net NUG Charge included in regulated elec-
tricity delivery rates, over the remaining term of the NUG contracts. The
above market portion of the costs of certain of ACE's power plants is being
recovered through a Market Transition Charge, included in regulated electric-
ity delivery rates. The NJBPU's Summary Order also provided that ACE's regula-
tory liability for over-recovered energy supply costs as of July 31, 1999
would be offset by any subsequent under-recoveries of BGS and certain other
costs. Due to under-recoveries of such costs from August 1, 1999 to December
31, 1999, ACE reduced its liability for over-recovered energy supply costs by
$17.2 million and recognized a like amount of revenue. Similarly, any over-re-
coveries will increase the regulatory liability. Customer rates are to be ad-
justed for any deferred balance remaining after the initial four-year transi-
tion period which began August 1, 1999.
Code of Conduct
The NJBPU is presently considering Code of Conduct issues concerning the re-
lationship between regulated and non-regulated activities.
Delaware Electric Utility Industry Restructuring
On March 31, 1999, Delaware enacted the Electric Utility Restructuring Act
of 1999 (the Delaware Act), which provided for a phase-in of retail customer
choice of electricity suppliers from October 1999 to October
II-45
2000, customer rate decreases, and other matters concerning restructuring the
electric utility industry in Delaware. On April 15, 1999, DPL submitted to the
DPSC a compliance plan for implementing the provisions of the Delaware Act in
DPL's Delaware service area. On August 31, 1999, the DPSC issued an order on
DPL's compliance plan. The DPSC's order is discussed below.
Implementation Dates
The DPSC approved implementation dates for retail customer choice of elec-
tric suppliers of October 1, 1999 for customers with a peak monthly load of
1,000 kilowatts (kW) or more; January 15, 2000 for customers with a peak
monthly load of 300 kW or more; and October 1, 2000 for other customers.
Rate Decrease
The DPSC approved DPL's proposed rate structure which provides for a 7.5%
decrease in DPL's Delaware residential electric rates, effective October 1,
1999, with those rates held constant from October 1, 1999 to September 30,
2003. Also, non-residential rates are to be held constant from October 1, 1999
to September 30, 2002. Management estimates that the initial 7.5% residential
rate reduction effective October 1, 1999, will reduce revenues by approxi-
mately $17.5 million (on an annualized basis, assuming fiscal year 1998 sales
and revenues).
Sale of Electric Generating Plants
The Delaware Act permits DPL to sell, transfer, or otherwise divest its
electric generating plants without DPSC approval after October 1, 1999. The
DPSC's order effectively provides that electric rates will remain unchanged as
a result of such divestiture. See Note 13 to the Consolidated Financial State-
ments for related information concerning the expected sales of electric gener-
ating plants.
Stranded Cost Recovery
The rate structure approved by the DPSC also provides for DPL's recovery of
stranded costs, $16 million net of taxes, or $31 million before taxes, through
a Competitive Transition Charge billed to non-residential customers from Octo-
ber 1, 1999 to September 30, 2002.
Shopping Credits
The system-average customer shopping credits, which include the costs of
electricity supply, transmission, and ancillary services, are 4.736 cents per
kWh for the year beginning October 1, 1999, 4.738 cents per kWh for the year
beginning October 1, 2000, and 4.740 cents per kWh for the year beginning Oc-
tober 1, 2001.
Default Service for Electricity Supply
The Delaware Act makes DPL the provider of default service to customers who
do not choose an alternative electricity supplier for a period of 3 or 4 years
(transition period) for non-residential and residential customers, respective-
ly. Thereafter, the DPSC may conduct a bidding process to select the default
supplier for such customers. During the transition period, the energy compo-
nent of customers' rates for default service will be set at DPL's average en-
ergy cost per kWh for the twelve months ended September 30, 1999.
The DPSC order permits customers with demand below 300 kW to choose an al-
ternative electric supplier and to switch back to DPL's default service with-
out any time restrictions or price differential. Customers with demand above
300 kW who choose an alternative supplier and switch back to DPL's default
service must either, at the customer's option, return to DPL's default service
for a minimum of 12 months or pay market prices.
II-46
Code of Conduct
The DPSC ruled that the existing Code of Conduct will remain in place, con-
ditioned upon the requirement that a revised code be proposed and, if neces-
sary, litigated. As requested by the DPSC, DPL filed a new Cost Accounting
Manual and Code of Conduct in November 1999.
Maryland Electric Utility Industry Restructuring
On April 8, 1999, Maryland enacted the Electric Customer Choice and Competi-
tion Act of 1999 (the Maryland Act), which provided for customer choice of
electricity suppliers, customer rate decreases, and other matters concerning
restructuring the electric utility industry in Maryland. On May 5, 1999, DPL
submitted to the MPSC a proposed settlement agreement (subsequently supple-
mented) for implementing the provisions of the Maryland Act in DPL's Maryland
service area. On October 8, 1999 the MPSC issued an order to DPL which ap-
proved the settlement agreement. The key elements of the approved settlement
agreement are discussed below.
Implementation Date
Effective July 1, 2000, all of DPL's Maryland-retail customers will be eli-
gible to select an alternative electricity supplier.
Rate Decrease
The MPSC approved a 7.5% decrease in DPL's Maryland residential electric
rates, effective July 1, 2000, with those rates held constant from July 1,
2000 to June 30, 2004. Also, non-residential rates are to be held constant
from July 1, 2000 to June 30, 2003. Management estimates that the initial 7.5%
residential rate reduction effective July 1, 2000, will reduce revenues by ap-
proximately $12.5 million (on an annualized basis, assuming fiscal year 1998
sales and revenues).
Sale of Electric Generating Plants
The Maryland Act in conjunction with the approved settlement effectively
provide that electric rates will not be changed in the event DPL sells or
transfers generating assets. See Note 13 to the Consolidated Financial State-
ments for related information concerning the expected sales of electric gener-
ating plants.
Stranded Cost Recovery
The MPSC approved DPL's recovery of stranded costs, $8 million net of taxes,
or $14 million before taxes, through a Competitive Transition Charge billed to
non-residential customers from July 1, 2000 to June 30, 2003.
Shopping Credits
The system-average customer shopping credits, which include the costs of
electricity supply, transmission, and ancillary services, are estimated to be
approximately 5.302 cents per kWh for the year beginning July 1, 2000, 5.305
cents per kWh for the year beginning July 1, 2001, and 5.307 cents per kWh for
the year beginning July 1, 2002. These estimated shopping credits will be re-
set so that the energy component is DPL's average energy cost per kWh for the
twelve months ended April 30, 2000.
Default Service for Electricity Supply
DPL is to provide default service to customers who do not choose an alterna-
tive electricity supplier during July 1, 2000 to July 1, 2004 for residential
customers and during July 1, 2000 to July 1, 2003 for non-residential custom-
ers. Subsequent to these default service periods, the MPSC is to determine the
default service supplier. During the initial periods when DPL provides default
service, the energy component of customers' rates will be set at DPL's average
energy cost per kWh for the twelve months ended April 30, 2000.
II-47
Code of Conduct
On July 26, 1999, the MPSC initiated a new review of the generic affiliate
transaction provisions of the Maryland Act. Subsequently, the MPSC conducted
hearings and is expected to issue an order within several months.
Virginia Electric Utility Industry Restructuring
On March 29, 1999, the Governor of Virginia signed the Virginia Electric
Utility Restructuring Act (the Virginia Act). In 1999, revenues from DPL's
Virginia customers comprised about 1.4% of consolidated Conectiv electric rev-
enues earned from regulated electricity sales and deliveries. Significant pro-
visions of the Virginia Act are as follows:
(a) A phase-in of retail electric competition is to start on January 1,
2002.
(b) The rates in effect on January 1, 2001 are to become "capped rates,"
which continue in effect through July 1, 2007, except for adjustments
for changes in fuel costs and state tax rates.
(c) A customer who chooses an alternative electricity supplier would pay
the incumbent utility the capped transmission and distribution rates
and a "wires" charge, representing the difference between the capped
generation rate and projected market prices for electricity.
(d) Just and reasonable net stranded costs are to be recovered through
capped rates and wires charges during the period January 1, 2001
through July 1, 2007.
Pursuant to the requirements of the Virginia Act, DPL filed in January 2000
an application for approval of a plan for functional separation of electric
generation from transmission and distribution by divestiture. The plan in-
volves complete divestiture by the third quarter of 2000 of DPL's generation
facilities, some of which would be sold to unaffiliated parties and the re-
mainder of which are proposed to be transferred to a Conectiv subsidiary. By
the completion of the divestiture, DPL proposes an overall revenue decrease of
2.6% (approximately $0.7 million on an annual basis). DPL also indicated in
its application that it expects to propose starting retail choice on or after
January 1, 2002 for all of its Virginia retail customers, instead of a phase-
in of retail choice.
Merger Rate Decrease
In accordance with the terms included in regulatory commissions orders'
which approved the Merger, ACE and DPL phased-in reductions in electric and
gas 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 de-
ferred other postretirement benefit costs; (2) $9.9 million effective March 1,
1998, and (3) $0.8 million effective January 1, 1999. DPL's total Merger-re-
lated base rate decrease of $13.0 million was phased-in as follows: (1) $11.5
million effective March 1, 1998, (2) $1.1 million effective March 1, 1999, and
(3) $0.4 million effective October 1, 1999.
NOTE 10. TERMINATION OF PURCHASED POWER CONTRACT
On November 10, 1999, the NJBPU issued an Order approving ACE's proposal to
terminate a contract under which ACE purchased energy and 116 megawatts (MW)
of capacity from a NUG partnership (Pedricktown Co-generation Limited Partner-
ship) owned 50% by other Conectiv subsidiaries. The NJBPU Order also provided
that ACE is entitled to recover from customers the contract termination pay-
ment of $228.5 million, together with reasonable and prudently incurred trans-
action costs and interim financing costs as specified therein. The NJBPU Order
also found that the contract termination payment and related transaction costs
are eligible for long-term financing through the issuance of transition bonds
(securitization). On December 28, 1999, ACE paid $228.5 million to terminate
the contract and borrowed funds from a credit facility (discussed in Note 19
to the Consolidated Financial Statements) which ACE arranged to finance the
contract termination payment. The contract termination payment and related
costs are included in "Recoverable Stranded Costs" on the balance sheet as of
II-48
December 31, 1999. ACE's customer rates were reduced by about 1% (approxi-
mately $11 million of revenues on an annualized basis) effective January 1,
2000 as a result of the net savings expected to result from the contract ter-
mination.
ACE anticipates that securitization will ultimately be used to finance the
stranded costs associated with the buyout or buydown of its NUG contracts (in-
cluding the buyout described above), along with stranded costs determined in
connection with the planned divestiture of certain of ACE's generating units.
As noted above, there can be no assurances that the NJBPU will approve the is-
suance of transition bonds for such costs or that ACE will be able to issue
and sell any such bonds.
On December 28, 1999, the Conectiv subsidiaries which own 50% of the NUG
partnership with which ACE terminated its contract received an $82.2 million
distribution from the NUG partnership. The distribution was primarily the re-
sult of a gain realized by the NUG partnership from the contract termination;
the Conectiv subsidiaries' share of the gain was $70.8 million, which was de-
ferred in Conectiv's Consolidated Balance Sheet as of December 31, 1999 and
classified under "Deferred Credits and Other Liabilities." The deferred gain
is expected to be amortized to income over the period revenues are collected
from ACE's customers to repay the securitized debt attributed to the contract
termination payment.
NOTE 11. ENERGY HEDGING AND TRADING ACTIVITIES
Conectiv actively participates in the wholesale energy markets to support
its wholesale utility and competitive retail marketing activities. Conectiv
engages in commodity hedging activities to minimize the risk of market fluctu-
ations associated with the purchase and sale of energy commodities (natural
gas, petroleum and electricity). Some hedging activities are conducted using
energy derivatives. The remainder of Conectiv's hedging activity is conducted
by backing physical transactions with offsetting physical positions. The hedg-
ing objectives include the assurance of stable and known minimum cash flows
and the fixing of favorable prices and margins when they become available.
Conectiv also engages in energy commodity trading and arbitrage activities,
which expose Conectiv to commodity market risk when, at times, Conectiv cre-
ates net open energy commodity positions or allows net open positions to con-
tinue. To the extent that Conectiv has net open positions, controls are in
place that are intended to keep risk exposures within management-approved risk
tolerance levels.
Conectiv utilizes futures, options and swap agreements to manage risk.
Futures help manage commodity price risk by fixing purchase or sales prices.
Options provide a floor or ceiling on future purchases or sales prices while
allowing Conectiv to benefit from favorable price movements. Swaps are struc-
tured to provide the same risk protection as futures and options. Basis swaps
are used to manage risk by fixing the basis differential that exists between a
delivery location index and the commodity futures price.
Exposed commodity positions may be "long" or "short." A long position indi-
cates that Conectiv has an excess of the commodity available for sale. A short
position means Conectiv will have to obtain additional commodity to fulfill
its sales requirements. A "delta" position is the conversion of an option into
futures contract equivalents. The option delta is dependent upon the strike
price, volatility, current market price and time-value of the option.
Counterparties to its various hedging and trading contracts expose Conectiv
to credit losses in the event of nonperformance. Management has evaluated such
risk and implemented credit checks and has established reserves for credit
losses. A large portion of the hedging and trading activities are conducted on
national exchanges backed by exchange clearinghouses. Management believes that
the overall business risk is minimized as a result of these procedures.
Natural Gas Activities
At December 31, 1999, Conectiv's open futures contracts represented a net
long position with a notional quantity of 8.5 billion cubic feet (Bcf),
through March 2002. Conectiv also had a net long commodity swap
II-49
position at December 31, 1999 equivalent to 1.2 Bcf and a net short basis
swaps position equivalent to 0.2 Bcf. At December 31, 1998, Conectiv's open
futures contracts represented a net long position with a notional quantity of
13.1 Bcf, through February 2001. Conectiv also had a net long commodity swap
position at December 31, 1998 equivalent to 4.6 Bcf and a net long basis swaps
position equivalent to 5.3 Bcf.
During 1999, a gain of $5.0 million, including a $3.0 million unrealized
gain, was recognized for gas trading positions (physical and financial com-
bined). In 1999, the annual average unrealized gain on trading activities was
$2.1 million. During 1998, recognized and unrealized gains from gas trading
positions were not material to Conectiv's results of operations or financial
position.
Unrealized hedging losses of $7.6 million and $8.6 million as of December
31, 1999 and 1998, respectively, from natural gas futures, swaps and options
contracts used to hedge gas marketing activities are deferred in the Consoli-
dated Balance Sheets. These losses are offset by gains on the physical commod-
ity transactions being hedged.
Electricity Marketing and Trading Activities
At December 31, 1999, Conectiv had a net long exposure of 219,900 megawatt-
hours (MWH) through December 2000 primarily from forward contracts. At Decem-
ber 31, 1998, Conectiv had a net short exposure of 102,400 MWH through Decem-
ber 1999 primarily from forward contracts.
During 1999, a gain of $6.0 million, including a $1.3 million unrealized
gain, was recognized for electricity trading activities (physical and finan-
cial combined). During 1998, a gain of $11.4 million, including a $1.2 million
unrealized gain, was recognized for electricity trading activities (physical
and financial combined). The annual average unrealized gain on electricity
trading activities was $0.1 million in 1999 and $1.3 million in 1998.
The deferred gains and losses from hedges of electricity marketing activi-
ties were not material to Conectiv's financial position as of December 31,
1999 and December 31, 1998.
Electricity Generation Activities
Under the NJBPU's Summary Order, the electricity output from certain ACE
electric generating units is not dedicated to supplying BGS customers, but in-
stead is being operated on a deregulated basis, effective August 1, 1999. Ef-
fective October 1, 1999, the Delaware portion (approximately 59%) of DPL's
electric generating plants was deregulated and the plants' output may, at
DPL's option, be sold in deregulated markets or used to supply default service
customers in Delaware. Similarly, effective July 1, 2000, the Maryland portion
(approximately 30%) of DPL's electric generating plants is deregulated and the
plants' output may, at DPL's option, be sold in deregulated markets or used to
supply default service customers in Maryland.
Conectiv hedges the newly deregulated portion of its electric generating
units using derivative financial instruments and forward contracts. Conectiv
hedges portions of the fuel purchased and the electricity output of the gener-
ating plants to stabilize fuel costs and to lock-in prices for electricity
generated. As of December 31, 1999, Conectiv hedged 3,865,800 MWH of forward
generation output, through the sale of forward contracts, which resulted in an
$11.0 million unrealized and unrecognized gain as of December 31, 1999. A net
unrealized loss of $4.1 million which resulted from hedging the cost of gas
burned by electric generating units was deferred in the Consolidated Balance
Sheet as of December 31, 1999. This hedge consisted of a long position of nat-
ural gas futures, forwards and swaps with a combined notional amount of 12.9
Bcf.
Petroleum Activities
Conectiv markets petroleum products through a subsidiary. To hedge a portion
of its petroleum sales commitments, the subsidiary had net long futures posi-
tions as of December 31, 1999 and 1998 with notional equivalents of 376,000
barrels and 315,000 barrels, respectively. An unrealized hedging gain of $3.0
million was
II-50
deferred as of December 31, 1999 and an unrealized hedging loss of $3.1 mil-
lion was deferred as of December 31, 1998.
Petroleum trading activities began in 1999 and a $1.3 million trading gain
was recognized, including a $0.7 million unrealized gain. The average annual
unrealized gain on 1999 petroleum trading activities was $0.5 million.
NOTE 12. JOINTLY OWNED PLANT
Conectiv's Consolidated Balance Sheets include its proportionate share of
assets and liabilities related to jointly owned plant. Both DPL and ACE have
ownership interests in electric power plants, transmission facilities, and
other facilities in which various parties have ownership interests. DPL's and
ACE's proportionate shares of operating and maintenance expenses of the
jointly owned plant is included in the corresponding expenses in Conectiv's
Consolidated Statements of Income. DPL and ACE are responsible for providing
their share of financing for the jointly owned facilities.
DPL and ACE own 14.82% of Salem in the aggregate. Salem Units 1 and 2 were
removed from operation by Public Service Electric & Gas Company (PSE&G), the
Salem operator, in the second quarter of 1995 due to operational problems and
safety concerns. PSE&G returned Unit 2 to service in August 1997, and Unit 1
to service in April 1998. The net increase in expenses due to unrecovered re-
placement power and other costs, net of the benefit of lawsuit settlement pro-
ceeds received in 1997, was $3.1 million in 1998 and $7.1 million in 1997.
Information with respect to DPL's and ACE's shares of jointly owned plant as
of December 31, 1999 is shown below and reflects the write-downs which re-
sulted from discontinuing application of SFAS No. 71 as discussed in Note 6 to
the Consolidated Financial Statements. As discussed in Note 13 to the Consoli-
dated Financial Statements, agreements have been reached to sell to third par-
ties the jointly-owned nuclear and coal-fired plants listed below.
Megawatt Construction
Ownership Capability Plant in Accumulated Work in
Share Owned Service Depreciation Progress
--------- ---------- -------- ------------ ------------
(Dollars in Thousands)
Nuclear
Peach Bottom.......... 15.02% 328 MW $ 9,548 $ 204* $ --
Salem................. 14.82% 334 MW 7,742 190* --
Hope Creek............ 5.00% 52 MW 1,930 29* --
Coal-Fired
Keystone.............. 6.17% 106 MW 34,755 14,580 299
Conemaugh............. 7.55% 129 MW 68,494 23,014 1,351
Transmission
Facilities............. Various 28,670 12,428 --
Other Facilities........ Various 3,269 792 14,586
-------- ------- -------
Total................... $154,408 $51,237 $16,236
======== ======= =======
- --------
* Excludes nuclear decommissioning reserve.
NOTE 13. SUBSEQUENT EVENT--EXPECTED SALES OF ELECTRIC GENERATING PLANTS
Pursuant to the financial and strategic initiatives announced by Conectiv in
May 1999, Conectiv distributed offering memoranda for the proposed sale of nu-
clear and non-strategic baseload fossil electric generating plants owned by
DPL and ACE. Management intends to retain certain fossil fuel-fired electric
generating plants which are strategic to Conectiv's energy business, pursuant
to Conectiv's "mid-merit" strategy as discussed in the "Deregulated Generation
and Power Plant Sales" section of Management's Discussion and Analysis of Fi-
nancial Condition and Results of Operations (MD&A). A summary of the electric
generating plants which have been offered for sale is shown in the following
table.
II-51
Consolidated DPL Generating ACE Generating
Conectiv Units Units
----------------- ----------------- -----------------
MW of Net Book MW of Net Book MW of Net Book
Capacity Value(a) Capacity Value(a) Capacity Value(a)
-------- -------- -------- -------- -------- --------
Fossil Units:
Wholly-owned.......... 1,640.0 $355.3 954.0 $277.3 686.0 $ 78.0
Jointly-owned......... 234.5 67.3 126.8 31.8 107.7 35.5
Jointly-owned nuclear
units.................. 714.0 18.8 331.0 8.4 383.0 10.4
------- ------ ------- ------ ------- ------
2,588.5 $441.4 1,411.8 $317.5 1,176.7 $123.9
======= ====== ======= ====== ======= ======
- --------
(a) The net book values shown above are as of December 31, 1999, are stated in
millions of dollars, and reflect the write-downs discussed in Note 6 to
the Consolidated Financial Statements.
On September 30, 1999, Conectiv announced that DPL and ACE reached agree-
ments to sell their ownership interests in nuclear plants to PSEG Power LLC (a
subsidiary of Public Service Enterprise Group Incorporated) and PECO Energy
Company (PECO) for approximately $20 million, plus the net book value of the
interests of DPL and ACE in nuclear fuel on-hand as of the closing date. The
combined interests of DPL and ACE in the nuclear units which are being sold
include a 15.02 percent (328 MW) interest in Peach Bottom, a 14.82 percent in-
terest (334 MW) in Salem and a 5.0 percent interest (52 MW) in Hope Creek.
Upon completion of the sale, DPL and ACE will transfer their respective nu-
clear decommissioning trust funds to the purchasers and PSEG Power LLC and
PECO will assume full responsibility for the decommissioning of Peach Bottom,
Salem, and Hope Creek. The sales are subject to various federal and state reg-
ulatory approvals and are expected to close by the third quarter of 2000.
On January 19, 2000, Conectiv announced that DPL and ACE reached agreements
to sell the wholly- and jointly-owned fossil units listed in the above table,
which have a total capacity of 1,874.5 MW and a net book value of $422.6 mil-
lion as of December 31, 1999 (net of the write downs recorded as a result of
deregulation), to NRG Energy, Inc., a subsidiary of Northern States Power Com-
pany, for $800 million. The sales are subject to various federal and state
regulatory approvals and are expected to be completed during the third quarter
of 2000. Management expects that the aggregate proceeds from the sale of the
electric generating plants will be used for debt repayment, repurchases of
common stock and new investments that fit with Conectiv's strategies, includ-
ing expansion of the mid-merit generation business.
The terms of DPL's agreement with NRG Energy, Inc. provide for DPL to pur-
chase from NRG Energy, Inc. 500 megawatt-hours of firm electricity per hour
from completion of the sale through December 31, 2005. DPL expects to use
electricity purchased under this agreement and other purchased power agree-
ments to fulfill its obligations in Delaware and Maryland as a default service
provider. Recently DPL entered into an agreement to purchase 350 MW of capac-
ity and energy from PECO from March 2000 to February 2003.
Under the restructuring orders issued by the DPSC and MPSC, as discussed in
Note 9 to the Consolidated Financial Statements, DPL's Delaware and Maryland
retail electric rates will not be changed in the event DPL sells or transfers
generating assets. Based on the terms of the restructuring orders and DPL's
sales agreement with NRG Energy, Inc, management expects to recognize a net
gain in earnings of approximately $140 million to $150 million when DPL com-
pletes the sale of its electric generating plants which were not impaired from
deregulation. There can be no assurances, however, that the sales of DPL's, or
ACE's, electric generating plants will be completed pursuant to the agree-
ments, or that any gain will be realized from such sales of electric generat-
ing plants.
Under the NJBPU's Summary Order, any gain or loss realized upon the sale of
ACE's electric generating plants (other than the Deepwater plant and combus-
tion turbines owned by ACE) will affect the amount of ACE's recoverable
stranded costs. Accordingly, any gain or loss realized by ACE on the sale of
these plants would not affect future earnings. Any loss on a sale within three
years of the Deepwater plant and combustion turbines owned by ACE, which began
operating on a deregulated basis effective August 1, 1999, cannot be recovered
II-52
from ACE's customers. ACE's agreement for the sale of electric generating
units to NRG Energy, Inc. includes the sale of the 239 MW Deepwater plant at a
loss which was recorded in the fourth quarter of 1999 as an adjustment to the
extraordinary item initially estimated and recorded in the third quarter of
1999.
For pro forma information concerning the expected sale of power plants, see
Exhibit 99 to this report on Form 10-K.
NOTE 14. NUCLEAR DECOMMISSIONING
Conectiv's subsidiaries, DPL and ACE, record liabilities for their share of
the estimated cost of decommissioning the Peach Bottom, Salem, and Hope Creek
nuclear reactors over the remaining lives of the plants based on amounts col-
lected in rates charged to electric customers. ACE estimates its share of fu-
ture nuclear decommissioning costs ($157 million) based on site specific stud-
ies filed with and approved by the NJBPU. DPL estimates its share of future
nuclear decommissioning costs ($98 million) based on Nuclear Regulatory Com-
mission (NRC) regulations concerning the minimum financial assurance amount
for nuclear decommissioning. The ultimate cost of nuclear decommissioning for
the Peach Bottom, Salem, and Hope Creek reactors may exceed the current esti-
mates, which are updated periodically.
Conectiv's consolidated accrued nuclear decommissioning liability, which is
reflected in the accumulated reserve for depreciation, was $179.5 million as
of December 31, 1999 and $167.7 million as of December 31,1998. The provision
reflected in depreciation expense for nuclear decommissioning was $6.7 million
in 1999, $10.6 million in 1998, and $4.2 million in 1997. External trust funds
established by DPL and ACE for the purpose of funding nuclear decommissioning
costs had an aggregate book balance (stated at fair market value) of $166.9
million as of December 31, 1999 and $155.9 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. As discussed in Note 13 to the Consolidated Financial
Statements, upon completion of the expected sale of the nuclear plants, DPL
and ACE will transfer their respective nuclear decommissioning trust funds to
the purchasers who will then assume full responsibility for the
decommissioning of the nuclear plants.
The staff of the Securities and Exchange Commission (SEC) has questioned
certain of the current accounting practices of the electric utility industry,
including Conectiv, regarding the recognition, measurement and classification
of decommissioning costs for nuclear generating stations in the financial
statements of electric utilities. Recently, the FASB issued an exposure draft
of a new accounting pronouncement which addresses the accounting for obliga-
tions associated with the retirement of long-lived assets, such as
decommissioning costs of nuclear generating stations. Under this proposed pro-
nouncement, the present value of the decommissioning obligation would be capi-
talized as part of the cost of the nuclear generating station and recorded as
a liability. The cost capitalized would be depreciated over the life of the
nuclear generating station. Changes in the liability due to the passage of
time would be recorded as interest expense. Changes in the liability resulting
from revisions in the timing or amount of cash flows would increase or de-
crease the liability and the carrying amount of the nuclear generating sta-
tion. Trust fund income from the external decommissioning trusts would be re-
ported as investment income under the proposed pronouncement rather than as a
reduction of decommissioning expense.
NOTE 15. REGULATORY ASSETS AND LIABILITIES
In conformity with SFAS No. 71, Conectiv's accounting policies reflect the
financial effects of rate regulation and decisions by regulatory commissions
having jurisdiction over the regulated utility businesses of DPL and ACE. Reg-
ulatory commissions occasionally provide for future recovery from customers of
current period expenses. When this happens, the expenses are deferred as regu-
latory assets and subsequently recognized in the Consolidated Statement of In-
come during the period the expenses are recovered from customers. Similarly,
regulatory liabilities may also be created due to the economic impact of an
action taken by a regulatory commission.
As discussed in Notes 1, 6, and 9 to the Consolidated Financial Statements,
in the third quarter of 1999, the electricity supply businesses of ACE and DPL
no longer met the requirements of SFAS No. 71. Accordingly,
II-53
regulatory assets and liabilities related to the electricity supply business
were written off, except to the extent that future cost recovery was provided
for through the regulated electricity delivery business. A new regulatory as-
set, "Recoverable stranded costs," was established to recognize amounts to be
collected from regulated delivery customers for stranded costs which resulted
from deregulation of the electricity supply business.
The table below displays the regulatory assets and liabilities as of Decem-
ber 31, 1999 and December 31, 1998.
December 31, December 31,
Regulatory Assets (Liabilities) 1999 1998
------------------------------- ------------ ------------
(Millions of Dollars)
Recoverable stranded costs....................... $1,030.0 --
Deferred recoverable income taxes................ 93.9 $184.4
Deferred debt refinancing costs.................. 21.1 44.2
Unrecovered state excise taxes................... 22.6 35.6
Deferred other postretirement benefit costs...... 32.5 35.0
Unrecovered purchased power costs................ 28.9 48.3
Deferred energy supply costs--DPL................ 8.6 (0.4)
Deferred energy supply costs--ACE................ (46.4) (15.6)
Deferred costs for nuclear
decommissioning/decontamination................. 5.6 11.9
Regulatory liability for New Jersey income tax
benefit......................................... (49.3) --
Asbestos removal costs........................... 8.3 8.5
Deferred demand-side management costs............ 4.1 5.7
Other............................................ 2.7 20.1
-------- ------
Total............................................ $1,162.6 $377.7
======== ======
Recoverable Stranded Costs: Represents amounts to be collected from regu-
lated delivery customers (net of amounts which have been amortized to expense)
for stranded costs which resulted from deregulation of the electricity supply
business. Any gain realized on the sale of certain of ACE's electric generat-
ing plants will reduce the amount of recoverable stranded costs. The $1.0 bil-
lion pre-tax balance as of December 31, 1999 is net of amounts amortized and
includes the $228.5 million NUG contract termination payment discussed in Note
10 to the Consolidated Financial Statements, with the remaining balance aris-
ing from the write-down of property, plant and equipment and recognition of
certain liabilities in conjunction with discontinuing the application of SFAS
No. 71 due to deregulation of the electricity supply business, as discussed in
Note 6 to the Consolidated Financial Statements.
Deferred Recoverable Income Taxes: Represents the portion of deferred income
tax liabilities applicable to DPL's and ACE's utility operations that has not
been reflected in current customer rates for which future recovery is proba-
ble. As temporary differences between the financial statement and tax bases of
assets reverse, deferred recoverable income taxes are amortized. Due to dis-
continuing the application of SFAS No. 71 to the electricity supply business,
the portion of deferred recoverable income taxes attributable to the electric-
ity supply businesses of DPL and ACE was written off in 1999.
Deferred Debt Refinancing Costs: See "Deferred Debt Refinancing Costs" in
Note 1 to the Consolidated Financial Statements.
Unrecovered State Excise Taxes: Represents additional amounts paid, by ACE,
as a result of prior legislative changes in the computation of New Jersey
state excise taxes. These costs are included in current customer rates, with
the remaining balance scheduled for full recovery over the next 3 years.
Deferred Other Postretirement Benefit Costs: Represents the non-cash portion
of other postretirement benefit costs deferred by ACE during 1993 through
1997. This cost is being recovered over a 15-year period which began on Janu-
ary 1, 1998.
II-54
Unrecovered Purchased Power Costs: Includes prior deferrals by ACE of capac-
ity costs ($12 million as of December 31, 1999) which had exceeded the related
recovery from customers. These capacity costs are scheduled for recovery
through customer rates within the next year. Unrecovered purchased power costs
also includes costs incurred by ACE for renegotiation of a long-term capacity
and energy contract. These costs are included in current customer rates with
the balance scheduled for full recovery over the next 15 years.
Deferred Energy Supply Costs: See "Energy Supply Costs" in Note 1 to the
Consolidated Financial Statements.
Deferred Costs for Nuclear Decommissioning/Decontamination: The December 31,
1999 balance represents amounts recoverable from ACE's customers for amounts
owed by ACE to the U.S. government for clean-up of gaseous diffusion enrich-
ment facilities pursuant to the Energy Policy Act of 1992.
Regulatory liability for New Jersey income tax benefit: In 1999, a deferred
tax asset arising from the write down of ACE's electric generating plant was
established. The deferred tax asset represents the future tax benefit expected
to be realized when the higher tax basis of the generating plants is deducted
for New Jersey state income tax purposes. ACE has requested the New Jersey Di-
vision of Taxation to rule on whether or not this tax benefit may be used to
reduce the rates charged to ACE's regulated electricity delivery customers for
stranded cost recovery. To recognize that this tax benefit probably will be
given to ACE's regulated electricity customers through lower electric rates,
ACE established a regulatory liability.
Asbestos Removal Costs: Represents costs incurred by ACE to remove asbestos
insulation from a wholly-owned generating station. These costs are included in
current customer rates with the balance scheduled for full recovery over the
next 30 years.
Deferred Demand-Side Management Costs: Represents deferred costs of programs
which allow DPL to reduce the peak demand for power. These costs are being re-
covered over 4 years.
NOTE 16. CONECTIV COMMON STOCK
Significant Transactions
Offer to Purchase
Pursuant to an offer to purchase shares of Conectiv common stock (the Of-
fer), in June 1999, Conectiv paid $361.4 million (including expenses) to pur-
chase 14,077,466 shares of Conectiv common stock through the Offer at a price
of $25.50 per share, which was determined based on procedures described in the
Offer. Holders of shares of Class A common stock could participate in the Of-
fer by electing to convert shares of Class A common stock into shares of
Conectiv common stock and tendering such shares of Conectiv common stock pur-
suant to the Offer. The 14,077,466 shares of Conectiv common stock purchased
through the Offer included 1,309,251 shares of Conectiv common stock (1.59997
shares of Conectiv common stock for each share of Class A common stock con-
verted) which were issued to and then tendered by holders of 818,297 shares of
Class A common stock who elected to convert shares of Class A common stock
through the Offer.
Buyback program
Conectiv also purchases shares of Conectiv common stock, from time to time,
pursuant to a plan to purchase up to $60 million (market value) of Conectiv
common stock. Under the buyback program, Conectiv purchased 1,670,000 shares
of Conectiv common stock for $31.4 million in 1999 and 503,700 shares of
Conectiv common stock for $11.3 million in 1998. On January 19, 2000, Conectiv
announced that its Board of Directors approved the open market purchase of up
to an additional 5 million shares of common stock.
II-55
Merger
See Note 4 to the Consolidated Financial Statements and the Statement of
Changes in Common Stockholders' Equity for information concerning changes in
common stock due to the Merger.
Other Common Stock Transactions
For additional information concerning issuances and redemptions of common
stock during 1997 through 1999, see the Consolidated Statements of Changes in
Common Stockholders' Equity.
Dividends
Conectiv announced on May 11, 1999 that it intended to reduce the dividends
on Conectiv common stock to a targeted payout ratio of 40% to 60% of earnings
per average share of common stock outstanding. Conectiv's Board of Directors
declared a quarterly dividend per share on Conectiv common stock of $0.385 for
the first quarter of 1999, and $0.22 per share in the second, third, and
fourth quarters of 1999, or a total of $1.045 in 1999 which represented ap-
proximately 55% of the $1.89 of earnings per average share of Conectiv common
stock outstanding adjusted to exclude the special and extraordinary charges
discussed in Notes 5 and 6 to the Consolidated Financial Statements.
Conectiv's common dividends paid to public stockholders are funded from the
common dividends DPL and ACE pay to Conectiv. DPL's and ACE's certificates of
incorporation require payment of all preferred dividends in arrears (if any)
prior to payment of common dividends to Conectiv, and have certain other limi-
tations on the payment of common dividends to Conectiv.
Under the Public Utility Holding Company Act of 1935, as amended, Conectiv
may not pay dividends on the shares of common stock and Class A common stock
from an accumulated deficit or paid-in-capital without SEC approval. As of De-
cember 31, 1999, Conectiv had an accumulated deficit of $36.5 million. In Jan-
uary 2000, the SEC approved payment of the dividends declared by Conectiv on
its common stock and Class A common stock in December 1999. Conectiv expects
to have retained earnings sufficient to offset dividends declared on shares of
common stock and Class A common stock beginning in the third quarter of 2000,
when the sale of the electric generating units discussed in Note 13 to the
Consolidated Financial Statements is expected to be completed. There can be no
assurances, however, that the sales of the electric generating units will be
completed, or that any gain will be realized from such sales of the electric
generating units. In any event, Conectiv expects to receive the necessary SEC
approvals during 2000 for the quarterly payment of dividends on shares of its
common stock and Class A common stock.
Stock-Based Compensation
Through the effective date of the Merger (March 1, 1998), DPL's Long-Term
Incentive Plan (LTIP) provided long-term incentives to key employees through
contingent awards of performance-based restricted stock, dividend rights, and
stock options. The DPL common stock options outstanding as of the Merger date
were converted to Conectiv common stock options and included in the Conectiv
Incentive Compensation Plan (CICP). The restricted common stock previously
granted under DPL's LTIP is earned and payable at the end of a four-year pe-
riod to the extent that stock performance compares favorably with the stock
performance of a peer group of utility companies. The 1994 awards were for-
feited in early 1998 when the required performance targets were not met. Re-
strictions on shares contingently granted in 1995 and 1996 lapsed upon the
Merger and the shares became fully vested. The restricted DPL common stock
contingently granted in 1997 was exchanged for Conectiv common stock upon the
Merger and is included in the CICP. As of December 31, 1999, there were 95,415
shares of the 1997 awards outstanding which had a $19 1/8 per share fair value
on the date of grant.
The CICP provides long-term awards to key employees and directors through
awards of stock-based compensation. Up to 5,000,000 shares of common stock may
be issued under the CICP during the ten-year period from March 1, 1998,
through February 28, 2008. Awards granted under the CICP which can be settled
in common stock have included performance accelerated restricted stock (PARS),
stock options, and performance accelerated stock options (PASO's).
II-56
Conectiv granted 52,700 shares of PARS in 1998 and 71,500 shares of PARS in
1999 which are earned by participants over a seven-year vesting period unless
accelerated vesting occurs, in whole or in part, after three years due to sat-
isfaction of certain conditions required for accelerated vesting. For 22,000
shares of the PARS granted in 1998 and 22,000 shares of the PARS granted in
1999, a total stockholder return of 8% must be earned over the seven years for
those shares to vest, unless vesting is accelerated. The 52,700 shares of the
PARS granted in 1998 and the 71,500 shares of the PARS granted in 1999 had per
share fair values on the grant dates of $22.84 and $24.25, respectively.
Conectiv issued 289,000 stock options in 1998 and 367,800 stock options in
1999, which do not contain performance acceleration features and have an exer-
cise price of $22.84 per share and $24.25 per share, respectively. These stock
options have a ten-year life, with 50% of the options vesting after two years
and the remaining 50% vesting after three years. Conectiv also issued 150,000
PASO's in 1999 (exercise price of $24.25 per share) and 750,000 PASO's in 1998
(exercise price of $22.84 per share). The PASO's have a ten-year life and vest
after nine and a half years. One third of the PASO's will vest if Conectiv's
common stock price closes at or above $26 per share for ten consecutive days,
two thirds will vest if the stock price closes at or above $28 per share for
ten consecutive days, and all of the PASO's will vest if the stock price
closes at or above $30 per share for ten consecutive days.
Changes in stock options (including PASO's) are summarized below.
1999 1998 1997
----------------------- ----------------------- -----------------------
Number Weighted Number Weighted Number Weighted
of Shares Average Price of Shares Average Price of Shares Average Price
--------- ------------- --------- ------------- --------- -------------
Beginning-of-year
balance................ 1,072,150 $22.77 38,500 $20.55 43,950 $20.19
Options exercised....... 5,600 $20.23 3,200 $19.89 5,450 $17.61
Options forfeited....... 42,400 $22.70 2,150 $19.73 -- --
Options issued.......... 517,800 $24.28 1,039,000 $22.84 -- --
End-of-year balance..... 1,541,950 $23.28 1,072,150 $22.77 38,500 $20.55
Exercisable............. 11,950 $20.11 33,150 $20.67 38,500 $20.55
For options outstanding as of December 31, 1999, the range of exercise
prices was $18.13 to $24.75, and the weighted average remaining contractual
life was 8.3 years.
Conectiv recognizes compensation costs for its stock-based employee compen-
sation plans based on the accounting prescribed by Accounting Principles Board
(APB) Opinion No. 25, "Accounting for Stock Issued to Employees." Stock-based
employee compensation costs charged to expense were $1.8 million in 1999, $0.9
million in 1998, and $2.2 million in 1997. Pro forma net income (loss), based
on the application of SFAS No. 123, "Accounting for Stock-Based Compensation,"
was $(199.306) million for 1999, $152.676 million for 1998, and $101.638 mil-
lion for 1997. Pro forma earnings (loss) per share of Conectiv common stock
was $(2.03) for 1999, $1.49 for 1998 and $1.66 for 1997.
The fair values of each option and PASO granted in 1999 and 1998, estimated
on the date of grant using the Black Scholes option pricing model, and related
valuation assumptions are as follows:
1999 1998
----- -----
Weighted Average Fair Value Per Option......................... $3.38 $2.64
Weighted Average Fair Value Per PASO........................... $3.93 $2.87
Expected Option Term (years)................................... 3.5 3.5
Expected PASO Term (years)..................................... 5.5 5.3
Expected Volatility............................................ 20.0% 20.0%
Expected Dividend Yield........................................ 4.0% 6.0%
Risk-free Interest Rate........................................ 4.7% 5.6%
II-57
Stockholders Rights Plan
Under Conectiv's Stockholders Rights Plan (Plan), holders of Conectiv common
stock and holders of Conectiv Class A common stock were granted preferred
stock purchase rights on May 11, 1998, by means of a dividend at the rate of
one Right for each share of common stock and one Right for each share of Class
A common stock held. The Rights expire in 10 years.
The purpose of the Plan is to guard against partial tender offers or abusive
or unfair tactics that might be used in an attempt to gain control of Conectiv
without paying all stockholders a fair price for their shares. The Plan will
not prevent takeovers, but is designed to deter coercive, abusive, or unfair
takeover tactics and to encourage individuals or entities attempting to ac-
quire Conectiv to first negotiate with the Board of Directors.
Each Right would, after the Rights become exercisable, entitle the holder to
purchase from Conectiv one one-hundredth of one share of Series One Junior
Preferred Stock or one one-hundredth of one share of Series Two Junior Pre-
ferred Stock at an initial price of $65. The Rights will be exercisable only
if a person or group acquires beneficial ownership of 15% or more of the ag-
gregate voting power represented by Conectiv's outstanding securities (i.e.,
becomes an "Acquiring Person" as defined in the Plan) or commences a tender or
exchange offer to acquire beneficial ownership of 15% or more of the aggregate
voting power represented by Conectiv's outstanding securities. Conectiv gener-
ally will be entitled to redeem the Rights at $.01 per Right at any time be-
fore a person or group becomes an Acquiring Person.
NOTE 17. CONECTIV CLASS A COMMON STOCK
General
Conectiv Class A common stock provides its holders a proportionately greater
opportunity to share in the growth prospects of, and a proportionately greater
exposure to the uncertainties associated with, the electric utility business
of ACE. Earnings applicable to Class A common stock are equal to a percentage
of "Company Net Income Attributable to the Atlantic Utility Group," which is
earnings of the Atlantic Utility Group (AUG) less $40 million per year. The
AUG includes the assets and liabilities of the electric generation, transmis-
sion, and distribution businesses of ACE which existed on August 9, 1996 and
were regulated by the NJBPU.
The percentage of "Company Net Income Attributable to the Atlantic Utility
Group" applicable to Class A common stock was 30% at the date of the Merger.
Certain circumstances, as specified in the Restated Certificate of Incorpora-
tion of Conectiv, result in an adjustment to the percentage of "Company Net
Income Attributable to the Atlantic Utility Group" applicable to Class A com-
mon stock. As discussed in Note 16 to the Consolidated Financial Statements,
the number of shares of Class A common stock outstanding decreased by 818,297
as a result of the Offer. Due to this reduction in the number of shares of
Class A common stock outstanding and in accordance with the Restated Certifi-
cate of Incorporation of Conectiv, the percentage of "Company Net Income At-
tributable to the Atlantic Utility Group" applicable to Class A common stock
decreased to 27.3% in June 1999, when the Offer was completed.
The earnings of the Atlantic Utility Group (AUG) will be affected by the im-
plementation of the Summary Order in New Jersey, including the rate decreases
required by the Summary Order. (See Note 9 to the Consolidated Financial
Statements for information concerning the Summary Order.) The planned sales of
most of ACE's electric generating plants are expected to decrease the earnings
capacity of the AUG. The extent of the decrease in earnings capacity will be
affected by how the proceeds from the sales of the generating plants are uti-
lized, which has not yet been finalized by Conectiv's management and Board of
Directors. On January 19, 2000, Conectiv announced that it expects to use the
proceeds for debt repayment, repurchases of common stock and new investments
that fit with Conectiv's strategies, including expansion of the mid-merit gen-
eration business. Under certain circumstances, the percentage of "Company Net
Income Attributable to the Atlantic Utility Group" applicable to Class A com-
mon stock may be adjusted. The electric generating plants of ACE which are not
sold to third parties are expected to be transferred to another Conectiv sub-
sidiary; such transfer would not
II-58
affect the earnings of the AUG or the percentage of "Company Net Income At-
tributable to the Atlantic Utility Group" applicable to Class A common stock
because the transferred electric generating plants would remain part of the
AUG.
Dividends
Dividends declared per share of Class A common stock were $3.20 for 1999 and
$3.20 for 1998. In comparison, earnings excluding special charges and the ex-
traordinary item which were applicable to Class A common stock were $1.44 in
1999 and $1.82 in 1998.
Computation of Earnings Applicable to Conectiv Class A Common Stock
Twelve Months Ended Ten Months Ended
December 31, 1999 December 31, 1998
------------------- -----------------
(Dollars in Thousands)
Net earnings of ACE [a]................. $ 3,703 $ 23,742
Exclude:
Employee separation and other Merger-
related costs........................ 837 47,886
Net loss of nonutility activities..... 1,712 1,402
Pro-rata portion of fixed amount of
$40 million per year................. (40,000) (33,333)
-------- --------
Company Net Income (Loss) Attributable
to the Atlantic Utility Group.......... (33,748) 39,697
Percentage applicable to Class A Common
Stock[b]............................... 28.5% 30.0%
-------- --------
Earnings (loss) applicable to Class A
Common Stock........................... $ (9,618) $ 11,909
======== ========
Earnings (loss) applicable to Class A
Common Stock
Before extraordinary item[c].......... $ 6,939 $ 11,909
Extraordinary item[d]................. (16,557) --
-------- --------
$ (9,618) $ 11,909
======== ========
- --------
[a] Under the purchase method of accounting, the 1998 Conectiv Consolidated
Statement of Income includes ten months of ACE's operating results from
March 1, 1998 to December 31, 1998.
[b] The percentage applicable to Class A common stock in a reporting period is
a weighted average based on the number of days the percentage was in ef-
fect during the reporting period.
[c] Includes "Special charges" of $1.9 million for 1999, as discussed in Note
5 to the Consolidated Financial Statements.
[d] Represents the portion of the extraordinary item recorded by ACE, as dis-
cussed in Note 6 to the Consolidated Financial Statements, which is appli-
cable to Class A common stock based on the percentage of "Company Net In-
come Attributable to the Atlantic Utility Group" applicable to Class A
common stock in 1999.
II-59
Summarized Financial Information of ACE
Twelve Months Ended Ten Months Ended
December 31, 1999 December 31, 1998
------------------- -----------------
(Dollars in Thousands)
Income Statement Information(1)
-------------------------------
Operating Revenues................... $1,076,585 $875,741
Operating Income(2).................. $ 171,931 $105,099
Income before extraordinary item(2).. $ 63,930 $ 23,940
Extraordinary item, net of income
taxes(3)............................ $ (58,095) --
Earnings applicable to common stock.. $ 3,703 $ 23,742
- --------
(1) Under the purchase method of accounting, the 1998 Conectiv Consolidated
Statement of Income includes ten months of ACE's operating results from
March 1, 1998 to December 31, 1998.
(2) In 1999, special charges for employee separations, additional merger
costs, and certain other items reduced ACE's operating income by $12.3
million and income before extraordinary item by $7.3 million. For the ten
months ended December 31, 1998, employee separation and other Merger-re-
lated costs reduced ACE's operating income by $80.1 million and income be-
fore extraordinary item by $47.9 million. In the Consolidated Conectiv Fi-
nancial Statements, ACE's employee separation and other Merger-related
costs incurred in 1998 were capitalized as costs of the Merger.
(3) For information concerning the extraordinary item, refer to Note 6 to the
Consolidated Financial Statements.
As of December 31,
-----------------------
1999 1998
----------- -----------
(Dollars in Thousands)
Balance Sheet Information
-------------------------
Current assets...................................... $ 340,774 $ 236,177
Noncurrent assets................................... 2,313,885 2,131,045
----------- -----------
Total assets........................................ $ 2,654,659 $ 2,367,222
=========== ===========
Current liabilities................................. $ 300,837 $ 236,546
Noncurrent liabilities.............................. 1,550,690 1,275,402
Preferred stock..................................... 125,181 125,181
Common stockholders' equity......................... 677,951 730,093
----------- -----------
Total capitalization and liabilities................ $ 2,654,659 $ 2,367,222
=========== ===========
Conversion and Redemption Provisions Relating to Class A Common Stock
Conectiv may at any time convert each share of Conectiv Class A common stock
into the number of shares of Conectiv common stock equal to a specified per-
centage set forth in Conectiv's Restated Certificate of Incorporation
(Conectiv Charter) of the Market Value Ratio of Conectiv Class A common stock
to Conectiv common stock (as defined in the Conectiv Charter).
If the holders of more than 50% of the Conectiv Class A common stock accept
a tender offer by Conectiv for all of the Conectiv Class A common stock for
either (a) a cash price of at least 110% of the market price of Conectiv Class
A common stock, or (b) a number of shares of Conectiv common stock equal to at
least 110% of the Market Value Ratio of Conectiv Class A common stock to
Conectiv common stock, then, based on terms specified in the Conectiv Charter,
Conectiv may either redeem each share of Conectiv Class A common stock remain-
ing outstanding for cash or convert each share of Conectiv Class A common
stock remaining outstanding into shares of Conectiv common stock.
If any person (including Conectiv) consummates a tender offer for all of the
outstanding shares of Conectiv common stock at an all cash price that is ac-
cepted by the holders of more than 50% of Conectiv common stock,
II-60
Conectiv may, based on terms specified in the Conectiv Charter, either redeem
each share of Conectiv Class A common stock for cash or convert each share of
Conectiv Class A common stock into shares of Conectiv common stock.
If any person (including Conectiv) makes a tender offer to purchase shares
of Conectiv common stock for cash, property, or other securities, any holder
of Conectiv Class A common stock may elect to convert shares of Conectiv Class
A common stock into shares of Conectiv common stock based on terms specified
in the Conectiv Charter.
Upon the disposition of all or substantially all (as defined in the Conectiv
Charter) of the assets attributed to the AUG to an entity which is not con-
trolled by Conectiv, the Conectiv Charter provides for the payment of a divi-
dend to holders of Conectiv Class A common stock or redemption of some or all
of the shares of Conectiv Class A common stock or conversion of shares of
Conectiv Class A common stock into shares of Conectiv common stock, in each
case subject to the terms specified in the Conectiv Charter.
NOTE 18. PREFERRED STOCK
Conectiv (the parent holding company), ACE, and DPL are each authorized to
separately issue preferred stock. Conectiv is authorized to issue 20,000,000
shares of $0.01 per share par value preferred stock, none of which has been
issued. ACE is authorized to issue 799,979 shares of $100 par value Cumulative
Preferred Stock, 2,000,000 shares of No Par Preferred Stock, and 3,000,000
shares of Preference Stock. DPL has $1, $25, and $100 par value per share pre-
ferred stock for which 10,000,000, 3,000,000, and 1,800,000 shares are autho-
rized, respectively. Dividends on ACE and DPL preferred stock are cumulative.
Information concerning shares of preferred stock outstanding is shown below.
Preferred Stock of Subsidiaries Not Subject to Mandatory Redemption
The amounts outstanding as of December 31, 1999, and 1998 of DPL's and ACE's
preferred stock not subject to mandatory redemption are presented below.
Shares Outstanding Amount
Current ------------------- -----------------------
Issuer Series Redemption Price 1999 1998 1999 1998
- ------ ------------------------ ---------------- --------- --------- ----------- -----------
(Dollars in Thousands)
ACE(1) $100 per share par value
4.00%-5.00% $100.00-$105.50 62,305 62,305 $ 6,230 $ 6,230
DPL $25 per share par value
7 3/4% (2) 316,500 316,500 7,913 7,913
DPL $100 per share par value
3.70%-5.00% $103.00-$105.00 181,698 181,698 18,170 18,170
DPL 6 3/4% (3) 35,000 35,000 3,500 3,500
DPL Adjustable rate(4) $100 151,200 151,200 15,120 15,120
DPL Auction rate(5) $100 450,000 450,000 45,000 45,000
----------- -----------
$ 95,933 $ 95,933
=========== ===========
- --------
(1) Under purchase accounting for the Merger, ACE and its wholly-owned trusts
were consolidated in Conectiv's financial statements beginning March 1,
1998.
(2) Redeemable beginning September 30, 2002, at $25 per share.
(3) Redeemable beginning November 1, 2003, at $100 per share.
(4) Average rates were 5.5% during 1999 and 1998.
(5) Average rates were 4.3% during 1999 and 4.2% during 1998.
In the fourth quarter of 1998, ACE purchased and retired 237,695 shares, or
$23.8 million, of various series of $100 per share par value preferred stock,
which had an average dividend rate of 4.4%. A $2.5 million gain on the redemp-
tion is presented in the 1998 Consolidated Statement of Income as a reduction
of Preferred Stock Dividend Requirements of Subsidiaries.
II-61
Preferred Stock of Subsidiaries Subject to Mandatory Redemption
The amounts outstanding as of December 31, 1999, and 1998 of Conectiv's sub-
sidiaries preferred stock subject to mandatory redemption are presented below.
Shares Outstanding Amount
------------------- -----------------------
Issuer Series 1999 1998 1999 1998
- ------ --------------------- --------- --------- ----------- -----------
(Dollars in Thousands)
DPL
financing
trust(1) $25 per share, 8.125% 2,800,000 2,800,000 $ 70,000 $ 70,000
ACE(2) $100 per share, $7.80 239,500 239,500 23,950 23,950
ACE
financing
trust(1) $25 per share, 8.25% 2,800,000 2,800,000 70,000 70,000
ACE
financing
trust(1) $25 per share, 7.375% 1,000,000 1,000,000 25,000 25,000
----------- -----------
$ 188,950 $ 188,950
=========== ===========
- --------
(1) Per share value is stated liquidation value. See additional information
below.
(2) No par value; stated value is $100 per share. Beginning May 1, 2001,
115,000 shares are subject to mandatory redemption annually.
On August 3, 1998, ACE redeemed the remaining 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 November 1998, a financing subsidiary trust owned by ACE issued $25 mil-
lion (1,000,000 shares) of 7 3/8% preferred stock.
DPL and ACE have established wholly-owned subsidiary trusts for the purposes
of issuing common and preferred trust securities and holding Junior Subordi-
nated Debentures (the Debentures) issued by DPL and ACE, respectively. The De-
bentures held by the trusts are their only assets. The trusts use interest
payments received on the Debentures they hold to make cash distributions on
the trust securities.
DPL's and ACE's obligations pursuant to the Debentures and guarantees of
distributions with respect to the trusts' securities, to the extent the trusts
have funds available therefor, constitute full and unconditional guarantees of
the obligations of the trusts under the trust securities the trusts have is-
sued. DPL and ACE own all of the common securities of the trusts, which con-
stitute approximately 3% of the liquidation amount of all of the trust securi-
ties issued by the trusts.
For consolidated financial reporting purposes, the Debentures are eliminated
in consolidation against the trust's investment in the Debentures. The pre-
ferred trust securities are subject to mandatory redemption upon payment of
the Debentures at maturity or upon redemption. The Debentures mature in 2026
to 2036. The Debentures are subject to redemption, in whole or in part, at the
option of DPL and/or ACE, at 100% of their principal amount plus accrued in-
terest, after an initial period during which they may not be redeemed and at
any time upon the occurrence of certain events.
NOTE 19. DEBT
Substantially all utility plant of DPL and ACE are subject to the liens of
the Mortgages collateralizing First Mortgage Bonds issued by DPL and ACE.
Maturities of long-term debt and sinking fund requirements during the next
five years are as follows: 2000--$48.9 million; 2001--$100.8 million; 2002--
$370.6 million; 2003--$212.8 million; 2004--$154.7 million.
As of December 31, 1999, Conectiv and its subsidiaries had credit agreements
providing $1.05 billion of aggregate borrowing capability, as follows: (a)
Conectiv (the holding company) had a $300 million credit agreement with a
five-year term that expires in February 2003; (b) Conectiv (the holding compa-
ny) had a $500 million credit agreement with a one-year term that expired in
February 2000, when Conectiv renewed the one-
II-62
year credit agreement and increased its capacity from $500 million to $730
million; (c) ACE had a $250 million credit facility which is discussed below.
On a consolidated basis, $273 million was available for borrowing as of Decem-
ber 31, 1999 under the various credit agreements and credit lines.
As discussed in Note 10 to the Consolidated Financial Statements, ACE bor-
rowed $228.5 million from a $250 million revolving credit facility on December
28, 1999 to finance a payment for termination of a NUG purchased power con-
tract. ACE arranged this credit facility to provide interim financing of the
NUG contract termination payment until securitized bonds are issued. (See Note
9 to the Consolidated Financial Statements for information concerning the ex-
pected securitization of ACE's stranded costs.) The revolving loan balance is
due on December 20, 2000 unless ACE elects to convert the outstanding loan
balance to a term loan. If securitized bonds have not been issued by December
20, 2000, ACE intends to exercise its option to convert the revolving loan
balance to a term loan. The term loan balance is due in two installments; (1)
25% of the principal balance is due December 20, 2001, and (2) the remaining
term loan principal is due December 20, 2002.
Conectiv had a $579.7 million consolidated short-term debt balance (average
interest rate of 6.4%) as of December 31, 1999, an increase of $203.6 million
from the $376.1 million balance (average interest rate of 6.0%) as of December
31, 1998. The $203.6 million increase was primarily due to financing part of
the common stock purchased pursuant to the Offer and funding the expansion of
Conectiv Communications, Inc.'s telecommunications business.
On May 26, 1999, Conectiv issued $250 million of 6.73% Medium Term Notes
which mature as follows: $100 million in 2002; $50 million in 2003; $50 mil-
lion in 2004; $30 million in 2005; and $20 million in 2006. Proceeds from the
issuance of the Medium Term Notes and short-term borrowings under Conectiv's
bank credit lines were used to finance the $361.4 million purchase of Conectiv
common stock pursuant to the Offer, as discussed in Note 16 to the Consoli-
dated Financial Statements.
In May 1999, DPL repaid at maturity $30 million of 7.50% Medium Term Notes
and ACE repaid at maturity $30 million of 7.52% Medium Term Notes. In June
1999, ACE purchased $18.9 million of its First Mortgage Bonds, which had an
average interest rate of 6.88% and were scheduled to mature in 2013 ($6.4 mil-
lion) and 2023 ($12.5 million). In July 1999, the Delaware Economic Develop-
ment Authority issued, on behalf of DPL, $33.33 million of Variable Rate De-
mand Bonds (VRDB) due on demand or at maturity in July 2024. The proceeds from
the VRDB were used to refinance $22.33 million of 7.3% long-term debt in Sep-
tember 1999 and $11.0 million of 7.5% long-term debt in October 1999.
In December 1999, ATE Investments, Inc., a Conectiv subsidiary, repaid at
maturity $15.0 million of long-term debt bearing an interest rate of 7.44%.
On December 14, 1999, the SEC approved Conectiv's request regarding the fol-
lowing financing matters: (a) The authorized short-term debt borrowing capac-
ity of Conectiv (the holding company) and DPL was increased from a total of
$800 million to a total of $1.3 billion and (b) Conectiv was authorized to is-
sue securities as long as consolidated common equity as a percent of total
capitalization (common equity ratio) is 20% or higher. Conectiv also requested
SEC approval for the following financing matters: (a) The issuance of up to
$500 million of additional long-term debt by Conectiv (the holding company),
which would bring the total amount of authorized Conectiv long-term debt to $1
billion, of which $250 million has been issued. Proceeds from the additional
long-term debt would be used to pay down short term debt; and (b) The authori-
zation to use proceeds from the issuance of securities for investments in a
Conectiv subsidiary that will own contractual rights for non-utility, combus-
tion turbine generating facilities. The SEC has currently "reserved jurisdic-
tion" over these requests, which requires additional information to be filed
by Conectiv prior to any SEC authorization.
On September 28, 1999, the parties to the agreements for Conectiv's $800
million short-term credit facilities agreed to an amendment permitting a ratio
of total indebtedness to total capitalization of 70% through December 31,
2000. As of December 31, 1999, the ratio of total indebtedness to total capi-
talization computed in accordance with the terms of the credit agreements,
which allow for an adjustment to increase common equity by the amount of the
extraordinary item, was 63.5%.
II-63
Long-term debt outstanding as of December 31, 1999, and 1998 is presented be-
low:
Interest Rates Due 1999 1998
-------------- --------- ----------- -----------
(Dollars in Thousands)
First Mortgage Bonds:... 6.95% 2002 $ 30,000 $ 30,000
6.40% 2003 90,000 90,000
6.625%-8.15% 2011-2015 161,770 190,500
5.90%-7.60% 2017-2021 152,200 163,200
6.85%-8.50% 2022-2025 227,500 240,000
6.05%-7.00% 2028-2032 90,000 90,000
Amortizing First
Mortgage Bonds......... 6.95% 2000-2008 22,962 24,149
----------- -----------
774,432 827,849
----------- -----------
Pollution Control Bonds
and Notes.............. 7.125%-7.25% 2000-2006 2,700 2,800
6.375% 2006 2,275 2,350
6.80% 2021 38,865 38,865
5.60%-7.20% 2025-2029 58,650 58,650
----------- -----------
102,490 102,665
----------- -----------
Medium-Term Notes
(secured):............. 7.52% 1999 -- 30,000
6.83% 2000 46,000 46,000
6.86% 2001 40,000 40,000
7.02% 2002 30,000 30,000
6.00%-7.18% 2003 40,000 40,000
6.19%-7.98% 2004-2008 223,000 223,000
7.25%-7.63% 2010-2014 8,000 8,000
7.68% 2015-2016 17,000 17,000
----------- -----------
404,000 434,000
----------- -----------
Medium-Term Notes
(unsecured):........... 7.50% 1999 -- 30,000
6.46%-9.29% 2002 136,000 36,000
6.63%-6,73% 2003 80,000 30,000
6.73%-8.30% 2004 85,000 35,000
6.73%-6.84% 2005 40,000 10,000
6.73%-6.75% 2006 40,000 20,000
7.06%-8.125% 2007 106,500 106,500
7.54%-7.62% 2017 40,700 40,700
6.59%-6.84% 2018 33,000 33,000
7.61%-9.95% 2019-2021 73,000 73,000
7.72% 2027 30,000 30,000
----------- -----------
664,200 444,200
----------- -----------
Other Obligations:...... 7.44% 1999 -- 15,000
8.00% 1999 -- 3,351
7.11% 2001 57,125 --
7.11% 2002 171,375 --
6.00%-11.00% 2000-2002 819 193
9.65% 2002(1) 3,437 4,441
Unamortized premium and
discount, net.......... (4,043) (4,315)
Current maturities of
long-term debt......... (48,937) (80,822)
----------- -----------
Total long-term debt.... 2,124,898 1,746,562
Variable Rate Demand
Bonds(2)............... 158,430 125,100
----------- -----------
Total long-term debt and
Variable Rate Demand
Bonds.................. $ 2,283,328 $ 1,871,662
=========== ===========
- --------
(1) Repaid through monthly payments of principal and interest over 15 years
ending November 2002.
II-64
(2) The debt obligations of Conectiv's subsidiaries included VRDB in the
amounts of $158.4 million and $125.1 million as of December 31, 1999 and
1998, respectively. The VRDB are classified as current liabilities because
the VRDB are due on demand by the bondholder. However, bonds submitted to
Conectiv's subsidiaries for purchase are remarketed by a remarketing agent
on a best efforts basis. Management expects that bonds submitted for pur-
chase will continue to be remarketed successfully due to the credit wor-
thiness of Conectiv's subsidiaries and the bonds' interest rates being set
at market. Conectiv's subsidiaries also may utilize one of the fixed
rate/fixed term conversion options of the bonds. Thus, management consid-
ers the VRDB to be a source of long-term financing. The $158.4 million
balance of VRDB outstanding as of December 31, 1999, matures in 2009
($12.5 million), 2014 ($18.2 million), 2017 ($30.4 million), 2024 ($33.33
million); 2028 ($15.5 million), 2029 ($30.0 million) and 2031 ($18.5 mil-
lion). Average annual interest rates on the VRDB were 3.3% in 1999 and
3.4% in 1998.
NOTE 20. FAIR VALUE OF FINANCIAL INSTRUMENTS
The year-end fair values of certain financial instruments are listed below.
The fair values were based on quoted market prices of Conectiv's securities or
securities with similar characteristics.
1999 1998
--------------------- ---------------------
Carrying Fair Carrying Fair
Amount Value Amount Value
---------- ---------- ---------- ----------
(Dollars in Thousands)
Funds held by trustee............. $ 173,247 $ 173,247 $ 174,509 $ 174,509
Preferred stock of subsidiaries
subject to mandatory redemption.. $ 188,950 $ 163,900 $ 188,950 $ 194,178
Long-term debt.................... $2,124,898 $2,075,510 $1,746,562 $1,878,044
NOTE 21. LONG-TERM PURCHASED POWER CONTRACTS
As of December 31, 1999, ACE's and DPL's commitments under long-term pur-
chased power contracts were as follows: ACE-708 MW of capacity; DPL-243 MW of
capacity; and DPL-100 MWH of firm electricity per hour. As discussed in Note 6
to the Consolidated Financial Statements, the net present value of expected
losses under uneconomic purchased power contracts was included in the extraor-
dinary item in the third quarter of 1999. Historical information is presented
below for these contracts (including ACE from March 1, 1998 forward) and also
includes amounts for the 116 MW NUG purchased power contract which was termi-
nated on December 28, 1999, as discussed in Note 10 to the Consolidated Finan-
cial Statements.
1999 1998 1997
------ ------ -----
Percent of system capacity............................ 16.8% 17.6% 6.4%
Percent of energy output.............................. 23.4% 26.2% 12.1%
Capacity charges ($ in millions)...................... $200.6 $182.7 $28.5
Energy charges ($ in millions)........................ $144.4 $166.5 $38.1
Based on existing contracts as of December 31, 1999, Conectiv's commitments
during the next five years for capacity and energy under long-term purchased
power contracts are estimated to be $312.6 million in 2000; $306.1 million in
2001; $310.2 million in 2002; $314.5 million in 2003; and $319.0 million in
2004.
The terms of DPL's wholly-owned power plant sale agreement discussed in Note
13 to the Consolidated Financial Statements provide for DPL to purchase from
NRG Energy, Inc. 500 MWH of firm electricity per hour from completion of the
sale through December 31, 2005. DPL expects to use electricity purchased under
this agreement and other purchased power agreements to fulfill its obligations
in Delaware and Maryland as a default service provider. Recently, DPL entered
into an agreement to purchase 350 MW of capacity and energy from PECO from
March 2000 to February 2003. These planned power purchases are excluded from
the commitments discussed above.
II-65
NOTE 22. LEASES
Nuclear Fuel
The ownership interests of DPL and ACE in nuclear fuel at Peach Bottom, Sa-
lem, and Hope Creek are financed through nuclear fuel energy contracts, which
are accounted for as capital leases. Payments under the contracts are based on
the quantity of nuclear fuel burned by the plants. The obligations of DPL and
ACE under the contracts are generally the net book values of the nuclear fuel
financed, which was $56.0 million, in total, as of December 31, 1999. As dis-
cussed in Note 13 to the Consolidated Financial Statements, under sales agree-
ments for the nuclear power plants which are pending completion, the nuclear
fuel is to be sold at its net book value, in conjunction with the sale of the
plants.
Lease Commitments
DPL leases an 11.9% interest in the Merrill Creek Reservoir. The lease is an
operating lease and payments over the remaining lease term, which ends in
2032, are $167.6 million in aggregate. As discussed in Note 6 to the Consoli-
dated Financial Statements, the net present value of water-supply capacity
from the Merrill Creek Reservoir in excess of the electric generating plants'
requirements was included in the extraordinary item in the third quarter of
1999. DPL, ACE and other Conectiv subsidiaries also have long-term leases for
certain other facilities and equipment. Minimum commitments as of December 31,
1999, under the Merrill Creek Reservoir lease and other lease agreements (ex-
cluding payments under the nuclear fuel energy contracts, which cannot be rea-
sonably estimated) are as follows: 2000--$19.7 million; 2001--$19.7 million;
2002--$19.7 million; 2003--$21.7 million; 2004--$19.1 million; after 2004--
$162.9 million; total--$262.8 million.
Rentals Charged To Operating Expenses
The following amounts were charged to operating expenses for rental payments
under both capital and operating leases.
1999 1998 1997
------- ------- -------
(Dollars in Thousands)
Interest on capital leases.......................... $ 2,466 $ 2,468 $ 1,548
Amortization of capital leases...................... 24,237 19,554 6,499
Operating leases.................................... 22,344 17,443 11,590
------- ------- -------
$49,047 $39,465 $19,637
======= ======= =======
Leveraged Leases
The leveraged leases of Conectiv's subsidiaries included five aircraft
leases and two containership leases as of December 31, 1999 and 1998. During
1999, declines in the estimated residual values of the airplanes and cargo
container-ships leased by Conectiv's subsidiaries to third parties under
leveraged leases resulted in a write-down of the investments in leveraged
leases by $43.7 million before taxes ($26.7 million after taxes). The net in-
vestment in leveraged leases as of December 31, 1999, and 1998 was as follows:
1999 1998
-------- --------
(Dollars in
Thousands)
Rentals receivable (net of principal and interest on
nonrecourse debt).................................... $ 66,771 $ 75,014
Estimated residual value.............................. 9,234 75,944
Unearned and deferred income.......................... (3,844) (28,702)
-------- --------
Investment in leveraged leases........................ 72,161 122,256
Deferred income tax liability......................... 87,669 116,481
-------- --------
Net investment in leveraged leases.................... $(15,508) $ 5,775
======== ========
II-66
NOTE 23. PENSION AND OTHER POSTRETIREMENT BENEFITS
Assumptions
1999 1998 1997
----- ----- -----
Discount rates used to determine projected benefit
obligation as of December 31........................... 7.75% 6.75% 7.00%
Expected long-term rates of return on assets............ 9.00% 9.00% 9.00%
Rates of increase in compensation levels................ 4.50% 4.50% 5.00%
Health care cost trend rate on covered charges.......... 6.50% 7.00% 7.50%
The health-care cost trend rate, or the expected rate of increase in health-
care costs, is assumed to gradually decrease to 5.0% by 2002. Increasing the
health-care cost trend rates of future years by one percentage point would in-
crease the accumulated postretirement benefit obligation by $15.9 million and
would increase annual aggregate service and interest costs by $1.8 million.
Decreasing the health-care cost trend rates of future years by one percentage
point would decrease the accumulated postretirement benefit obligation by
$14.0 million and would decrease annual aggregate service and interest costs
by $1.6 million.
The following schedules reconcile the beginning and ending balances of the
pension and other postretirement benefit obligations and related plan assets
for Conectiv. Other postretirement benefits include medical benefits for re-
tirees and their spouses and retiree life insurance.
Change in Benefit Obligation
Other Postretirement
Pension Benefits Benefits
------------------- ----------------------
1999 1998 1999 1998
-------- --------- ---------- ----------
(Dollars in Thousands)
Benefit obligation at beginning
of year......................... $748,689 $ 515,590 $ 232,374 $ 80,500
Merger with Atlantic............. -- 316,700 -- 125,300
Service cost..................... 20,288 20,193 5,282 5,828
Interest cost.................... 51,442 51,721 13,839 15,105
Plan participants' contribu-
tions........................... -- -- 500 497
Plan amendments.................. -- (21,392) -- --
Actuarial (gain) loss............ (75,244) 59,046 (43,861) (2,863)
Special termination benefits..... -- 59,610 -- 2,682
Curtailment (gain) loss.......... -- (10,256) -- 6,614
Settlement (gain) loss........... -- (45,291) -- 6,457
Benefits paid.................... (64,671) (197,232) (9,436) (7,746)
Other............................ (7,409) -- (4,667) --
-------- --------- ---------- ----------
Benefit obligation at end of
year............................ $673,095 $ 748,689 $ 194,031 $ 232,374
======== ========= ========== ==========
II-67
Change in Plan Assets
Other Postretirement
Pension Benefits Benefits
-------------------- ----------------------
1999 1998 1999 1998
---------- -------- ---------- ----------
(Dollars in Thousands)
Fair value of assets at beginning
of year......................... $ 951,474 $771,257 $ 95,164 $ 48,591
Merger with Atlantic............. -- 260,200 -- 19,700
Actual return on plan assets..... 138,450 117,249 13,494 6,263
Employer contributions........... -- -- 25,017 27,859
Plan participant contributions... -- -- 500 497
Benefits paid.................... (64,671) (197,232) (9,436) (7,746)
Other............................ (7,409) -- (4,667) --
---------- -------- ---------- ---------
Fair value of assets at end of
year............................ $1,017,844 $951,474 $ 120,072 $ 95,164
========== ======== ========== =========
Reconciliation of Funded Status of the Plans
Other Postretirement
Pension Benefits Benefits
-------------------- ---------------------
1999 1998 1999 1998
--------- --------- ---------- ----------
(Dollars in Thousands)
Funded status at end of year..... $ 344,749 $ 202,785 $ (73,959) $ (137,210)
Unrecognized net actuarial
(gain).......................... (300,864) (173,243) (63,286) (9,094)
Unrecognized prior service cost.. 4,129 2,361 198 248
Unrecognized net transition (as-
set) obligation................. (13,009) (15,773) 40,659 43,787
--------- --------- --------- ----------
Net amount recognized at end of
year............................ $ 35,005 $ 16,130 $ (96,388) $ (102,269)
========= ========= ========= ==========
Based on fair values as of December 31, 1999, the pension plan assets were
comprised of publicly traded equity securities ($723.5 million or 71.1%) and
fixed income obligations ($294.3 million or 28.9%). Based on fair values as of
December 31, 1999, the other postretirement benefit plan assets included eq-
uity securities ($74.8 million or 62.3%) and fixed income obligations ($45.3
million or 37.3%).
Components of Net Periodic Benefit Cost
Other Postretirement
Pension Benefits Benefits
---------------------------- -------------------------
1999 1998 1997 1999 1998 1997
-------- -------- -------- ------- ------- -------
(Dollars in Thousands)
Service cost............ $ 20,288 $ 18,933 $ 12,779 $ 5,282 $ 5,221 $ 2,393
Interest cost........... 51,442 48,291 34,173 13,839 13,636 5,547
Expected return on
assets................. (83,999) (81,259) (60,020) (6,769) (4,845) (2,580)
Amortization of:
Transition obligation
(asset).............. (2,764) (2,764) (3,314) 3,128 3,244 3,617
Prior service cost.... 406 1,911 2,035 49 50 53
Actuarial (gain)...... (4,248) (9,165) (7,814) (1,059) (567) (712)
-------- -------- -------- ------- ------- -------
Benefit cost before
items below............ (18,875) (24,053) (22,161) 14,470 16,739 8,318
Special termination
benefits............... -- 59,610 -- -- 2,682 --
Curtailment (gain)
loss................... -- (10,256) -- -- 6,614 --
Settlement (gain) loss.. -- (45,291) -- -- 6,457 --
-------- -------- -------- ------- ------- -------
Total net periodic
benefit cost........... $(18,875) $(19,990) $(22,161) $14,470 $32,492 $ 8,318
======== ======== ======== ======= ======= =======
Portion of net periodic
benefit cost included
in results of
operations............. $(13,892) $(22,258) $(16,621) $10,935 $20,440 $ 6,239
======== ======== ======== ======= ======= =======
II-68
The special termination benefits and curtailment and settlement gains and
losses shown above for 1998 resulted from Merger-related employee separation
programs discussed in Note 5 to the Consolidated Financial Statements.
Conectiv also maintains 401(k) savings plans for covered employees. Conectiv
contributes to the plan, in the form of Conectiv stock, at varying levels up
to $0.50 for each dollar contributed by employees, up to 6% of employee base
pay. The amount expensed for Conectiv's matching contributions was $5.6 mil-
lion in 1999, $4.9 million in 1998, and $3.0 million in 1997.
NOTE 24. COMMITMENTS AND CONTINGENCIES
Commitments
Conectiv's expected capital and acquisition expenditures are estimated to be
approximately $375 million to $400 million in 2000.
See Note 21 to the Consolidated Financial Statements for commitments related
to long-term purchased power contracts and Note 22 to the Consolidated Finan-
cial Statements for commitments related to leases.
Environmental Matters
Conectiv's subsidiaries are subject to regulation with respect to the envi-
ronmental effects of their operations, including air and water quality con-
trol, solid and hazardous waste disposal, and limitations on land use by vari-
ous federal, regional, state, and local authorities. Federal and state stat-
utes authorize governmental agencies to compel responsible parties to clean up
certain abandoned or uncontrolled hazardous waste sites. Costs may be incurred
to clean up facilities found to be contaminated due to past disposal practic-
es. Conectiv's current liabilities include $3.0 million as of December 31,
1999, and 1998, respectively, for potential clean-up and other costs related
to sites at which a Conectiv subsidiary is a potentially responsible party or
alleged to be a third party contributor. Conectiv does not expect such future
costs to have a material effect on its financial position or results of opera-
tions.
Nuclear Insurance
In conjunction with the ownership interests of DPL and ACE in Peach Bottom,
Salem, and Hope Creek, they 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), they could be assessed up to $57.0 million on an aggregate
basis for such third-party claims. In addition, Congress could impose a reve-
nue-raising measure on the nuclear industry to pay such claims.
The co-owners of Peach Bottom, Salem, and Hope Creek maintain property in-
surance coverage of approximately $2.8 billion for each unit for loss or dam-
age to the units, including coverage for decontamination expense and premature
decommissioning. In addition, Conectiv is a member of an industry mutual in-
surance company, which provides replacement power cost coverage in the event
of a major accidental outage at a nuclear power plant. Under these coverages,
Conectiv is subject to potential retrospective loss experience assessments of
up to $7.3 million on an aggregate basis.
II-69
NOTE 25. BUSINESS SEGMENTS
The following information is presented in accordance with SFAS No. 131,
"Disclosures about Segments of an Enterprise and Related Information." In ac-
cordance with SFAS No. 131, Conectiv's business segments were determined from
Conectiv's internal organization and management reporting, which are based
primarily on differences in products and services. Conectiv's business seg-
ments under SFAS No. 131 are as follows: "Energy"--generates, purchases, and
sells electricity (includes trading activities), also operates power plants
and thermal heating and cooling systems; "Power Delivery"--delivers electric-
ity and gas to customers at regulated prices over transmission and distribu-
tion systems; "Telecommunications"--represents services provided by Conectiv
Communications Inc. (CCI), including local and long-distance telephone service
and Internet services; "HVAC"--represents heating, ventilation, and air condi-
tioning (HVAC) services provided by Conectiv Services, Inc. (CSI). Segment in-
formation for 1998 and 1997 has been restated to conform with the current pre-
sentation.
All revenues of Conectiv's business segments are from customers located in
the United States. Also, all assets of Conectiv's business segments are lo-
cated in the United States.
As discussed in Note 9 to the Consolidated Financial Statements, Conectiv's
electricity supply businesses were deregulated in the third quarter of 1999.
Prior to deregulation, billings to electric customers included unspecified
amounts for electricity supply and delivery; during this period revenues were
allocated directly to the Energy and Power Delivery business segments based on
the cost of services provided.
The services provided by one business segment to another business segment
are recorded as a transfer of costs, based on the fully-distributed cost of
the service provided. Common services which are shared by the business units
(shared services) are assigned directly or allocated based on various cost
causative factors, depending on the nature of the service provided. The depre-
ciation associated with shared services' assets is allocated to the business
segments; however, the assets and related capital expenditures are not allo-
cated.
The business segments' operating results are evaluated based on "earnings
before interest and income taxes," which is generally equivalent to Operating
Income plus Other Income, less certain interest charges allocated to the busi-
ness segments. "Earnings before interest and income taxes" for 1999 and 1998
exclude the "Special charges" which are discussed in Note 5 to the Consoli-
dated Financial Statements. "All Other" business segments' "earnings before
interest and income taxes" for 1999 includes $42.1 million from equity in
earnings of Enertech as discussed in Note 7 to the Consolidated Financial
Statements. "Earnings before interest and income taxes" for 1998 includes the
January and February 1998 (pre-Merger) operating results of the former Atlan-
tic-owned companies. "Earnings before interest and income taxes" for the En-
ergy business segment in 1998 includes $17.7 million of equity in earnings of
a nonutility generation joint venture. "Earnings before interest and income
taxes" for 1997 excludes the gain on the sale of the Pine Grove landfill and
its related waste-hauling company, which is discussed in Note 7 to the Consol-
idated Financial Statements.
II-70
For internal management reporting purposes, Investments and Property, Plant
and Equipment are assigned to business segments, but Current Assets and De-
ferred Charges and Other Assets are not.
As of
Year Ended December 31, 1999 December 31, 1999
-------------------------------------------------------- -----------------
Depreciation Earnings Investments and
and Before Interest Capital Property, Plant
Business Segments Revenues Amortization and Taxes Expenditures & Equipment
- ----------------- ---------- ------------ --------------- ------------ -----------------
(Dollars in Thousands)
Energy.................. $3,002,736 $132,538 $271,181 $ 88,677 $1,064,159
Power Delivery.......... 765,551 91,519 260,835 115,273 2,223,571
Telecommunications...... 36,253 5,229 (43,344) 54,798 116,101
HVAC.................... 134,942 3,316 (13,655) 1,172 21,623
All Other............... 6,470 2,981 34,339 17,316 288,229
---------- -------- -------- -------- ----------
$3,945,952(1) $235,583(2) $509,356(3) $277,236(4) $3,713,683(5)
========== ======== ======== ======== ==========
- --------
(1) Includes intercompany revenues which are eliminated in consolidation as
follows: Energy business segment--$195,498; Telecommunications--$4,482;
All Other business segments--$1,075.
(2) Excludes $7,073 of goodwill amortization pursuant to the Merger and
$28,692 of depreciation classified in business segment operating expenses
which are included in consolidated depreciation and amortization expense.
(3) The following items are subtracted from "earnings before interest and in-
come taxes" to arrive at consolidated income before income taxes and ex-
traordinary item: (a) $182,451 of interest expense and preferred stock
dividends, (b) $105,648 of Special Charges, which are discussed in Note 5
to the Consolidated Financial Statements, and (c) $1,863 of net Merger-re-
lated consolidation adjustments.
(4) Consolidated capital expenditures of $320,395 include $43,159 of shared
services' capital expenditures which are excluded above.
(5) Excludes $273,972 of shared services' property, plant & equipment and cer-
tain investments, all Current Assets ($793,995), and all Deferred Charges
and Other Assets ($1,356,812) which are included in total consolidated as-
sets of $6,138,462. Amounts invested in equity method investees as of De-
cember 31, 1999 were $60,371 by Energy and $26,601 by All Other business
segments.
As of
Year Ended December 31, 1998 December 31, 1998
-------------------------------------------------------- -----------------
Depreciation Earnings Investments and
and Before Interest Capital Property, Plant
Business Segments Revenues Amortization and Taxes Expenditures & Equipment
- ----------------- ---------- ------------ --------------- ------------ -----------------
(Dollars in Thousands)
Energy.................. $2,450,274 $130,863 $267,463 $ 41,254 $1,985,956
Power Delivery.......... 666,894 88,612 256,886 102,651 2,139,111
Telecommunications...... 10,620 2,992 (29,591) 25,814 66,751
HVAC.................... 94,907 1,984 (21,676) 955 45,622
All Other............... 14,096 3,781 (9,570) 13,919 316,264
---------- -------- -------- -------- ----------
$3,236,791(1) $228,232(2) $463,512(3) $184,593(4) $4,553,704(5)
========== ======== ======== ======== ==========
- --------
(1) Includes $165,185 of revenues for January to February 1998 of the formerly
Atlantic-owned companies which are excluded from consolidated revenues of
$3,071,606.
(2) Includes $14,629 of depreciation for January to February 1998 of the for-
merly Atlantic-owned companies which is excluded from consolidated depre-
ciation expense of $241,420. Excludes $6,174 of goodwill amortization pur-
suant to the Merger and $21,643 of depreciation classified in business
segment operating expenses which are included in consolidated depreciation
and amortization expense.
(3) The following items are subtracted from "earnings before interest and tax-
es" to arrive at consolidated income before income taxes and extraordinary
item: (a) $20,914 for the January to February 1998 "earnings before inter-
est and taxes" of the formerly Atlantic-owned companies; (b) $27,704 of
employee separation
II-71
and other Merger-related costs; (c) $154,044 of interest expense and pre-
ferred stock dividends; and (d) $1,832 of net Merger-related consolidation
adjustments.
(4) Consolidated capital expenditures of $224,831 include $53,862 of shared
services' capital expenditures which are excluded above and exclude
$13,624 of January to February 1998 capital expenditures of the formerly
Atlantic-owned companies which are included above.
(5) Excludes $314,361 of shared services' property, plant & equipment and cer-
tain investments, all Current Assets ($723,872), and all Deferred Charges
and Other Assets ($495,737) which are included in total consolidated as-
sets of $6,087,674. Amounts invested in equity method investees as of De-
cember 31, 1998 were $62,420 by Energy and $15,854 by All Other business
segments.
As of
Year Ended December 31, 1997 December 31, 1997
----------------------------------------------------- ------------------
Depreciation Earnings Investments and
and Before Interest Capital Property, Plant
Business Segments Revenues Amorization and Taxes Expenditures & Equipment
- ----------------- ---------- ------------ --------------- ------------ ------------------
(Dollars in Thousands)
Energy.................. $ 955,676 $ 63,554 $117,187 $ 27,579 $ 969,900
Power Delivery.......... 351,454 49,292 133,359 76,581 1,145,872
Telecommunications...... 1,671 697 (9,510) 35,198 43,989
HVAC.................... 64,928 1,747 (10,515) 3,074 21,298
All Other............... 41,638 5,704 10,522 3,708 65,683
---------- -------- -------- -------- ----------
$1,415,367 $120,994(1) $241,043(2) $146,140(3) $2,246,742(4)
========== ======== ======== ======== ==========
- --------
(1) Excludes $15,346 of depreciation expense classified in business segment
operating expenses which is included in total consolidated depreciation
and amortization expense of $136,340.
(2) Excludes the $22,910 pre-tax gain on the sale of the Pine Grove landfill
and waste-hauling company and $90,580 of interest expense and preferred
stock dividends which are reflected in consolidated income before income
taxes and extraordinary item.
(3) Excludes $10,668 of shared services' capital expenditures included in con-
solidated capital expenditures of $156,808.
(4) Excludes $181,435 of shared services' property, plant & equipment and cer-
tain investments, all Current Assets ($340,891), and all Deferred Charges
and Other Assets ($246,413) which are included in total consolidated as-
sets of $3,015,481.
II-72
NOTE 26. QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
The quarterly data presented below reflect all adjustments necessary in the
opinion of Conectiv management for a fair presentation of the interim results.
Quarterly data normally vary seasonally because of temperature variations,
differences between summer and winter rates, the timing of rate orders, and
the scheduled downtime and maintenance of electric generating units.
1999
--------------------------------------------------
First Second Third Fourth
Quarter Quarter Quarter Quarter Year
-------- -------- ---------- -------- ----------
(Dollars in Thousands, Except Per Share Amounts)
Operating Revenues........ $946,585 $802,480 $1,080,412 $915,420 $3,744,897
Operating Income.......... 102,538 85,858 107,333 49,860 345,589
Income Before
Extraordinary Item....... 48,695 31,359 20,239 13,285 113,578
Extraordinary Item(1)..... -- -- (271,106) (40,612) (311,718)
Net Income (Loss)......... 48,695 31,359 (250,867) (27,327) (198,140)
Earnings (Loss) Per Common
Share
Before Extraordinary
Item................... 0.47 0.31 0.15 0.19 1.14
Extraordinary Item...... -- -- (3.04) (0.34) (3.16)
Earnings (Loss) Per Class
A Common Share
Before Extraordinary
Item................... 0.20 0.20 1.25 (0.51) 1.14
Extraordinary Item...... -- -- (0.83) (1.93) (2.71)
- --------
(1) For information concerning the extraordinary item recorded in the third
and fourth quarters of 1999, see Note 6 to the Consolidated Financial
Statements.
As discussed in Note 5 to the Consolidated Financial Statements, special
charges were recorded in the third quarter of 1999 primarily for write-downs
of investments in non-utility businesses and accrued employee separation
costs. These special charges decreased operating income by $105.6 million, in-
come before extraordinary item by $71.6 million, third quarter 1999 earnings
per share of common stock by $0.80, and third quarter 1999 earnings per share
of Class A common stock by $0.30.
As discussed in Note 7 to the Consolidated Financial Statements, Conectiv
recorded investment income in 1999 for equity in the earnings of the Enertech
venture capital fund. This investment income increased (a) income before ex-
traordinary item and earnings per share of common stock in the first quarter
of 1999 by $9.4 million and $0.09, respectively, and (b) income before ex-
traordinary item and earnings per share of common stock in the fourth quarter
of 1999 by $14.2 million and $0.16, respectively,
1998
-------------------------------------------------
First Second Third Fourth
Quarter Quarter Quarter Quarter Year
-------- -------- ---------- -------- ----------
(Dollars in Thousands, Except Per Share Amounts)
Operating Revenues.......... $503,591 $684,039 $1,012,479 $871,497 $3,071,606
Operating Income............ 22,163 109,429 200,755 54,568 386,915
Net Income (Loss)........... (3,978) 39,344 93,668 24,167 153,201
Earnings (Loss) Per Common
Share...................... (0.06) 0.37 0.83 0.24 1.50
Earnings (Loss) Per Class A
Common Share............... 0.02 0.31 1.44 0.04 1.82
As discussed in Note 5 to the Consolidated Financial Statements, special
charges for the cost of DPL employee separations associated with the Merger-
related workforce reduction and other Merger-related costs were recorded in
1998. These special charges caused (a) operating income, net income, and earn-
ings per share of common stock to decrease by $40.6 million, $24.6 million,
and $0.33, respectively, in the first quarter of 1998, and (b) operating in-
come, net income, and earnings per share of common stock to increase by $14.3
million $8.6 million, and $0.09, respectively, in the second quarter of 1998.
II-73
The total of 1999 and 1998 quarterly earnings per share does not equal an-
nual earnings per share for 1999 and 1998, respectively, due to different
amounts for average quarterly common shares outstanding. The quarterly average
number of common shares and Class A common shares outstanding during 1999 and
1998 are presented below.
Average Number of Shares
Outstanding
-----------------------------
Class A
Common Stock Common Stock
--------------- -------------
1999 1998 1999 1998
------- ------- ------ ------
(Thousands of Shares)
First Quarter.................................. 100,532 74,684 6,561 6,561
Second Quarter................................. 98,120 101,063 6,408 6,561
Third Quarter.................................. 87,711 101,011 5,743 6,561
Fourth Quarter................................. 86,916 100,592 5,742 6,561
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
II-74
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
"Proposal No. 1--Election of Directors" is incorporated by reference herein
from the Definitive Proxy Statement which was filed with the SEC on February
22, 2000.
Information about Conectiv's executive officers is included under Item 1.
Information about reporting on Form 4, Statement of Changes in Beneficial
Ownership of Securities, and on Form 5, Annual Statement of Beneficial Owner-
ship of Securities, is incorporated by reference herein from the "Section
16(a) Beneficial Ownership Compliance" section of the Definitive Proxy State-
ment which was filed with the SEC on February 22, 2000.
ITEM 11. EXECUTIVE COMPENSATION
The information required by Item 11 of Form 10-K is incorporated herein by
reference from Conectiv's Definitive Proxy Statement, which was filed with the
SEC on February 22, 2000, except that the Report of the Personnel & Compensa-
tion Committee and the Stock Performance Chart are specifically excluded.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The information required by Item 12 of Form 10-K is set forth under the
heading "Security Ownership of Directors, Executive Officers and Certain Bene-
ficial Owners" in the Definitive Proxy Statement which was filed with the SEC
on February 22, 2000 and is incorporated herein by reference.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information required by Item 13 of Form 10-K is set forth under the
heading "Personnel & Compensation Committee Interlocks and Insider Participa-
tion" in the Definitive Proxy Statement which was filed with the SEC on Febru-
ary 22, 2000 and is incorporated herein by reference.
III-1
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(a) Documents 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-27
Consolidated Statements of Income for the years ended December 31,
1999, 1998, and 1997................................................ II-28
Consolidated Statements of Cash Flows for the years ended December
31, 1999, 1998, and 1997............................................ II-29
Consolidated Balance Sheets as of December 31, 1999 and 1998......... II-30, 31
Consolidated Statements of Changes in Common Stockholders' Equity for
the years ended December 31, 1999, 1998, and 1997................... II-32
Notes to Consolidated Financial Statements........................... II-33
2. Financial Statement Schedules
Schedule I, Condensed Financial Information of Registrant, and Schedule II,
Valuation and Qualifying Accounts, are 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 1
Condensed Financial Information of Registrant
Condensed financial statements of Conectiv, the holding company, are pre-
sented below. Conectiv accounts for its subsidiaries on the equity method of
accounting. Since Conectiv was established through a series of merger transac-
tions on March 1, 1998, the periods presented for the Statements of Income and
Statements of Cash Flows do not include 1997 and January to February of 1998.
Conectiv's $250 million balance of long-term debt matures as follows: $100
million in 2002; $50 million in 2003; $50 million in 2004; $30 million in
2005; and $20 million in 2006. For additional information see Note 19 to the
Consolidated Financial Statements included in Item 8 of Part II.
For information concerning Conectiv's common stock and Class A common stock,
see Notes 16 and 17, respectively, to the Consolidated Financial Statements
included in Item 8 of Part II.
Cash dividends received by Conectiv from consolidated subsidiaries were
$135.7 million in 1999 and $132.4 million in 1998.
IV-1
CONECTIV
STATEMENTS OF INCOME
Year Ended December 31,
-------------------------
1999 1998
------------ -----------
(Dollars in Thousands)
Operating Expenses.................................. $ 2,003 $ 1,639
------------ -----------
Operating Income.................................... (2,003) (1,639)
------------ -----------
Other Income
Equity in earnings of consolidated subsidiaries
excluding extraordinary item..................... 129,209 156,511
Other income...................................... 513 624
------------ -----------
129,722 157,135
------------ -----------
Interest Expense.................................... 22,557 3,914
------------ -----------
Income Before Income Taxes And Extraordinary Item... 105,162 151,582
------------ -----------
Income Tax Benefit, Excluding Income Taxes
Applicable To Extraordinary Item................... (8,416) (1,619)
------------ -----------
Income Before Extraordinary Item.................... 113,578 153,201
------------ -----------
Equity In Extraordinary Item Of Consolidated
Subsidiaries....................................... (311,718) --
------------ -----------
Net Income (Loss)................................... $ (198,140) $ 153,201
============ ===========
As discussed on IV-1, the above amounts are for Conectiv, the holding company;
not Conectiv on a consolidated basis.
IV-2
CONECTIV
STATEMENTS OF CASH FLOWS
Year Ended December 31,
------------------------
1999 1998
----------- -----------
(Dollars in Thousands)
Cash Flows From Operating Activities
Net income (loss).................................. $ (198,140) $ 153,201
Adjustments to reconcile net income to net cash
provided by operating activities
Equity in loss (earnings) of subsidiaries........ 182,509 (156,511)
Net change in:
Accounts receivable............................ 9,742 (16,124)
Taxes accrued.................................. (4,476) 5,903
Other current assets and liabilities........... (2,992) (4,501)
Dividends received from subsidiaries............... 135,691 132,357
Other, net......................................... 2,380 (170)
----------- -----------
Net cash provided by operating activities........ 124,714 114,155
----------- -----------
Cash Flows From Investing Activities
Increase in loans receivable from subsidiaries..... (48,130) (45,456)
Decrease (increase) in notes receivable from
subsidiaries...................................... 16,452 (168,003)
Capital contributions to subsidiaries.............. (39,018) (27,496)
Other, net......................................... 143 239
----------- -----------
Net cash used by investing activities............ (70,553) (240,716)
----------- -----------
Cash Flows From Financing Activities
Common dividends paid.............................. (135,134) (130,451)
Common stock issued................................ 68 --
Common stock redeemed.............................. (390,397) (11,135)
Long-term debt issued.............................. 250,000 --
Long-term debt redeemed............................ -- (53,500)
Net change in short-term debt...................... 210,685 339,000
Costs of issuances and refinancings................ (4,114) 365
----------- -----------
Net cash provided (used) by financing
activities...................................... (68,892) 144,279
----------- -----------
Net change in cash and cash equivalents............ (14,731) 17,718
Beginning of year cash and cash equivalents........ 18,691 973
----------- -----------
End of year cash and cash equivalents.............. $ 3,960 $ 18,691
=========== ===========
As discussed on IV-1, the above amounts are for Conectiv, the holding company;
not Conectiv on a consolidated basis.
IV-3
CONECTIV
BALANCE SHEETS
As of December 31,
---------------------
1999 1998
---------- ----------
(Dollars in
Thousands)
ASSETS
Current Assets
Cash and cash equivalents.............................. $ 3,960 $ 18,691
Dividends receivable from subsidiaries................. 23,536 43,953
Accounts receivable.................................... 600 467
Loans receivable from subsidiaries..................... 136,456 45,456
Other.................................................. 1,838 --
---------- ----------
166,390 108,567
---------- ----------
Investments
Investment in subsidiary companies..................... 1,647,529 1,957,463
Notes receivable from subsidiary companies............. 151,178 176,094
Other investments...................................... 5,675 --
---------- ----------
1,804,382 2,133,557
---------- ----------
Deferred Charges And Other Assets
Unamortized debt expense............................... 1,477 --
Deferred charges....................................... 297 239
---------- ----------
1,774 239
---------- ----------
---------- ----------
Total Assets............................................. $1,972,546 $2,242,363
========== ==========
As discussed on IV-1, the above amounts are for Conectiv, the holding company;
not Conectiv on a consolidated basis.
IV-4
CONECTIV
BALANCE SHEETS
As of December 31,
----------------------
1999 1998
---------- ----------
(Dollars in
Thousands)
CAPITALIZATION AND LIABILITIES
Current Liabilities
Short-term debt...................................... $ 549,685 $ 339,000
Taxes accrued........................................ 8,231 12,707
Dividends payable.................................... 25,983 45,845
Other................................................ 474 1,529
---------- ----------
584,373 399,081
---------- ----------
Deferred income taxes.................................. -- 121
---------- ----------
Capitalization
Common stock: $0.01 per share par value 150,000,000
shares authorized; shares outstanding--86,173,169 in
1999, and 100,516,768 in 1998....................... 863 1,007
Class A common stock, $0.01 par value; 10,000,000
shares authorized; shares outstanding-- 5,742,315 in
1999, 6,560,612 in 1998............................. 57 66
Additional paid-in-capital--common stock............. 1,085,060 1,462,675
Additional paid-in-capital--Class A common stock..... 93,738 107,095
Accumulated deficit/retained earnings................ (36,472) 276,939
---------- ----------
1,143,246 1,847,782
Treasury shares, at cost............................. (3,446) (3,797)
Unearned compensation................................ (1,627) (824)
---------- ----------
Total common stockholders' equity.................... 1,138,173 1,843,161
Long-term debt....................................... 250,000 --
---------- ----------
1,388,173 1,843,161
---------- ----------
Total Capitalization and Liabilities................... $1,972,546 $2,242,363
========== ==========
As discussed on IV-1, the above amounts are for Conectiv, the holding company;
not Conectiv on a consolidated basis.
IV-5
Schedule II
Valuation and Qualifying Accounts
Years Ended December 31, 1999, 1998, 1997
(Dollars in thousands)
Column B Column C Column D Column E
--------- ----------------- ---------- --------
Additions
-----------------
Balance Charged Charged Balance
at to to at
beginning cost and other end of
Description of period expenses accounts Deductions period
- ----------- --------- -------- -------- ---------- --------
1999
Allowance for doubtful
accounts.................. $4,743 $23,917 $1,000 $18,096(b) $11,564
1998
Allowance for doubtful
accounts.................. 196 8,697 3,500(a) 7,650(b) 4,743
1997
Allowance for doubtful
accounts.................. -- 3,344 -- 3,148(b) 196
- --------
(a) Consolidation of ACE's balance due to the Merger discussed in Note 4 to
the Consolidated Financial Statements included in Item 8 of Part II.
(b) Accounts receivable written off.
3. Exhibits
Exhibit
Number
- -------
2 Amended and Restated Agreement and Plan of Merger, dated as of December 26,
1996 between DPL, Atlantic Energy, Inc., Conectiv and DS Sub, Inc. (filed
with Registration Statement No. 333-18843)
3-A Restated Certificate of Incorporation of Conectiv, filed with Delaware
Secretary of State, effective as of March 2, 1998 (filed with Conectiv's
Current Report on Form 8-K dated March 6, 1998)
3-B 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 with Conectiv's Current Report on Form 8-K
dated March 6, 1998)
3-C Certificate of Merger of Atlantic Energy, Inc. with and into Conectiv, Inc.,
filed with the Delaware Secretary of State, effective as of March 1, 1998
(filed with Conectiv's Current Report on Form 8-K dated March 6, 1998)
3-D Certificate of Merger of Atlantic Energy, Inc. with and into Conectiv, Inc.
filed with the New Jersey Secretary of State, effective as of March 1, 1998
(filed with Conectiv's Current Report on Form 8-K dated March 6, 1998)
3-E Certificate of Merger of DS Sub, Inc., a Delaware Corporation with and into
Delmarva Power & Light Company, filed with the Delaware Secretary of State,
effective as of March 1, 1998 (filed with Conectiv's Current Report on Form
8-K dated March 6, 1998)
3-F Certificate of Merger of DS Sub, Inc., a Delaware Corporation with and into
Delmarva Power & Light Company, effective as of March 1, 1998, filed with
the Virginia State Corporation Commission, effective as of March 1, 1998
(filed with Conectiv's Current Report on Form 8-K dated March 6, 1998)
3-G Conectiv's By-Laws as amended February 16, 1999 (filed with Conectiv's 1999
Report on Form 10-K)
IV-6
Exhibit
Number
- -------
10-A Conectiv Incentive Compensation Plan (filed with Conectiv, Inc. Registration
Statement No. 333-18843)
10-B Conectiv Deferred Compensation Plan, effective January 1, 1999 (filed with
Conectiv's 1999 Report on Form 10-K)
10-C Change-in-Control Severance Agreement between Conectiv and certain executive
officers (filed with Conectiv's 1999 Report on Form 10-K)
10-D Change-in-Control Severance Agreement between Conectiv and certain select
employees (filed with Conectiv's 1999 Report on Form 10-K)
10-E Stockholders Rights Agreement between Conectiv and Conectiv Resource
Partners, Inc. as of April 23, 1998 (filed with Conectiv's Current Report on
Form 8-K dated April 22, 1998
12 Ratio of earnings to fixed charges (filed herewith)
21 Subsidiaries of the registrant (filed herewith)
23 Consent of Independent Public Accountants (filed herewith)
27 Financial Data Schedule (filed herewith)
99 Pro Forma Financial Statements -- Generation Asset Sale and Transfer (filed
herewith)
(b) Reports on Form 8-K
The following Reports on Form 8-K were filed in the fourth quarter of 1999:
On October 7, 1999, Conectiv filed a Report on Form 8-K dated September 30,
1999 reporting on Item 5, Other Events, and Item 7 (c), Exhibits.
On October 26, 1999, Conectiv filed a Report on Form 8-K dated October 26,
1999 reporting on Item 5, Other Events.
IV-7
Signatures
Pursuant to the requirements of Section 13 or 15(d) of the Securities Ex-
change Act of 1934 the Registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized, on March 29, 2000.
Conectiv
(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 Regis-
trant and in the capacities indicated, on March 29, 2000.
Signature Title
--------- -----
/s/ Howard E. Cosgrove Chairman of the Board, President, 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/ R. Franklin Balotti Director
___________________________________________
(R. Franklin Balotti)
/s/ Robert D. Burris Director
___________________________________________
(Robert D. Burris)
/s/ Audrey K. Doberstein Director
___________________________________________
(Audrey K. Doberstein)
/s/ Michael B. Emery Director
___________________________________________
(Michael B. Emery)
/s/ Sarah I. Gore Director
___________________________________________
(Sarah I. Gore)
/s/ Jerrold L. Jacobs Director
___________________________________________
(Jerrold L. Jacobs)
/s/ Richard B. McGlynn Director
___________________________________________
(Richard B. McGlynn)
/s/ Bernard J. Morgan Director
___________________________________________
(Bernard J. Morgan)
IV-8
Exhibit Index
Exhibit
Number Description
------- -----------
12 Ratio of Earnings to Fixed Charges
21 Subsidiaries of the registrant
23 Consent of Independent Accountants
27 Financial Data Schedule
99 Pro Forma Information Financial Statements - Generation Asset
Sale and Transfer