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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, 2000
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) 429-3069
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Securities registered pursuant to Section 12(b) of the Act:
Name of each exchange
Title of each class 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, 2000 was $1,730.4 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, 2001
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Common stock, $0.01 par value 82,972,179 shares
Class A common stock, $0.01 par value 5,742,315 shares
Documents Incorporated by Reference
Part of Form 10-K Document Incorporated by Reference
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III Portions of the Preliminary Joint Proxy Statement/Prospectus for New RC Inc.
on Form S-4 which was filed with the Securities and Exchange Commission on
March 14, 2001.
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TABLE OF CONTENTS
Page
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PART I
Item 1.Business
Overview.................................................................. I-1
General.................................................................. I-1
Business Segments........................................................ I-1
Regulation............................................................... I-2
Sources of Revenues...................................................... I-2
Certain Business Focus Changes During 2000............................... I-3
Earnings Outlook......................................................... I-3
Power Delivery............................................................ I-3
Energy.................................................................... I-3
Electric Utility Industry Restructuring.................................. I-4
Basic Generation Service................................................. I-4
Default Service.......................................................... I-4
Conectiv Energy Holding Company.......................................... I-4
Mid-merit Electric Generation............................................ I-5
Agreements for the Sales of Electric Generating Plants................... I-5
Telecommunications........................................................ I-6
HVAC...................................................................... I-7
Other Businesses.......................................................... I-7
Capacity.................................................................. I-7
Electric Generating Plants............................................... I-7
Purchased Power.......................................................... I-8
Supplying Forecasted Peak Loads.......................................... I-8
PJM Interconnection, L.L.C. .............................................. I-8
Nuclear Power Plants...................................................... I-9
Fuel Supply for Electric Generation....................................... I-9
Coal..................................................................... I-10
Oil...................................................................... I-10
Gas...................................................................... I-10
Nuclear.................................................................. I-10
Energy Adjustment Clauses................................................. I-11
Retail Electric Rates..................................................... I-11
Customer Billing.......................................................... I-12
New Jersey Electric System Reliability Standards.......................... 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-14
Air Quality Regulations.................................................. I-14
Water Quality Regulations................................................ I-15
Hazardous Substances..................................................... I-16
Executive Officers........................................................ I-17
Item 2.Properties.......................................................... I-18
Item 3.Legal Proceedings................................................... I-19
Item 4.Submission of Matters to a Vote of Security Holders................. I-19
i
Page
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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-26
Item 8.Financial Statements and Supplementary Data...................... II-28
Item 9. Changes in and Disagreements with Accountants on Accounting and
Financial Disclosure............................................ II-81
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-9
ii
ITEM 1. BUSINESS
Overview
General
Conectiv was formed on March 1, 1998 (the 1998 Merger), through a series of
merger transactions and an exchange of common stock with Delmarva Power &
Light Company (DPL) and Atlantic Energy, Inc. (Atlantic). For additional in-
formation about the 1998 Merger, refer to Note 4 to the Consolidated Financial
Statements included in Item 8 of Part II. As used in this document, references
to Conectiv may mean the activities of one or more subsidiaries. Conectiv's
primary businesses are the supply and delivery of electricity and gas in mar-
kets subject to price regulation ("regulated") and the supply and trading of
electricity and gas in markets not subject to price regulation ("non-regulat-
ed"). These businesses, particularly the regulated businesses, are weather
sensitive and seasonal because sales of electricity are usually higher during
the summer months, due to air conditioning usage, and natural gas sales are
usually higher in the winter when gas is used for space-heating.
On February 9, 2001, the Boards of Directors of Conectiv and Potomac Elec-
tric Power Company (Pepco) approved an Agreement and Plan of Merger
(Conectiv/Pepco Merger Agreement) under which Pepco will acquire Conectiv for
a combination of cash and stock. The transaction is subject to various statu-
tory and regulatory approvals and approval by the stockholders of Conectiv and
Pepco. For information about the Conectiv/Pepco Merger Agreement, see Note 5
to the Consolidated Financial Statements included in Item 8 of Part II or
"Agreement For The Acquisition Of Conectiv" in Management's Discussion and
Analysis of Financial Condition and Results of Operations (MD&A) included in
Item 7 of Part II.
Conectiv's two largest subsidiaries, DPL and Atlantic City Electric Company
(ACE), are public utilities that supply and deliver electricity to their cus-
tomers under the trade name Conectiv Power Delivery. A 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. Substantially all of the
customers of DPL and ACE can now elect to choose an alternative electricity
supplier. DPL also supplies and delivers natural gas to its customers.
Conectiv Energy Holding Company (CEH) was formed during 2000. CEH and its sub-
sidiaries are engaged in non-regulated electricity production and sales, en-
ergy trading and marketing.
Conectiv is changing the types of electric generating plants it owns. Based
on megawatts (MW) of generating capacity, approximately 54% (2,203.5 MW) of
the electric generating plants owned by Conectiv as of December 31, 2000
(4,079.5 MW) were under agreements for sale. Conectiv is also building new
"mid-merit" electric generating plants, which management expects will provide
a better strategic fit with Conectiv's energy trading activities and have more
profitable operating characteristics than the plants to be sold. See "Mid-
merit Electric Generation" beginning on I-5 for additional information.
At December 31, 2000, Conectiv had 3,573 employees, including 1,871 employ-
ees represented by labor organizations. The number of employees as of December
31, 2000 decreased by 1,274 from December 31, 1999, primarily due to the sale
of the heating, ventilation, and cooling (HVAC) businesses in 2000 and staff-
ing reductions for the telecommunications businesses of Conectiv Communica-
tions, Inc. (CCI).
Business Segments
A brief description of Conectiv's business segments is presented below. Also
see the more detailed discussions about the business segments, which begin on
page I-3 within Part I and see Note 27 to Conectiv's Consolidated Financial
Statements included in Item 8 of Part II for financial information about the
business segments.
"Power Delivery" includes activities related to delivery of electricity and
gas to customers at regulated prices over transmission and distribution sys-
tems. The Power Delivery business is conducted by DPL and ACE.
I-1
"Energy" includes (a) the generation, purchase, trading and sale of elec-
tricity, including the obligations of DPL and ACE to supply electricity to
customers who do not choose an alternative electricity supplier; (b) gas and
other energy supply and trading activities, (c) power plant operation servic-
es, and (d) district heating and cooling systems operation and construction
services provided by Conectiv Thermal Systems, Inc. (CTS).
"Telecommunications" represents services provided by CCI, including local
and long-distance telephone service and Internet services.
"HVAC" represents heating, ventilation, and air conditioning services, which
were provided by Conectiv Services, Inc. (CSI) prior to the sale of this busi-
ness in the latter half of 2000.
Regulation
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. The costs of CRP are directly assigned
and allocated to the Conectiv subsidiaries.
Certain aspects of Conectiv's electric and gas utility businesses are sub-
ject 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 En-
ergy Regulatory Commission (FERC). As discussed below and under "Energy" be-
ginning on page I-3, the nature of regulation of retail electricity sales by
these regulatory commissions changed during 1999. Retail gas sales are subject
to regulation by the DPSC. Excluding sales not subject to price regulation,
the percentages of retail electric and gas utility operating revenues regu-
lated by each regulatory commission for the year ended December 31, 2000, were
as follows: NJBPU, 45.9%; DPSC, 34.0%; MPSC, 18.4%; and VSCC, 1.7%. Wholesale
electricity sales are subject to FERC regulation.
Sources of Revenues
The sources of Conectiv's consolidated revenues on a percentage basis are
shown in the table below. Regulated electric and gas revenues include the sup-
ply and delivery of these commodities within the service areas of DPL and ACE.
2000 1999 1998
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Regulated electric revenues *........................... 39.8% 57.4% 62.4%
Non-regulated electric revenues......................... 18.0 8.3 9.3
Regulated gas revenues.................................. 2.2 3.1 3.5
Non-regulated gas revenues.............................. 28.2 18.7 13.9
Other services.......................................... 11.8 12.5 10.9
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Total revenues.......................................... 100.0% 100.0% 100.0%
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* In 2000, Conectiv's consolidated regulated electric retail revenues were
earned from the following customer classes: residential--48.0%; commer-
cial--37.2%; industrial--12.4%; and other--2.4%.
During 1998-2000, the percentage of Conectiv's revenues provided by non-reg-
ulated electricity and gas sales have increased and the percentage of
Conectiv's revenues provided by regulated electricity and gas sales have de-
creased. This change in the composition of Conectiv's revenues has primarily
resulted from growth of Conectiv's energy trading activities, deregulation of
Conectiv's electric generating plants in 1999, customers within the service
areas of DPL and ACE choosing alternative suppliers, and rate reductions asso-
ciated with restructuring the electric utility industry. The business activi-
ties included in "other services" revenues are telecommunications, HVAC, pe-
troleum sales, and other activities.
I-2
Certain Business Focus Changes During 2000
During mid- to late-2000, Conectiv sold its HVAC business and portions of
CTS, which constructs and operates district heating and cooling systems.
Conectiv also began exiting from the competitive retail energy business (the
supply of electricity and gas in deregulated retail markets). In addition,
Conectiv initiated a process in 2000 to identify a strategic partner for CCI.
Due to weaknesses in the valuations of telecommunications businesses, Conectiv
continues to evaluate its partnering or other options.
Earnings Outlook
Conectiv's businesses have undergone significant change during 2000 and are
expected to continue to change. Among other things, deregulated electricity
generation and energy trading now constitute a greater portion of Conectiv's
earnings. The sale of the HVAC businesses during 2000 has removed an unprofit-
able operation from Conectiv. On-going business developments are also expected
to cause future operating results to differ from the past. Accordingly, past
results are not an indication of future business prospects or financial re-
sults. As Conectiv exits from the regulated electricity production business
and builds mid-merit electric generation, operating earnings may temporarily
decrease and may also be more volatile.
For additional information concerning factors that are expected to influence
future operating results, see "Common Stock Earnings Outlook" and "Class A
Common Stock Earnings Outlook" in the MD&A included in Item 7 of Part II.
Power Delivery
In addition to the topics that are discussed within this section, informa-
tion about the "Power Delivery" business is included in Part I under the fol-
lowing captions: "Retail Electric Rates," "Customer Billing," "New Jersey
Electric System Reliability Standards," "New Jersey Demand Side Management,"
"Cost Accounting Manual/Code of Conduct," "Affiliated Transactions," and "Reg-
ulated Gas Delivery and Supply."
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 delivery
services are subject to regulation primarily by the DPSC, MPSC, and VSCC.
Rates charged to ACE's customers for electric delivery service are subject to
regulation primarily by the NJBPU.
DPL and ACE deliver electricity within their service areas to approximately
973,600 customers through their respective transmission and distribution sys-
tems and also supply electricity to most of their electricity delivery custom-
ers. DPL has about 472,600 customers in its service area and ACE has about
501,000 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 110,800 customers in a service territory that covers
about 275 square miles in northern Delaware and has a population of approxi-
mately 0.5 million.
The electricity delivered by Power Delivery may be supplied to customers by
alternative suppliers, DPL or ACE. Gas delivered may be supplied to customers
by alternative suppliers or DPL.
Energy
In addition to the topics that are discussed within this section, informa-
tion about the "Energy" business is included in Part I under the following
captions: "Capacity," "PJM Interconnection, L.L.C.," "Nuclear Power Plants,"
"Fuel Supply for Electric Generation," "Energy Adjustment Clauses," "Retail
Electric Rates," "Fed-
I-3
eral Decontamination & Decommissioning Fund," "Regulated Gas Delivery and Sup-
ply," and "Environmental Matters."
Electric Utility Industry Restructuring
The electric utility businesses of DPL and ACE were restructured in 1999
pursuant to legislation enacted in Delaware, Maryland, and New Jersey and or-
ders issued by the DPSC, MPSC, and NJBPU. Among other things, the electric re-
structuring orders provided for the choice of alternative electricity suppli-
ers by customers, decreases in customer electric rates, recovery of stranded
costs (which are the uneconomic portion of assets and long-term contracts that
resulted from electric utility industry restructuring), 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 restruc-
turing the electricity supply business of DPL and ACE, see Notes 1, 7, 10, 11
and 17 to the Consolidated Financial Statements, included in Item 8 of Part
II, and "Electric Utility Industry Restructuring" within the MD&A, included in
Item 7 of Part II.
All customers in ACE's service area could choose an alternative electricity
supplier, effective August 1, 1999. All of DPL's Delaware and Maryland custom-
ers, or about 95% of DPL's customers, could choose an alternative electricity
supplier by October 1, 2000. Power Delivery customers representing approxi-
mately 6% of the combined peak loads of DPL and ACE were purchasing electric-
ity from suppliers other than Conectiv as of December 31, 2000.
Basic Generation 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. ACE supplies the BGS load requirement with
purchased power and the output generated by certain units to be sold. To re-
place the output of the generating units to be sold, ACE plans to increase the
amount of power it purchases to supply the BGS load. ACE intends to manage BGS
supply requirements (net of sources otherwise available to it at any particu-
lar time) through the use of a portfolio approach, including the use of com-
petitive bidding. ACE's customer rates are designed to recover the costs of
providing BGS service, including above-market portions of long-term purchased
power contracts. As a result, ACE recognizes revenues for BGS service equal to
the related costs incurred. Any difference between such revenues and costs re-
sults in a related adjustment to "Deferred energy supply costs." ACE had a
regulatory liability of $34.7 million as of December 31, 2000 and $46.4 mil-
lion as of December 31, 1999 for over-recovered energy supply costs. ACE's
customer rates are to be adjusted for any deferred balance remaining after the
initial four-year transition period ends July 31, 2003. ACE's recovery of BGS
supply costs is subject to review by the NJBPU.
Default Service
DPL is obligated to supply electricity to customers who do not choose an al-
ternative electricity supplier for three years for non-residential customers
and four years for residential customers during the transition periods that
began on October 1, 1999, in Delaware and July 1, 2000, in Maryland. Differ-
ences between DPL's actual energy costs and the related amounts included in
customer rates began affecting Conectiv's earnings as of October 1, 1999, for
DPL's Delaware business and July 1, 2000, for DPL's Maryland business.
Conectiv Energy Holding Company
CEH and its subsidiaries are engaged in non-regulated electricity production
and sales, energy trading and marketing. CEH was formed effective July 1, 2000
by transferring (a) certain strategic electric generating plants of DPL and
ACE to subsidiaries of CEH and (b) trading, arbitrage and competitive sales of
electricity and natural gas from DPL to Conectiv Energy Supply, Inc. (CESI), a
subsidiary of CEH. CESI uses futures, options, swap agreements, and forward
contracts to hedge firm commitments or anticipated transactions of energy com-
modities and also creates net open energy commodity positions, or trading po-
sitions. For additional information concerning energy hedging and trading ac-
tivities, see Note 12 to the Consolidated Financial Statements included in
I-4
Item 8 of Part II. As of December 31, 2000, the electric generating plants of
CEH's subsidiaries had 2,002.8 MW of capacity, which includes 126.8 MW for
certain jointly-owned fossil plants expected to be sold during 2001.
During 2001 CESI is expected to seek to supply some or all the electricity
necessary to meet the load requirements of customers of DPL who have not cho-
sen an alternative electricity supplier.
Mid-merit Electric Generation
Conectiv is changing the types of electric generating plants it owns in con-
junction with implementing its asset-backed, "merchant" strategy focusing on
"mid-merit" electric generating plants. Mid-merit electric generating plants
can quickly increase or decrease their kilowatt-hour (kWh) output level on an
economic basis. Mid-merit plants typically have relatively low fixed operating
and maintenance costs and also can use different types of fuel. These plants
are generally operated during times when demand for electricity rises and
prices are higher. In contrast, baseload electric generating plants run almost
continuously to supply the base level of demand for electricity, or the mini-
mum demand level which generally always exists on an electrical system. 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. As discussed below, DPL sold its ownership interests in
baseload nuclear electric generating plants on December 29, 2000, and the own-
ership interests of Conectiv subsidiaries in other baseload electric generat-
ing plants are expected to be sold during 2001, pursuant to existing agree-
ments.
Conectiv plans to add to its mid-merit electric generating plants by build-
ing combined cycle units, which are constructed with combustion turbines,
waste heat recovery boilers and a steam turbine. On September 21, 2000,
Conectiv announced that it had ordered 21 combustion turbine units, which,
with additional equipment, could be configured into 8 combined cycle plants.
Each combined cycle plant would have approximately 550 MW of capacity, al-
lowing Conectiv to add up to 4,400 MW of electric generating capacity, repre-
senting a potential total investment of about $2.6 billion. Under an acceler-
ated schedule, construction would occur in phases and would be completed by
the end of 2004. Conectiv is actively working on developing sites for combined
cycle plants within the region of the PJM Interconnection, L.L.C. (PJM).
The three new combustion turbines planned for the Hay Road site are expected
to be operational during the summer of 2001 (adding 330 MW of capacity). The
waste heat recovery boiler and steam turbine needed for the new combined cycle
operation at Hay Road are expected to be completed by the third quarter of
2002 (resulting in 550 MW of total capacity for the combined cycle plant).
The number of combined cycle plants ultimately built under Conectiv's mid-
merit construction program and the timing of construction will depend on vari-
ous factors including the following: growth in demand for electricity; con-
struction of generating units by competitors; fuel prices; availability of
suitable financing; possible construction delays; and the timing and ability
to obtain required permits and licenses. The level of the construction program
could also potentially be affected by the planned acquisition of Conectiv by
Pepco. Conectiv has made progress payments on the 21 combustion turbines that
have been ordered. However, Conectiv's Board of Directors has thus far ap-
proved construction of 2 combined cycle plants, for which only 6 combustion
turbines would be needed. Should Conectiv choose not to build all 8 combined
cycle plants, then Conectiv would attempt to sell its related investment in
such combustion turbines and development sites. The ability to find a buyer
and the amount of the proceeds from such a sale would be determined by market
conditions. Through January 31, 2001, Conectiv had made $49 million in pro-
gress payments on the 15 combustion turbines needed to build up to 6 combined
cycle plants in addition to the 2 combined cycle plants currently approved by
the Board of Directors.
Agreements for the Sales of Electric Generating Plants
DPL and ACE have entered into agreements for the sale of their respective
ownership interests in non-strategic baseload fossil fuel-fired electric gen-
erating plants and ACE has executed agreements for the sale of its ownership
interests in nuclear electric generating plants. Pursuant to agreements, DPL
sold its ownership interests in nuclear electric generating plants (331 MW) on
December 29, 2000 and the related nuclear fuel for
I-5
approximately $32 million. As of December 31, 2000, the electric generating
plants of Conectiv subsidiaries that are subject to sales agreements had a net
book value of $423.2 million and aggregate capacity of 2,203.5 MW. These elec-
tric generating plants held for sale include the following:
(i) The ownership interests of ACE in nuclear electric generating plants:
(a) The agreed upon selling price is $11 million plus the net book value of
ACE's interests in nuclear fuel as of the closing date; (b) As of December
31, 2000, the capacity and the net book value of ACE's interests in these
plants were 383 MW and $14.5 million, respectively.
(ii) The ownership interests of Conectiv subsidiaries in certain wholly and
jointly owned fossil fuel-fired electric generating units: (a) The agreed
upon selling price is $800 million, before certain adjustments and selling
expenses; (b) As of December 31, 2000, the capacity and the net book value
for Conectiv subsidiaries' ownership interests in these electric generating
units were 1,820.5 MW and $408.7 million, respectively.
Consummation of the sales of the electric generating plants is subject to
the receipt of required regulatory approvals. In addition, the agreements for
the sales of the electric generating plants contemplated that the sales of the
plants of ACE and DPL would occur simultaneously. Appeals related to the
NJBPU's final order concerning restructuring the electricity supply business
of Public Service Electric and Gas Company (PSE&G) and recent electricity
shortages and price increases in California have resulted in delays in the is-
suance of required regulatory approvals, the NJBPU's final order concerning
restructuring the electricity supply business of ACE, and the closings of the
sales of the electric generating units. Effective October 3, 2000, the agree-
ments relating to the sale of the nuclear plants were amended to, among other
things, permit separate closings of the sales of the ACE and DPL interests in
the nuclear plants. DPL's ownership interests in the nuclear electric generat-
ing plants were sold on December 29, 2000, as discussed above. On December 6,
2000, the New Jersey Supreme Court affirmed the judgment of the New Jersey Su-
perior Court Appellate Division, which had previously upheld the NJBPU's final
order concerning the PSE&G restructuring. Management currently expects the
sales of ACE's nuclear and fossil, and DPL's fossil, electric generating
plants to take place during 2001. However, management cannot predict the tim-
ing of the issuance of required NJBPU approvals, the timing or outcome of ap-
peals, if any, of such approvals, the effect of any of the foregoing on the
ability of ACE or DPL to consummate the sales of various electric generating
plants or the impact of any of the foregoing on ACE's ability to recover or
securitize any related stranded costs.
For additional information, see "Agreements for the Sales of Electric Gener-
ating Plants" within the MD&A, included in Item 7 of Part II, and Note 14 to
the Consolidated Financial Statements included in Item 8 of Part II.
Telecommunications
As discussed under "Common Stock Earnings Summary" in the MD&A included in
Item 7 of Part II, the telecommunication operations of CCI resulted in losses
during 1998-2000. Conectiv continues to evaluate its partnering or other op-
tions for CCI.
CCI is a competitive local exchange carrier (CLEC) providing local, region-
al, and long distance voice and data services to business and residential cus-
tomers in Delaware, Pennsylvania, New Jersey, and Maryland. CCI owns and oper-
ates a fiber optic network of more than 856 route miles and 45,296 fiber
miles. CCI has installed its equipment in 64 Verizon central offices in order
to provide facilities-based services through its Nortel DMS-500 switch.
CCI had installed approximately 111,000 access line equivalents (comprised
of 24,000 residential access lines, 36,000 business access lines, and 51,000
business voice grade equivalents) as of December 31, 2000. In comparison, CCI
had installed approximately 77,000 access line equivalents (comprised of
26,000 residential access lines, 20,000 business access lines, and 31,000
business voice grade equivalents) as of December 31, 1999.
I-6
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
As discussed under "Common Stock Earnings Summary" in the MD&A included in
Item 7 of Part II, the HVAC operations of CSI resulted in losses during 1998-
2000. During mid- to late-2000, Conectiv sold the HVAC businesses of CSI.
Prior to its sale, CSI was a full-service HVAC business operating in the Mid-
Atlantic region. CSI provided customers with mechanical HVAC/piping construc-
tion and installation, design services, sheet metal fabrication, refrigeration
services, preventive maintenance and repair services.
Other Businesses
As discussed in Note 8 to the Consolidated Financial Statements included in
Item 8 of Part II, an indirect Conectiv subsidiary holds a limited partner in-
terest in EnerTech Capital Partners, L.P. and EnerTech Capital Partners II,
L.P. (the EnerTech funds). The EnerTech funds are venture capital funds that
invest in energy related technology and Internet service companies. The in-
vestments of the EnerTech funds include, among others, Capstone Turbine Corpo-
ration, essential.com, ICG Commerce, Inc., and Sagemaker, Inc. Due to the na-
ture of the investments of the EnerTech funds, the earnings of the funds may
be volatile from period to period.
Capacity
Capacity is the capability to produce electric power from owned electric
generating units and differs from the electric energy markets, which trade the
actual energy being generated. Capacity may also be purchased through third-
party contracts. As discussed below, the PJM power pool operates a centralized
capacity market, which allows PJM member companies such as Conectiv to buy or
sell capacity as needed for electric utility operations. As a member of the
PJM, Conectiv is obligated to maintain capacity levels based on its allocated
share of estimated aggregate PJM capacity requirements. More capacity will
need to be purchased after the electric generating units subject to sales
agreements are sold.
Electric Generating Plants
The capacity provided by the electric generating plants of Conectiv's sub-
sidiaries as of December 31, 2000 is summarized in the chart below. For a more
detailed listing, see Item 2, Properties. The net generating capacity avail-
able for operations at any time may be less than the total net installed gen-
erating capacity due to generating units being out of service for inspection,
maintenance, repairs, or unforeseen circumstances.
MW of Electric Generating Capacity
------------------------------------------
As of Units Expected Units Expected to
12/31/00 to be Sold to be Retained**
-------- -------------- -----------------
Coal-fired generating units..... 1,624.0 1,364.0 260.0
Oil-fired generating units...... 839.0 394.0 445.0
Combustion turbines/combined
cycle generating units......... 1,205.0 56.0 1,149.0
Nuclear generating units........ 380.0* 380.0 --
Diesel units.................... 31.5 9.5 22.0
------- ------- -------
Electric Generating Capacity.. 4,079.5 2,203.5 1,876.0
======= ======= =======
- --------
* Excludes a 3 MW ownership interest of ACE in a combustion turbine located
at the Salem Nuclear Generating Station
** Represents the electric generating units as of December 31, 2000 less the
units expected to be sold during 2001.
I-7
Purchased Power
As discussed in Note 23 to the Consolidated Financial Statements included in
Item 8 of Part II, as of December 31, 2000, Conectiv's subsidiaries had long-
term purchased power contracts, which provided 1,421 MW of capacity and vary-
ing amounts of firm electricity per hour during each month of a given year.
Also, the terms of the agreement for the sale of DPL's wholly owned electric
generating plants provides for DPL to purchase 500 megawatt-hours of firm
electricity per hour from the buyer of the plants beginning upon completion of
the sale and continuing through December 31, 2005.
Supplying Forecasted Peak Loads
Management currently forecasts peak loads in 2001 of 2,530 MW for DPL's de-
fault service and 2,074 MW for ACE's BGS.
During 2001, DPL expects to enter into contracts with one or more suppliers
that would supply all electricity requirements for DPL's default service obli-
gation. CESI, a subsidiary of CEH, may seek to supply some or all of DPL's de-
fault service load obligation. Once DPL has secured such supply contract(s),
it expects to sell the capacity and energy of its electric generating plants
to CESI and also assign its rights and obligations under purchased power
agreements to CESI. Should DPL not enter into such supply contracts, then ap-
proximately 65% of DPL's forecasted 2001 default service load requirement
would be supplied from a combination of long-term power purchases and elec-
tricity generated by plants of DPL. The balance of the supply would be pur-
chased from the spot market.
ACE intends to manage its BGS supply requirement through the use of a port-
folio approach, including the use of competitive bidding. Approximately 50% of
ACE's forecasted 2001 BGS load requirement will be supplied from a combination
of existing bilateral long-term power purchases and electricity generated by
plants of ACE. The balance of the supply is expected to be provided through
additional bilateral contracts and the spot market.
PJM Interconnection, L.L.C
As a member of the PJM, the generation and transmission facilities of
Conectiv are operated on an integrated basis with other electricity suppliers
in Pennsylvania, New Jersey, Maryland, and the District of Columbia, and are
interconnected with other major utilities in the eastern half of the United
States. This power pool improves the reliability and operating economies of
the systems in the group and provides capital economies by permitting shared
reserve requirements. The PJM's installed capacity as of December 31, 2000,
was 58,701 MW. The PJM's peak demand during 2000 was 49,430 MW on August 9,
which resulted in a summer reserve margin of 18.4% (based on installed capac-
ity of 58,524 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) re-
ceived 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 prov-
iders' bids. The LMP will be higher in congested areas reflecting the price
bids of those higher cost generating units that are dispatched to supply de-
mand and alleviate the transmission constraint. Furthermore, in the event that
all available generation within the PJM control area is insufficient to sat-
isfy demand, the PJM may institute emergency purchases from adjoining regions.
The cost of such emergency purchases is not subject to any PJM price cap.
There are a number of factors that distinguish the PJM market from Califor-
nia, and make the types of problems recently experienced there less likely.
The most prominent difference is the extent to which there is adequate gener-
ating capacity to meet demand in the region. The PJM's reserve margin is 18
percent, which is considerably higher than the reserve margin in California.
The two markets have also operated differently.
I-8
Considerable price risk for California utilities resulted from requirements to
sell a significant portion of their generation assets and, until recently, buy
their energy from the spot market (longer-term forward contracts were not per-
mitted). In contrast, PJM utilities have not been required to divest of their
generation assets and have been permitted to lock in prices through long-term
contracts, and to mitigate risk with use of other hedging instruments. Final-
ly, California is highly dependent on gas-fired and hydro electric generation,
both of which are highly dependent on weather. In contrast, PJM has a more di-
verse fuel mix, including a substantial base of coal and nuclear generators.
Nuclear Power Plants
As discussed in Note 14 to the Consolidated Financial Statements included in
Item 8 of Part II, DPL and ACE entered into agreements during 1999 for the
sale of their nuclear electric generating plants to PSEG Power LLC (a subsidi-
ary of Public Service Enterprise Group) and PECO Energy Company (PECO). Pursu-
ant to the agreements, DPL sold its 7.51% (164 MW) interest in Peach Bottom
Atomic Power Station (Peach Bottom) and 7.41% (167 MW) interest in Salem Nu-
clear Generating Station (Salem) on December 29, 2000. As a result, DPL no
longer has an ownership interest in any nuclear electric generating plants. In
accordance with the sales agreements, DPL transferred its decommissioning
trust funds and related obligation for decommissioning the plants to the pur-
chasers.
ACE owns 5% of Hope Creek Nuclear Generating Station (Hope Creek), which has
1,031 MW of capacity, 7.41% of Salem, which has 2,212 MW of capacity excluding
the on-site combustion turbine, and 7.51% of Peach Bottom, which has 2,186 MW
of capacity. The Hope Creek Unit and Salem Units 1 and 2 are located adjacent
to each other in Salem County, New Jersey, and are operated by PSE&G. Peach
Bottom Units 2 and 3 are located in York County, Pennsylvania, and are oper-
ated by PECO. The agreements for the sale of ACE's interests in the nuclear
plants (164 MW in Peach Bottom, 167 MW in Salem, and 52 MW in Hope Creek) pro-
vide for (a) a sales price of approximately $11 million plus the net book
value of the interests of ACE in nuclear fuel on-hand as of the closing date
and (b) the transfer of ACE's nuclear decommissioning funds and related obli-
gation for decommissioning the plants to the purchasers upon completion of the
sales.
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.
For information concerning funding ACE's share of the estimated future cost
of decommissioning the Salem, Hope Creek, and Peach Bottom nuclear reactors,
see Note 16 to the Consolidated Financial Statements included in Item 8 of
Part II.
Fuel Supply for Electric Generation
The electric generating capacity of Conectiv by fuel type is shown above un-
der "Electric Generating Plants." To facilitate the purchase of adequate
amounts of fuel, Conectiv contracts with various suppliers of coal, oil, and
natural gas on both a long- and short-term basis. Conectiv's long-term coal
contracts generally contain provisions for periodic and limited price adjust-
ments, which are based on current market prices. Oil and natural gas contracts
generally are of shorter term with prices determined by market-based indices.
Conectiv's obligations for coal and oil supply contracts related to the fos-
sil 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. The agreements for sale of the ownership interests of ACE in nu-
clear generating units provide for ACE to receive proceeds for the book value
of the nuclear fuel inventories, which management expects would be used to
liquidate ACE's obligations for the lease of the nuclear fuel inventories.
I-9
Management does not anticipate any difficulty in obtaining adequate amounts
of fuel for Conectiv's electric generating plants.
Coal
Conectiv's wholly and jointly owned electric generating plants that use coal
as a source of fuel have 1,624 MW of capacity and are listed in Item 2. During
2000, the coal supply for certain electric generating units with 1,153 MW of
capacity was purchased as follows: 70% under contracts of less than three
years in duration, 10% under long-term contracts (up to ten years), and 20% on
the spot market. For the other 471 MW of coal-fired electric generating
plants, approximately 80% of the coal supply was purchased under contracts ex-
piring in 2002 and 20% was purchased on the spot market. During 2001, manage-
ment expects that approximately 75% of the coal requirements will be purchased
under supply contracts and the other 25% purchased on the spot market.
Oil
A two-year residual oil supply contract that expires in 2001 provides 90% to
100% of the fuel supply requirements for the Vienna Generating Station (153
MW). Oil supply for the other electric generating units, which use oil as a
primary or secondary fuel, is purchased on the spot market.
Gas
Natural gas is the primary fuel for the three combustion turbines at the Hay
Road site (521 MW) and a secondary fuel for the Edge Moor units (705 MW). Nat-
ural gas for these generating units is purchased on a firm or interruptible
basis from suppliers such as marketers, producers, and utilities. The second-
ary fuel for the Hay Road combustion turbines is low-sulfur diesel fuel, which
is purchased in the spot market. Five combustion turbines (316 MW), in addi-
tion to those located at Hay Road, use natural gas as a primary fuel source
and the units at the Deepwater station, which use coal and oil as primary fu-
els, use natural gas as a secondary fuel. Natural gas for these five combus-
tion turbines and the Deepwater station is primarily purchased from a local
gas distribution company on a semi-firm basis and is also purchased from other
suppliers such as marketers, producers, and utilities. Natural gas is deliv-
ered through the interstate pipeline system under a mix of long-term firm,
short-term firm, and interruptible contracts.
Nuclear
PSE&G has informed ACE that it has several long-term contracts with uranium
ore operators, converters, enrichers and fabricators to meet the currently
projected fuel requirements for Salem and Hope Creek. ACE has also been ad-
vised 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.
On December 29, 2000, DPL's former nuclear fuel disposal obligations were
assumed by the purchasers of DPL's ownership interests in nuclear electric
generating units.
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
has stated that it would not be able to open a permanent, high level nuclear
waste storage facility until 2010, at the earliest.
Pursuant to NRC rules, spent nuclear fuel generated in any reactor can be
stored in reactor facility storage pools or in independent spent nuclear fuel
storage installations located at or away from reactor sites for at least 30
years beyond the licensed life for operation (which may include the term of a
revised or renewed license).
I-10
PSE&G has advised ACE that adequate spent fuel storage capacity is estimated
to be available through 2011 for Salem Unit 1, 2015 for Salem Unit 2, and 2007
for Hope Creek. PECO has advised ACE that it has constructed an on-site dry
storage facility at Peach Bottom which provides adequate storage capacity
through the end of the current licenses for the two Peach Bottom units.
Energy Adjustment Clauses
As a result of electric utility industry restructuring, energy adjustments
in DPL's regulated retail electric tariffs were eliminated effective October
1, 1999 in Delaware and effective June 30, 2000 in Maryland and Virginia. The
energy adjustment clauses provided for collection from customers of fuel costs
and purchased energy costs. Earnings volatility may increase due to elimina-
tion of DPL's energy adjustment clauses.
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.
Natural gas commodity prices and futures rose to unprecedented levels during
2000 due to increased demand for gas to generate electricity, low storage lev-
els nationally, and cold weather. DPL's Gas Cost Rate (GCR) was increased by
9.6% on December 1, 2000 to recover those increases in the natural gas commod-
ities. On December 8, 2000, DPL was required by its gas service tariff to file
for an additional increase of 23%, which became effective on February 1, 2001.
DPL is currently involved in an evidentiary process to prove the reasonable-
ness of those rate increases, and expects final approval in 2001. As of Decem-
ber 31, 2000, DPL had deferred $16.9 million of natural gas costs in anticipa-
tion of recovering such costs from customers through the gas cost rate clause.
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 non-utility 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 non-utility electricity suppliers. Under
the terms of the NJBPU's Summary Order concerning restructuring ACE's elec-
tricity 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 would increase
the regulatory liability. ACE had a regulatory liability of $34.7 million as
of December 31, 2000 and $46.4 million as of December 31, 1999 for over-recov-
ered energy supply costs. Customer rates are to be adjusted for any deferred
balance remaining after the initial four-year transition period, which ends
July 31, 2003. ACE's recovery of BGS supply costs is subject to review by the
NJBPU.
Retail Electric 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. The 7.5% Delaware residential
rate reduction reduced revenues by approximately $17.5 million on an
annualized basis.
I-11
A 7.5% reduction in DPL's Maryland residential electric rates became effec-
tive July 1, 2000, in connection with the restructuring of the Maryland elec-
tric utility industry. Also, the electric rates in effect on July 1, 2000 are
to remain unchanged for four years for Maryland residential customers and
three years for Maryland non-residential customers. Management estimates that
the initial 7.5% Maryland residential rate reduction will reduce revenues by
approximately $12.5 million on an annualized basis.
In its Summary Order, the NJBPU directed ACE to implement a 5% aggregate
rate reduction effective August 1, 1999 and an additional 2% rate reduction by
January 1, 2001. By August 1, 2002, rates must be reduced by 10% from the
rates that were in effect as of April 30, 1997. The initial 5% rate reduction
effective August 1, 1999 reduced annual revenues by approximately $50 million.
The additional 2% rate reduction required by January 1, 2001 was implemented
through two separate 1% rate reductions effective January 1, 2000 and 2001,
respectively. Each of the 1% rate reductions reduced annual revenues by ap-
proximately $10 million, or $20 million in total. The final rate reduction,
which is required by August 1, 2002, is expected to reduce revenues by an ad-
ditional $30 million, which would result in a cumulative rate reduction of
$100 million since August 1, 1999.
Customer Billing
In December 1999, a new customer billing system was installed primarily to
accommodate the unbundled utility bills required by electric utility industry
restructuring. As with any complex billing system changeover, errors occurred.
The financial impact for Conectiv of the conversion to the new customer bill-
ing system was primarily slower collection of accounts receivable. In a set-
tlement to conclude a DPSC review of the billing system, DPL agreed to provide
a credit of approximately $2.5 million to customers bills. The credits were
reflected on customers bills in February 2001.
New Jersey Electric System Reliability Standards
In November 1999, the NJBPU began a general review of the reliability of the
electric systems of ACE and all other New Jersey utilities. The NJBPU began
its review as a result of electric service outages which occurred during an
extended period of hot and humid weather in July 1999. On November 28, 2000,
the NJBPU approved interim reliability standards which are in effect through
2002 and are designed to reduce outage frequency and duration, as well as im-
prove maintenance and inspection of electric facilities. Final reliability
standards are expected to be adopted in late-2002, after the NJBPU reviews
data submitted by the utilities. Expenditures of approximately $5 million are
expected by ACE during 2001 in order to comply. The NJBPU could fine utilities
up to $50,000 per violation of the rule requirements.
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 of New Jersey public utilities. On
June 9, 1999, the NJBPU initiated the Comprehensive 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 incor-
poration of new energy efficiency and renewable energy programs. A key issue
in the CRA proceeding is the determination of the appropriate level of funding
for energy efficiency and renewable energy programs on a statewide basis.
Hearings have been conducted and a record has been established to permit the
NJBPU to render decisions for each New Jersey utility in lieu of settlements,
if necessary. A decision by the NJBPU is expected in 2001.
I-12
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.
Most of Conectiv's unregulated activities are now conducted by subsidiaries
other than DPL and ACE. In general, these Codes of Conduct limit information
obtained through utility activities from being disseminated to employees en-
gaged in non-regulated activities, restrict or prohibit sales leads, joint
sales calls and joint promotions; require separation of certain employees and
functions; and require separation of certain office space and facilities.
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. A compliance audit
of these interim standards was conducted during 2000 and a final order is
pending by the NJBPU.
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. On December 29, 2000, DPL's
former liability to the D&D Fund was assumed by the purchasers of DPL's owner-
ship interests in nuclear electric generating units. The liability accrued for
ACE's D&D Fund liability was $5.1 million as of December 31, 2000. The terms
of agreements for the sale of ACE's interests in the nuclear power plants pro-
vide for the buyers of the plants to assume the amount of this liability which
exists at the time the sale is 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. Primarily due to high natural
gas prices and market price volatility, most of the customers participating in
the pilot program were returned to DPL by their supplier in the last quarter
of 2000. As of March 1, 2001, no customers remained in the pilot program,
which expires in October 2001.
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).
I-13
Number of Expiration Daily
Contracts Dates Mcf
--------- ---------- -------
Supply......................................... 1 2001 9,180
Transportation................................. 19 2001-2016 86,152
Storage........................................ 11 2001-2013 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 175,059 Mcf on January 17, 2000. 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 18 to 21 to the Consolidated Financial State-
ments, 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 1996-2000 are shown below.
Year Ended December 31,
------------------------
2000 1999 1998 1997 1996
---- ---- ---- ---- ----
Ratio of Earnings to Fixed Charges (SEC Method)... 2.13 1.98 2.38 2.63 2.83
Under the SEC Method, earnings, including Allowance For Funds Used During
Construction, are income before extraordinary item plus income taxes and fixed
charges, less non-utility capitalized interest and undistributed earnings of
equity method investees. Fixed charges include gross interest expense, the es-
timated interest component of rentals, and preferred stock dividend require-
ments of subsidiaries. Preferred stock dividend requirements for purposes of
computing the ratio have been increased to an amount representing the pre-tax
earnings that would be required to cover such dividend requirements.
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 $10 million in 2001.
Air Quality Regulations
The federal Clean Air Act required utilities and other industries to signif-
icantly reduce emissions of air pollutants such as sulfur dioxide (SO\\2\\)
and oxides of nitrogen (NOx) by the year 2000. All wholly or jointly owned
electric generating units of Conectiv are in compliance with these require-
ments.
I-14
The electric generating plants of Conectiv also must comply with Title I of
the Clean Air Act, the ozone non-attainment provisions, which require states
to promulgate Reasonably Available Control Technology (RACT) regulations for
existing sources located within ozone non-attainment areas or within the
Northeast Ozone Transport Region (NOTR). To comply with RACT regulations, low
NOx burner technology has been installed on a number of electric generating
units. Additional "post-RACT" NOx emission regulations are being pursued by
states in the NOTR. In 2000, the electric generating plants of Conectiv com-
plied with post-RACT requirements. In addition to the above requirements, the
United States Environmental Protection Agency (USEPA) has proposed summer sea-
sonal 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 Jer-
sey. Since the State of New Jersey will require a greater percent reduction
than that required by the USEPA, the ACE facilities will most likely achieve
compliance with the USEPA requirement by 2003. The estimated cost to comply is
approximately $5-$8 million over the next five years. 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.
The USEPA requested data from a number of electric utilities regarding older
coal-fired units in order to determine compliance with the regulations for the
Prevention of Significant Deterioration of Air Quality (PSD). A number of set-
tlements have been announced throughout the utility industry. On February 23,
2000, ACE received a request for data from the USEPA and the New Jersey De-
partment of Environmental Protection (NJDEP) on coal-fired operations at the
Deepwater and B.L. England electric generating stations. Data was submitted,
as requested by the USEPA throughout 2000. At this time it is not possible to
predict the impact of this request, if any, on Deepwater or B.L. England oper-
ations.
Water Quality Regulations
The Clean Water Act provides for the imposition of effluent limitations to
regulate the discharge of pollutants, including heat, into the waters of the
United States. National Pollution Discharge Elimination System (NPDES) permits
issued by state environmental regulatory agencies specify effluent limita-
tions, monitoring requirements, and special conditions with which facilities
discharging waste-waters must comply. To ensure that water quality is main-
tained, permits are issued for a term of five years and are modified as neces-
sary to reflect requirements of new or revised regulations or changes in fa-
cility 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
NJPDES permit for the Deepwater Station expired in 1991. The permit has been
administratively extended and the plant continues to operate under the condi-
tions of the existing permit while negotiations are underway for permit renew-
al. The NJPDES permit for the B.L. England station expired in December 1999,
but has been administratively extended and the plant continues to operate un-
der the conditions of the existing permit until a renewal permit is issued by
NJDEP.
Conectiv's subsidiaries hold NPDES permits for the Vienna, Indian River, and
Edge Moor power plants. The NPDES permit for the Vienna power plant is ex-
pected to be renewed, maintaining the current permit limitations, in early
2001. The NPDES permit issued by the Delaware Department of Natural Resources
and Environmental Control (DNREC) for the Indian River power plant expired in
1992 but has been administratively extended and the plant continues to operate
under the conditions of the existing permit. Studies have been conducted to
determine thermal impacts and the results of the studies are currently under
evaluation by DNREC. The studies are intended to support a request for a vari-
ance from thermal water quality standards in order to allow the plant to con-
tinue operating under the current discharge temperature limitations. In addi-
tion, the NPDES
I-15
permits for the Indian River and Edge Moor power plants require studies to de-
termine impacts on aquatic organisms by the plants' intake structures. The
studies began in 1999 and will be completed in 2001. The results of these
studies will determine whether upgrades to intake structures are required to
minimize environmental impacts.
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 recover oil from the soil.
Remediation costs are expected to be approximately $10 million, including ap-
proximately $3 million of cumulative expenditures which had been incurred as
of December 31, 2000. In addition, DPL paid $350,000 in penalties and $100,000
for an environmental improvement project to DNREC in connection with the oil
leak and another matter related to the Indian River power plant.
Conectiv's current liabilities included $9.8 million as of December 31, 2000
and $3.0 million as of December 31, 1999 for potential clean-up and other
costs related to sites at which a Conectiv subsidiary is a potentially respon-
sible party or alleged to be a third-party contributor, including the Indian
River power plant discussed above. Conectiv does not expect such future costs
to have a material effect on its financial position or results of operations.
I-16
Executive Officers
The names, ages, and positions of all of the executive officers of Conectiv
as of December 31, 2000, 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, 2000)
Name, Age and Position Business Experience During Past 5 Years
---------------------- ---------------------------------------
Howard E. Cosgrove, 57........ Elected 1998 as Chairman of the Board and Chief
Chairman of the Board and Executive Officer of Conectiv. Elected 1992 as
Chief Executive Officer Chairman of the Board, President and Chief
Executive Officer and Director of Delmarva Power
& Light Company.
Thomas S. Shaw, 53............ Elected 2000 as President and Chief Operating
President and Chief Operating Officer of Conectiv. Elected 1998 as Executive
Officer Vice President of Conectiv. Elected 1992 as
Senior Vice President of Delmarva Power & Light
Company.
John C. van Roden, 51......... Elected 1998 as Senior Vice President and Chief
Senior Vice President and Financial Officer of Conectiv. Principal, Cook
Chief Financial Officer and Belier, Inc. in 1998. Senior Vice
President/Chief Financial Officer and Vice
President/Treasurer, Lukens, Inc. from 1987 to
1998.
Barbara S. Graham, 52......... Elected 1999 as Senior Vice President of
Senior Vice President Conectiv. Elected 1998 as Senior Vice President
and Chief Financial Officer of Conectiv. Elected
1994 as Senior Vice President, Treasurer and
Chief Financial Officer of Delmarva Power &
Light Company.
Joseph M. Rigby, 44........... Elected 2000 as Senior Vice President of
Senior Vice President Conectiv. 1999, Vice President, Electric
Delivery, Conectiv. 1998, Vice President, Gas
Delivery, Conectiv. 1997, Vice President, Merger
Integration Team, Conectiv. 1996, Director of
Human Resources, Atlantic Energy, Inc.
William H. Spence, 43......... Elected 2000 as Senior Vice President of
Senior Vice President Conectiv. Vice President and General Manager of
Merchant Energy, Conectiv, 1998-1999. Director
of Merchant Energy, Delmarva Power & Light
Company, 1996-1997.
James P. Lavin, 53............ Elected 1998 as Controller of Conectiv. Elected
Controller and Chief 1993 as Comptroller, Delmarva Power & Light
Accounting Officer Company.
I-17
ITEM 2. PROPERTIES
Generating
Electric Generating 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*
Keystone................ Shelocta, PA........................ 105,000*
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
---------
839,000
---------
Combustion
Turbines/Combined Cycle
Hay Road................ Wilmington, DE...................... 521,000
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....... 3,000*
---------
1,205,000
---------
Nuclear
Peach Bottom............ Peach Bottom Twp., PA............... 164,000*
Salem................... Lower Alloways Creek Twp., NJ....... 164,000*
Hope Creek.............. Lower Alloways Creek Twp., NJ....... 52,000*
---------
380,000
---------
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*
Conemaugh............... New Florence, PA.................... 800*
---------
31,500
---------
Total Electric Generating Capacity............................. 4,079,500
---------
- --------
* Represents Conectiv's subsidiaries ownership interests in jointly owned
plants.
I-18
The electric properties of Conectiv's subsidiaries are located in New Jer-
sey, Delaware, Maryland, Virginia, and Pennsylvania. The above table sets
forth the summer electric generating capacity of the electric generating
plants owned by Conectiv's subsidiaries.
Substantially all utility plant and properties of Conectiv's subsidiaries
are subject to liens of the Mortgages under which First Mortgage Bonds are is-
sued.
On a combined basis, the electric transmission and distribution systems of
DPL and ACE include 2,624 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.
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 eight 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 Conectiv's gas pipeline miles:
Transmission Mains.................................................... 111*
Distribution Mains.................................................... 1,605
Service Lines......................................................... 1,179
- --------
* Includes 7.2 miles of joint-use gas pipeline that is used 10% for gas oper-
ations and 90% for electric generation.
Conectiv's subsidiaries also own and occupy a number of properties and
buildings that are used for office, service, and other purposes.
ITEM 3. LEGAL PROCEEDINGS
On October 24, 2000, the City of Vineland, New Jersey, filed an action in a
New Jersey Superior Court to acquire by eminent domain ACE electric distribu-
tion facilities located within the City limits. The City has offered approxi-
mately $11 million for these assets, including the right to provide electric
service in this area. ACE believes that, properly evaluated, the assets sought
by the City are worth approximately $40 million.
For information concerning penalties paid in connection with the environ-
ment, see "Hazardous Substances," under "Environmental Matters," which is
above and within Item 1 of Part I.
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, through the so-
licitation of proxies or otherwise.
I-19
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, 2000, there were 62,318 holders of Conectiv's common
stock and 28,249 holders of Conectiv's Class A common stock.
Conectiv Common stock
2000 1999
----------------------------- ------------------------
Price Price
Dividend -------------------- Dividend ---------------
Declared High Low Declared High Low
-------- --------- ---------- -------- ------- -------
First Quarter............ $0.220 $18 1/4 $13 7/16 $0.385 $24 3/8 $19 3/8
Second Quarter........... 0.220 18 13/16 15 0.220 25 1/2 19 3/8
Third Quarter............ 0.220 19 3/16 15 1/2 0.220 25 1/4 19
Fourth Quarter........... 0.220 20 3/4 15 13/16 0.220 20 3/4 16 1/4
Conectiv Class A common stock
2000 1999
-------------------------- ---------------------------
Price Price
Dividend ----------------- Dividend ------------------
Declared High Low Declared High Low
-------- --------- ------- -------- --------- --------
First Quarter............ $0.80 $32 1/4 $21 3/4 $0.80 $40 $34 7/8
Second Quarter........... 0.80 24 5/8 19 3/8 0.80 42 1/4 34 3/8
Third Quarter............ 0.80 25 9/16 17 3/4 0.80 43 37 5/16
Fourth Quarter........... 0.80 20 1/4 8 1/2 0.80 40 13/16 26 1/2
Stock Stock Symbol
Conectiv common stock CIV (New York Stock Exchange)
Conectiv Class A common stock CIV A (New York Stock Exchange)
Dividends on Common Stock
As discussed in Note 5 to the Consolidated Financial Statements, during the
period the Conectiv/Pepco Merger Agreement is in effect, Conectiv's dividend
payments cannot exceed $0.22 per share of Conectiv common stock per quarter.
In 2000, Conectiv's Board of Directors declared quarterly dividends per
share of common stock of $0.22, or $0.88 for the year, which represented ap-
proximately 45% of earnings per share of common stock of $1.97. In the second
quarter of 1999, Conectiv established the objective of having a dividend pay-
out ratio on common stock of 40% to 60% of earnings per share of common stock
and also reduced the quarterly dividend from $0.385 per share to $0.22 per
share.
Dividends on Class A Common Stock
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 Di-
rectors to consider the financial condition and regulatory environment of
Conectiv and the results of its operations; and also subject to the limita-
tions under applicable law and the provisions of Conectiv's Restated Certifi-
cate of Incorporation.
II-1
As disclosed at the time of the 1998 Merger, 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 the results of its operations, to
pay annual dividends on the Class A common stock at a rate equal to 90% of
annualized earnings of the Class A common stock (taking into account the
notional fixed charge of $40 million per year in accordance with Conectiv's
Restated Certificate of Incorporation). 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 the earnings that were applica-
ble to the Class A common stock during the Initial Period, Conectiv's Board of
Directors may consider such fact in determining the appropriate annual divi-
dend rate on the Class A common stock following the Initial Period. Management
expects that during the Initial Period the earnings applicable to Class A com-
mon stock will be less than the dividends on the Class A common stock. Divi-
dends declared per share of Class A common stock were $3.20 for 2000, $3.20
for 1999 and $3.20 for 1998. In comparison, earnings excluding special charges
and the extraordinary item which were applicable to Class A common stock were
$1.06 for 2000, $1.44 for 1999 and $1.82 for 1998.
As discussed in Note 5 to the Consolidated Financial Statements, after March
31, 2001 and during the period the Conectiv/Pepco Merger Agreement is in ef-
fect, dividends on Conectiv Class A common stock may be paid at an annual rate
up to 90% of annualized earnings of Class A common stock.
Dividend Restriction
Under PUHCA, Conectiv may not pay dividends on the shares of common stock
and Class A common stock from an accumulated deficit or paid-in-capital with-
out SEC approval. In the first and second quarters of 2000, Conectiv had accu-
mulated deficits and received SEC approval for the payment of quarterly divi-
dends on shares of common stock and Class A common stock.
Conectiv's common dividends paid to public stockholders are currently funded
from the common dividends DPL and ACE pay to Conectiv. Under PUHCA, DPL and
ACE are prohibited from paying a dividend from an accumulated deficit or paid-
in-capital, unless SEC approval is obtained. Also, certificates of incorpora-
tion of DPL and ACE require payment of all preferred dividends in arrears (if
any) prior to payment of common dividends to Conectiv, and have certain other
limitations on the payment of common dividends to Conectiv.
II-2
CONECTIV
ITEM 6. SELECTED FINANCIAL DATA
Year Ended December 31,
-------------------------------------------------------------------
2000 1999 1998(1) 1997 1996
---------- ---------- ---------- ---------- ----------
(Dollars in Thousands, Except Per Share Amounts)
Operating Results
Operating Revenues...... $5,029,124 $3,744,897 $3,071,606 $1,415,367 $1,168,664
Operating Income........ $ 487,834(2) $ 345,589 (2) $ 386,915(2) $ 226,294 $ 250,389
Income Before
Extraordinary Item..... $ 170,830(2) $ 113,578 (2) $ 153,201(2) $ 101,218(3) $ 107,251
Extraordinary Item, Net
of $188,254 of Income
Taxes (4).............. -- $ (311,718) -- -- --
Net Income (Loss)....... $ 170,830(2) $ (198,140)(2) $ 153,201(2) $ 101,218(3) $ 107,251
Common Stock Information
Basic and Diluted
Earnings (Loss)
Applicable to:
Common Stock
Income Before
Extraordinary Item.... $ 164,719(5) $ 106,639 (5) $ 141,292(5) $ 101,218(3) $ 107,251
Extraordinary Item,
Net of Income Taxes
(4)................... -- (295,161) -- -- --
---------- ---------- ---------- ---------- ----------
Total................ $ 164,719 $ (188,522) $ 141,292 $ 101,218 $ 107,251
---------- ---------- ---------- ---------- ----------
Class A Common Stock
Income Before
Extraordinary Item.... $ 6,111 $ 6,939 (6) $ 11,909 -- --
Extraordinary Item,
Net of Income Taxes
(4)................... -- (16,557) -- -- --
---------- ---------- ---------- ---------- ----------
Total................ $ 6,111 $ (9,618) $ 11,909 -- --
---------- ---------- ---------- ---------- ----------
Earnings (Loss) Per
Share of:
Common Stock
Before Extraordinary
Item.................. $ 1.97(5) $ 1.14 (5) $ 1.50(5) $ 1.66(3) $ 1.77
Extraordinary Item
(4)................... -- (3.16) -- -- --
---------- ---------- ---------- ---------- ----------
Total................ $ 1.97 $ (2.02) $ 1.50 $ 1.66 $ 1.77
---------- ---------- ---------- ---------- ----------
Class A Common Stock
Before Extraordinary
Item.................. $ 1.06 $ 1.14 (6) $ 1.82 -- --
Extraordinary Item
(4)................... -- (2.71) -- -- --
---------- ---------- ---------- ---------- ----------
Total................ $ 1.06 $ (1.57) $ 1.82 -- --
---------- ---------- ---------- ---------- ----------
Dividends Declared Per
Share of:
Common Stock........... $ 0.88 $ 1.045 $ 1.54 $ 1.54 $ 1.54
Class A Common Stock... $ 3.20 $ 3.20 $ 3.20 -- --
Average Shares
Outstanding (000):
Common Stock........... 83,686 93,320 94,338 61,122 60,698
Class A Common Stock... 5,742 6,110 6,561 -- --
Year-End Stock Price:
Common Stock........... $ 20 1/16 $ 16 13/16 $ 24 1/2 $ 23 1/16 $ 20 3/8
Class A Common Stock... $ 12 7/8 $ 29 5/8 $ 39 1/2 -- --
Book Value Per Common
Share (7).............. $ 13.10 $ 12.38 $ 17.21 $ 15.59 $ 15.41
Return on Average Common
Stockholders' Equity
(8).................... 15.1% 8.0% 8.3% 10.6% 11.4%
Capitalization
Common Stockholders'
Equity................. $1,160,269 $1,138,173 $1,843,161 $ 954,496 $ 934,913
Preferred Stock of
Subsidiaries:
Not Subject to
Mandatory
Redemption............ 95,933 95,933 95,933 89,703 89,703
Subject to Mandatory
Redemption............ 188,950 188,950 188,950 70,000 70,000
Variable Rate Demand
Bonds (VRDB) (9)....... 158,430 158,430 125,100 71,500 85,000
Long-Term Debt.......... 2,021,789 2,124,898 1,746,562 983,672 904,033
---------- ---------- ---------- ---------- ----------
Total Capitalization
with VRDB.............. $3,625,371 $3,706,384 $3,999,706 $2,169,371 $2,083,649
========== ========== ========== ========== ==========
Other Information
Total Assets............ $6,477,995 $6,138,462 $6,087,674 $3,015,481 $2,931,855
Long-Term Capital Lease
Obligation............. $ 13,744 $ 30,395 $ 36,603 $ 19,877 $ 20,552
Capital Expenditures.... $ 390,540 $ 320,395 $ 224,831 $ 156,808 $ 165,595
- --------
(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 1998
II-3
Merger) on March 1, 1998. The 1998 Merger was accounted for under the pur-
chase method of accounting, with DPL as the acquirer. Accordingly, the
1998 Consolidated Statement of Income includes 10 months of operating re-
sults for ACE and other former subsidiaries of Atlantic Energy, Inc.
(2) Special Charges, as discussed in Note 6 to the Consolidated Financial
Statements, decreased operating income, income before extraordinary item,
and net income by $25.2 million, $23.4 million and $23.4 million, respec-
tively, in 2000; $105.6 million, $71.6 million, and $71.6 million, respec-
tively, in 1999; and $27.7 million, $16.8 million and $16.8 million, re-
spectively in 1998. In 2000, a gain on the sale of the ownership interests
of DPL in nuclear electric generating plants increased operating income,
income before extraordinary item, and net income by $16.6 million, $12.8
million, and $12.8 million, respectively, as discussed in Note 14 to the
Consolidated Financial Statements.
(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 com-
mon share by $13.7 million, $13.7 million, and $0.22, respectively.
(4) As discussed in Note 7 to the Consolidated Financial Statements, the ex-
traordinary item resulted from the restructuring of the electric utility
industry and discontinuing the application of Statement of Financial Ac-
counting Standards No. 71, "Accounting for the Effects of Certain Types of
Regulation."
(5) Special Charges, as discussed in Note 6 to the Consolidated Financial
Statements, decreased income before extraordinary item applicable to
Conectiv common stock by $23.4 million ($0.28 per average share outstand-
ing) in 2000, $69.7 million ($0.75 per average share outstanding) in 1999
and $16.8 million ($0.18 per average share outstanding) in 1998. In 2000,
a gain on the sale of the ownership interests of DPL in nuclear electric
generating plants increased income before extraordinary item applicable to
Conectiv common stock by $12.8 million ($0.15 per average share outstand-
ing), as discussed in Note 14 to the Consolidated Financial Statements.
(6) Special Charges, as discussed in Note 6 to the Consolidated Financial
Statements, decreased income before extraordinary item applicable to
Conectiv Class A common stock by $1.9 million ($0.30 per average share
outstanding) in 1999.
(7) Due to the terms of Conectiv's Restated Certificate of Incorporation,
Conectiv common stock and Conectiv Class A common stock have the same book
value per common share.
(8) Before extraordinary charge of $311,718, net of $188,254 of income taxes,
in 1999.
(9) Although Variable Rate Demand Bonds are classified as current liabilities,
management intends to use the bonds as a source of long-term financing, as
discussed in Note 21 to the Consolidated Financial Statements.
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
acceptable terms; 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 sales;
sales retention and growth; federal and state regulatory actions; future liti-
gation results; costs of construction; operating restrictions; increased costs
and construction delays attributable to environmental regulations; nuclear
decommissioning and the availability of reprocessing and storage facilities
for spent nuclear fuel; and credit market concerns. Conectiv undertakes no ob-
ligation to publicly update or revise any forward-looking statements, whether
as a result of new information, future events or otherwise. The foregoing list
of factors pursuant to the Litigation Reform Act should not be construed as
exhaustive or as any admission regarding the adequacy of disclosures made
prior to the effective date of the Litigation Reform Act.
OVERVIEW
Conectiv was formed on March 1, 1998 (the 1998 Merger), through a series of
merger transactions and an exchange of common stock with Delmarva Power &
Light Company (DPL) and Atlantic Energy, Inc. (Atlantic). Conectiv's two larg-
est subsidiaries, DPL and Atlantic City Electric Company (ACE), supply and de-
liver electricity. DPL also supplies and delivers gas to its customers. A
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. Sub-
stantially all of the customers of DPL and ACE can now elect to choose an al-
ternative electricity supplier.
On July, 1, 2000, certain strategic electric generating plants of DPL and
ACE were transferred to subsidiaries of Conectiv Energy Holding Company (CEH).
CEH and its subsidiaries are engaged in non-regulated electricity production
and sales, energy trading and marketing. On December 29, 2000, DPL sold its
ownership interests in nuclear electric generating plants. Certain other elec-
tric generating plants are expected to be sold during 2001, pursuant to exist-
ing agreements. After the sales of these plants, the principal remaining busi-
nesses of DPL and ACE will be the transmission and distribution, or delivery,
of electricity. Proceeds from these sales and securitization of ACE's stranded
costs (securitization is discussed under "Stranded Cost Recovery and
Securitization") are expected to be used to repay debt and fund expansion of
the "mid-merit" electric generation business. As discussed under "Mid-Merit
Electric Generation," mid-merit electric generating plants can quickly in-
crease or decrease their output level on an economic basis and are expected to
have relatively low operating costs. Conectiv is building combustion turbines
and combined cycle units as part of its mid-merit electric generation busi-
ness, which also includes most of the plants operated by subsidiaries of CEH.
During 2000, Conectiv began exiting from certain business activities. During
mid- to late-2000, Conectiv sold its heating, ventilation, and air condition-
ing (HVAC) business and portions of Conectiv Thermal Systems, Inc. (CTS),
which constructs and operates district heating and cooling systems. Conectiv
also began exiting from
II-5
the competitive retail energy business (the supply of electricity and gas in
deregulated retail markets). In addition, Conectiv initiated a process in 2000
to identify a strategic partner for CCI. Due to weaknesses in the valuations
of telecommunications businesses, Conectiv continues to evaluate its
partnering or other options.
Under the purchase method of accounting for the 1998 Merger, with DPL as the
acquirer, the Consolidated Statements of Income include the results of opera-
tions for ACE and formerly Atlantic-owned non-utility businesses from March 1,
1998 and thereafter. See Note 4 to the Consolidated Financial Statements for
additional information concerning the 1998 Merger.
As used in this document, references to Conectiv may mean the activities of
one or more subsidiary companies.
AGREEMENT FOR THE ACQUISITION OF CONECTIV
On February 9, 2001, the Boards of Directors of Conectiv and Potomac Elec-
tric Power Company (Pepco) approved an Agreement and Plan of Merger
(Conectiv/Pepco Merger Agreement) under which Pepco will acquire Conectiv for
a combination of cash and stock. The transaction is subject to various statu-
tory and regulatory approvals and approval by the stockholders of Conectiv and
Pepco. Upon completion of the transaction, Conectiv and Pepco will become sub-
sidiaries of a new holding company (HoldCo), to be named at a later date.
HoldCo is expected to be a registered holding company under PUHCA. Approxi-
mately 67% of the shares of HoldCo are expected to be owned by Pepco stock-
holders and 33% of the shares of HoldCo are expected to be owned by Conectiv
stockholders.
Under the terms of the Conectiv/Pepco Merger Agreement, holders of Pepco's
common stock will receive one share of HoldCo common stock for each share of
Pepco common stock owned.
Under the Conectiv/Pepco Merger Agreement, holders of Conectiv common stock
and Conectiv Class A common stock may elect to exchange their shares for cash,
HoldCo common stock, or a combination of cash and HoldCo common stock. Howev-
er, such elections will be subject to a proration procedure that will cause
the aggregate consideration paid to holders of Conectiv common stock and
Conectiv Class A common stock to be 50% cash and 50% HoldCo common stock. Sub-
ject to certain restrictions described below, (i) Conectiv stockholders elect-
ing to receive cash would receive $25 per share of Conectiv common stock ex-
changed and $21.69 per share of Conectiv Class A common stock exchanged, and
(ii) Conectiv stockholders electing to receive HoldCo common stock would re-
ceive a number of shares of HoldCo common stock determined by the exchange ra-
tio described below. Subject to certain limitations, the exchange ratio is de-
signed to provide holders of Conectiv common stock with a number of shares of
HoldCo common stock having a market value of $25.00 and holders of Conectiv
Class A common stock with a number of shares of HoldCo common stock having a
market value of $21.69.
The exchange ratio will be $25.00 divided by the volume-weighted average of
the closing trading prices of Pepco common stock for 20 trading days randomly
selected by lot out of 30 consecutive trading days ending on the fifth busi-
ness day immediately preceding the closing date of the transaction (Average
Final Price).
If the Average Final Price is below $19.50, then Conectiv common stockhold-
ers will have the right to receive 1.28205 shares of HoldCo common stock for
each share of stock exchanged and Conectiv Class A common stockholders will
have the right to receive 1.11227 shares of HoldCo common stock for each share
of stock exchanged. In this instance, the fair value of HoldCo common stock
received for each share of Conectiv common stock exchanged and each share of
Conectiv Class A common stock exchanged will be less than $25.00 and $21.69,
respectively.
If the Average Final Price is above $24.50, then Conectiv common stockhold-
ers will have the right to receive 1.02041 shares of HoldCo common stock for
each share of stock exchanged and Conectiv Class A common stockholders will
have the right to receive 0.88528 shares of HoldCo common stock for each share
of
II-6
stock exchanged. In this instance, the fair value of HoldCo common stock re-
ceived for each share of Conectiv common stock exchanged and each share of
Conectiv Class A common stock exchanged will be more than $25.00 and $21.69,
respectively.
Conectiv may terminate the Conectiv/Pepco Merger Agreement if the Average
Final Price is less than $16.50, unless Pepco, at its option, chooses to in-
crease the consideration that will be paid to Conectiv's stockholders for
their shares of Conectiv stock. If the Average Final Price is less than
$16.50, Pepco has the option of (i) adjusting the exchange ratio so as to pro-
vide Conectiv's stockholders with HoldCo common stock having a value of $21.25
for each share of Conectiv common stock and $18.35 for each share of Conectiv
Class A common stock, (ii) paying additional cash to the stockholders so that
they receive a total consideration of $21.25 for each share of Conectiv common
stock and $18.35 for each share of Conectiv Class A common stock, or (iii) un-
dertaking a combination of (i) and (ii), provided that any such combination
must be in the same proportion with respect to the Conectiv common stock and
the Conectiv Class A common stock.
The Conectiv/Pepco Merger Agreement may be terminated by either Conectiv or
Pepco if the transaction has not occurred by August 9, 2002 (18 months after
the date of the Conectiv/Pepco Merger Agreement). If however, on August 9,
2002, the conditions required to complete the merger have been satisfied, ex-
cept that additional time is needed to obtain the necessary statutory and reg-
ulatory approvals, then the Conectiv/Pepco Merger Agreement is extended for
six additional months. If Conectiv terminates the Conectiv/Pepco Merger Agree-
ment under certain circumstances, Conectiv is required to pay a $60 million
termination fee to Pepco. For example, if Conectiv's Board of Directors con-
cludes that a business combination with another party is more favorable to
Conectiv's stockholders and Conectiv terminates the Conectiv/Pepco Merger
Agreement, then Conectiv is obligated to pay a $60 million termination fee to
Pepco.
COMMON STOCK EARNINGS SUMMARY
Earnings applicable to common stock for 2000 were $164.7 million, or $1.97
per share of common stock (83,686,000 average shares outstanding) and reflect
a gain ($12.8 million after-taxes, or $0.15 per common share) on the sale of
DPL's ownership interests in nuclear power plants and special charges ($23.4
million after-taxes, or $0.28 per share of common stock) for losses on the
sales of the HVAC business and two CTS projects. For 1999, Conectiv reported a
net loss applicable to common stock of $188.5 million, or a loss of $2.02 per
share of common stock (93,320,000 average shares outstanding). The net loss
resulted from (i) a $295.1 million extraordinary charge applicable to common
stock ($3.16 per share of common stock) for discontinuing the application of
Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the
Effects of Certain Types of Regulation," (SFAS No. 71) to the electricity sup-
ply businesses of DPL and ACE because of deregulation, and (ii) $69.7 million
of special charges applicable to common stock ($0.75 per share of common
stock) primarily for write-downs of investments in non-utility businesses and
employee separation costs. For 1998, earnings applicable to common stock were
$141.3 million, or $1.50 per share of common stock (94,338,000 average shares
outstanding), after special charges of $16.8 million ($0.18 per share of com-
mon stock).
For additional information concerning the gain on the sale of the ownership
interests of DPL in nuclear electric generating plants, see "Agreements for
the Sales of Electric Generating Plants" in "Management's Discussion and Anal-
ysis of Financial Condition and Results of Operations" (MD&A) and Note 14 to
the Consolidated Financial Statements. For additional information concerning
special charges, see "Special Charges" in the MD&A and Note 6 to the Consoli-
dated Financial Statements. For additional information concerning deregulation
and the extraordinary charge to earnings, see "Electric Utility Industry Re-
structuring" in the MD&A and Notes 1, 7, 10, 11 and 17 to the Consolidated Fi-
nancial Statements.
As discussed in Note 10 to the Consolidated Financial Statements, ACE's por-
tion of the 1999 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
indicated that a more detailed order would be issued at a later time. If the
NJBPU's final detailed order were to differ materially from the Summary Order,
then another extraordinary item may result due to adjustment of the 1999 ex-
traordinary
II-7
charge. For information concerning a delay in the issuance of the NJBPU's fi-
nal detailed order, see "Agreements for the Sales of Electric Generating
Plants" in the MD&A.
A summary of common stock earnings is shown in the table below.
2000 1999 1998
-------- --------- --------
(Dollars in Millions,
Except Per Share Amounts)
After-tax Contribution to Earnings (Loss)
Applicable to Common Stock
Income Excluding Special Charges, Gain on
Sale of DPL's Interest in Nuclear Plants,
and Extraordinary Item..................... $ 175.3 $ 176.3 $ 158.1
Special Charges............................. (23.4) (69.7) (16.8)
Gain on Sale of DPL's Interest in Nuclear
Plants..................................... 12.8 -- --
-------- --------- --------
Income Before Extraordinary Item............. $ 164.7 $ 106.6 $ 141.3
Extraordinary Item........................... -- (295.1) --
-------- --------- --------
Earnings (Loss) Applicable to Common Stock... $ 164.7 $ (188.5) $ 141.3
======== ========= ========
Average Shares of Common Stock Outstanding
(000)....................................... 83,686 93,320 94,338
-------- --------- --------
After-tax Contribution to Earnings (Loss) Per
Average Share of Common Stock
(1) CCI (telecommunications)............... $ (0.46) $ (0.33) $ (0.19)
(2) CSI (HVAC)............................. (0.09) (0.10) (0.15)
(3) Investment income...................... 0.13 0.27 --
(4) Energy, Power Delivery, and Other...... 2.52 2.05 2.02
-------- --------- --------
Income Excluding Special Charges, Gain on
Sale of DPL's Interest in Nuclear Plants,
and Extraordinary Item.................... $ 2.10 $ 1.89 $ 1.68
Special Charges............................ (0.28) (0.75) (0.18)
Gain on Sale of DPL's Interest in Nuclear
Plants.................................... 0.15 -- --
-------- --------- --------
Earnings (Loss) Per Average Share of Common
Stock:
Before Extraordinary Item.................. $ 1.97 $ 1.14 $ 1.50
Extraordinary Item......................... -- (3.16) --
-------- --------- --------
Earnings (Loss) Per Average Share of Common
Stock....................................... $ 1.97 $ (2.02) $ 1.50
======== ========= ========
(1) CCI (Telecommunications)
As shown above, the loss per share of common stock that resulted from CCI's
operations was $0.46 for 2000, $0.33 for 1999, and $0.19 for 1998. The higher
losses per share of common stock resulted from increased operating and inter-
est expenses due to expansion of CCI's operations and fewer average shares
outstanding of common stock. As discussed above, Conectiv initiated a process
in 2000 to identify a strategic partner for CCI. In the fourth quarter of
2000, CCI reduced the number of its employees in order to minimize expected
operating losses while Conectiv continues to evaluate its partnering or other
options.
(2) CSI (HVAC)
As discussed above, Conectiv sold the HVAC businesses of CSI during mid- to
late-2000. The loss per share of common stock that resulted from CSI's opera-
tions was $0.09 for 2000, $0.10 for 1999, and $0.15 for 1998. In 1999, CSI's
operating losses decreased compared to 1998 due to higher sales and improved
operational efficiencies.
(3) Investment Income
As discussed in Note 8 to the Consolidated Financial Statements, Conectiv
earns investment income primarily from investments in three venture capital
funds, including the EnerTech funds and Tech Leaders II.
II-8
Mainly as a result of distributions of marketable securities received from
these funds, Conectiv also owns marketable securities.
Earnings per share of common stock that resulted from Conectiv's equity in
earnings of the EnerTech funds were $0.16 in 2000, $0.27 in 1999, and insig-
nificant in 1998. The earnings of the EnerTech funds in 2000 resulted primar-
ily from an unrealized gain on the initial public offering of common shares of
Capstone Turbine Corporation (Capstone). Capstone develops, designs, assem-
bles, and sells micro-turbines worldwide in the distributed power generation
market and hybrid electric vehicle market. In 1999, Conectiv's equity in earn-
ings of the EnerTech funds resulted primarily from the initial public offering
of common shares of a business-to-business Internet company. The earnings of
the EnerTech funds may be volatile from period to period due to the nature of
their investments in energy related technology and Internet service companies.
As of December 31, 2000, the carrying amount of Conectiv's investment in the
EnerTech funds was $38.6 million.
Conectiv's other investments that affect its results of operations include
marketable securities (other than those held in nuclear decommissioning trust
funds) and minority interests in a venture capital fund and an Internet start-
up project. For 2000, these investments resulted in a net loss, including $3.0
million before taxes ($2.0 million after taxes, or $0.02 per share of common
stock), which was recognized in earnings and $3.1 million before taxes ($2.0
million after taxes), which was recognized in other comprehensive income (a
separate component of common stockholders' equity). The earnings on these in-
vestments in 1999 and 1998 were insignificant. The carrying value of these in-
vestments was $4.6 million as of December 31, 2000.
(4) Energy, Power Delivery, and Other
The Energy business segment includes (a) the generation, purchase, trading
and sale of electricity, including the obligations of DPL and ACE to supply
electricity to customers who do not choose an alternative electricity suppli-
er; (b) gas and other energy supply and trading activities, (c) power plant
operation services, and (d) district heating and cooling systems operation and
construction services provided by CTS. The Power Delivery business segment in-
cludes activities related to delivery of electricity and gas to customers at
regulated prices over transmission and distribution systems.
Operating Results for 2000 Compared to 1999
The contribution to earnings per share of common stock by "Energy, Power De-
livery, and Other" increased to $2.52 in 2000 from $2.05 in 1999. The $0.47
increase in contribution to earnings per share of common stock was primarily
due to higher profits from Conectiv's non-regulated wholesale energy marketing
and trading operations, higher earnings from a non-utility generation joint
venture, and lower pension and other postretirement benefit costs. The in-
crease in earnings per share of common stock was also enhanced by fewer aver-
age common shares outstanding. Conectiv repurchased 3.4 million and 14.4 mil-
lion shares of Conectiv common stock during 2000 and 1999, respectively. These
common stock repurchases increased earnings per share of common stock for 2000
compared to 1999 by $0.09, after considering the interest expense incurred to
finance the common stock repurchases. These positive variances were partly
offset by the revenue decrease from reductions in regulated Power Delivery
customer rates that resulted from electric utility restructuring in mid- to
late-1999 and the effect of higher average energy prices incurred by DPL in
supplying electricity to customers, as discussed below.
Discontinuing the application of SFAS No. 71 in the third quarter of 1999
benefited the Energy business in 2000 due to related decreases in purchased
capacity and depreciation costs. On the other hand, regulated energy adjust-
ment clauses prior to deregulation had generally eliminated the effect of sea-
sonal and other energy price fluctuations on costs expensed. Since DPL's aver-
age energy costs for supplying electricity increased in 2000, the absence of
the energy adjustment clauses unfavorably affected earnings for 2000 compared
to 1999.
Operating Results for 1999 Compared to 1998
The contribution to earnings per share of common stock by "Energy, Power De-
livery, and Other" increased to $2.05 in 1999 from $2.02 in 1998. The $0.03
increase in contribution to earnings per share of common stock
II-9
was due to higher earnings from electric and gas utility operations attributed
to additional revenue from increased retail sales, partly offset by electric
rate decreases and higher operating expenses. Also, the repurchase of 14.4
million shares of common stock during 1999 contributed $0.06 to the increase
in earnings per share. Lower earnings of a non-utility generation joint ven-
ture partly offset the positive variances from utility operations and the re-
purchase of common stock.
Energy Commodity Market Risk
Conectiv's participation in energy markets results in exposure to commodity
market risk. Conectiv has controls in place that are intended to keep risk ex-
posures within certain management-approved risk tolerance levels. For addi-
tional information concerning commodity market risk, see "Quantitative and
Qualitative Disclosures About Market Risk," included herein.
COMMON STOCK EARNINGS OUTLOOK
As discussed above under "Overview," Conectiv's businesses have undergone
significant change and are expected to continue to change. Among other things,
deregulated electricity generation and energy trading now constitute a greater
portion of Conectiv's earnings. The sale of the HVAC businesses during 2000
has removed an unprofitable operation from Conectiv. On-going business devel-
opments are also expected to cause future operating results to differ from the
past. Accordingly, past results are not an indication of future business pros-
pects or financial results. As Conectiv exits from the regulated electricity
production business and builds mid-merit generation, operating earnings may
temporarily decrease and may also be more volatile. A summary of the key fac-
tors that are expected to affect Conectiv's future earnings are shown below.
. The returns on the proceeds from the expected sale of power plants com-
pared to returns earned on such power plants prior to their sale;
. The performance and operating results of deregulated power plants, which
previously were subject to rate regulation;
. The operating results of energy trading activities, including the impact
of implementing SFAS No. 133, "Accounting for Derivative Instruments and
Hedging Activities," which is expected to increase the volatility of
earnings;
. The profit or loss that results from supplying electricity to customers
who do not choose an alternative energy supplier;
. The amount of income from investments, including the EnerTech funds;
. The level of success encountered in minimizing the expected operating
losses of CCI and finding a partner in the telecommunications business;
. The effect of changes in short-term interest rates on Conectiv's inter-
est expense; and
. Conectiv's ability to achieve cost reductions and streamline operations.
DIVIDENDS ON COMMON STOCK
As discussed in Note 5 to the Consolidated Financial Statements, during the
period the Conectiv/Pepco Merger Agreement is in effect, Conectiv's dividend
payments cannot exceed $0.22 per share of Conectiv common stock per quarter.
Conectiv's Board of Directors declared dividends per share of common stock
of $0.88 in 2000, $1.045 in 1999, and $1.54 in 1998. The decrease in dividends
per share of common stock from 1998-2000 resulted from changing the quarterly
dividend per share in the second quarter of 1999 to $0.22, from $0.385. On May
11, 1999, Conectiv announced that it intended to reduce the dividends on com-
mon stock to a targeted payout ratio of 40% to 60% of earnings per share of
common stock. In 2000, dividends declared per share of common stock repre-
sented approximately 45% of earnings per share of common stock of $1.97.
II-10
CLASS A COMMON STOCK EARNINGS SUMMARY
A summary of Class A common stock earnings is shown in the table below.
2000 1999 1998
------ ------ ------
(Dollars in
Millions,
Except Per Share
Amounts)
After-tax Contribution to Earnings (Loss) Applicable
to Class A Common Stock
Income Excluding Special Charges and Extraordinary
Item............................................. $ 6.1 $ 8.8 $ 11.9
Special Charges................................... -- (1.9) --
------ ------ ------
Income Before Extraordinary Item.................... $ 6.1 $ 6.9 $ 11.9
Extraordinary Item.................................. -- (16.5) --
------ ------ ------
Earnings (Loss) Applicable to Class A Common Stock.. $ 6.1 $ (9.6) $ 11.9
====== ====== ======
Average Shares of Class A Common Stock Outstanding
(000).............................................. 5,742 6,110 6,561
------ ------ ------
After-tax Contribution to Earnings Per Average Share
of Class A Common Stock
Income Excluding Special Charges and Extraordinary
Item............................................. $ 1.06 $ 1.44 $ 1.82
Special Charges................................... -- (0.30) --
------ ------ ------
Earnings (Loss) Per Average Share of Class A Common
Stock:
Before Extraordinary Item......................... $ 1.06 $ 1.14 $ 1.82
Extraordinary Item................................ -- (2.71) --
------ ------ ------
Earnings (Loss) Per Average Share of Class A Common
Stock.............................................. $ 1.06 $(1.57) $ 1.82
====== ====== ======
Earnings applicable to Class A common stock are equal to a percentage of
"Company Net Income Attributable to the Atlantic Utility Group," which con-
sists of earnings of the Atlantic Utility Group (AUG) less $40 million per
year. The AUG includes the assets and liabilities of the electric generation,
transmission, and distribution businesses of ACE that existed on August 9,
1996 and were regulated by the NJBPU. Combustion turbines of ACE that were
transferred on July 1, 2000 to another Conectiv subsidiary, Conectiv Atlantic
Generation, LLC (CAG), remain in the AUG. The percentage of "Company Net In-
come Attributable to the Atlantic Utility Group" that is applicable to Class A
common stock is the "Outstanding Atlantic Utility Fraction" (as defined in
Conectiv's Restated Certificate of Incorporation). The Outstanding Atlantic
Utility Fraction was 27.3% as of December 31, 2000, and 1999, and 30.0% as of
December 31, 1998.
Earnings applicable to Class A common stock were $6.1 million, or $1.06 per
share of Class A common stock, for 2000. For 1999, there was a net loss appli-
cable to Class A common stock of $9.6 million, or $1.57 per share of Class A
common stock. Excluding the $16.5 million extraordinary item that resulted
from deregulation of the electricity supply business of ACE (as discussed in
Notes 1, 7, 10, 11 and 17 to the Consolidated Financial Statements) and $1.9
million of special charges applicable to Class A common stock, earnings appli-
cable to Class A common stock for 1999 were $8.8 million, or $1.44 per share
of Class A common stock. Based on income excluding the special charges and ex-
traordinary item, earnings per share of Class A common stock decreased $0.38
in 2000 compared to 1999. This decrease was mainly due to rate reductions as-
sociated with deregulation of ACE's electricity supply business and the ad-
verse effect of cooler summer weather on ACE's regulated electricity sales. A
lower effective income tax rate for ACE mitigated these unfavorable variances.
Based on income excluding special charges and extraordinary item, earnings
per share of Class A common stock decreased to $1.44 for 1999 from $1.82 for
1998. This $0.38 decrease was mainly due to higher operating expenses for
ACE's electricity delivery and generation businesses and rate decreases, which
became effective on August 1, 1999 due to restructuring of the electric util-
ity industry in New Jersey.
II-11
CLASS A COMMON STOCK EARNINGS OUTLOOK
Any change in the earnings of the AUG impacts the earnings per share of
Class A common stock much more than the earnings per share of Conectiv's com-
mon stock primarily due to the apportionment of the earnings of the AUG be-
tween Conectiv common stock and Conectiv Class A common stock, in accordance
with Conectiv's Restated Certificate of Incorporation, and because a greater
diversity of businesses contribute to earnings applicable to Conectiv common
stock.
The earnings of the AUG have been and will continue to be affected by the
implementation of electric utility industry restructuring in New Jersey, in-
cluding related rate decreases. (See Note 10 to the Consolidated Financial
Statements for information concerning New Jersey electric utility industry re-
structuring.) The planned sales of most of ACE's electric generating plants
(discussed under "Agreements for the Sales of Electric Generating Plants") are
expected to decrease the earnings capacity of the AUG. The extent of the de-
crease in earnings capacity will be affected by how the proceeds from the
sales of the generating plants are utilized. Currently, the proceeds are ex-
pected to be used to repay debt and fund expansion of the mid-merit electric
generation business (which is discussed under "Mid-Merit Electric Genera-
tion"). Under certain circumstances, the Outstanding Atlantic Utility Fraction
may be adjusted. Due to the aforementioned factors, past results are not an
indication of future business prospects or financial results of the AUG.
DIVIDENDS ON CLASS A COMMON STOCK
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 Di-
rectors to consider the financial condition and regulatory environment of
Conectiv and the results of its operations; and also subject to the limita-
tions under applicable law and the provisions of Conectiv's Restated Certifi-
cate of Incorporation.
As disclosed at the time of the 1998 Merger, 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 the results of its operations, to
pay annual dividends on the Class A common stock at a rate equal to 90% of
annualized earnings of the Class A common stock (taking into account the
notional fixed charge of $40 million per year in accordance with Conectiv's
Restated Certificate of Incorporation). 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 the earnings that were applica-
ble to the Class A common stock during the Initial Period, Conectiv's Board of
Directors may consider such fact in determining the appropriate annual divi-
dend rate on the Class A common stock following the Initial Period. Management
expects that during the Initial Period the earnings applicable to Class A com-
mon stock will be less than the dividends on the Class A common stock. Divi-
dends declared per share of Class A common stock were $3.20 for 2000, $3.20
for 1999 and $3.20 for 1998. In comparison, earnings excluding special charges
(discussed in Note 6 to the Consolidated Financial Statements) and the ex-
traordinary item which were applicable to Class A common stock were $1.06 for
2000, $1.44 for 1999 and $1.82 for 1998.
As discussed in Note 5 to the Consolidated Financial Statements, after March
31, 2001 and during the period the Conectiv/Pepco Merger Agreement is in ef-
fect, dividends on Conectiv Class A common stock may be paid at an annual rate
up to 90% of annualized earnings of Class A common stock.
ELECTRIC UTILITY INDUSTRY RESTRUCTURING
During the latter half of 1999, as discussed in Notes 1, 7, 10, and 17 to
the Consolidated Financial Statements, the NJBPU issued a Summary Order to
ACE, and the Delaware Public Service Commission (DPSC) and Maryland Public
Service Commission (MPSC) issued orders to DPL, concerning restructuring the
electricity supply businesses of ACE and DPL, respectively. Based on these or-
ders, 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
II-12
September 30, 1999, respectively. As a result, ACE and DPL discontinued apply-
ing SFAS No. 71 and applied the requirements of SFAS No. 101, "Regulated En-
terprises--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 Applica-
tion of FASB Statements 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 could first elect to choose an alternative electric-
ity supplier. DPL has proposed to the Virginia State Corporation Commission
(VSCC) to offer all of its Virginia retail customers the option of choosing an
alternative electricity supplier beginning on January 1, 2002. Revenues from
regulated retail electricity sales in Virginia represented approximately 1.7%
of Conectiv's regulated retail electric and gas revenues for 2000.
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 on the dates shown in
the table below.
Estimated Annualized
State Revenue Decrease Effective Date
- ----- ------------------------- ---------------
New Jersey........................... $50.0 million, or 5% August 1, 1999
New Jersey........................... $10.0 million, or 1% January 1, 2000
New Jersey........................... $10.0 million, or 1% (1) January 1, 2001
Delaware............................. $17.5 million, or 7.5% (2) October 1, 1999
Maryland............................. $12.5 million, or 7.5% (2) July 1, 2000
- --------
(1) In addition, by August 1, 2002, rates must be ten percent lower than the
rates that were in effect April 30, 1997. This rate decrease is expected
to result in an additional $30 million revenue reduction.
(2) 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 restructuring orders issued by the DPSC and MPSC, 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 agreements for the sale of certain electric generating plants, management
expects to recognize a net gain in earnings when the sales of certain electric
generating plants are completed. There can be no assurances, however, that the
sales of the electric generating plants will be completed pursuant to the
agreements, or that any gain will be realized from such sales of electric gen-
erating plants.
Except for the Deepwater plant (185 megawatts of capacity), any gain or loss
realized upon the sale of electric generating plants of ACE that are subject
to the agreements discussed below under "Agreements for the Sales of Electric
Generating Plants" will affect the amount of ACE's recoverable stranded costs,
due to the terms of the Summary Order. Accordingly, any gain or loss realized
by ACE on the sale of these plants would not
II-13
affect future earnings. Any loss on a sale by July 31, 2002, of the Deepwater
plant, or the combustion turbines formerly owned by ACE before the transfer to
CAG, cannot be recovered from ACE's customers. The agreements for the sale of
electric generating units include the sale of the Deepwater plant at a loss,
which was recorded in the fourth quarter of 1999 as an extraordinary item.
Stranded Cost Recovery and Securitization
Stranded costs are the uneconomic portion of assets and long-term contracts
that resulted from electric utility industry restructuring. The NJBPU's Sum-
mary 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 non-utility generators (NUGs). The
Summary Order, in conjunction with the New Jersey Act, also permits
securitization of stranded costs through the issuance of transition bonds in
the amount of the after-tax stranded cost recovery approved by the NJBPU. Man-
agement expects the transition bonds will be issued after completion of the
sale of the electric generating units of ACE. The ability to issue transition
bonds would depend not only upon approval of the NJBPU, but also on the condi-
tions in the relevant capital markets at the times of the offerings. Proceeds
from the transition bonds may be used to refinance ACE's debt and preferred
securities, finance the restructuring of purchased power contracts, or other-
wise reduce costs in order to decrease regulated electricity rates. Amounts
designed to repay the principal of and interest on the transition bonds will
be collected from customers through a transition bond charge. The income tax
expense associated with the revenues from transition bond charges will be col-
lected from customers through a separate market transition charge. As of De-
cember 31, 2000, the balance for ACE's pre-tax recoverable stranded costs was
approximately $959 million, which includes the stranded costs estimated and
recorded as a result of discontinuing the application of SFAS No. 71 during
1999 and the $228.5 million payment in December 1999 to terminate a NUG con-
tract (see "Termination and Restructuring of Purchased Power Contracts" be-
low). 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 re-
coverable through customer rates under the New Jersey Act.
Based on the DPSC and MPSC restructuring orders, DPL recorded recoverable
stranded costs in the third quarter of 1999, which had a pre-tax balance of
approximately $29 million as of December 31, 2000. Although only partial
stranded cost recovery was provided for by the restructuring orders of the
DPSC and MPSC, any gain that may be realized on the sale of the electric gen-
erating units that were owned by DPL at the time of deregulation will increase
future earnings.
Basic Generation 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. In accordance with the Summary Order, ACE sup-
plies the BGS load requirement primarily with power purchased under its NUG
contracts and the output generated by certain units to be sold. To replace the
output of the generating units to be sold, ACE plans to increase the amount of
power it purchases to supply the BGS load. ACE intends to manage BGS supply
requirements (net of sources otherwise available to it at any particular time)
through the use of a portfolio approach, including the use of competitive bid-
ding. ACE's customer rates are designed to recover the costs of providing BGS
service, including above-market portions of NUG power. As a result, ACE recog-
nizes revenues for BGS service equal to the related costs incurred. Any dif-
ference between such revenues and costs results in a related adjustment to
"Deferred energy supply costs." ACE's customer rates are to be adjusted for
any deferred balance remaining after the initial four-year transition period
ends July 31, 2003. ACE's recovery of BGS supply costs is subject to review by
the NJBPU.
Default Service
DPL is obligated to supply electricity to customers who do not choose an al-
ternative electricity supplier for three years for non-residential customers
and four years for residential customers during the transition periods
II-14
that began on October 1, 1999, in Delaware and July 1, 2000, in Maryland. Dif-
ferences between DPL's actual energy costs and the related amounts included in
customer rates began affecting Conectiv's earnings as of October 1, 1999, for
DPL's Delaware business and July 1, 2000, for DPL's Maryland business.
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.
Termination and Restructuring of Purchased Power Contracts
On November 10, 1999, the NJBPU issued an order approving termination of a
contract under which ACE had purchased energy and 116 megawatts (MW) of capac-
ity from a NUG partnership (Pedricktown Co-generation Limited Partnership, or
"Pedricktown"), which is owned 50% by other Conectiv subsidiaries. The NJBPU
order provided that ACE is entitled to recover from customers the contract
termination payment of $228.5 million, transaction costs, and interim financ-
ing costs. 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. On December 28, 1999, ACE paid $228.5 million to
terminate the contract and borrowed funds to finance the contract termination
payment (as discussed in Note 21 to the Consolidated Financial Statements).
The contract termination payment and related costs are included in "Recover-
able Stranded Costs" on the Consolidated Balance Sheets. ACE's customer rates
were reduced by about 1% (approximately $10 million of revenues on an
annualized basis) effective January 1, 2000 as a result of the net savings
from the contract termination.
On December 6, 2000, the NJBPU approved ACE's payment on January 22, 2001 of
$3.45 million in connection with restructuring ACE's purchased power contract
with a NUG, American Ref-Fuel Company of Delaware Valley, L.P.
Management anticipates that securitization will ultimately be used to fi-
nance the stranded costs associated with the buyout or buydown of ACE's NUG
contracts.
On December 28, 1999, the Conectiv subsidiaries that own 50% of the
Pedricktown NUG partnership with which ACE terminated its contract received an
$82.2 million distribution from Pedricktown. The distribution was primarily
the result of a gain realized by Pedricktown from the contract termination;
the Conectiv subsidiaries' share of the gain was estimated at $75.0 million as
of December 31, 2000 and $70.8 million as of December 31, 1999. Conectiv's
subsidiaries share of the gain is deferred in Conectiv's Consolidated Balance
Sheets and classified under "Deferred Credits and Other Liabilities." The de-
ferred gain is expected to be either (a) amortized to income over the period
revenues are collected from ACE's customers to repay the transition bonds ex-
pected to be issued to recover the contract termination payment, or (b) recog-
nized in income if the Conectiv subsidiaries no longer hold an ownership in-
terest in Pedricktown.
MID-MERIT ELECTRIC GENERATION
Conectiv is changing the types of electric generating plants it owns in con-
junction with implementing its asset-backed, "merchant" strategy focusing on
"mid-merit" electric generating plants. Mid-merit electric generating plants
can quickly increase or decrease their kWh output level on an economic basis.
Mid-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.
In contrast, baseload electric generating plants run almost continuously to
supply the base level of demand for electricity, or the minimum demand level
which generally always exists on an electrical system. Management expects that
mid-merit electric generating plants will be more profitable and provide
higher returns on invested capital than baseload electric generating plants.
As discussed below, DPL sold its ownership interests in baseload nuclear elec-
tric generating plants on December 29, 2000, and the ownership interests of
Conectiv subsidiaries in other baseload electric generating plants are ex-
pected to be sold during 2001, pursuant to existing agreements.
II-15
As a result of electric utility industry restructuring orders issued in
1999, deregulated operation of the electric generating plants owned by
Conectiv subsidiaries was phased in from August 1, 1999 to July 1, 2000. As of
July 1, 2000, approximately 79% of Conectiv's electric generating capacity was
being operated on a deregulated basis and the remaining 21% was dedicated to
supplying BGS customers, in accordance with the terms of the Summary Order is-
sued by the NJBPU.
Conectiv plans to add to its mid-merit electric generating plants by build-
ing combined cycle units, which are constructed with combustion turbines,
waste heat recovery boilers and a steam turbine. On September 21, 2000,
Conectiv announced that it had ordered 21 combustion turbine units, which,
with additional equipment, could be configured into 8 combined cycle plants.
Each combined cycle plant would have approximately 550 MW of capacity, al-
lowing Conectiv to add up to 4,400 MW of electric generating capacity, repre-
senting a potential total investment of about $2.6 billion. Under an acceler-
ated schedule, construction would occur in phases and would be completed by
the end of 2004. Conectiv is actively working on developing sites for combined
cycle plants within the region of the PJM Interconnection, L.L.C. (PJM).
The three new combustion turbines planned for the Hay Road site are expected
to be operational during the summer of 2001 (adding 330 MW of capacity). The
waste heat recovery boiler and steam turbine needed for the new combined cycle
operation at Hay Road are expected to be completed by the third quarter of
2002 (resulting in 550 MW of total capacity for the combined cycle plant).
The number of combined cycle plants ultimately built under Conectiv's mid-
merit construction program and the timing of construction will depend on vari-
ous factors including the following: growth in demand for electricity; con-
struction of generating units by competitors; fuel prices; availability of
suitable financing; possible construction delays; and the timing and ability
to obtain required permits and licenses. The level of the construction program
could also potentially be affected by the planned acquisition of Conectiv by
Pepco. Conectiv has made progress payments on the 21 combustion turbines that
have been ordered. However, Conectiv's Board of Directors has thus far ap-
proved construction of 2 combined cycle plants, for which only 6 combustion
turbines would be needed. Should Conectiv choose not to build all 8 combined
cycle plants, then Conectiv would attempt to sell its related investment in
such combustion turbines and development sites. The ability to find a buyer
and the amount of the proceeds from such a sale would be determined by market
conditions. Through January 31, 2001, Conectiv had made $49 million in pro-
gress payments on the 15 combustion turbines needed to build up to 6 combined
cycle plants in addition to the 2 combined cycle plants currently approved by
the Board of Directors.
AGREEMENTS FOR THE SALES OF ELECTRIC GENERATING PLANTS
As discussed below, DPL and ACE have entered into agreements for the sale of
their respective ownership interests in non-strategic baseload fossil fuel-
fired electric generating plants and ACE has executed agreements for the sale
of its ownership interests in nuclear electric generating plants. Excluding
the ownership interests of DPL in nuclear electric generating plants that were
sold on December 29, 2000, the plants that are subject to sales agreements had
a net book value of $423.2 million and aggregate capacity of 2,203.5 MW as of
December 31, 2000.
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). Pursuant to the agreements, DPL sold its 7.51% (164 MW) inter-
est in Peach Bottom and 7.41% (167 MW) interest in Salem on December 29, 2000
and the related nuclear fuel for approximately $32 million. DPL used approxi-
mately $26 million of the proceeds to repay the lease obligation related to
the nuclear fuel. In accordance with the sales agreements, DPL transferred its
decommissioning trust funds and related obligation for decommissioning the
plants to the purchasers. Completion of these sales resulted in a gain of
$16.6 million before income taxes ($12.8 million after income taxes, or $0.15
per share of Conectiv common stock). The pre-tax gain primarily resulted from
the reversal of previously accrued liabilities associated with the nuclear
plants and is classified as a reduction of operating expenses in the 2000 Con-
solidated Statement
II-16
of Income. ACE's interests in the nuclear units that are subject to the sales
agreements had a $14.5 million net book value as of December 31, 2000 and in-
clude a 7.51% (164 MW) interest in Peach Bottom, a 7.41% interest (167 MW) in
Salem and a 5.0% interest (52 MW) in Hope Creek. The agreements for the sale
of ACE's interests in the nuclear plants provide for (a) a sales price of ap-
proximately $11 million plus the net book value of the interests of ACE in nu-
clear fuel on-hand as of the closing date and (b) the transfer of ACE's nu-
clear decommissioning funds and related obligation for decommissioning the
plants to the purchasers upon completion of the sales.
On January 19, 2000, Conectiv announced that DPL and ACE reached agreements
to sell certain wholly and jointly owned fossil fuel-fired units to NRG Ener-
gy, Inc. (NRG), a subsidiary of Northern States Power Company, for $800 mil-
lion. The units to be sold to NRG have a total capacity of 1,820.5 MW, and had
a net book value of $408.7 million as of December 31, 2000. Management expects
the proceeds from the planned sales of the electric generating plants will be
used to repay debt and to fund expansion of the mid-merit generation business.
The terms of DPL's agreement with NRG provide for DPL to purchase from NRG 500
megawatt-hours of firm electricity per hour from completion of the sale
through December 31, 2005. Upon completion of the sales of the non-strategic
baseload electric generating plants, DPL and ACE will purchase power to supply
electricity to customers who do not choose alternative electricity suppliers.
For information concerning long-term purchased power contracts, see Note 23 to
the Consolidated Financial Statements.
Consummation of the sales of the electric generating plants is subject to
the receipt of required regulatory approvals. In addition, the agreements for
the sales of the electric generating plants contemplated that the sales of the
plants of ACE and DPL would occur simultaneously. Appeals related to the
NJBPU's final order concerning restructuring the electricity supply business
of Public Service Electric and Gas Company (PSE&G) and recent electricity
shortages and price increases in California have resulted in delays in the is-
suance of required regulatory approvals, the NJBPU's final order concerning
restructuring the electricity supply business of ACE, and the closings of the
sales of the electric generating units. Effective October 3, 2000, the agree-
ments relating to the sale of the nuclear plants were amended to, among other
things, permit separate closings of the sales of the ACE and DPL interests in
the nuclear plants. DPL's ownership interests in the nuclear electric generat-
ing plants were sold on December 29, 2000, as discussed above. On December 6,
2000, the New Jersey Supreme Court affirmed the judgment of the New Jersey Su-
perior Court Appellate Division, which had previously upheld the NJBPU's final
order concerning the PSE&G restructuring. Management currently expects the
sales of ACE's nuclear and fossil, and DPL's fossil, electric generating
plants to take place during 2001. However, management cannot predict the tim-
ing of the issuance of required NJBPU approvals, the timing or outcome of ap-
peals, if any, of such approvals, the effect of any of the foregoing on the
ability of ACE or DPL to consummate the sales of various electric generating
plants or the impact of any of the foregoing on ACE's ability to recover or
securitize any related stranded costs.
Based on the terms of the restructuring orders and the sales agreements with
NRG, management expects to recognize a net gain in earnings when DPL completes
the sale of its electric generating plants. There can be no assurances, howev-
er, that the sales of the electric generating plants will be completed pursu-
ant to the agreements, or that any gain will be realized from such sales of
electric generating plants. As of December 31, 2000, approximately $20 million
of costs associated with selling the electric generating plants had been de-
ferred as an adjustment to the expected future gain or loss on the sales. In
the event the sales are not completed, these costs would be expensed.
OPERATING REVENUES
Electric Revenues
2000 1999 1998
-------- -------- --------
(Dollars in millions)
Regulated electric revenues...................... $2,000.3 $2,150.1 $1,918.2
Non-regulated electric revenues.................. 906.0 309.9 285.5
-------- -------- --------
Total electric revenues.......................... $2,906.3 $2,460.0 $2,203.7
======== ======== ========
II-17
The table above shows the amounts of electric revenues earned that are sub-
ject to price regulation (regulated) and that are not subject to price regula-
tion (non-regulated). "Regulated electric revenues" include revenues for de-
livery (transmission and distribution) service and electricity supply service
within the service areas of DPL and ACE.
Regulated Electric Revenues
In 2000, "Regulated electric revenues" decreased by $149.8 million to
$2,000.3 million, from $2,150.1 million for 1999. In 1999, "Regulated electric
revenues" increased by $231.9 million to $2,150.1 million, from $1,918.2 mil-
lion in 1998. Details of the variances in "Regulated electric revenues" are
shown below.
Increase (Decrease) in
Regulated Electric Revenues
---------------------------
2000 compared 1999 compared
to 1999 to 1998
------------- -------------
(Dollars in millions)
Customers choosing alternative electricity
suppliers..................................... $(164.0) $ (7.5)
Decrease in retail rates due to electric
utility industry restructuring, the 1998
Merger, and other............................. (58.9) (27.6)
Variance in volumes of interchange and resale
sales......................................... 33.3 14.6
Revenue adjustment related to BGS cost
recovery...................................... 0.3 17.2
Two additional months of revenues for ACE *.... -- 163.5
Retail sales volume, sales mix, and all other.. 39.5 71.7
------- ------
$(149.8) $231.9
======= ======
- --------
* As a result of the purchase method of accounting and a date of March 1,
1998 for the 1998 Merger, there are two additional months of ACE's revenues
in 1999 compared to 1998.
As discussed above under "Electric Utility Industry Restructuring," the op-
tion of choosing an alternative electricity supplier: (a) became effective Au-
gust 1, 1999 for ACE's customers; (b) was phased-in from October 1, 1999 to
October 1, 2000 for DPL's Delaware customers; and (c) became effective July 1,
2000 for DPL's Maryland customers. Power Delivery customers representing ap-
proximately 6% of the combined peak loads of DPL and ACE were purchasing elec-
tricity from suppliers other than Conectiv as of December 31, 2000.
Regulated retail electricity delivery sales increased by approximately 3% in
2000 and in 1999. Since average customer rates are higher during the summer,
sales variances caused by summer weather have a more significant revenue im-
pact than changes in sales at other times of the year. Summer weather was hot-
ter in 1999 than in 1998 and in 2000; as a result, the positive revenue asso-
ciated with sales for 1999 compared to 1998 was greater than the positive rev-
enue variance for 2000 compared to 1999.
Non-regulated Electric Revenues
"Non-regulated electric revenues" result primarily from electricity trading
activities, bulk sales of electricity including sales of output from deregu-
lated electric generating plants, and competitive retail sales (the supply of
electricity and gas in deregulated retail markets). For 2000, electricity
trading and strategic generation electricity sales each provided about 40% of
"non-regulated electric revenues," and the remaining approximate 20% of "non-
regulated electric revenues" was earned from competitive retail sales.
Customers representing approximately 3% of the combined peak loads of DPL
and ACE were purchasing electricity marketed by "Conectiv Energy" (the trade
name under which Conectiv subsidiaries market competitive retail and wholesale
energy) as of December 31, 2000. Conectiv is in the process of terminating its
competitive retail energy business. Revenues from the competitive retail sales
by Conectiv Energy are included in "non-regulated electric revenues."
II-18
As discussed in Note 12 to the Consolidated Financial Statements, the net
pre-tax gains or gross margin (revenues less related purchased power costs)
from electricity trading activities were $12.5 million in 2000, $6.0 million
in 1999, and $11.4 million in 1998. The gross margin as a percentage of reve-
nues (gross margin percentage) from electricity trading activities is gener-
ally lower than the gross margin percentage for electric generation and deliv-
ery activities. Thus, as Conectiv's electricity trading program has grown over
the past several years, Conectiv's gross margin percentage on total electric
revenues has decreased.
In 2000, "Non-regulated electric revenues" increased by $596.1 million to
$906.0 million, from $309.9 million for 1999. This revenue increase resulted
from higher wholesale sales of electricity generated by deregulated power
plants, increased volumes of electricity traded, and higher competitive retail
electricity sales. A significant portion of the revenue increase is due to the
timing of the deregulation of the electric generating plants. Since DPL's
electric generating plants were deregulated October 1, 1999 in Delaware and
July 1, 2000 in Maryland, the operations of the DPL electric generating plants
for the first nine months of 1999 did not result in any non-regulated electric
revenues. Similarly, since certain electric generating plants of ACE began to
operate on a deregulated basis effective August 1, 1999, only five months of
electricity sales from these plants were included in non-regulated electric
revenues for 1999.
In 1999, "Non-regulated electric revenues" increased by $24.4 million to
$309.9 million, from $285.5 million for 1998. The $24.4 million increase was
mainly due to higher bulk sales of electricity, including sales of the output
of the power plants deregulated during the latter half of 1999, partially off-
set by lower electricity trading volumes. Higher competitive retail electric-
ity sales in Pennsylvania and revenues from ACE's deregulated electric gener-
ating units also contributed to the increase.
Gas Revenues
2000 1999 1998
-------- ------ ------
(Dollars in millions)
Regulated gas revenues............................... $ 112.3 $115.9 $106.7
Non-regulated gas revenues........................... 1,417.5 700.3 428.4
-------- ------ ------
Total gas revenues................................... $1,529.8 $816.2 $535.1
======== ====== ======
DPL earns gas revenues from on-system natural gas sales, which generally are
subject to price regulation, and from the transportation of natural gas for
customers. Conectiv subsidiaries also trade and sell natural gas in transac-
tions that are not subject to price regulation. The table above shows the
amounts of gas revenues earned from sources that were subject to price regula-
tion (regulated) and that were not subject to price regulation (non-regulat-
ed).
For 2000, "Regulated gas revenues" decreased $3.6 million primarily because
some commercial and industrial customers elected to buy gas from alternative
suppliers. Since DPL's gross margin from supplying regulated gas customers is
insignificant, the effect of the revenue decrease on pre-tax profits was mini-
mal. For 1999, "Regulated gas revenues" increased $9.2 million mainly due to
colder winter weather, which caused an increase in residential customers' gas
usage levels for home heating.
"Non-regulated gas revenues" increased by $717.2 million in 2000 and $271.9
million in 1999, primarily due to higher volumes of natural gas traded. In
2000, significantly higher natural gas prices also contributed to the revenue
increase. Revenues from competitive retail gas sales were also higher; howev-
er, Conectiv Energy is phasing-out its competitive retail gas business. As
discussed in Note 12 to the Consolidated Financial Statements, the net pre-tax
gains or gross margin (revenues less related purchased gas costs) from gas
trading activities were $19.7 million in 2000, $5.0 million in 1999, and in-
significant in 1998. The gross margin as a percentage of revenues (gross mar-
gin percentage) from gas trading activities is generally lower than the gross
margin percentage for regulated gas delivery services. Thus, as Conectiv's gas
trading program has grown over the past several years, Conectiv's gross margin
percentage on total gas revenues has decreased.
II-19
Other Services Revenues
Other services revenues were comprised of the following:
2000 1999 1998
------ ------ ------
(Dollars in
millions)
Petroleum sales and trading............................ $338.5 $201.4 $140.6
HVAC................................................... 89.6 134.9 94.9
Telecommunications..................................... 56.1 36.2 10.6
Operation of power plants.............................. 53.6 32.8 26.0
Thermal systems........................................ 27.4 26.1 22.0
Other.................................................. 27.8 37.3 38.7
------ ------ ------
Total................................................ $593.0 $468.7 $332.8
====== ====== ======
Other services revenues increased $124.3 million for 2000 compared to 1999,
primarily due to a $137.1 million increase attributed to higher volumes and
market prices for petroleum sold and traded. The pre-tax gains (revenues less
commodity costs) from petroleum trading activities were $6.6 million in 2000
and $1.3 million in 1999. Other significant revenue variances for 2000 in-
cluded a $20.8 million increase from the operation of additional power plants
for others, a $19.9 million increase in revenue from growth of CCI's telecom-
munications business, and a $45.3 million decrease in HVAC revenues, which re-
sulted from the sale of that business during mid- to late-2000. CCI's revenue
growth is expected to slow as CCI shifts its focus to cost containment while
Conectiv continues to evaluate its partnering or other options for CCI.
Other services revenues for 1999 compared to 1998 increased $135.9 million
primarily due to an additional three months of revenues from a business ac-
quired by Conectiv in March 1998 which sells and trades petroleum, acquisi-
tions of HVAC service businesses, and expansion of CCI's telecommunications
business.
OPERATING EXPENSES
Electric Fuel and Purchased Energy and Capacity
For 2000 compared to 1999, "Electric fuel and purchased energy and capacity"
increased $444.8 million mainly due to more purchased energy for expanded
trading activities and supplying demand within the service areas of ACE and
DPL that were previously supplied by electric generating plants, which are now
deregulated and selling their output in the open market. The increases were
mitigated by lower costs due to termination of the Pedricktown purchased power
contract in the fourth quarter of 1999 and lower capacity costs due to discon-
tinuance of SFAS No. 71 for the electricity supply business.
"Electric fuel and purchased energy and capacity" increased $110.3 million
in 1999 mainly due to expenses associated with the additional two months of
ACE's operations included in the 1999 operating results compared to 1998.
Gas Purchased
Gas purchased increased by $690.9 million for 2000 mainly due to higher vol-
umes of non-regulated natural gas trading activities and higher natural gas
prices, partly offset by lower volumes of gas supplied under regulated tariffs
to commercial and industrial customers in DPL's service area. In 1999, gas
purchased increased $268.6 million primarily due to larger volumes of gas pur-
chased for resale off-system.
Other Services' Cost of Sales
For 2000 compared to 1999, other services' cost of sales increased by $129.7
million, primarily due to higher volumes and market prices of petroleum pur-
chased for resale. The variance also reflects increases associ-
II-20
ated with higher volumes of power plant operation and telecommunication serv-
ices provided, and decreases from the sale of HVAC divisions. In 1999, other
services' cost of sales increased by $111.6 million principally due to in-
creased volumes of petroleum sold and higher volumes of HVAC services provid-
ed.
Special Charges
In 2000, special charges of $25.2 million before income taxes ($23.4 million
after income taxes or $0.28 per share of common stock) resulted from losses on
sales of the HVAC business and two CTS projects. Proceeds of $56 million have
been received from the sales of these businesses, which had total assets of
$79 million at the time of sale.
In 1999, special charges of $105.6 million before taxes were recorded pri-
marily for impairments of assets, including a $43.7 million write-down of in-
vestments in leveraged leases and a $35.6 million write-down of goodwill asso-
ciated with HVAC businesses. The remaining $26.3 million of special charges
were mainly for employee separation costs and costs related to the 1998 Merg-
er. The 1999 special charges decreased net income $71.6 million, earnings per
share of Conectiv common stock by $0.75 and earnings per share of Conectiv
Class A common stock 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 share of Conectiv
common stock) for the cost of DPL employee separations associated with the
1998 Merger-related workforce reduction and other 1998 Merger-related costs.
The 1998 employee separation, relocation, and other 1998 Merger-related costs
for Atlantic and its former subsidiaries were capitalized as costs of the 1998
Merger.
For additional information concerning special charges, see Note 6 to the
Consolidated Financial Statements.
Gain on Sale of Interest in Nuclear Plants
For information concerning the gain in 2000 on the sale of the ownership in-
terests of DPL in nuclear electric generating plants, see the discussion above
under "Agreements for the Sales of Electric Generating Plants."
Operation and Maintenance Expenses
For 2000 compared to 1999, operation and maintenance expenses decreased by
$7.3 million primarily due to lower costs of pension and other postretirement
benefits and a decrease from the sale of the HVAC business, partly offset by
higher operating expenses for electric generating plants and the telecommuni-
cations business.
After excluding the $35.5 million of operation and maintenance expenses at-
tributed to the two additional months of ACE's operations included in 1999 op-
erating results compared to 1998, operation and maintenance expenses increased
by $67.0 million in 1999. This increase was attributed to increased costs as-
sociated with operating and expanding the telecommunications business, operat-
ing electric generating plants, and customer care services for the Power De-
livery business.
Depreciation and Amortization
Depreciation and amortization expenses decreased $11.3 million in 2000
mainly due to the write-downs in the third and fourth quarters of 1999 of the
electric generating plants in connection with restructuring the electric util-
ity industry in Delaware, Maryland, and New Jersey. Depreciation of capital
improvements to the electric transmission and distribution systems placed in-
service during 2000, depreciation of a larger telecommunications system asset
base, and increased amortization of "Recoverable stranded costs" partly offset
the decrease from lower depreciation expense for power plants.
After excluding the two additional months of operating results of ACE and
other former Atlantic-owned businesses included in 1999 operating results com-
pared to 1998, depreciation and amortization expense increased
II-21
$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 the telecommunications and HVAC businesses.
Taxes Other Than Income Taxes
"Taxes other than income taxes" decreased $7.8 million for 2000 compared to
1999 mainly due to a decrease in New Jersey's transitional energy facility as-
sessment, which is being phased out over a five-year period that ends December
31, 2003. The $13.7 million increase in "taxes other than income taxes" for
1999 was principally due to the inclusion of two additional months of operat-
ing results of ACE and other former Atlantic-owned businesses in 1999 compared
to 1998.
OTHER INCOME
Other income for 2000 decreased $21.4 million from 1999 primarily due to a
$21.8 million decrease in Conectiv's equity in earnings of the EnerTech funds,
as discussed above under "Common Stock Earnings Summary." Additional other in-
come from higher equity in earnings of a non-utility generation joint venture
and a gain on the sale of an investment in a leveraged lease was offset by the
write-down of marketable securities, losses on an investment in an Internet
start-up project, prior year income from implementation of mark-to-market ac-
counting for energy trading activities, and other items.
Other income for 1999 increased $34.0 million from 1998 due to the following
items: (a) a $42.1 million increase from the 1999 equity in earnings of the
EnerTech funds; (b) a $17.7 million decrease due to the 1998 equity in earn-
ings of a non-utility generation joint venture; and (c) a $9.6 million in-
crease due to the 1998 write-off of a non-utility investment, 1999 interest
income related to a successful tax appeal, two additional months of ACE's op-
erating results in 1999, and implementation of mark-to-market accounting for
energy trading activities in January 1999.
FINANCING COSTS
Financing costs reflected in the Consolidated Statements of Income include
interest expense and preferred stock dividend requirements of subsidiaries.
In 2000, financing costs increased $35.9 million from 1999 mainly due to ad-
ditional interest expense on borrowings to finance repurchases of Conectiv
common stock, the $228.5 million payment in December 1999 for termination of
the Pedricktown purchased power contract, and the operations of CCI and other
non-utility subsidiaries. Higher short-term interest rates also contributed to
the increases in financing costs.
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 operating results compared to 1998, financing costs increased $21.2 mil-
lion in 1999. This increase was mainly due to additional interest expense on
borrowings to finance repurchases of common stock and the operation of non-
utility businesses.
INCOME TAXES
The effective income tax rate on "Income Before Income Taxes and Extraordi-
nary Item" was higher in 1999 than in 2000 and 1998 primarily due to the
write-off of goodwill (as discussed in Note 6 to the Consolidated Financial
Statements), which was only partly deductible for income tax purposes, and
higher state income tax expenses. See Note 3 to the Consolidated Financial
Statements for a reconciliation of the amount computed by multiplying "income
before income taxes and extraordinary item" by the federal statutory rate to
income tax expense on operations.
NEW ACCOUNTING STANDARD
Conectiv implemented the provisions of SFAS No. 133, "Accounting for Deriva-
tive Instruments and Hedging Activities" (SFAS No. 133), as amended, effective
January 1, 2001. SFAS No. 133 establishes accounting
II-22
and reporting standards for derivative instruments and for hedging activities.
SFAS No. 133 requires all derivative instruments, within the scope of the
statement, to be recognized as assets or liabilities on the balance sheet at
fair value. Changes in the fair value of derivatives that are not hedges, un-
der SFAS No. 133, are recognized in earnings. The gain or loss on a derivative
that hedges exposure to variable cash flow of a forecasted transaction is ini-
tially recorded in other comprehensive income (a separate component of common
stockholders' equity) and is subsequently reclassified into earnings when the
forecasted transaction occurs. Changes in the fair value of other hedging de-
rivatives result in a change in the value of the asset, liability, or firm
commitment being hedged, to the extent the hedge is effective. Any ineffective
portion of a hedge is recognized in earnings immediately.
The initial impact on Conectiv's financial statements of adopting SFAS No.
133 effective January 1, 2001 included the following: (a) recognition of $43.8
million of assets and $38.0 million of liabilities for the fair value of cer-
tain contracts which are classified as derivatives under SFAS No. 133; (b)
derecognition (or elimination) of $0.2 million of deferred credits and $3.1
million of current assets associated with deferred gains and losses from hedg-
ing derivatives; and (c) a "cumulative effect" type of adjustment, which was
recorded as a $5.8 million pre-tax ($3.3 million after-tax) credit to other
comprehensive income. During 2001, approximately $7.6 million before-taxes
($4.4 million after-taxes) of the cumulative effect adjustment recorded in
other comprehensive income is expected to be reclassified to earnings. Subse-
quent to initial adoption, SFAS No. 133 may cause increased volatility in
Conectiv's earnings, revenues and common stockholders' equity.
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 2,203.5 MW of capacity in 2001 for approximately $811 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 mid-merit and other electric gener-
ating units, and repayment of debt and equity securities and capital lease ob-
ligations.
Conectiv's cash flows for 2000, 1999, and 1998 are summarized below.
Cash Provided/(Used)
-------------------------
2000 1999 1998
------- ------- -------
(Dollars in Millions)
Operating Activities.............................. $ 465.3 $ 310.2 $ 372.3
Investing Activities.............................. (278.5) (344.5) (259.4)
Financing Activities.............................. (119.5) 24.7 (82.4)
------- ------- -------
Net change in cash and cash equivalents........... $ 67.3 $ (9.6) $ 30.5
======= ======= =======
Cash Flows From Operating Activities
In 2000, cash flows from operating activities increased by $155.1 million to
$465.3 million, from $310.2 million for 1999. In 1999, net cash provided by
operating activities included a net $146.3 million net cash outflow related to
termination of the Pedricktown NUG purchased power contract, comprised of the
$228.5 million payment by ACE to terminate the contract and $82.2 million of
cash received by the Conectiv subsidiaries with an ownership interest in
Pedricktown. Excluding the impact of the Pedricktown contract termination, op-
erating activities provided a net cash flow of $456.5 million in 1999 compared
to $465.3 million in 2000. This
II-23
$8.8 million increase in cash flow for 2000 compared to 1999 reflects a $101.5
million increase due to lower income taxes paid (net of refunds), which was
largely offset by higher interest expense payments, slower collection of ac-
counts receivable caused by conversion to a new customer billing system in De-
cember 1999, lower cash distributions from investments, and certain other
items.
Cash flows from operating activities for 1999, excluding the net impact of
the Pedricktown contract termination, increased $84.2 million to $456.5 mil-
lion, from $372.3 million in 1998. This increase was primarily due to $45 mil-
lion of cash distributions received from the EnerTech funds in 1999 and two
additional months of ACE's operations included in the consolidated 1999 finan-
cial statements compared to the 1998 financial statements.
Accounts receivable as of December 31, 2000 increased from the balance as of
December 31, 1999 primarily due to higher natural gas and other energy trading
activities, and slower collections of accounts receivable caused by conversion
to a new customer billing system in December 1999. Increased energy trading
activity was the primary reason for an increase in the balance of accounts
payable as of December 31, 2000, compared to December 31, 1999.
Cash Flows From Investing Activities
The most significant items included in cash flows from investing activities
during 2000, 1999, and 1998 are summarized below.
Cash Provided/(Used)
-------------------------
2000 1999 1998
------- ------- -------
(Dollars in Millions)
Capital expenditures............................. $(390.5) $(320.4) $(224.8)
Investments in partnerships...................... (11.8) (23.6) (28.6)
Proceeds from sale of assets..................... 114.6 -- 9.4
All other investing cash flows, net.............. 9.2 (0.5) (15.4)
------- ------- -------
Net cash used by investing activities............ $(278.5) $(344.5) $(259.4)
======= ======= =======
Capital expenditures increased $70.1 million for 2000 to $390.5 million,
from $320.4 million for 1999. This increase was primarily due to the capital
requirements of Conectiv's mid-merit electric generation strategy, including
construction expenditures for combustion turbines that are expected to be con-
figured into combined cycle units. Upgrades of the electric transmission and
distribution systems, which increased system reliability, also contributed to
the increase in capital expenditures.
Capital expenditures increased $95.6 million in 1999 primarily due to con-
struction 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.
Investments in partnerships of $11.8 million for 2000 included the EnerTech
funds and an investment in an Internet start-up business. Investments in part-
nerships of $23.6 million in 1999 and $28.6 million in 1998 were primarily for
funding investments in the EnerTech funds and construction of two jointly
owned CTS projects, which were sold in 2000.
The $114.6 million of proceeds from sale of assets for 2000 includes $56
million for the sales of the HVAC business and two jointly owned CTS projects,
$32 million for the sale of DPL's ownership interests in nuclear electric gen-
erating plants and the related nuclear fuel, and $26.6 million for various
other asset sales. DPL used approximately $26 million of the proceeds from the
sale of its ownership interests in nuclear electric generating plants to repay
the lease obligation related to the nuclear fuel. Primarily due to repayment
of DPL's nuclear fuel lease obligation in 2000, the cash used for "Principal
portion of capital lease payments" (classified within cash
II-24
flows from financing activities) increased in 2000. The sale of DPL's owner-
ship interests in nuclear electric generating plants also resulted in the
transfer of nuclear decommissioning funds to the purchasers, which was the
primary reason for the decrease in the balance of "Funds held by trustee" from
$173.3 million as of December 31, 1999, to $122.4 million as of December 31,
2000.
Cash Flows From Financing Activities
Common dividend payments were $92.0 million in 2000, $135.1 million in 1999,
and $154.1 million in 1998. The decrease in common dividends paid in 2000 and
1999 was due to lower common dividends declared per share of common stock
($0.88 in 2000, $1.045 in 1999, and $1.54 in 1998) and repurchases of common
stock and Class A common stock.
As a registered holding company under PUHCA, Conectiv is required to obtain
SEC authorization for certain financing transactions. Under PUHCA, 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. In the
first and second quarters of 2000, Conectiv had accumulated deficits and re-
ceived SEC approval for the payment of quarterly dividends on shares of common
stock and Class A common stock. PUHCA also prohibits Conectiv, the parent com-
pany, from borrowing from its subsidiaries.
Cash flows from financing activities that resulted from issuing, repurchas-
ing, and redeeming and debt and equity securities of Conectiv and its subsidi-
aries are summarized below for 2000, 1999, and 1998.
Net Cash Provided/(Used)
---------------------------------
Total 2000 1999 1998
------- ------ ------- -------
(Dollars in Millions)
Common stock............................. $(458.0) $(54.5) $(390.3) $ (13.2)
Long-term debt........................... 127.2 (51.0) 345.3 (167.1)
Variable rate demand bonds............... 33.3 -- 33.3 --
Short-term debt.......................... 616.3 129.8 203.6 282.9
Preferred securities..................... (8.8) -- -- (8.8)
------- ------ ------- -------
$ 310.0 $ 24.3 $ 191.9 $ 93.8
======= ====== ======= =======
As shown in the above table, during 2000-1998, cash was used for common
stock and preferred stock financing activities in the amounts of $458.0 mil-
lion and $8.8 million, respectively, and cash was provided by long-term debt,
variable rate demand bonds, and short-term debt financing activities in the
amounts of $127.2 million, $33.3 million, and $616.3 million, respectively.
Most of the common stock financing activity during the three-year period re-
sulted from a repurchase of stock in June of 1999, which reduced the number of
shares of common stock and Class A common stock outstanding by 12.8 million
and 0.8 million, respectively. Conectiv also repurchased shares of common
stock under buyback programs during the three-year period. Repurchases of com-
mon stock have generally been financed through the issuance of long- and
short-term debt. As of December 31, 2000, 2,760,700 shares of common stock re-
mained authorized for repurchase by the Board of Directors.
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, 2000, and December 31, 1999.
December 31, December 31,
2000 1999
------------ ------------
Common stockholders' equity...................... 26.2% 26.2%
Preferred stock of subsidiaries.................. 6.4% 6.6%
Long-term debt and variable rate demand bonds.... 49.2% 52.7%
Short-term debt and current maturities of long-
term debt....................................... 18.2% 14.5%
II-25
Most of Conectiv's short-term borrowing occurs under two credit agreements.
As of December 31, 2000, Conectiv (the holding company) had a $300 million
credit agreement with a five-year term that expires in February 2003 and a
$730 million credit agreement with a one-year term that expires in April 2001.
Conectiv expects to renew the $730 million credit agreement. As of December
31, 2000, Conectiv's credit agreements required a ratio of total indebtedness
to total capitalization of 70% or less and the ratio was 64%, computed in ac-
cordance with the terms of the credit agreements. DPL has a $150 million re-
volving credit facility that expires January 31, 2003 and provides liquidity
for DPL's $104.8 million of Variable Rate Demand Bonds and general corporate
purposes. On a consolidated basis, $468 million was available for borrowing as
of December 31, 2000 under the various credit agreements and credit lines.
In December 2000, Conectiv filed a request with the SEC to increase the au-
thorized short-term debt borrowing capacity for Conectiv (the holding company)
from $1.3 billion (including the short-term debt of DPL) to $2.0 billion (ex-
cluding the short-term debt of DPL). The SEC has "reserved jurisdiction," or
withheld approval pending additional filings, over Conectiv's previous request
for the authority to issue up to $750 million of additional long-term debt.
Under existing SEC financing orders, Conectiv is permitted to issue securi-
ties, other than long-term debt, if the ratio of consolidated common equity to
total capitalization (common equity ratio) is 20% or higher. Based on a re-
cently issued SEC order to another holding company under PUHCA, management be-
lieves that the SEC will authorize the issuance of additional long-term debt
by Conectiv when the common equity ratio is 30% or higher.
Planned Capital Requirements
Management expects future capital expenditures will be primarily for con-
struction of mid-merit electric generating plants and improvements to the
transmission and distribution systems of the Power Delivery business segment.
For 2001, management expects $640 million in capital expenditures, including
$450 million for mid-merit electric generating plants, $140 million for Power
Delivery, and $50 million for various other purposes. After 2001, the level of
capital expenditures will be dependent primarily upon the magnitude of the
mid-merit electric generation construction program, which is discussed under
"Mid-Merit Electric Generation," and the strategies of the new company that is
expected to result from the planned business combination of Conectiv and
Pepco. Construction scheduling, permitting, and other factors may also change
the amount of planned capital expenditures.
Scheduled maturities of long-term debt, including debt sinking fund require-
ments, are $100.7 million in 2001, $370.5 million in 2002, $212.3 million in
2003; $154.5 million in 2004; and $82.8 million in 2005. These amounts include
$57.1 million in 2001 and $171.4 million in 2002 for repayment of $228.5 mil-
lion borrowed in December 1999 to finance ACE's payment to terminate the
Pedricktown NUG contract. This $228.5 million borrowing is expected to be re-
financed by issuing transition bonds. Capital requirements for 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, leasing, 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 such forward-looking in-
formation. For a description of Conectiv's significant accounting policies as-
sociated with these activities see Notes 1 and 12 to the Consolidated Finan-
cial Statements.
II-26
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. The effect of a hypothetical 10%
change in interest rates on the interest costs for short-term and variable
rate debt was approximately $6.1 million as of December 31, 2000 and $4.3 mil-
lion as of December 31, 1999. The increase in the effect of a 10% change in
interest rates was due to higher amounts of short-term debt and higher inter-
est rates.
Equity Price Risk
As discussed in Note 8 to the Consolidated Financial Statements, Conectiv
holds investments in venture capital funds, which invest in securities of en-
ergy related technology and Internet service companies, and in marketable se-
curities. Conectiv is exposed to equity price risk through the securities in-
vested in by the venture capital funds and the marketable securities held di-
rectly by Conectiv. The potential change in the fair value of these invest-
ments resulting from a hypothetical 10% change in quoted securities prices was
approximately $4.0 million as of December 31, 2000 and $2.7 million as of De-
cember 31, 1999. The increase in the potential change in fair value was due to
increased investment in the EnerTech funds. Due to the nature of these invest-
ments and market conditions, the fair value of these investments may change by
substantially more than 10%.
ACE maintains trust funds, as required by the Nuclear Regulatory Commission,
to fund certain costs of nuclear decommissioning (See Note 16 to the Consoli-
dated Financial Statements). These funds are invested primarily in domestic
and international equity securities, fixed-rate, fixed income securities, and
cash and cash equivalents. The equity securities included in ACE's portfolio
are exposed to price fluctuations in equity markets, and the fixed-rate, fixed
income securities are exposed to changes in interest rates. The accounting for
nuclear decommissioning recognizes that the net costs are recovered through
electric rates and the effects of fluctuations in equity prices and interest
rates on the securities in the nuclear decommissioning trust funds do not af-
fect Conectiv's earnings.
Commodity Price Risk
Conectiv's participation in wholesale energy markets includes trading and
arbitrage activities, which expose Conectiv to commodity market risk. 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 lev-
els. Conectiv engages in commodity hedging activities to minimize the risk of
market fluctuations associated with the purchase and sale of energy commodi-
ties (natural gas, petroleum and electricity). Some hedging activities are
conducted using derivative instruments. The remainder of Conectiv's hedging
activity is conducted by backing physical transactions with offsetting physi-
cal 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 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. Conectiv's calculated value at risk with respect to its commodity price
exposure associated with contractual arrangements was approximately $16.9 mil-
lion as of December 31, 2000 and $4.0 million as of December 31, 1999. The
value at risk increased due to an increased level of energy trading activi-
ties. The average, high, and low value at risk for the year ended December 31,
2000 was $16.6 million, $29.7 million and $9.3 million, respectively.
II-27
CONECTIV
ITEM 8. FINANCIAL STATEMENT 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 of America, 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 per-
sonnel.
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 of America which include a review of selected internal controls
to determine 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.
/s/ Howard E. Cosgrove /s/ John C. van Roden
_____________________________________ _____________________________________
Howard E. Cosgrove John C. van Roden
Chairman of the Board and Senior Vice President and
Chief Executive Officer Chief Financial Officer
February 12, 2001
II-28
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, 2000 and 1999, and the results of their op-
erations and their cash flows for each of the three years in the period ended
December 31, 2000 in conformity with accounting principles generally accepted
in the United States of America. 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 con-
solidated financial statements. These financial statements and financial
statement schedules are the responsibility of Conectiv's management; our re-
sponsibility is to express an opinion on these financial statements and finan-
cial statement schedules based on our audits. We conducted our audits of these
statements in accordance with auditing standards generally accepted in the
United States of America, which require that we plan and perform the audit to
obtain reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements, assessing
the accounting principles used and significant estimates made by management,
and evaluating the overall financial statement presentation. We believe that
our audits provide a reasonable basis for our opinion.
/s/ PricewaterhouseCoopers LLP
_____________________________________
PricewaterhouseCoopers LLP
Philadelphia, Pennsylvania
February 12, 2001
II-29
CONECTIV
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31,
----------------------------------
2000 1999 1998
---------- ---------- ----------
(Dollars in Thousands,
Except Per Share Amounts)
Operating Revenues
Electric.................................. $2,906,342 $2,459,970 $2,203,748
Gas....................................... 1,529,785 816,245 535,082
Other services............................ 592,997 468,682 332,776
---------- ---------- ----------
5,029,124 3,744,897 3,071,606
---------- ---------- ----------
Operating Expenses
Electric fuel and purchased energy and
capacity................................. 1,613,579 1,168,792 1,058,492
Gas purchased............................. 1,445,911 754,990 486,411
Other services' cost of sales............. 504,615 374,918 263,319
Special charges........................... 25,162 105,648 27,704
Gain on sale of interest in nuclear
plants................................... (16,612) -- --
Operation and maintenance................. 627,667 634,966 532,419
Depreciation and amortization............. 260,082 271,348 241,420
Taxes other than income taxes............. 80,886 88,646 74,926
---------- ---------- ----------
4,541,290 3,399,308 2,684,691
---------- ---------- ----------
Operating Income........................... 487,834 345,589 386,915
---------- ---------- ----------
Other Income............................... 49,495 70,881 36,860
---------- ---------- ----------
Interest Expense
Interest charges.......................... 223,445 182,821 153,644
Capitalized interest and allowance for
borrowed funds used during
construction............................. (10,843) (5,639) (4,213)
---------- ---------- ----------
212,602 177,182 149,431
---------- ---------- ----------
Preferred Stock Dividend Requirements of
Subsidiaries.............................. 20,383 19,894 15,326
---------- ---------- ----------
Income Before Income Taxes and
Extraordinary Item........................ 304,344 219,394 259,018
Income Taxes, Excluding Income Taxes
Applicable to Extraordinary Item.......... 133,514 105,816 105,817
---------- ---------- ----------
Income Before Extraordinary Item........... 170,830 113,578 153,201
Extraordinary Item (Net of $188,254 of
income taxes)............................. -- (311,718) --
---------- ---------- ----------
Net Income (Loss).......................... $ 170,830 $ (198,140) $ 153,201
========== ========== ==========
Earnings (Loss) Applicable To:
Common stock
Income before extraordinary item......... $ 164,719 $ 106,639 $ 141,292
Extraordinary item, net of income taxes.. -- (295,161) --
---------- ---------- ----------
Total................................... $ 164,719 $ (188,522) $ 141,292
========== ========== ==========
Class A common stock
Income before extraordinary item......... $ 6,111 $ 6,939 $ 11,909
Extraordinary item, net of income taxes.. -- (16,557) --
---------- ---------- ----------
Total................................... $ 6,111 $ (9,618) $ 11,909
========== ========== ==========
Average Shares Outstanding (000)
Common stock.............................. 83,686 93,320 94,338
Class A common stock...................... 5,742 6,110 6,561
Earnings (Loss) Per Average Share, Basic
and Diluted
Common stock
Before extraordinary item................ $ 1.97 $ 1.14 $ 1.50
Extraordinary item....................... -- (3.16) --
---------- ---------- ----------
Total................................... $ 1.97 $ (2.02) $ 1.50
========== ========== ==========
Class A common stock
Before extraordinary item................ $ 1.06 $ 1.14 $ 1.82
Extraordinary item....................... -- (2.71) --
---------- ---------- ----------
Total................................... $ 1.06 $ (1.57) $ 1.82
========== ========== ==========
Dividends Declared Per Share
Common stock.............................. $ 0.88 $ 1.045 $ 1.54
Class A common stock...................... $ 3.20 $ 3.20 $ 3.20
See accompanying Notes to Consolidated Financial Statements.
II-30
CONECTIV
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
-------------------------------
2000 1999 1998
--------- --------- ---------
(Dollars in Thousands)
Cash Flows From Operating Activities
Net income (loss)........................... $ 170,830 $(198,140) $ 153,201
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............................ 25,162 105,648 27,704
Depreciation and amortization.............. 283,057 294,902 261,457
Investment tax credit adjustments, net..... (10,115) (5,094) (4,002)
Deferred income taxes, net................. 114,257 44,752 4,620
Net change in:
Accounts receivable........................ (267,477) (92,952) (118,578)
Inventories................................ 5,817 (14,753) (9,691)
Accounts payable........................... 182,105 61,561 107,005
Accrued/prepaid taxes...................... 24,252 (34,757) 12,894
Other current assets & liabilities (1)..... (25,869) (393) (22,676)
Other, net.................................. (36,733) (4,672) (39,625)
--------- --------- ---------
Net cash provided by operating activities... 465,286 310,169 372,309
--------- --------- ---------
Cash Flows From Investing Activities
Acquisition of businesses, net of cash
acquired................................... (954) (17,138) (2,590)
Capital expenditures........................ (390,540) (320,395) (224,831)
Investments in partnerships................. (11,786) (23,570) (28,594)
Proceeds from assets sold................... 114,639 -- 9,421
Deposits to nuclear decommissioning trust
funds...................................... (738) (5,880) (10,676)
Decrease in bond proceeds held in trust
funds...................................... -- 12,449 --
Leveraged leases, net....................... 9,569 8,242 2,410
Other, net.................................. 1,319 1,826 (4,492)
--------- --------- ---------
Net cash used by investing activities....... (278,491) (344,466) (259,352)
--------- --------- ---------
Cash Flows From Financing Activities
Common stock dividends paid................. (92,009) (135,134) (154,101)
Common stock issued......................... 187 68 63
Common stock redeemed....................... (54,651) (390,397) (13,232)
Preferred securities issued................. -- -- 25,000
Preferred securities redeemed............... -- -- (33,769)
Long-term debt issued....................... 70,140 478,500 33,000
Long-term debt redeemed..................... (121,119) (133,218) (200,078)
Variable rate demand bonds issued........... -- 33,330 --
Principal portion of capital lease
payments................................... (48,547) (23,554) (20,037)
Net change in short-term debt............... 129,842 203,627 282,889
Cost of issuances and refinancings.......... (3,315) (8,570) (2,147)
--------- --------- ---------
Net cash provided (used) by financing
activities................................. (119,472) 24,652 (82,412)
--------- --------- ---------
Net change in cash and cash equivalents....... 67,323 (9,645) 30,545
Beginning of year cash and cash equivalents... 56,239 65,884 35,339
--------- --------- ---------
End of year cash and cash equivalents......... $ 123,562 $ 56,239 $ 65,884
========= ========= =========
- --------
(1) Other than debt and deferred income taxes classified as current.
See accompanying Notes to Consolidated Financial Statements.
II-31
CONECTIV
CONSOLIDATED BALANCE SHEETS
As of December 31,
---------------------
2000 1999
---------- ----------
(Dollars in
Thousands)
ASSETS
Current Assets
Cash and cash equivalents.............................. $ 123,562 $ 56,239
Accounts receivable, net of allowances of $31,339 and
$11,564, respectively................................. 792,843 544,463
Inventories, at average cost
Fuel (coal, oil and gas)............................. 54,578 65,360
Materials and supplies............................... 62,675 58,177
Deferred energy supply costs........................... 22,094 8,612
Prepaid income taxes................................... -- 15,674
Other prepayments...................................... 23,354 20,295
Deferred income taxes, net............................. 13,155 25,175
---------- ----------
1,092,261 793,995
---------- ----------
Investments
Investment in leveraged leases......................... 53,706 72,161
Funds held by trustee.................................. 122,387 173,247
Other investments...................................... 70,780 100,764
---------- ----------
246,873 346,172
---------- ----------
Property, Plant and Equipment
Electric generation.................................... 1,576,550 1,571,556
Electric transmission and distribution................. 2,711,907 2,633,375
Gas transmission and distribution...................... 277,650 265,708
Other electric and gas facilities...................... 390,313 405,303
Telecommunications, thermal systems, and other
property, plant, and equipment........................ 251,567 238,229
---------- ----------
5,207,987 5,114,171
Less: Accumulated depreciation......................... 2,179,951 2,097,529
---------- ----------
Net plant in service................................... 3,028,036 3,016,642
Construction work-in-progress.......................... 406,884 199,390
Leased nuclear fuel, at amortized cost................. 28,352 55,983
Goodwill, net of accumulated amortization of $33,437
and $22,277, respectively............................. 344,514 369,468
---------- ----------
3,807,786 3,641,483
---------- ----------
Deferred Charges and Other Assets
Recoverable stranded costs, net........................ 988,153 1,030,049
Deferred recoverable income taxes...................... 84,730 93,853
Unrecovered purchased power costs...................... 14,487 28,923
Unrecovered New Jersey state excise tax................ 10,360 22,567
Deferred debt refinancing costs........................ 20,656 21,113
Deferred other postretirement benefit costs............ 29,981 32,479
Prepaid pension costs.................................. 69,963 35,005
Unamortized debt expense............................... 25,553 28,045
License fees........................................... 21,956 23,331
Other.................................................. 65,236 41,447
---------- ----------
1,331,075 1,356,812
---------- ----------
Total Assets............................................. $6,477,995 $6,138,462
========== ==========
See accompanying Notes to Consolidated Financial Statements.
II-32
CONECTIV
CONSOLIDATED BALANCE SHEETS
As of December 31,
----------------------
2000 1999
---------- ----------
(Dollars in Thousands)
CAPITALIZATION AND LIABILITIES
Current Liabilities
Short-term debt.............................. $ 709,530 $ 579,688
Long-term debt due within one year........... 100,721 48,937
Variable rate demand bonds................... 158,430 158,430
Accounts payable............................. 490,887 307,764
Taxes accrued................................ 10,877 --
Interest accrued............................. 45,296 41,137
Dividends payable............................ 27,111 27,545
Deferred energy supply costs................. 34,650 46,375
Current capital lease obligation............. 15,591 28,715
Above-market purchased energy contracts and
other electric restructuring liabilities.... 23,891 41,101
Other........................................ 107,025 91,353
---------- ----------
1,724,009 1,371,045
---------- ----------
Deferred Credits and Other Liabilities
Other postretirement benefits obligation..... 90,335 96,388
Deferred income taxes, net................... 823,094 730,987
Deferred investment tax credits.............. 64,316 74,431
Regulatory liability for New Jersey income
tax benefit................................. 49,262 49,262
Above-market purchased energy contracts and
other electric restructuring liabilities.... 103,575 119,704
Deferred gain on termination of purchased
energy contract............................. 74,968 70,849
Long-term capital lease obligation........... 13,744 30,395
Other........................................ 67,751 47,447
---------- ----------
1,287,045 1,219,463
---------- ----------
Capitalization
Common stock: $0.01 per share par value;
150,000,000 shares authorized; shares
outstanding--82,859,779 in 2000, and
86,173,169 in 1999.......................... 830 863
Class A common stock, $0.01 per share par
value; 10,000,000 shares authorized; shares
outstanding-- 5,742,315 in 2000 and 1999.... 57 57
Additional paid-in capital--common stock..... 1,028,780 1,085,060
Additional paid-in capital--Class A common
stock....................................... 93,738 93,738
Retained earnings/(Accumulated deficit)...... 42,768 (36,472)
Treasury shares, at cost:
130,604 shares in 2000; 167,514 shares in
1999........................................ (2,688) (3,446)
Unearned compensation........................ (1,172) (1,627)
Accumulated other comprehensive income....... (2,044) --
---------- ----------
Total common stockholders' equity........... 1,160,269 1,138,173
Preferred stock and securities of
subsidiaries:
Not subject to mandatory redemption......... 95,933 95,933
Subject to mandatory redemption............. 188,950 188,950
Long-term debt............................... 2,021,789 2,124,898
---------- ----------
3,466,941 3,547,954
---------- ----------
Commitments and Contingencies (Notes 23, 24,
and 26)
---------- ----------
Total Capitalization and Liabilities........... $6,477,995 $6,138,462
========== ==========
See accompanying Notes to Consolidated Financial Statements.
II-33
CONECTIV
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDERS' EQUITY
Additional
Par Value Paid-in Capital
----------------- ------------------
Class Retained
Common Total Common A Class A Earnings
Shares Stockholders' Common Common Common Common (Accumulated Treasury Unearned
Outstanding Equity Stock (1) Stock Stock Stock Deficit) Stock Compensation
----------- ------------- --------- ------ --------- ------- ------------ --------- ------------
(Dollars in Thousands)
Balance as of
December 31,
1997............. 61,210,262 $ 954,496 $ 139,116 $ 526,812 $ 300,757 $ (11,687) $ (502)
Net income....... 153,201 153,201
Comprehensive
income...........
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
CICP (2)........ 78,381 63 7 (427) 1,613 (1,130)
1998 Merger (3)
(4)............. 45,924,284 915,854 (138,111) 66 946,804 107,095
Reacquired common
stock............ (598,862) (13,232) (5) (10,947) (2,280)
Redemption of
preferred stock.. -- (587) 136 (723)
Incentive
compensation
Expense
recognition..... -- 572 309 263
Forfeited common
shares.......... (25,158) -- (12) (533) 545
----------- --------- --------- --- --------- ------- --------- --------- ------
Balance as of
December 31,
1998 (4)......... 107,077,380 1,843,161 1,007 66 1,462,675 107,095 276,939 (3,797) (824)
Net loss......... (198,140) (198,140)
Comprehensive
income...........
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 (2)........ 95,676 68 1 1,475 375 (1,783)
Reacquired common
stock
Tender Offer
(5)............. (13,586,512) (361,373) (128) (9) (347,879) (13,357)
Common stock
purchased....... (1,671,060) (31,397) (17) (31,356) (24)
Incentive
compensation
expense.......... 1,125 145 980
----------- --------- --------- --- --------- ------- --------- --------- ------
Balance as of
December 31,
1999 (6)......... 91,915,484 1,138,173 863 57 1,085,060 93,738 (36,472) (3,446) (1,627)
Accumulated
Other
Comprehensive Comprehensive
Income/(Loss) Income/(Loss)
------------- -------------
Balance as of
December 31,
1997.............
Net income....... $ 153,201
-------------
Comprehensive
income........... $ 153,201
=============
Cash dividends
declared
Common stock
($1.54 per
share)..........
Class A common
stock ($3.20 per
share)..........
Issuance of
common stock
Business
acquisitions....
CICP (2)........
1998 Merger (3)
(4).............
Reacquired common
stock............
Redemption of
preferred stock..
Incentive
compensation
Expense
recognition.....
Forfeited common
shares..........
------------- -------------
Balance as of
December 31,
1998 (4).........
Net loss......... $(198,140)
-------------
Comprehensive
income........... $(198,140)
=============
Cash dividends
declared
Common stock
($1.045 per
share)..........
Class A common
stock ($3.20 per
share)..........
Issuance of
common stock
CICP (2)........
Reacquired common
stock
Tender Offer
(5).............
Common stock
purchased.......
Incentive
compensation
expense..........
------------- -------------
Balance as of
December 31,
1999 (6).........
Continued on following page
II-34
Additional
Par Value Paid-in Capital
------------- -------------------
Class Retained Accumulated
Common Total Common Common A Class A Earnings Other
Shares Stockholders' Stock Common Common Common (Accumulated Treasury Unearned Comprehensive
Outstanding Equity (1) Stock Stock Stock Deficit) Stock Compensation Income/(Loss)
----------- ------------- ------ ------ ---------- ------- ------------ -------- ------------ -------------
(Dollars in Thousands)
Balance as of
December 31,
1999 (6)......... 91,915,484 $1,138,173 $863 $57 $1,085,060 $93,738 $(36,472) $(3,446) $(1,627)
Net Income....... 170,830 170,830
Unrealized net
loss on
marketable
securities, net
of $890 of income
taxes............ (1,653) (1,653)
Reclassification
adjustment for
realized gain on
marketable
securities net of
$211 of income
taxes............ (391) (391)
Comprehensive
income...........
Cash dividends
declared
Common stock
($0.88 per
share).......... (73,215) (73,215)
Class A common
stock ($3.20 per
share).......... (18,375) (18,375)
Issuance of
common stock
CICP (2)........ 146,975 187 1 520 1,059 (1,393)
Reacquired common
stock (7)........ (3,411,465) (54,650) (34) (54,610) (6)
Incentive
compensation
Expense
recognition..... (637) (1,437) 800
Forfeited common
shares.......... (48,900) -- (753) (295) 1,048
---------- ---------- ---- --- ---------- ------- -------- ------- ------- -------
Balance as of
December 31,
2000 (8)......... 88,602,094 $1,160,269 $830 $57 $1,028,780 $93,738 $ 42,768 $(2,688) $(1,172) $(2,044)
========== ========== ==== === ========== ======= ======== ======= ======= =======
Comprehensive
Income/(Loss)
-------------
Balance as of
December 31,
1999 (6).........
Net Income....... $170,830
Unrealized net
loss on
marketable
securities, net
of $890 of income
taxes............ (1,653)
Reclassification
adjustment for
realized gain on
marketable
securities net of
$211 of income
taxes............ (391)
-------------
Comprehensive
income........... $168,786
=============
Cash dividends
declared
Common stock
($0.88 per
share)..........
Class A common
stock ($3.20 per
share)..........
Issuance of
common stock
CICP (2)........
Reacquired common
stock (7)........
Incentive
compensation
Expense
recognition.....
Forfeited common
shares..........
Balance as of
December 31,
2000 (8).........
(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 1998 Merger
and $0.01 per share after the 1998 Merger on March 1, 1998.
(2) Includes restricted common shares granted and stock options exercised un-
der the Conectiv Incentive Compensation Plan (CICP), and under the incen-
tive plan of Delmarva Power & Light Company (DPL) in 1998.
(3) Conectiv common stock and Conectiv Class A common stock were issued to
former Atlantic common shareholders, and Conectiv common stock was issued
to former DPL common stockholders, pursuant to the 1998 Merger discussed
in Note 4 to the Consolidated Financial Statements.
(4) Includes 6,560,612 shares of Conectiv Class A common stock; all other
shares are Conectiv common stock.
(5) 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 18 to the Consolidated Financial Statements.
(6) Includes 86,173,169 shares of Conectiv common stock and 5,742,315 shares
of Conectiv Class A common stock.
(7) As of December 31, 2000, 2,760,700 shares of common stock remained autho-
rized for purchase under a stock purchase program.
(8) Includes 82,859,779 shares of Conectiv common stock and 5,742,315 shares
of Conectiv Class A common stock.
See accompanying Notes to Consolidated Financial Statements.
II-35
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 transactions (the 1998 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.
On February 9, 2001, the Boards of Directors of Conectiv and Potomac Elec-
tric Power Company (Pepco) approved an Agreement and Plan of Merger
(Conectiv/Pepco Merger Agreement) under which Pepco will acquire Conectiv for
a combination of cash and stock. The transaction is subject to various statu-
tory and regulatory approvals and approval by the stockholders of Conectiv and
Pepco. See Note 5 to the Consolidated Financial Statement for additional in-
formation.
DPL and ACE are public utilities that supply and deliver electricity to
their customers under the trade name Conectiv Power Delivery. As discussed be-
low, DPL also supplies and delivers natural gas to its customers. A 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 de-
liver electricity within their service areas to approximately 973,600 custom-
ers through their respective transmission and distribution systems. DPL and
ACE also supply electricity to most of their electricity delivery customers
who have the option of choosing an alternative supplier. DPL's regulated elec-
tric 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 Jersey. On a combined basis, DPL's and ACE's regu-
lated electric service areas encompass 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
110,800 customers located in a service territory that covers about 275 square
miles with a population of approximately 0.5 million in northern Delaware.
During 1998-2000, DPL also sold gas off-system and in markets that are not
subject to price regulation.
Strategic electric generating plants of DPL and ACE, with capacity of 1,501
megawatts (MW) and 502 MW, respectively, were transferred to other Conectiv
subsidiaries on July 1, 2000. The Conectiv subsidiaries which received the
transferred plants became subsidiaries of Conectiv Energy Holding Company
(CEH). CEH and its subsidiaries are engaged in non-regulated electricity pro-
duction and sales, energy trading and marketing.
During 1999 and 2000, as discussed in Note 14 to the Consolidated Financial
Statements, DPL and ACE entered into agreements for the sale of their nuclear
and non-strategic baseload fossil fuel-fired electric generating plants. Pur-
suant to the agreements, DPL sold its 7.51% (164 MW) interest in Peach Bottom
Atomic Power Station (Peach Bottom) and 7.41% (167 MW) interest in Salem Nu-
clear Generating Station (Salem) on December 29, 2000. After completion of the
sales of the non-strategic baseload fossil electric generating plants of DPL
and the nuclear and non-strategic baseload fossil fuel-fired electric generat-
ing plants of ACE, the principal remaining businesses of DPL and ACE will be
the transmission and distribution, or delivery, of electricity. DPL and ACE
will purchase power to supply electricity to customers who do not choose al-
ternative electricity suppliers. DPL will also continue to supply and deliver
gas under regulated tariffs.
II-36
"Other services," which are not subject to price regulation, are provided
primarily by Conectiv's non-utility subsidiaries and, to a lesser extent, by
DPL and ACE. The principal businesses included in revenues from "Other servic-
es" are as follows: heating, ventilation, and air conditioning (HVAC) con-
struction and services; telecommunications, including local and long-distance
phone services; construction and operation of district heating and cooling
systems; power plant operation services; leveraged leases; and sales of petro-
leum products. As discussed in Note 6 to the Consolidated Financial State-
ments, Conectiv sold its HVAC businesses and portions of its district heating
and cooling systems business during 2000. (Revenues from non-regulated elec-
tricity and gas sales are included in "Electric" revenues and "Gas" revenues,
respectively.)
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 (NJBPU), the Virginia
State Corporation Commission (VSCC), and the Federal Energy Regulatory Commis-
sion (FERC). As discussed below, the nature of regulation of retail electric-
ity sales by these regulatory commissions changed during 1999. Excluding sales
not subject to price regulation, the percentages of retail electric and gas
utility operating revenues regulated by each regulatory commission for the
year ended December 31, 2000, were as follows: NJBPU, 45.9%; DPSC, 34.0%;
MPSC, 18.4%; and VSCC, 1.7%. Wholesale sales are subject to FERC regulation.
Retail gas sales are subject to regulation by the DPSC.
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 commission actions.
In the latter half of 1999, as discussed in Note 10 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
electric restructuring legislation enacted earlier in 1999. Based on these or-
ders, 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 electric-
ity supply businesses and applied the requirements of SFAS No. 101, "Regulated
Enterprises--Accounting for the Discontinuation of Application of FASB State-
ment 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 Ap-
plication of FASB Statements No. 71 and No. 101" (EITF 97-4). For information
concerning the extraordinary charge to 1999 earnings that resulted from apply-
ing the requirements of SFAS No. 101 and EITF 97-4, refer to Note 7 to the
Consolidated Financial Statements.
Refer to Note 17 to the Consolidated Financial Statements for information
about regulatory assets and liabilities 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.
II-37
Within the Consolidated Statements of Income, amounts previously reported
for 1999 and 1998 as "Electric fuel and purchased power" and "Purchased elec-
tric capacity" have been combined and reported as "Electric fuel and purchased
energy and capacity." Certain other 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 accounting prin-
ciples generally accepted in the United States of America requires management
to make certain estimates and assumptions. These assumptions affect the re-
ported amounts of assets and liabilities and disclosure of contingent assets
and liabilities at the date of the financial statements and the reported
amounts of revenues and expenses during the reporting period. Actual results
could differ from those estimates and assumptions.
Revenue Recognition
DPL and ACE recognize revenues for the supply and delivery of electricity
and gas upon delivery to the customer, including amounts for services ren-
dered, but not yet billed. Similarly, revenues from "Other services" are rec-
ognized when services are performed or products are delivered.
Energy Supply Costs
Prior to deregulation of electricity supply in 1999, regulated electric cus-
tomer rates were subject to adjustment for differences between energy costs
incurred in supplying regulated customers and amounts billed to customers for
recovery of such costs. These customer rate adjustments occurred under "energy
adjustment clauses." As a result of the energy adjustment clauses, 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 the regulated customers. An asset was recorded 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 10 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
and July 1, 2000 for DPL's Maryland electricity supply business, the practice
of deferring the difference between the amount collected in revenues for en-
ergy costs and the amount of actual energy costs incurred was ended. As a re-
sult, differences between DPL's energy revenues and expenses have affected
earnings subsequent to the elimination of the rate adjustment mechanism.
As discussed under "Shopping Credits and Basic Generation Service" in Note
10 to the Consolidated Financial Statements, the electric restructuring Sum-
mary Order issued by the NJBPU to ACE provides for recovery through customer
rates of energy 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 re-
turn on certain electric generating plants.
The amount recognized in the Consolidated Statements of Income for the cost
of gas purchased to supply DPL's regulated gas customers is adjusted to the
amount included in customer billings for such costs since customer rates are
periodically adjusted to reflect amounts actually paid by DPL for purchased
gas.
Nuclear Fuel
As discussed in Note 14 to the Consolidated Financial Statements, DPL sold
its ownership interests in Peach Bottom and Salem and the related nuclear fuel
on December 29, 2000. Prior to the sales, the ownership interests
II-38
of DPL in nuclear fuel at Peach Bottom and Salem were financed through nuclear
fuel energy contracts, which were accounted for as capital leases. ACE has
similar contracts in place, which are considered capital leases, that finance
its ownership interest in the nuclear fuel at Peach Bottom, Salem, and Hope
Creek Nuclear Generating Station (Hope Creek). Nuclear fuel costs, including
estimated future disposal costs, are charged to fuel expense on a unit-of-pro-
duction basis.
Energy Trading and Risk Management Activities
Conectiv uses futures, options, swap agreements, and forward contracts to
hedge firm commitments or anticipated transactions of energy commodities and
also creates net open energy commodity positions, or trading positions. On
January 1, 1999, Conectiv adopted the EITF consensus EITF 98-10, "Accounting
for Contracts Involved in Energy Trading and Risk Management Activities" (EITF
98-10) under which contracts (including derivative instruments) entered into
in connection with energy trading activities are marked to market, with gains
and losses (unrealized and realized) included in earnings. Energy trading ac-
tivities are recorded on a gross basis, with sales reported as revenues and
purchases included in operating expenses. The initial implementation of EITF
98-10 did not have a material impact on net income. In 1998, prior to imple-
mentation of EITF 98-10, certain energy trading transactions were accounted
for with "hedge accounting," as discussed below.
Conectiv implemented the provisions of SFAS No. 133, "Accounting for Deriva-
tive Instruments and Hedging Activities" (SFAS No. 133), as amended, effective
January 1, 2001. SFAS No. 133 establishes accounting and reporting standards
for derivative instruments and for hedging activities. SFAS No. 133 requires
all derivative instruments, within the scope of the statement, to be recog-
nized as assets or liabilities on the balance sheet at fair value. Changes in
the fair value of derivatives that are not hedges, under SFAS No. 133, are
recognized in earnings. The gain or loss on a derivative that hedges exposure
to variable cash flow of a forecasted transaction is initially recorded in
other comprehensive income (a separate component of common stockholders' equi-
ty) and is subsequently reclassified into earnings when the forecasted trans-
action occurs. Changes in the fair value of other hedging derivatives result
in a change in the value of the asset, liability, or firm commitment being
hedged, to the extent the hedge is effective. Any ineffective portion of a
hedge is recognized in earnings immediately.
During 1998-2000, gains and losses related to derivative hedging instruments
were deferred, as deferred credits or current assets, and then recognized in
operating results when the underlying transaction occurred. If, subsequent to
being hedged, the underlying transaction was no longer likely to occur or the
hedge was no longer effective, the gain or loss on the related derivative was
recognized currently in operating results. Premiums paid for options purchased
during 1998-2000 were recorded as current assets and amortized to expense over
the life of the options.
Gains and losses on hedges of the cost of energy are reflected within the
Consolidated Statements of Income as "Electric fuel and purchased energy and
capacity" or "Gas purchased," as appropriate for the hedged transaction. Gains
and losses on hedges of the selling price of generated electricity are recog-
nized in revenues. Margin requirements for futures contracts are recorded as
current assets.
The initial impact on Conectiv's financial statements of adopting SFAS No.
133 effective January 1, 2001 included the following: (a) recognition of $43.8
million of assets and $38.0 million of liabilities for the fair value of cer-
tain contracts which are classified as derivatives under SFAS No. 133; (b)
derecognition (or elimination) of $0.2 million of deferred credits and $3.1
million of current assets associated with deferred gains and losses from hedg-
ing derivatives; and (c) a "cumulative effect" type of adjustment, which was
recorded as a $5.8 million pre-tax ($3.3 million after-tax) credit to other
comprehensive income. During 2001, approximately $7.6 million before-taxes
($4.4 million after-taxes) of the cumulative effect adjustment recorded in
other comprehensive income is expected to be reclassified to earnings. Subse-
quent to initial adoption, SFAS No. 133 may cause increased volatility in
Conectiv's earnings, revenues and common stockholders' equity.
The cash flows from derivatives are included in the "Cash Flows From Operat-
ing Activities" section of the Consolidated Statements of Cash Flows.
II-39
For additional information concerning energy trading and risk management ac-
tivities, refer to Note 12 to the Consolidated Financial Statements.
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 3.4% for 2000, 3.5% for 1999, and
3.8% for 1998. 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 16 to the Consoli-
dated Financial Statements for additional information on nuclear
decommissioning.
Non-utility 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, which are current and deferred. Current income taxes represent the amounts
of tax expected to be reported on Conectiv's federal and state income tax re-
turns. 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 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. The costs of future debt refinancing costs that are to be recovered
through customer rates of the regulated utility businesses will be deferred
and subsequently amortized to interest expense during the rate recovery peri-
od. The costs of other debt refinancings 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 paid 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 Consolidated Balance Sheets and are being amortized over 20 years.
II-40
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 7 to the Consolidated Financial Statements, the book
cost basis of electric generation plants that became impaired as a result of
deregulation of the electric utility industry in 1999, is the estimated fair
value of the plants at the time of deregulation. 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 14 to the Consolidated
Financial Statements. Utility plant that is not impaired is stated at original
cost.
Utility plant is generally subject to a first mortgage lien.
Capitalized Interest and Allowance for Funds Used During Construction
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" (SFAS No. 34). Other non-utility con-
struction projects also include financing costs in accordance with SFAS No.
34. Interest costs were capitalized on these projects at the rates of 6.8%
during 2000 and 5.3% during 1999.
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 8.4% in 2000, 8.6% in 1999, and 8.8% in 1998.
Stock-based Employee Compensation
Refer to Note 18 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. Substantially all of the
goodwill as of December 31, 2000 had a 40 year life. The amount of goodwill
amortized to expense was as follows: in 2000, $10.5 million, or $0.11 per
share of common stock, in 1999, $11.0 million, or $0.10 per share of common
stock, and in 1998, $9.7 million, or $0.09 per share of common stock.
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 24 to the Consolidated Financial Statements
for additional information on leveraged leases.
II-41
Funds Held By Trustee
Funds held by trustee are stated at fair value and primarily include depos-
its in external nuclear decommissioning trusts and unexpended, restricted,
tax-exempt bond proceeds. Changes in the fair 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 have been computed in accordance with SFAS No. 128,
"Earnings Per Share" (SFAS No. 128). 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, excluding
non-vested shares of performance accelerated restricted stock. Diluted earn-
ings per share are computed based on earnings applicable to common stock di-
vided by the weighted average number of shares of common stock outstanding
during the period after giving effect to securities considered to be dilutive
common stock equivalents, such as non-vested shares of performance accelerated
restricted stock. The effect of dilutive common stock equivalents was not sig-
nificant, and thus, for 2000, 1999, and 1998, Conectiv's basic and diluted
earnings 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 1998 Merger.
The Consolidated Statement of Cash Flows for 2000 excludes the assumption of
DPL's former nuclear decommissioning liability by the purchasers of the owner-
ship interests of DPL in nuclear electric generating plants and also excludes
the transfer of nuclear decommissioning trust funds to the purchasers. The nu-
clear decommissioning trust funds which were transferred had a fair value of
approximately $68.0 million. For information about the sale of the ownership
interests of DPL in nuclear electric generating plants, refer to Note 14 to
the Consolidated Financial Statements.
Cash Paid During the Year
2000 1999 1998
-------- -------- --------
(Dollars in Thousands)
Interest, net of capitalized amounts................ $200,737 $164,370 $142,503
Income taxes, net of refunds........................ $ 10,150 $111,667 $107,755
During 2000, Conectiv received $118 million of income tax refunds. Approxi-
mately $91 million of the income tax refunds received in 2000 were related to
the tax benefit associated with ACE's payment of $228.5 million on December
28, 1999 to terminate ACE's purchase of electricity under a contract with the
Pedricktown Co-generation Limited Partnership (Pedricktown). For additional
information concerning the Pedricktown contract termination, see Note 11 to
the Consolidated Financial Statements.
II-42
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
2000 1999 1998
-------- -------- --------
(Dollars in Thousands)
Operations
Federal: Current............................. $ 8,410 $ 44,468 $ 80,408
Deferred............................ 108,145 36,088 7,387
State: Current............................. 20,962 21,690 24,791
Deferred............................ 6,112 8,664 (2,767)
Investment tax credit adjustments, net (1).... (10,115) (5,094) (4,002)
-------- -------- --------
$133,514 $105,816 $105,817
-------- -------- --------
Extraordinary Item
Federal: Deferred............................ -- (155,702) --
State: Deferred............................ -- (32,552) --
-------- -------- --------
-- (188,254) --
-------- -------- --------
Total Income Tax Expense........................ $133,514 $(82,438) $105,817
======== ======== ========
Deferred federal income taxes included in other
comprehensive income........................... $ (1,101) -- --
======== ======== ========
- --------
(1) Includes a $4.4 million credit in 2000 which resulted from reversal of the
deferred investment tax credits in connection with sale of the ownership
interests of DPL in Peach Bottom and Salem on December 29, 2000, as dis-
cussed in Note 14 to the Consolidated Financial Statements.
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).
2000 1999 1998
-------------- -------------- --------------
Amount Rate Amount Rate Amount Rate
-------- ---- -------- ---- -------- ----
(Dollars in Thousands)
Statutory federal income tax
expense.......................... $106,520 35% $ 76,788 35% $ 90,656 35%
Increase (decrease) due to:
State income taxes, net of
federal tax benefit............ 17,598 6 19,730 9 14,316 6
Depreciation.................... 4,717 2 5,915 3 5,047 2
Non-deductible goodwill......... 7,320 2 9,536 4 2,188 1
Investment tax credit
amortization................... (10,115) (3) (5,094) (2) (4,002) (2)
Other, net...................... 7,474 2 (1,059) (1) (2,388) (1)
-------- --- -------- --- -------- ---
Total income tax expense for
operations....................... $133,514 44% $105,816 48% $105,817 41%
======== === ======== === ======== ===
II-43
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,
-------------------
2000 1999
---------- --------
(Dollars in
Thousands)
Deferred Tax Liabilities
Plant basis differences............................... $ 691,952 $636,762
Leveraged leases...................................... 69,354 87,669
Deferred recoverable income taxes..................... 42,208 46,215
Termination of purchased energy contract.............. 64,358 65,487
Prepaid pension costs................................. 33,293 23,342
Other................................................. 141,406 85,593
---------- --------
Total deferred tax liabilities........................ $1,042,571 $945,068
---------- --------
Deferred Tax Assets
Deferred investment tax credits....................... 29,080 32,895
Electric restructuring liabilities.................... 42,824 52,340
Other postretirement benefits obligation.............. 19,002 20,269
Other................................................. 141,726 133,752
---------- --------
Total deferred tax assets............................. 232,632 239,256
---------- --------
Total deferred taxes, net............................... $ 809,939 $705,812
========== ========
There were no valuation allowances for deferred tax assets as of December
31, 2000 and $0.8 million as of December 31, 1999.
NOTE 4. 1998 MERGER
On March 1, 1998, DPL and ACE became wholly owned subsidiaries of Conectiv
(1998 Merger). Before the 1998 Merger, Atlantic owned ACE, an electric utility
serving the southern one-third of New Jersey, and non-utility subsidiaries. As
a result of the 1998 Merger, Atlantic's existence ended, and Conectiv became
the owner (directly or indirectly) of ACE, DPL, and the non-utility subsidiar-
ies formerly held separately by Atlantic and DPL. Conectiv is a registered
holding company under PUHCA.
Effective March 1, 1998, DPL common stockholders received one share of
Conectiv common stock in exchange for each share of DPL common stock, and At-
lantic 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 exchange for each
share of Atlantic common stock. Atlantic stockholders and DPL stockholders re-
ceived 39,363,672 and 61,832,699 shares of Conectiv common stock, respective-
ly. Atlantic stockholders received 6,560,612 shares of Conectiv Class A common
stock. See Note 19 to the Consolidated Financial Statements for information
concerning Conectiv Class A common stock and the apportionment of earnings be-
tween Conectiv Class A common stock and Conectiv common stock.
The 1998 Merger was accounted for under the purchase method of accounting,
with DPL as the acquirer. In connection with the 1998 Merger, $289.0 million
of goodwill was recorded, which is being amortized over 40 years. Subsequent
to March 1, 1998, the results of operations for ACE and other formerly Atlan-
tic-owned businesses are included in the Consolidated Statements of Income.
NOTE 5. SUBSEQUENT EVENT--AGREEMENT FOR THE ACQUISITION OF CONECTIV
On February 9, 2001, the Boards of Directors of Conectiv and Potomac Elec-
tric Power Company (Pepco) approved an Agreement and Plan of Merger
(Conectiv/Pepco Merger Agreement) under which Pepco will
II-44
acquire Conectiv for a combination of cash and stock. The transaction is sub-
ject to various statutory and regulatory approvals and approval by the stock-
holders of Conectiv and Pepco. Upon completion of the transaction, Conectiv
and Pepco will become subsidiaries of a new holding company (HoldCo), to be
named at a later date. HoldCo is expected to be a registered holding company
under PUHCA. Approximately 67% of the shares of HoldCo are expected to be
owned by Pepco stockholders and 33% of the shares of HoldCo are expected to be
owned by Conectiv stockholders
Under the terms of the Conectiv/Pepco Merger Agreement, holders of Pepco's
common stock will receive one share of HoldCo common stock for each share of
Pepco common stock owned.
Under the Conectiv/Pepco Merger Agreement, holders of Conectiv common stock
and Conectiv Class A common stock may elect to exchange their shares for cash,
HoldCo common stock, or a combination of cash and HoldCo common stock. Howev-
er, such elections will be subject to a proration procedure that will cause
the aggregate consideration paid to holders of Conectiv common stock and
Conectiv Class A common stock to be 50% cash and 50% HoldCo common stock. Sub-
ject to certain restrictions described below, (i) Conectiv stockholders elect-
ing to receive cash would receive $25 per share of Conectiv common stock ex-
changed and $21.69 per share of Conectiv Class A common stock exchanged, and
(ii) Conectiv stockholders electing to receive HoldCo common stock would re-
ceive a number of shares of HoldCo common stock determined by the exchange ra-
tio described below. Subject to certain limitations, the exchange ratio is de-
signed to provide holders of Conectiv common stock with a number of shares of
HoldCo common stock having a market value of $25.00 and holders of Conectiv
Class A common stock with a number of shares of HoldCo common stock having a
market value of $21.69.
The exchange ratio will be $25.00 divided by the volume-weighted average of
the closing trading prices of Pepco common stock for 20 trading days randomly
selected by lot out of 30 consecutive trading days ending on the fifth busi-
ness day immediately preceding the closing date of the transaction (Average
Final Price).
If the Average Final Price is below $19.50, then Conectiv common stockhold-
ers will have the right to receive 1.28205 shares of HoldCo common stock for
each share of stock exchanged and Conectiv Class A common stockholders will
have the right to receive 1.11227 shares of HoldCo common stock for each share
of stock exchanged. In this instance, the fair value of HoldCo common stock
received for each share of Conectiv common stock exchanged and each share of
Conectiv Class A common stock exchanged will be less than $25.00 and $21.69,
respectively.
If the Average Final Price is above $24.50, then Conectiv common stockhold-
ers will have the right to receive 1.02041 shares of HoldCo common stock for
each share of stock exchanged and Conectiv Class A common stockholders will
have the right to receive 0.88528 shares of HoldCo common stock for each share
of stock exchanged. In this instance, the fair value of HoldCo common stock
received for each share of Conectiv common stock exchanged and each share of
Conectiv Class A common stock exchanged will be more than $25.00 and $21.69,
respectively.
Conectiv may terminate the Conectiv/Pepco Merger Agreement if the Average
Final Price is less than $16.50, unless Pepco, at its option, chooses to in-
crease the consideration that will be paid to Conectiv's stockholders for
their shares of Conectiv stock. If the Average Final Price is less than
$16.50, Pepco has the option of (i) adjusting the exchange ratio so as to pro-
vide Conectiv's stockholders with HoldCo common stock having a value of $21.25
for each share of Conectiv common stock and $18.35 for each share of Conectiv
Class A common stock, (ii) paying additional cash to the stockholders so that
they receive a total consideration of $21.25 for each share of Conectiv common
stock and $18.35 for each share of Conectiv Class A common stock, or (iii) un-
dertaking a combination of (i) and (ii), provided that any such combination
must be in the same proportion with respect to the Conectiv common stock and
the Conectiv Class A common stock.
The Conectiv/Pepco Merger Agreement may be terminated by either Conectiv or
Pepco if the transaction has not occurred by August 9, 2002 (18 months after
the date of the Conectiv/Pepco Merger Agreement). If
II-45
however, on August 9, 2002, the conditions required to complete the merger
have been satisfied, except that additional time is needed to obtain the nec-
essary statutory and regulatory approvals, then the Conectiv/Pepco Merger
Agreement is extended for six additional months. If Conectiv terminates the
Conectiv/Pepco Merger Agreement under certain circumstances, Conectiv is re-
quired to pay a $60 million termination fee to Pepco. For example, if
Conectiv's Board of Directors concludes that a business combination with an-
other party is more favorable to Conectiv's stockholders and Conectiv termi-
nates the Conectiv/Pepco Merger Agreement, then Conectiv is obligated to pay a
$60 million termination fee to Pepco.
During the period the Conectiv/Pepco Merger Agreement is in effect,
Conectiv's dividend payments cannot exceed $0.22 per share of Conectiv common
stock per quarter and $0.80 per share of Conectiv Class A common stock per
quarter through March 31, 2001; after March 31, 2001, dividends on Conectiv
Class A common stock may be paid at an annual rate up to 90% of annualized
earnings of Class A common stock.
NOTE 6. SPECIAL CHARGES
2000 1999 1998
------- -------- -------
(Dollars in Thousands,
Except Per Share
Amounts)
Special Charges
Before Income Taxes.......................... $25,162 $105,648 $27,704
After Income Taxes........................... $23,412 $ 71,562 $16,764
Effect of Special Charges on Basic and Diluted
Earnings Per Average Share
Common Stock................................. $ (0.28) $ (0.75) $ (0.18)
Class A Common Stock......................... -- $ (0.30) --
"Special charges" recorded in the second quarter of 2000 of $25.2 million
before income taxes, or $23.4 million after income taxes ($0.28 per share of
common stock), resulted from losses on the sales of Conectiv Services, Inc.
(CSI) and portions of Conectiv Thermal Systems, Inc. (CTS). CSI provided heat-
ing, ventilation, and air conditioning (HVAC) services and its results of op-
erations are presented as the "HVAC" business segment in Note 27 to the Con-
solidated Financial Statements. CTS constructs and operates district heating
and cooling systems and its results of operations are included in the Energy
business segment in Note 27 to the Consolidated Financial Statements included
herein. Proceeds of $56 million were received from the sale of these business-
es, which had total assets of $79 million at the time of sale.
Conectiv's operating results for 1999 included "Special charges" of $105.6
million before taxes, or $71.6 million after taxes, which were recorded in the
third quarter. The special charges decreased 1999 earnings per share of common
stock by $0.75 and earnings per share of Class A common stock 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
containerships leased by certain Conectiv subsidiaries to third parties
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 employee separations.
(c) Lower actual operating cash flows than initially expected when certain
HVAC businesses were acquired caused the net book value of the HVAC busi-
nesses to be impaired, which resulted in a write-down of goodwill by
$35.6 million before taxes ($29.1 million after taxes).
(d) Charges for additional costs related to the 1998 Merger, impairments of
certain 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, or $16.8 million after taxes ($0.18 per share of common
stock) for the cost of DPL employee separations associated with
II-46
the 1998 Merger-related workforce reduction and other 1998 Merger-related
costs. The $27.7 million pre-tax charge includes a net $45.5 million gain from
curtailments and settlements of pension and other postretirement benefits. The
1998 employee separation, relocation, and other 1998 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 1998 Merger.
NOTE 7. 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 in 1999 which, on a consolidated basis, reduced earnings by
$311.7 million, after $188.3 million of income taxes. The extraordinary charge
was apportioned between Conectiv common stock ($295.161 million or $3.16 per
share) and Conectiv Class A common stock ($16.557 million or $2.71 per share).
The portion of the 1999 extraordinary charge related to impaired assets was
determined in accordance with SFAS No. 121, "Accounting for the Impairment of
Long-Lived Assets and for Long-Lived Assets To Be Disposed Of" (SFAS No. 121).
The 1999 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 certain electric generating plants, which are dis-
cussed in Note 14 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 10 to the Consolidated Financial Statements, ACE's por-
tion of the 1999 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 another extraordinary item may result due to adjustment of the 1999 ex-
traordinary charge.
The details of the 1999 extraordinary charge are shown in the following ta-
ble:
Items Included in the 1999 Extraordinary Consolidated
Charge Conectiv DPL ACE
---------------------------------------- ------------ ------- -------
(Dollars in millions)
(a) The net book value of nuclear and
certain fossil fuel-fired electric
generating 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)
======= ======= =======
II-47
NOTE 8. INVESTMENT INCOME
Investments in the EnerTech Funds
An indirect Conectiv subsidiary holds a limited partner interest in EnerTech
Capital Partners, L.P. and EnerTech Capital Partners II, L.P. (the EnerTech
funds). The EnerTech funds are venture capital funds that invest in energy re-
lated technology and Internet service companies. Due to the nature of the in-
vestments of the EnerTech funds, the earnings of the funds may be volatile
from period to period. The EnerTech funds record their investments at fair
value and include gains and losses on changes in the fair value of their in-
vestments in income in accordance with industry practice. Conectiv's subsidi-
ary accounts for its investment in the EnerTech funds on the equity method of
accounting. The pre-tax equity in earnings of the EnerTech funds are reported
as "Other income" in the Consolidated Statements of Income.
Conectiv's equity in earnings of the EnerTech funds was $20.3 million ($13.2
million after-income taxes or $0.16 per share of common stock) in 2000 and
$42.1 million ($24.9 million after-income taxes or $0.27 per share of common
stock) in 1999. Conectiv's equity in earnings of the EnerTech funds was not
significant in 1998. The earnings of the EnerTech funds during 2000 resulted
primarily from an unrealized gain on the initial public offering of common
shares of Capstone Turbine Corporation (Capstone). Capstone develops, designs,
assembles, and sells micro-turbines worldwide in the distributed power genera-
tion market and hybrid electric vehicle market. The earnings of the EnerTech
funds during 1999 resulted primarily from the initial public offering of a
business-to-business Internet company.
The carrying amount of Conectiv's subsidiary's investment in the EnerTech
funds was $38.6 million as of December 31, 2000 and $26.6 million as of Decem-
ber 31, 1999. Conectiv's subsidiary received from the EnerTech Funds cash and
marketable securities distributions in 2000 valued at $15 million and cash
distributions in 1999 of $45 million. In 1998, no distributions of cash or
marketable securities were received.
Summarized financial information for the EnerTech funds (in their entirety)
is presented below. Conectiv's subsidiary owns a partial interest in the
EnerTech funds.
Year Ended December 31,
-----------------------
Income Statement Information 2000 1999 1998
---------------------------- ------- ------- -------
(Dollars in Thousands)
Operating Revenues *............................... $69,513 $60,272 $(2,161)
Income (Loss) Before Taxes......................... 61,319 58,500 (3,743)
--------
* Includes the net change in investment valuation.
As of December
31,
----------------
Balance Sheet Information 2000 1999
------------------------- -------- -------
(Dollars in
Thousands)
Current assets............................................. $ 2,570 $11,387
Noncurrent assets.......................................... 105,740 42,761
-------- -------
Total assets............................................... $108,310 $54,148
======== =======
Current liabilities........................................ $ 3,000 $ 7,052
Partners' capital.......................................... 105,310 47,096
-------- -------
Total capitalization and liabilities....................... $108,310 $54,148
======== =======
Other Investments
Conectiv's other investments that affect its results of operations include
marketable securities (other than those held in nuclear decommissioning trust
funds) and minority interests in a venture capital fund and an Internet start-
up project. For 2000, these investments resulted in a net loss, including $3.0
million before taxes
II-48
($2.0 million after taxes, or $0.02 per share of common stock) which was rec-
ognized in earnings and $3.1 million before taxes ($2.0 million after taxes)
which was recognized in other comprehensive income. The earnings from these
investments in 1999 and 1998 was insignificant. The carrying value of these
investments was $4.6 million as of December 31, 2000.
See Note 9 to the Consolidated Financial Statements for additional informa-
tion concerning investment income.
NOTE 9. SUMMARIZED FINANCIAL INFORMATION OF ENTITIES NOT CONSOLIDATED
Summarized financial information for unconsolidated entities accounted for
on the equity method (excluding the EnerTech funds, which are shown in Note 8
to the Consolidated Financial Statements) is presented below for the periods
the unconsolidated entities are included in Conectiv's Consolidated Financial
Statements. The amounts presented below are primarily attributed to unconsoli-
dated electric co-generation projects and are for the unconsolidated entities
in their entirety.
Year Ended December 31,
-----------------------
Income Statement Information 2000 1999 1998
---------------------------- ------- ------- -------
(Dollars in Thousands)
Operating Revenues.................................. $90,144 $98,507 $99,208
Income Before Taxes................................. $24,848 $15,932 $50,077
As of December
31,
-----------------
Balance Sheet Information 2000 1999
------------------------- -------- --------
(Dollars in
Thousands)
Current assets............................................ $ 60,135 $ 77,404
Noncurrent assets......................................... 137,694 225,860
-------- --------
Total assets.............................................. $197,829 $303,264
======== ========
Current liabilities....................................... $ 27,786 $ 17,125
Noncurrent liabilities.................................... 123,074 147,443
Partners' capital......................................... 46,969 138,696
-------- --------
Total capitalization and liabilities...................... $197,829 $303,264
======== ========
The carrying amount of Conectiv's subsidiaries' investments in these enti-
ties was $20.8 million as of December 31, 2000 and $60.4 million as of Decem-
ber 31, 1999. The decrease in the carrying amount of the investment as of De-
cember 31, 2000 compared to December 31, 1999 was primarily due to the sale of
two projects that CTS had investments in, as discussed in Note 6 to the Con-
solidated Financial Statements. Conectiv's subsidiaries' equity in earnings of
these entities was $13.0 million in 2000, $6.4 million in 1999, and $22.2 mil-
lion in 1998. These amounts are included in "Other Income" in the Consolidated
Statements of Income. Conectiv's subsidiaries received cash distributions from
these entities of $13.4 million in 2000, $86.4 million in 1999, which includes
the $82.2 million distribution related to the purchased power contract termi-
nation discussed in Note 11 to the Consolidated Financial Statements, and
$22.2 million in 1998.
NOTE 10. REGULATORY 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
II-49
issued a Summary Order to ACE concerning stranded costs, unbundled rates, and
other matters related to restructuring. The NJBPU indicated that a more de-
tailed order would be issued at a later time. Issuance of the NJBPU's final
order for ACE has been delayed due to appeals of the NJBPU's final order con-
cerning restructuring the electricity supply business of Public Service Elec-
tric and Gas Company (PSE&G) and recent electricity shortages and price in-
creases in California. On December 6, 2000, the New Jersey Supreme Court af-
firmed the judgment of the New Jersey Superior Court Appellate Division which
had previously affirmed the NJBPU's final order concerning the PSE&G restruc-
turing. However, management cannot predict the timing or outcome of this or
related matters, such as securitization by ACE of its stranded costs and the
sale of electric generating plants, as discussed in Note 14 to the Consoli-
dated Financial Statements.
The key provisions of the Summary Order issued by the NJBPU to ACE are dis-
cussed below.
Rate Decreases
In its Summary Order, the NJBPU directed ACE to implement a 5% aggregate
rate reduction effective August 1, 1999 and an additional 2% rate reduction by
January 1, 2001. By August 1, 2002, rates must be reduced by 10% from the
rates that were in effect as of April 30, 1997.
The initial 5% rate reduction effective August 1, 1999 reduced annual reve-
nues by approximately $50 million. The additional 2% rate reduction required
by January 1, 2001 was implemented through two separate 1% rate reductions ef-
fective January 1, 2000 and 2001, respectively. Each of the 1% rate reductions
reduced annual revenues by approximately $10 million, or $20 million in total.
The final rate reduction, which is required by August 1, 2002, is expected to
reduce revenues by an additional $30 million, which would result in a cumula-
tive rate reduction of $100 million since August 1, 1999.
Stranded Cost Recovery and Securitization
Stranded costs are the uneconomic portion of assets and long-term contracts
that resulted from electric utility industry restructuring. The Summary Order
provides that ACE may divest its nuclear and fossil fuel-fired baseload units
and transfer combustion turbine electric generating units to a non-utility af-
filiated company at net book value. Additional NJBPU approvals are required
prior to the sale of the nuclear and fossil fuel-fired baseload units of ACE.
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 non-utility generators
(NUGs), subject to further NJBPU proceedings. The Summary Order, in conjunc-
tion with the New Jersey Act, also permits securitization of stranded costs
through the issuance of transition bonds in the amount of the after-tax
stranded cost recovery approved by the NJBPU. Management expects the transi-
tion bonds will be issued after ACE completes the sale of certain electric
generating units, as discussed in Note 14 to the Consolidated Financial State-
ments. The ability to issue transition bonds would depend not only upon ap-
proval of the NJBPU, but also on the conditions in the relevant capital mar-
kets at the times of the offerings. Proceeds from the transition bonds may be
used to refinance ACE's debt and preferred securities, finance the restructur-
ing of purchased power contracts, or otherwise reduce costs in order to de-
crease regulated electricity rates. 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 po-
tential NUG contract buyouts or buydowns, over a period not to exceed the re-
maining term of the restructured contracts. The Summary Order provides for the
principal of and interest on transition bonds to be collected from customers
through a transition bond charge over the securitization term. The Summary Or-
der also provides for customer rates to include a separate market transition
charge for recovery of the income tax expense associated with the revenues
from transition bond charges.
The balance for ACE's pre-tax recoverable stranded costs, net of amortized
amounts, was approximately $959 million as of December 31, 2000 and $988 mil-
lion as of December 31, 1999. The balances of recoverable stranded costs in-
clude the stranded costs estimated and recorded as a result of discontinuing
the application of SFAS No. 71 (as discussed in Note 7 to the Consolidated Fi-
nancial Statements) and the $228.5 million payment to terminate a NUG contract
(as discussed in Note 11 to the Consolidated Financial Statements). ACE's
amount
II-50
of recoverable stranded costs remains subject to adjustment based on the ac-
tual gains and losses realized on the sale of certain electric generating
plants, additional buyouts or buydowns of NUG contracts, the NJBPU's final re-
structuring 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 electricity 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 its Basic Generation Service (BGS) provided to
retail customers who do not choose an alternative electricity supplier. ACE is
obligated to provide BGS through July 31, 2002; thereafter, the BGS supplier
is expected be determined each year based on a competitive bidding process.
In accordance with the Summary Order, the rates charged to ACE's customers
for BGS include a component for the market-value of power purchased from NUGs.
The above-market portion of the cost of NUG power is being collected through a
non-bypassable "Net NUG Charge" included in regulated electricity 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 electricity delivery rates.
The NJBPU's Summary Order also provided that ACE's regulatory liability for
over-recovered energy supply costs as of July 31, 1999 would be offset by any
subsequent under-recoveries of the costs associated with BGS. Due to under-re-
coveries of such costs, ACE reduced its liability for over-recovered energy
supply costs and recognized like amounts of revenues in the amounts of $17.5
million for 2000 and $17.2 million for 1999. Customer rates are to be adjusted
for any deferred balance remaining after the initial four-year transition pe-
riod, which ends July 31, 2003. ACE's recovery of BGS supply costs is subject
to review by the NJBPU.
Customer Account Services
During the fourth quarter of 1999, the NJBPU began a proceeding concerning
customer metering, billing, and other account administration functions (Cus-
tomer Account Services). On December 22, 2000, the NJBPU approved a stipula-
tion, to which ACE and certain other New Jersey utilities were parties, in the
Customer Account Services proceeding. One of the terms of the stipulation re-
quires ACE to begin purchasing the receivables of third parties supplying
electricity to ACE's delivery customers in the second quarter of 2001. The
stipulation remains effective through August 1, 2003.
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 2000, customer
rate decreases, and other matters concerning restructuring the electric util-
ity industry in Delaware. On April 15, 1999, DPL submitted a compliance plan
to the DPSC for implementing the provisions of the Delaware Act in DPL's Dela-
ware service area. On August 31, 1999, the DPSC issued an order on DPL's com-
pliance 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
II-51
September 30, 2003. Also, non-residential rates are to be held constant from
October 1, 1999 to September 30, 2002. The initial 7.5% residential rate re-
duction reduced revenues by approximately $17.5 million on an annualized ba-
sis.
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 14 to the Consolidated Financial State-
ments for related information concerning the expected sales of electric gener-
ating plants.
Stranded Cost Recovery
The rates approved by the DPSC also provide for DPL's recovery of stranded
costs, $16 million net of taxes, or $31 million before taxes, through a "Com-
petitive Transition Charge" billed to non-residential customers from October
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, 4.719 cents per kWh for the year
beginning October 1, 2000, and 4.721 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 3 years ending September
30, 2002 for non-residential customers and the 4 years ending September 30,
2003 for residential customers (transition periods). Thereafter, the DPSC may
conduct a bidding process to select the default supplier for such customers.
The DPSC order permits customers with demand below 300 kW to choose an alter-
native electric supplier and to switch back to DPL's default service without
any time restrictions or price differential. Customers with demand above 300
kW who choose an alternative electricity supplier and switch back to DPL's de-
fault service must either, at the customer's option, return to DPL's default
service for a minimum of 12 months or pay market prices.
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 October 8, 1999,
the MPSC issued an order to DPL that approved a settlement agreement for im-
plementing the provisions of the Maryland Act in DPL's Maryland service area.
The key elements of the approved settlement agreement are discussed below.
Implementation Date
Effective July 1, 2000, all of DPL's Maryland retail customers were eligible
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. The initial 7.5% residential rate reduc-
tion reduced revenues by approximately $12.5 million on an annualized basis.
II-52
Sale of Electric Generating Plants
The Maryland Act in conjunction with the approved settlement effectively
provides that electric rates will not be changed in the event DPL sells or
transfers electric generating assets. See Note 14 to the Consolidated Finan-
cial Statements for related information concerning the expected sales of elec-
tric generating 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 5.385 cents per
kWh for the year beginning July 1, 2000, 5.388 cents per kWh for the year be-
ginning July 1, 2001, and 5.390 cents per kWh for the year beginning July 1,
2002.
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.
Virginia Electric Utility Industry Restructuring
On March 29, 1999, the Governor of Virginia signed the Virginia Electric
Utility Restructuring Act (the Virginia Act). In connection with the Virginia
Act, the VSCC issued an order on June 29, 2000 that, among other things, ap-
proved DPL's plan for the functional separation of electric generation opera-
tions from transmission and distribution operations and authorized the trans-
fer of certain electric generating plants and related assets to other Conectiv
subsidiaries. DPL has proposed to the VSCC to offer choice of electricity sup-
pliers to all of its retail Virginia customers as of January 1, 2002. Revenues
from regulated retail electricity sales in Virginia represented approximately
1.7% of Conectiv's regulated retail electric and gas revenues for 2000.
NOTE 11. TERMINATION AND RESTRUCTURING OF PURCHASED POWER CONTRACTS
On November 10, 1999, the NJBPU issued an order approving termination of a
contract under which ACE had purchased energy and 116 MW of capacity from
Pedricktown, a NUG partnership which was owned 50% by other Conectiv subsidi-
aries. The NJBPU order provided that ACE is entitled to recover from customers
the contract termination payment of $228.5 million, transaction costs, and in-
terim financing costs. The NJBPU order also found that the contract termina-
tion payment and related transaction costs are eligible for long-term financ-
ing through the issuance of securitized bonds. On December 28, 1999, ACE paid
$228.5 million to terminate the contract and borrowed funds to finance the
contract termination payment (as discussed in Note 21 to the Consolidated Fi-
nancial Statements). The contract termination payment and related costs are
included in "Recoverable Stranded Costs" on the Consolidated Balance Sheets.
ACE's customer rates were reduced by about 1% (approximately $10 million of
revenues on an annualized basis) effective January 1, 2000 as a result of the
net savings from the contract termination.
On December 6, 2000, the NJBPU approved ACE's payment on January 22, 2001 of
$3.45 million in connection with restructuring ACE's purchased power contract
with a NUG, American Ref-Fuel Company of Delaware Valley, L.P.
II-53
Management anticipates that transition bonds will ultimately be used to fi-
nance the stranded costs associated with the buyout or buydown of ACE's NUG
contracts.
On December 28, 1999, the Conectiv subsidiaries that own 50% of the
Pedricktown NUG partnership with which ACE terminated its contract received an
$82.2 million distribution from Pedricktown. The distribution was primarily
the result of a gain realized by Pedricktown from the contract termination;
the Conectiv subsidiaries' share of the gain was estimated at $75.0 million as
of December 31, 2000 and $70.8 million as of December 31, 1999. Conectiv's
subsidiaries share of the gain is deferred in Conectiv's Consolidated Balance
Sheets and classified under "Deferred Credits and Other Liabilities." The de-
ferred gain is expected to be either (a) amortized to income over the period
revenues are collected from ACE's customers to repay the transition bonds ex-
pected to be issued to recover the contract termination payment, or (b) recog-
nized in income if the Conectiv subsidiaries no longer hold an ownership in-
terest in Pedricktown.
NOTE 12. ENERGY TRADING AND RISK MANAGEMENT ACTIVITIES
Conectiv actively participates in the wholesale energy markets and engages
in commodity hedging activities to minimize the risk of market fluctuations
associated with the purchase and sale of energy commodities (natural gas, pe-
troleum and electricity). Some hedging activities are conducted using deriva-
tive instruments. 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's participation in wholesale energy markets includes trading and ar-
bitrage activities, which expose Conectiv to commodity market risk. To the ex-
tent that Conectiv has net open positions, controls are in place that are in-
tended to keep risk exposures within management-approved risk tolerance lev-
els.
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.
Open commodity positions may be "long" or "short." A long position indicates
that Conectiv has an excess of the commodity available for sale. A short posi-
tion 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, implemented credit checks and established reserves for credit losses.
Non-regulated Natural Gas Activities
At December 31, 2000, Conectiv's open futures contracts represented a net
long position with a notional quantity of 13.7 billion cubic feet (Bcf),
through April 2002. Conectiv also had a net short commodity swap position at
December 31, 2000 equivalent to 8.9 Bcf through May 2002, and a net short ba-
sis swaps position equivalent to 2.7 Bcf through November 2002. 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 position at December 31, 1999
equivalent to 1.2 Bcf and a net short basis swaps position equivalent to 0.2
Bcf.
Gains recognized for gas trading positions (physical and financial combined)
were as follows: 2000--$19.7 million, including a $35.3 million unrealized
gain; and 1999--$5.0 million, including a $3.0 million unrealized
II-54
gain. The annual average unrealized gain on gas trading activities was $7.8
million in 2000 and $2.1 million in 1999. During 1998, recognized and
unrealized gains from gas trading positions were not material to Conectiv's
results of operations or financial position.
An unrealized hedging gain of $5.6 million as of December 31, 2000 and an
unrealized hedging loss of $7.6 million as of December 31, 1999 from natural
gas futures, swaps and options contracts used to hedge gas marketing activi-
ties were deferred in the Consolidated Balance Sheets. A loss for 2000 and
gain for 1999 on the physical commodity transactions being hedged offset the
related hedging gain and loss, respectively.
Regulated Natural Gas Activities
Gains and losses on regulated gas hedging are included in the gas cost re-
covery provisions of the regulated energy adjustment clause.
At December 31, 2000, Conectiv's open futures contracts represented a net
long position with a notional quantity of 0.2 Bcf, through October 2001.
Conectiv also had a net long commodity swap position at December 31, 2000
equivalent to 14.1 Bcf through December 2002. At December 31, 1999, Conectiv
had a long commodity swap position of 4.0 Bcf for the regulated gas business.
Unrealized hedging gains of $14.4 million as of December 31, 2000 and an
unrealized loss of $1.4 million as of December 31, 1999 from natural gas
futures, swaps and options contracts used to hedge regulated gas activities
were deferred in the Consolidated Balance Sheets. During 1998, derivatives
were not used for regulated hedging.
Electricity Marketing and Trading Activities
Primarily resulting from forward contracts, at December 31, 2000, Conectiv
had a net long exposure of 1,195,000 megawatt-hours (MWH) through December
2003; and at December 31, 1999, Conectiv had a net long exposure of 219,900
MWH through December 2000.
The amounts of deferred gains and losses from hedges of electricity market-
ing activities were as follows: as of December 31, 2000, a loss of $0.2 mil-
lion was deferred and as of December 31, 1999, a gain of $0.1 million was de-
ferred in the Consolidated Balance Sheets.
During 1998 to 2000, the gains recognized for electricity trading activities
(physical and financial combined) were as follows: $12.5 million in 2000, in-
cluding a $3.6 million unrealized gain; $6.0 million in 1999, including a $1.3
million unrealized gain; and $11.4 million in 1998, including a $1.2 million
unrealized gain. The annual average unrealized gain on electricity trading ac-
tivities was $1.3 million in 2000, $0.1 million in 1999, and $1.3 million in
1998.
Electricity Generation Activities
As a result of electric utility industry restructuring orders issued in
1999, deregulated operation of the electric generating plants owned by
Conectiv subsidiaries was phased-in from August 1, 1999 to July 1, 2000. As of
July 1, 2000, approximately 79% of Conectiv's electric generating capacity was
being operated on a deregulated basis and the remaining 21% was dedicated to
supplying BGS customers, in accordance with the terms of the Summary Order is-
sued by the NJBPU.
Conectiv hedges portions of the fuel purchased and the electricity output of
the generating plants using derivative instruments and forward contracts to
stabilize fuel costs and to lock-in prices for electricity generated. As of
December 31, 2000, Conectiv hedged 680,800 MWH of forward generation output,
through the sale of forward contracts, which resulted in a $13.5 million
unrealized and unrecognized loss as of December 31, 2000. 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.
II-55
A net unrealized gain of $0.2 million that resulted from hedging the cost of
gas and oil burned by electric generating units was deferred in the Consoli-
dated Balance Sheet as of December 31, 2000. At December 31, 2000, forward
natural gas hedges consisted of a long position of futures, forwards and swaps
with a combined notional amount of 25.3 Bcf. At December 31, 2000, forward pe-
troleum hedges consisted of a long position in futures and swaps of 2.4 mil-
lion barrels. A net unrealized loss of $4.1 million which resulted from hedg-
ing 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 natural gas futures, forwards and swaps with a combined
notional amount of 12.9 Bcf.
Petroleum Activities
To hedge a portion of its petroleum sales commitments, Conectiv had a net
long position in futures as of December 31, 2000 and 1999 with notional equiv-
alents of 254,000 barrels and 376,000 barrels, respectively. An unrealized
hedging gain of $0.4 million was deferred as of December 31, 2000 and an
unrealized hedging gain of $3.0 million was deferred as of December 31, 1999.
In 2000, petroleum trading activities recognized a $6.6 million gain, in-
cluding a $0.9 million unrealized gain. In 1999 a $1.3 million trading gain
was recognized, including a $0.7 million unrealized gain. The average annual
unrealized gain on petroleum trading activities was $0.8 million for 2000, and
$0.5 million for 1999.
NOTE 13. JOINTLY OWNED PLANT
Conectiv's Consolidated Balance Sheets include its proportionate share of
assets and liabilities related to jointly owned plant. Conectiv's subsidiaries
have ownership interests in electric generating plants, transmission facili-
ties, and other facilities in which other parties have ownership interests.
Conectiv'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. Conectiv is responsible for providing its
share of financing for the jointly owned facilities.
Information with respect to Conectiv's shares of jointly owned plant as of
December 31, 2000 is shown below. As discussed in Note 14 to the Consolidated
Financial Statements, the ownership interests of DPL in nuclear electric gen-
erating plants were sold on December 29, 2000 and there are agreements to sell
to third parties the remaining jointly owned nuclear and coal-fired plants,
which are listed below.
Megawatt Construction
Ownership Capability Plant in Accumulated Work in
Share Owned Service Depreciation Progress
--------- ---------- -------- ------------ ------------
(Dollars in Thousands)
Nuclear
Peach Bottom.......... 7.51% 164 $ 4,847 $ 944* $ 4,760
Salem................. 7.41% 167 3,892 2,236* 2,517
Hope Creek............ 5.00% 52 1,930 923* 619
Coal-Fired
Keystone.............. 6.17% 106 34,733 15,285 1,193
Conemaugh............. 7.55% 129 68,796 24,318 1,698
Transmission
Facilities............. Various 29,448 13,878 --
Other Facilities........ Various 3,269 887 --
-------- ------- -------
Total................... $146,915 $58,471 $10,787
======== ======= =======
- --------
* Excludes nuclear decommissioning reserve.
II-56
NOTE 14. AGREEMENTS FOR THE SALES OF ELECTRIC GENERATING PLANTS
DPL and ACE have entered into agreements for the sale of their respective
ownership interests in non-strategic baseload fossil fuel-fired electric gen-
erating plants and ACE has executed agreements for the sale of its ownership
interests in nuclear electric plants. A summary of the electric generating
plants that were subject to agreements for sale as of December 31, 2000 is
shown in the table below. The ownership interests of DPL in nuclear electric
generating plants that were sold on December 29, 2000 are excluded from the
table. Management intends to retain certain fossil fuel-fired electric gener-
ating plants which are strategic to Conectiv's energy business, pursuant to
Conectiv's "mid-merit" strategy as discussed in the "Mid-Merit Electric Gener-
ation" section of Management's Discussion and Analysis of Financial Condition
and Results of Operations (MD&A). The operating results of the electric gener-
ating plants to be sold are included in the Energy business segment shown in
Note 27 to the Consolidated Financial Statements.
Electric Generating Plants Subject to Agreements for Sale
As of December 31, 2000
-------------------------
MW of Net Book
Capacity Value
------------ -----------
($ in millions)
Fossil Units:
Wholly owned................................... 1,586.0 $ 341.9
Jointly owned.................................. 234.5 66.8
Jointly owned nuclear units...................... 383.0 14.5
------------ -----------
2,203.5 $ 423.2
============ ===========
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). Pursuant to the agreements, DPL sold its 7.51% (164 MW) inter-
est in Peach Bottom and 7.41% (167 MW) interest in Salem and the related nu-
clear fuel on December 29, 2000 for approximately $32 million. DPL used ap-
proximately $26 million of the proceeds to repay the lease obligation related
to the nuclear fuel. In accordance with the sales agreements, DPL transferred
its decommissioning trust funds and related obligation for decommissioning the
plants to the purchasers. Completion of these sales resulted in a gain of
$16.6 million before income taxes ($12.8 million after income taxes, or $0.15
per share of Conectiv common stock). The pre-tax gain primarily resulted from
the reversal of previously accrued liabilities associated with the nuclear
plants and is classified as a reduction of operating expenses in the 2000 Con-
solidated Statement of Income. ACE's interests in the nuclear units that are
subject to the sales agreements include a 7.51% (164 MW) interest in Peach
Bottom, a 7.41% interest (167 MW) in Salem and a 5.0% interest (52 MW) in Hope
Creek. The agreements for the sale of ACE's interests in the nuclear plants
provide for (a) a sales price of approximately $11 million plus the net book
value of the interests of ACE in nuclear fuel on-hand as of the closing date
and (b) the transfer of ACE's nuclear decommissioning funds and related obli-
gation for decommissioning the plants to the purchasers upon completion of the
sales.
On January 19, 2000, Conectiv announced that DPL and ACE reached agreements
to sell certain wholly and jointly owned fossil units to NRG Energy, Inc.
(NRG), a subsidiary of Northern States Power Company, for $800 million. The
units to be sold under the agreements have a total capacity of 1,820.5 MW, and
had a net book value of $408.7 million as of December 31, 2000. Management ex-
pects the proceeds from the planned sales of the electric generating plants
will be used to repay debt and to fund expansion of the mid-merit generation
business. The terms of DPL's agreement with NRG provide for DPL to purchase
from NRG 500 megawatt-hours of firm electricity per hour from completion of
the sale through December 31, 2005. Upon completion of the sales of the non-
strategic baseload electric generating plants, DPL and ACE will purchase power
to supply electricity to customers who do not choose alternative electricity
suppliers. For information concerning long-term purchased power contracts, see
Note 23 to the Consolidated Financial Statements.
II-57
Consummation of the sales of the electric generating plants is subject to
the receipt of required regulatory approvals. In addition, the agreements for
the sales of the electric generating plants contemplated that the sales of the
plants of ACE and DPL would occur simultaneously. Appeals related to the
NJBPU's final order concerning restructuring the electricity supply business
of PSE&G and recent electricity shortages and price increases in California
have resulted in delays in the issuance of required regulatory approvals, the
NJBPU's final order concerning restructuring the electricity supply business
of ACE, and the closings of the sales of the electric generating units. Effec-
tive October 3, 2000, the agreements relating to the sale of the nuclear
plants were amended to, among other things, permit separate closings of the
sales of the ACE and DPL interests in the nuclear plants. DPL's ownership in-
terests in the nuclear electric generating plants were sold on December 29,
2000, as discussed above. On December 6, 2000, the New Jersey Supreme Court
affirmed the judgment of the New Jersey Superior Court Appellate Division,
which had previously upheld the NJBPU's final order concerning the PSE&G re-
structuring. Management currently expects the sales of ACE's nuclear and fos-
sil, and DPL's fossil, electric generating plants to take place during 2001.
However, management cannot predict the timing of the issuance of required
NJBPU approvals, the timing or outcome of appeals, if any, of such approvals,
the effect of any of the foregoing on the ability of ACE or DPL to consummate
the sales of various electric generating plants or the impact of any of the
foregoing on ACE's ability to recover or securitize any related stranded
costs.
Based on the terms of the restructuring orders and sales agreement with NRG,
management expects to recognize a net gain in earnings when the sale of the
electric generating plants is completed. There can be no assurances, however,
that the sales of the electric generating plants will be completed pursuant to
the agreements, or that any gain will be realized from such sales of electric
generating plants. As of December 31, 2000, approximately $20 million of costs
associated with selling the electric generating plants had been deferred as an
adjustment to the expected future gain or loss on the sales. In the event the
sales are not completed, these costs would be expensed.
NOTE 15. WHOLESALE TRANSACTION CONFIRMATION LETTER AGREEMENTS
On October 3, 2000, ACE entered into Wholesale Transaction Confirmation let-
ter agreements (Letter Agreements). The Letter Agreements provide for the sale
of the electricity output and capacity associated with the ownership interests
of ACE in Peach Bottom, Salem, and Hope Creek. PECO and PSEG Energy Resources
& Trade LLC (PSER&T), an indirect subsidiary of Public Service Enterprise
Group, purchase the electricity output and capacity from ACE under the Letter
Agreements. The Letter Agreements became effective October 7, 2000, and termi-
nate for each plant upon the earlier of (1) the closing of the sale of the
plant, (2) the termination of the agreement relating to the sale of the plant
or (3) September 30, 2001.
In exchange for the electricity output and capacity purchased from a given
plant, PECO and PSER&T reimburse ACE for the nuclear fuel amortized during the
term of the Letter Agreements at each plant, and are responsible for the pay-
ment of operation and maintenance costs, inventories, capital expenditures
(subject, in certain circumstances, to reimbursement by ACE) and certain other
liabilities associated with the ownership interests of ACE in each plant.
DPL had also entered into Letter Agreements, similar to the agreements en-
tered into by ACE, for the sale of the electricity output and capacity associ-
ated with the ownership interests of DPL in Peach Bottom and Salem, effective
October 7, 2000. DPL's Letter Agreements terminated effective with the sale of
DPL's interests in such nuclear plants on December 29, 2000.
NOTE 16. NUCLEAR DECOMMISSIONING
As discussed in Note 14 to the Consolidated Financial Statements, DPL sold
its ownership interests in Peach Bottom and Salem on December 29, 2000. As
part of the sales, DPL transferred its decommissioning trust funds and related
obligations for decommissioning the plants to the purchasers. As a result,
Conectiv's Consolidated Balance Sheet as of December 31, 2000 excludes any
amounts for the former decommissioning trust funds and
II-58
related decommissioning obligations of DPL. During 2001, ACE is expected to
sell its ownership interests in nuclear electric generating plants and trans-
fer its decommissioning trust funds and related obligation for decommissioning
the plants to the purchasers upon completion of the sales.
The portion of the estimated cost of decommissioning nuclear reactors re-
lated to ACE's ownership interests and DPL's former ownership interests in nu-
clear electric generating plants has been recorded over the estimated lives of
the plants based on amounts collected in rates charged to electric customers.
ACE estimates its share of future nuclear decommissioning costs ($157 million)
based on site-specific studies filed with and approved by the NJBPU. The ulti-
mate cost of nuclear decommissioning for ACE's ownership interests in the nu-
clear electric generating plants may exceed the estimate. Prior to the sale of
its ownership interests in nuclear electric generating plants, DPL had esti-
mated its share of nuclear decommissioning costs based on Nuclear Regulatory
Commission (NRC) regulations concerning the minimum financial assurance amount
for nuclear decommissioning.
Conectiv's consolidated balances for nuclear decommissioning liability and
related external trust funds decreased from December 31, 1999 to December 31,
2000 due to the sales of DPL's ownership interests in nuclear electric gener-
ating plants. Conectiv's consolidated accrued nuclear decommissioning liabili-
ty, which is reflected in the accumulated reserve for depreciation, was $109.0
million as of December 31, 2000 and $179.5 million as of December 31, 1999.
The provision reflected in depreciation expense for nuclear decommissioning
was $0.4 million in 2000, $6.7 million in 1999, and $10.6 million in 1998. Ex-
ternal trust funds established for the purpose of funding nuclear
decommissioning costs had an aggregate book balance (stated at fair market
value) of $109.0 million as of December 31, 2000 and $166.9 million as of De-
cember 31, 1999. Earnings on the trust funds are recorded as an increase to
the accrued nuclear decommissioning liability, which, in effect, reduces the
expense recorded for nuclear decommissioning.
The staff of the Securities and Exchange Commission (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. In February 2000, the FASB issued an expo-
sure draft of a new accounting standard that addresses the accounting for ob-
ligations associated with the retirement of long-lived assets, such as
decommissioning costs of nuclear generating stations. Under this proposed ac-
counting standard, the fair value of the decommissioning obligation would be
capitalized 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 accounting standard rather than
as a reduction of decommissioning expense.
NOTE 17. 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, 7, and 10 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, 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 regulatory asset,
II-59
"Recoverable stranded costs," was established to recognize amounts to be col-
lected from regulated delivery customers for stranded costs that resulted from
deregulation of the electricity supply business.
The table below displays the regulatory assets and liabilities as of Decem-
ber 31, 2000 and December 31, 1999.
December 31, December 31,
Regulatory Assets (Liabilities) 2000 1999
- ------------------------------- ------------ ------------
(Millions of Dollars)
Recoverable stranded costs.......................... $ 988.2 $1,030.0
Deferred recoverable income taxes................... 84.7 93.9
Deferred debt refinancing costs..................... 20.7 21.1
Unrecovered New Jersey state excise taxes........... 10.4 22.6
Deferred other postretirement benefit costs......... 30.0 32.5
Unrecovered purchased power costs................... 14.5 28.9
Deferred energy supply costs--DPL................... 22.1 8.6
Deferred energy supply costs--ACE................... (34.7) (46.4)
Deferred costs for nuclear
decommissioning/decontamination.................... 5.1 5.6
Regulatory liability for New Jersey income tax
benefit............................................ (49.3) (49.3)
Asbestos removal costs.............................. 8.0 8.3
Deferred demand-side management costs............... 2.4 4.1
Other............................................... 2.9 2.7
-------- --------
Total............................................... $1,105.0 $1,162.6
======== ========
Recoverable Stranded Costs: Represents amounts to be collected from regu-
lated delivery customers (net of amounts that 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 pre-tax
balances of $988.2 million as of December 31, 2000 and $1.0 billion as of De-
cember 31, 1999 arose from the $228.5 million NUG contract termination payment
in 1999, as discussed in Note 11 to the Consolidated Financial Statements, and
discontinuing the application of SFAS No. 71 to the electricity supply busi-
ness in 1999, as discussed in Note 7 to the Consolidated Financial Statements.
Deferred Recoverable Income Taxes: Represents the portion of deferred income
tax liabilities applicable to utility operations of DPL and ACE 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.
Deferred Debt Refinancing Costs: See "Deferred Debt Refinancing Costs" in
Note 1 to the Consolidated Financial Statements.
Unrecovered New Jersey 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 2
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 that began on January
1, 1998.
Unrecovered Purchased Power Costs: Includes costs incurred by ACE for rene-
gotiation of a long-term capacity and energy contract. These costs are in-
cluded in current customer rates with the balance scheduled for full recovery
over the next 14 years. The balance as of December 31, 1999 also included $12
million of prior deferrals by ACE of capacity costs; the amortization of these
costs to expense expired in 2000.
II-60
Deferred Energy Supply Costs: See "Energy Supply Costs" in Note 1 to the
Consolidated Financial Statements.
Deferred Costs for Nuclear Decommissioning/Decontamination: Represents
amounts recoverable from ACE's customers for amounts owed by ACE to the U.S.
government for clean-up of gaseous diffusion enrichment 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 plants 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 delivery 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 29 years.
Deferred Demand-Side Management Costs: Represents deferred costs of programs
that allow DPL to reduce the peak demand for power. The remaining recovery pe-
riod for these costs is 3 years.
NOTE 18. CONECTIV COMMON STOCK
Significant Transactions
Tender Offer
Pursuant to a tender offer to purchase shares of Conectiv common stock (the
Offer), in June 1999, Conectiv paid $361.4 million (including expenses) to
purchase 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 Offer 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) that 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 programs
Conectiv repurchased shares of Conectiv common stock under two buyback pro-
grams as follows: 3,411,100 shares for $54.7 million in 2000; 1,670,000 shares
for $31.4 million in 1999; and 503,700 shares for $11.3 million in 1998. As of
December 31, 2000, 2,760,700 shares of common stock remained authorized for
repurchase by the Board of Directors.
1998 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 1998 Merger.
Other Common Stock Transactions
For additional information concerning issuances and redemptions of common
stock during 1998 through 2000, see the Consolidated Statements of Changes in
Common Stockholders' Equity.
II-61
Dividend Payments
As discussed in Note 5 to the Consolidated Financial Statements, during the
period the Conectiv/Pepco Merger Agreement is in effect, Conectiv's dividend
payments cannot exceed $0.22 per share of Conectiv common stock per quarter.
In 2000, Conectiv's Board of Directors declared quarterly dividends per
share of common stock of $0.22, or $0.88 for the year, which represented ap-
proximately 45% of earnings per share of common stock of $1.97. In the second
quarter of 1999, Conectiv established the objective of having a dividend pay-
out ratio on common stock of 40% to 60% of earnings per share of common stock
and also reduced the quarterly dividend from $0.385 per share to $0.22 per
share.
Restrictions
Under PUHCA, Conectiv may not pay dividends on the shares of common stock
and Class A common stock from an accumulated deficit or paid-in-capital with-
out SEC approval. In the first and second quarters of 2000, Conectiv had accu-
mulated deficits and received SEC approval for the payment of quarterly divi-
dends on shares of common stock and Class A common stock.
Conectiv's common dividends paid to public stockholders are currently funded
from the common dividends DPL and ACE pay to Conectiv. Under PUHCA, DPL and
ACE are prohibited from paying a dividend from an accumulated deficit or paid-
in-capital, unless SEC approval is obtained. Also, certificates of incorpora-
tion of DPL and ACE require payment of all preferred dividends in arrears (if
any) prior to payment of common dividends to Conectiv, and have certain other
limitations on the payment of common dividends to Conectiv.
Stock-Based Compensation
The Conectiv Incentive Compensation Plan (CICP) provides long-term awards to
key employees 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
that can be settled in common stock have included performance accelerated re-
stricted stock (PARS), stock options, and performance accelerated stock op-
tions (PASO).
The number of shares of Conectiv common stock granted as PARS during 1998,
1999, and 2000 were 52,700, 71,500 and 84,100, respectively. The PARS are
earned by the participants over a seven-year vesting period unless accelerated
vesting occurs, in whole or in part, due to satisfaction of certain conditions
required for accelerated vesting. For the PARS shares granted in 1998, 1999,
and 2000, there are 22,000, 22,000, and 39,800 respective shares which have an
additional condition required for vesting; a total stockholder return of 8%
must be earned over the seven years for those shares to vest, unless vesting
is accelerated. The fair value per share on grant date of the PARS was $22.84
for the 1998 grant, $24.25 for the 1999 grant, and $16.56 for the 2000 grant.
II-62
Changes in stock options and PASO are summarized below.
2000 1999 1998
------------------ ------------------ ------------------
Weighted Weighted Weighted
Number of Average Number of Average Number of Average
Shares Price Shares Price Shares Price
--------- -------- --------- -------- --------- --------
Beginning-of-year
balance................ 1,541,950 $23.28 1,072,150 $22.77 38,500 $20.55
Options exercised....... 11,300 16.56 5,600 20.23 3,200 19.89
Options forfeited....... 159,700 20.07 42,400 22.70 2,150 19.73
Options issued.......... 1,156,900 16.65 367,800 24.29 289,000 22.84
PASO issued............. -- -- 150,000 24.25 750,000 22.84
PASO forfeited.......... 150,000 22.84 -- -- -- --
End-of-year balance..... 2,377,850 20.33 1,541,950 23.28 1,072,150 22.77
Exercisable............. 141,600 22.46 11,950 20.11 33,150 20.67
The stock options shown in the table above have a ten-year life, with 50% of
the options vesting after two years and the remaining 50% vesting after three
years. The PASO shown in the table above have a ten-year life and vest after
nine and a half years. One third of the PASO 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 will vest if the stock price closes at
or above $30 per share for ten consecutive days. For options and PASO out-
standing as of December 31, 2000, the range of exercise prices was $16.56 to
$24.75, and the weighted average remaining contractual life was 8.0 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" (APB 25).
Stock-based employee compensation costs charged to expense were $(0.2) million
in 2000, $1.8 million in 1999, and $0.9 million in 1998. The $0.2 million ex-
pense credit for 2000 includes the reversal of stock compensation expense pre-
viously accrued under APB 25 for PARS granted in 1997, which will not be
awarded to employees because the performance criteria were not met. Pro forma
net income (loss), based on the application of SFAS No. 123, "Accounting for
Stock-Based Compensation," was $169.760 million for 2000, $(199.306) million
for 1999, and $152.676 million for 1998. Pro forma earnings (loss) per share
of Conectiv common stock was $1.96 for 2000, $(2.03) for 1999, and $1.49 for
1998.
The fair values of each option and PASO granted in 2000, 1999 and 1998, es-
timated on the date of grant using the Black Scholes option pricing model, and
related valuation assumptions are as follows:
2000 1999 1998
----- ----- -----
Weighted Average Fair Value Per Option.................. $2.33 $3.38 $2.64
Weighted Average Fair Value Per PASO.................... -- $3.93 $2.87
Expected Option Term (years)............................ 3.5 3.5 3.5
Expected PASO Term (years).............................. -- 5.5 5.3
Expected Volatility..................................... 20.0% 20.0% 20.0%
Expected Dividend Yield................................. 5.0% 4.0% 6.0%
Risk-free Interest Rate................................. 6.2% 4.7% 5.6%
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
II-63
Plan will not prevent takeovers, but is designed to deter coercive, abusive,
or unfair takeover tactics and to encourage individuals or entities attempting
to acquire Conectiv to negotiate first 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 19. 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 that existed on August 9, 1996 and
were regulated by the NJBPU. Effective July 1, 2000, ACE contributed electric
generation assets to a newly formed subsidiary, Conectiv Atlantic Generation
LLC (CAG), which is part of the AUG. The percentage of "Company Net Income At-
tributable to the Atlantic Utility Group" that is applicable to Class A common
stock is the "Outstanding Atlantic Utility Fraction" (as defined in Conectiv's
Restated Certificate of Incorporation). The Outstanding Atlantic Utility Frac-
tion was 27.3% as of December 31, 2000 and 1999, and 30.0% as of December 31,
1998.
Certain circumstances, as specified in the Restated Certificate of Incorpo-
ration of Conectiv, result in an adjustment to the Outstanding Atlantic Util-
ity Fraction. As discussed in Note 18 to the Consolidated Financial State-
ments, 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
Certificate of Incorporation of Conectiv, the Outstanding Atlantic Utility
Fraction decreased to 27.3% in June 1999, when the Offer was completed.
The earnings of the AUG have been affected by the implementation of the Sum-
mary Order in New Jersey, including the rate decreases required by the Summary
Order. (See Note 10 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 utilized. (See Note 14 to
the Consolidated Financial Statements for information concerning agreements
for the sale of the electric generating plants of ACE and DPL.) Management ex-
pects the proceeds from the planned sales of the electric generating plants of
ACE and DPL will be used to repay debt and to fund expansion of the mid-merit
generation business. Under certain circumstances, the percentage of "Company
Net Income Attributable to the Atlantic Utility Group" applicable to Class A
common stock may be adjusted.
Dividend Payments
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 Di-
rectors to consider the financial condition and regulatory environment of
Conectiv and the results of its operations; and also subject to the limita-
tions under applicable law and the provisions of Conectiv's Restated Certifi-
cate of Incorporation.
II-64
As disclosed at the time of the 1998 Merger, 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 the results of its operations, to
pay annual dividends on the Class A common stock at a rate equal to 90% of
annualized earnings of the Class A common stock (taking into account the
notional fixed charge of $40 million per year in accordance with Conectiv's
Restated Certificate of Incorporation). 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 the earnings that were applica-
ble to the Class A common stock during the Initial Period, Conectiv's Board of
Directors may consider such fact in determining the appropriate annual divi-
dend rate on the Class A common stock following the Initial Period. Management
expects that during the Initial Period the earnings applicable to Class A com-
mon stock will be less than the dividends on the Class A common stock. Divi-
dends declared per share of Class A common stock were $3.20 for 2000, $3.20
for 1999 and $3.20 for 1998. In comparison, earnings excluding special charges
and the extraordinary item which were applicable to Class A common stock were
$1.06 for 2000, $1.44 for 1999 and $1.82 for 1998.
As discussed in Note 5 to the Consolidated Financial Statements, after March
31, 2001 and during the period the Conectiv/Pepco Merger Agreement is in ef-
fect, dividends on Conectiv Class A common stock may be paid at an annual rate
up to 90% of annualized earnings of Class A common stock.
Computation of Earnings Applicable to Conectiv Class A Common Stock
Twelve Months
Ended Ten Months
December 31, Ended
------------------ December 31,
2000 1999 1998
-------- -------- ------------
(Dollars in Thousands)
Net earnings of ACE [1]...................... $ 52,302 $ 3,703 $ 23,742
Exclude non-utility activities of ACE........ 189 1,712 1,402
Exclude 1998 Merger-related costs............ -- 837 47,886
Net earnings of CAG.......................... 9,895 -- --
-------- -------- --------
Net income of the AUG........................ 62,386 6,252 73,030
Pro-rata portion of fixed amount of $40
million per year............................ (40,000) (40,000) (33,333)
-------- -------- --------
Company Net Income (Loss) Attributable to the
AUG......................................... 22,386 (33,748) 39,697
Percentage applicable to Class A Common Stock
[2]......................................... 27.3% 28.5% 30.0%
-------- -------- --------
Earnings (loss) applicable to Class A Common
Stock....................................... $ 6,111 $ (9,618) $ 11,909
======== ======== ========
Earnings (loss) applicable to Class A Common
Stock
Before extraordinary item [3].............. $ 6,111 $ 6,939 $ 11,909
Extraordinary item [4]..................... -- (16,557) --
-------- -------- --------
$ 6,111 $ (9,618) $ 11,909
======== ======== ========
- --------
[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] The percentage applicable to Class A common stock (the Outstanding Atlan-
tic Utility Fraction) in a reporting period is a weighted average based on
the number of days the percentage was in effect during the reporting peri-
od.
[3] After "Special charges" of $1.9 million for 1999, as discussed in Note 6
to the Consolidated Financial Statements.
[4] Represents the portion of the extraordinary item recorded by ACE, as dis-
cussed in Note 7 to the Consolidated Financial Statements, applicable to
Class A common stock based on the Outstanding Atlantic Utility Fraction in
1999.
II-65
Summarized Combined Financial Information of ACE and CAG
Twelve Months
Ended Ten Months
December 31, Ended
--------------------- December 31,
Income Statement Information [1] 2000 1999 1998
- -------------------------------- ---------- ---------- ------------
(Dollars in Thousands)
Operating Revenues........................ $1,003,552 $1,076,585 $875,741
Operating Income [2]...................... 183,011 171,931 105,099
Income before extraordinary item [2]...... 64,329 63,930 23,940
Extraordinary item, net of income taxes
[3]...................................... -- (58,095) --
Earnings applicable to common stock....... 62,197 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 1998 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 1998 Merger-
related costs reduced ACE's operating income by $80.1 million and income
before extraordinary item by $47.9 million. In the Conectiv Consolidated
Financial Statements, ACE's employee separation and other 1998 Merger-
related costs were capitalized as costs of the 1998 Merger.
[3] For information concerning the extraordinary item, refer to Note 7 to the
Consolidated Financial Statements.
Balance Sheet Information
- -------------------------
As of December 31,
--------------------- ---
2000 1999
---------- ----------
(Dollars in
Thousands)
Current assets........................................ $ 348,958 $ 340,774
Noncurrent assets..................................... 2,239,297 2,313,885
---------- ----------
Total assets.......................................... $2,588,255 $2,654,659
========== ==========
Current liabilities................................... $ 308,801 $ 300,837
Noncurrent liabilities................................ 1,481,548 1,550,690
Preferred Stock....................................... 125,181 125,181
Common stockholders' equity........................... 672,725 677,951
---------- ----------
Total capitalization and liabilities.................. $2,588,255 $2,654,659
========== ==========
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 of the
Market Value Ratio of Conectiv Class A common stock to Conectiv common stock
(as defined in the Conectiv Restated Certificate of Incorporation).
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 Restated
Certificate of Incorporation, Conectiv may either redeem each share of
Conectiv Class A common stock remaining 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, Conectiv may,
based on terms specified in the Conectiv Restated Certificate of Incorpora-
tion, 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.
II-66
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 Restated Certificate of Incorporation.
Upon the disposition of all or substantially all (as defined in the Conectiv
Restated Certificate of Incorporation) of the assets attributed to the AUG to
an entity that is not controlled by Conectiv, the Conectiv Restated Certifi-
cate of Incorporation provides for the payment of a dividend 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 com-
mon stock into shares of Conectiv common stock, in each case subject to the
terms specified in the Conectiv Restated Certificate of Incorporation.
Allocation of Consideration in a Subsequent Merger
If there is a merger subsequent to the 1998 Merger described in Note 4 to
the Consolidated Financial Statements (subsequent merger), Conectiv's Restated
Certificate of Incorporation provides for an allocation of the consideration
between Conectiv common stock and Conectiv Class A common stock. In the event
of such a subsequent merger, the holders of shares of Conectiv Class A common
stock are entitled to receive, in exchange for each share held, consideration
equal to a "Market Value Ratio" of the consideration for one share of Conectiv
common stock. The Market Value Ratio is determined in accordance with the pro-
visions of Conectiv's Restated Certificate of Incorporation and is based on a
ratio of the trading prices of Conectiv Class A common stock to Conectiv com-
mon stock during a 20 day period immediately preceding announcement of the
subsequent merger.
NOTE 20. PREFERRED STOCK AND SECURITIES
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, 2000, and 1999 of DPL's and ACE's
preferred stock not subject to mandatory redemption are presented below.
Shares
Current Outstanding Amount
Redemption --------------- ---------------
Series Issuer Price 2000 1999 2000 1999
- ------ ------------------------ --------------- ------- ------- ------- -------
(Dollars in
Thousands)
ACE $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% (1) 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
6 3/4% (2) 35,000 35,000 3,500 3,500
Adjustable rate (3) $100 151,200 151,200 15,120 15,120
Auction rate (4) $100 450,000 450,000 45,000 45,000
------- -------
$95,933 $95,933
======= =======
- --------
(1) Redeemable beginning September 30, 2002, at $25 per share.
(2) Redeemable beginning November 1, 2003, at $100 per share.
(3) Average rates were 5.5% during 2000 and 5.5% during 1999.
(4) Average rates were 5.1% during 2000 and 4.3% during 1999.
II-67
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.
Preferred Stock and Securities of Subsidiaries Subject to Mandatory Redemption
The amounts outstanding as of December 31, 2000, and 1999 of Conectiv's sub-
sidiaries preferred stock and securities subject to mandatory redemption are
presented below.
Shares Outstanding Amount
------------------- -----------------
Issuer Series 2000 1999 2000 1999
------ --------------------- --------- --------- -------- --------
(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 total book value.
In November 1998, a financing subsidiary trust owned by ACE issued $25 mil-
lion (1,000,000 shares) of 7.375% preferred stock.
DPL and ACE have established wholly owned financing subsidiary trusts for the
purposes of issuing common and preferred trust securities and holding Junior
Subordinated Debentures (the Debentures) issued by DPL and ACE, respectively.
The Debentures held by the trusts are their only assets. The trusts use inter-
est payments received on the Debentures they hold to make cash distributions on
the trust securities.
The obligations of DPL and ACE 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 consti-
tute approximately 3% of the liquidation amount of all of the trust securities
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 op-
tion of DPL and/or ACE, at 100% of their principal amount plus accrued inter-
est, after an initial period during which they may not be redeemed and at any
time upon the occurrence of certain events.
NOTE 21. 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. The
mortgage indentures of DPL and ACE require that the electric generating plants
being sold (as discussed in Note 14 to the Consolidated Financial Statements)
be released from the liens of the respective mortgages. These assets may be re-
leased with a combination of cash, bondable property additions and credits rep-
resenting 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.
Maturities of long-term debt and sinking fund requirements during the next
five years are as follows: 2001--$100.7 million; 2002--$370.5 million; 2003--
$212.3 million; 2004--$154.5 million; and 2005--$82.8 million.
II-68
As of December 31, 2000, Conectiv (the holding company) had a $300 million
credit agreement with a five-year term that expires in February 2003 and a
$730 million credit agreement with a one-year term that expires in April 2001.
Conectiv expects to renew the $730 million credit agreement. As of December
31, 2000, Conectiv's credit agreements required a ratio of total indebtedness
to total capitalization of 70% or less and the ratio was 64%, computed in ac-
cordance with the terms of the credit agreements. DPL has a $150 million re-
volving credit facility that expires January 31, 2003 and provides liquidity
for DPL's $104.8 million of Variable Rate Demand Bonds and general corporate
purposes. On a consolidated basis, $468 million was available for borrowing as
of December 31, 2000 under the various credit agreements and credit lines.
Conectiv had a $709.5 million consolidated short-term debt balance (average
interest rate of 7.4%) as of December 31, 2000, compared to a $579.7 million
consolidated short-term debt balance (average interest rate of 6.4%) as of De-
cember 31, 1999. The $129.8 million increase was primarily due to financing
capital expenditures and purchases of Conectiv common stock.
ACE borrowed $228.5 million under a revolving credit facility on December
28, 1999 to provide interim financing for a payment made to terminate a NUG
purchased power contract with Pedricktown, as discussed in Note 11 to the Con-
solidated Financial Statements. In December 2000, ACE exercised its option to
convert the revolving loan balance to a term loan, which is due in two in-
stallments; (1) 25% of the principal balance is due December 20, 2001, and (2)
the remaining term loan principal is due December 20, 2002. ACE intends to re-
pay this debt with proceeds from the expected issuance of transition bonds,
which are discussed Note 10 to the Consolidated Financial Statements.
ACE redeemed $46.0 million of 6.83% Medium Term Notes at maturity on January
26, 2000. DPL redeemed $2.1 million of 7 1/8% Pollution Control Bonds on Feb-
ruary 1, 2000 and $1.4 million of 6.95% Amortizing First Mortgage Bonds on
June 1, 2000.
On behalf of DPL, the Delaware Economic Development Authority issued the
bonds listed below on July 7, 2000, and loaned the proceeds to DPL. The bonds
are not secured by a mortgage or security interest in property of DPL.
Interest
Principal Series Maturity Date Rate
--------- ----------------------------------- ------------- --------
($000)
Exempt Facilities Refunding Revenue
$11,150 Bonds, Series 2000A July 1, 2030 Variable (1)
Exempt Facilities Refunding Revenue
27,750 Bonds, Series 2000B July 1, 2030 Variable (1)
Pollution Control Refunding Revenue
15,000 Bonds, Series 2000C July 1, 2025 (2) 5.5%
Pollution Control Refunding Revenue
16,240 Bonds, Series 2000D July 1, 2028 (2) 5.65%
-------
$70,140
=======
- --------
(1) The interest rates on these bonds are set by either auction or remarketing
procedures for periods specified by DPL, which may be daily, weekly or
other periods, including long-term periods extending up to the bonds' ma-
turity date. The bonds may be subject to optional redemption prior to ma-
turity as provided for in the indenture for the bonds.
(2) The bonds are subject to mandatory tender on July 1, 2010. All or a por-
tion of the tendered bonds may be redeemed and/or remarketed. After July
1, 2010, the bonds may bear interest at a variable rate or fixed rate and
may be subject to optional redemption prior to maturity, as provided for
in the indenture for the bonds.
II-69
The proceeds from the issuance of the bonds listed above and additional cash
were used to redeem $70.17 million of bonds, which are listed below. The bonds
were called at 101.5% to 102% of their principal amount.
Principal Series Redemption Date Interest Rate
--------- -------------------------------- --------------- -------------
($000)
Exempt Facilities Revenue Bonds,
$11,170 Series 1985 September 1, 2000 7.3%
Exempt Facilities Revenue Bonds,
35,000 Series 1990A September 1, 2000 7.6%
Pollution Control Refunding
15,000 Revenue Bonds, Series 1990B September 1, 2000 7.3%
Exempt Facilities Revenue Bonds,
9,000 Series 1989 October 1, 2000 7.5%
-------
$70,170
=======
As a registered holding company under PUHCA, Conectiv is required to obtain
SEC authorization for certain financing transactions. In December 2000,
Conectiv filed a request with the SEC to increase the authorized short-term
debt borrowing capacity for Conectiv (the holding company) from $1.3 billion
(including the short-term debt of DPL) to $2.0 billion (excluding the short-
term debt of DPL). The SEC has "reserved jurisdiction," or withheld approval
pending additional filings, over Conectiv's previous request for the authority
to issue up to $750 million of additional long-term debt. Under existing SEC
financing orders, Conectiv is permitted to issue securities, other than long-
term debt, if the ratio of consolidated common equity to total capitalization
(common equity ratio) is 20% or higher. Based on a recently issued SEC order to
another holding company under PUHCA, management believes that the SEC will au-
thorize the issuance of additional long-term debt by Conectiv when the common
equity ratio is 30% or higher.
PUHCA regulations prohibit the parent holding-company (Conectiv), from bor-
rowing from its subsidiaries.
II-70
Long-term debt outstanding as of December 31, 2000, and 1999 is presented
below:
Type of Debt Interest Rates Due 2000 1999
- ------------ -------------- --------- ---------- ----------
(Dollars in
Thousands)
First Mortgage Bonds: 6.95% 2002 $ 30,000 $ 30,000
6.40% 2003 90,000 90,000
6.63%-8.15% 2011-2015 135,600 161,770
5.90%-7.30% 2017-2021 108,200 152,200
6.85%-8.50% 2022-2025 227,500 227,500
6.05%-7.00% 2028-2032 90,000 90,000
Amortizing First Mortgage
Bonds 6.95% 2001-2008 21,517 22,962
---------- ----------
702,817 774,432
---------- ----------
Pollution Control Bonds
and Notes 7.25% 2001 550 2,700
6.38% 2001-2006 2,200 2,275
6.80% 2021 38,865 38,865
5.50%-7.20% 2025-2029 (1) 89,890 58,650
---------- ----------
131,505 102,490
---------- ----------
Medium-Term Notes
(secured): 6.83% 2000 -- 46,000
6.86% 2001 40,000 40,000
7.02% 2002 30,000 30,000
6.00%-7.20% 2003 40,000 40,000
6.18%-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
---------- ----------
358,000 404,000
---------- ----------
Medium-Term Notes
(unsecured): 6.46%-9.29% 2002 136,000 136,000
6.63%-6.73% 2003 80,000 80,000
6.73%-8.30% 2004 85,000 85,000
6.73%-6.84% 2005 40,000 40,000
6.73%-6.75% 2006 40,000 40,000
7.06%-8.13% 2007 106,500 106,500
7.54%-7.62% 2017 40,700 40,700
6.81% 2018 33,000 33,000
7.61%-9.95% 2019-2021 73,000 73,000
7.72% 2027 30,000 30,000
---------- ----------
664,200 664,200
---------- ----------
Other Obligations: 7.32% 2001 57,125 57,125
7.32% 2002 171,375 171,375
9.65% 2001-2002 2,380 4,256
Variable 2030 38,900 --
Unamortized premium and
discount, net (3,792) (4,043)
Current maturities of
long-term debt (100,721) (48,937)
---------- ----------
Total long-term debt 2,021,789 2,124,898
Variable Rate Demand
Bonds (2) 158,430 158,430
---------- ----------
Total long-term debt and
Variable Rate Demand
Bonds $2,180,219 $2,283,328
========== ==========
- --------
(1) $31.24 million of the $89.89 million of the bonds listed above are subject
to mandatory tender on July 1, 2010. All or a portion of such tendered
bonds may be redeemed and/or remarketed.
(2) The debt obligations of Conectiv's subsidiaries included $158.4 million of
Variable Rate Demand Bonds (VRDB) as of December 31, 2000 and 1999. The
VRDB are classified as current liabilities because the VRDB are due on de-
mand by the bondholder. However, bonds submitted to Conectiv's subsidiar-
ies for purchase are remarketed by a remarketing agent on a best efforts
basis. Management expects that bonds submitted for purchase will continue
to be remarketed successfully due to the credit worthiness 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 considers the VRDB to be a source
of long-term financing. The $158.4 million balance of VRDB outstanding as
of December 31, 2000, matures in 2009 ($12.5 million), 2014 ($18.2 mil-
lion), 2017 ($30.4 million), 2024 ($33.33 million); 2028 ($15.5 million),
2029 ($30.0 million) and 2031 ($18.5 million). Average annual interest
rates on the VRDB were 4.1% in 2000 and 3.3% in 1999.
II-71
NOTE 22. 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.
2000 1999
--------------------- ---------------------
Carrying Fair Carrying Fair
Amount Value Amount Value
---------- ---------- ---------- ----------
(Dollars in Thousands)
Funds held by trustee........... $ 122,387 $ 122,387 $ 173,247 $ 173,247
Preferred stock and securities
of subsidiaries subject to
mandatory redemption........... $ 188,950 $ 187,283 $ 188,950 $ 163,900
Long-term debt.................. $2,021,789 $2,018,853 $2,124,898 $2,075,510
NOTE 23. LONG-TERM PURCHASED POWER CONTRACTS
As of December 31, 2000, the commitments of Conectiv's subsidiaries under
long-term purchased power contracts included 1,421 MW of capacity and varying
amounts of firm electricity per hour during each month of a given year. As
discussed in Note 7 to the Consolidated Financial Statements, the net present
value of expected losses under uneconomic purchased power contracts that ex-
isted when electric utility deregulation occurred in the third quarter of 1999
was included in the extraordinary item recorded in 1999. Based on existing
contracts as of December 31, 2000, the commitments of Conectiv's subsidiaries
during the next five years for capacity and energy under long-term purchased
power contracts are estimated to be as follows: $445 million in 2001, $413
million in 2002; $312 million in 2003; $297 million in 2004; and $328 million
in 2005.
The terms of DPL's wholly owned electric generating plant sale agreement
discussed in Note 14 to the Consolidated Financial Statements provide for DPL
to purchase from NRG 500 MWH of firm electricity per hour from completion of
the sale through December 31, 2005. This planned power purchase is excluded
from the commitments discussed above, since it is contingent upon completion
of the sale of the electric generating plants.
NOTE 24. LEASES
Nuclear Fuel
As discussed in Note 14 to the Consolidated Financial Statements, DPL sold
its ownership interests in Peach Bottom and Salem and the related nuclear fuel
on December 29, 2000. Prior to the sales, the ownership interests of DPL in
nuclear fuel at Peach Bottom and Salem were financed through nuclear fuel en-
ergy contracts, which were accounted for as capital leases. DPL's obligations
under the contracts were repaid on December 29, 2000 with proceeds from the
sale. ACE has similar contracts in place, which are considered capital leases,
to finance its ownership interest in the nuclear fuel at Peach Bottom, Salem,
and Hope Creek. Payments under these contracts are based on the quantity of
nuclear fuel burned by the plants. ACE's obligations under the contracts are
generally the net book values of the nuclear fuel financed, which was $28.4
million, in total, as of December 31, 2000. As discussed in Note 14 to the
Consolidated Financial Statements, there are agreements for the sale of the
ownership interests of ACE in the nuclear power plants, under which ACE's in-
terest in the nuclear fuel is to be sold at its net book value.
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 $139.1 million in aggregate. As discussed in Note 7 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 that existed when electric utility deregulation occurred was in-
cluded in the extraordinary item in the third quarter of 1999. DPL, ACE and
other Conectiv
II-72
subsidiaries also have long-term leases for certain other facilities and
equipment. Minimum commitments as of December 31, 2000, under the Merrill
Creek Reservoir lease and other lease agreements (excluding payments under the
nuclear fuel energy contracts, which cannot be reasonably estimated) are as
follows: 2001--$19.7 million; 2002--$20.7 million; 2003--$23.0 million; 2004--
$20.4 million; 2005--$19.2 million; after 2005--$134.0 million; total--$237.0
million.
Rentals Charged To Operating Expenses
The following amounts were charged to operating expenses for rental payments
under both capital and operating leases.
2000 1999 1998
------- ------- -------
(Dollars in Thousands)
Interest on capital leases............................. $ 3,297 $ 2,466 $ 2,468
Amortization of capital leases......................... 23,029 24,237 19,554
Operating leases....................................... 31,230 22,344 17,443
------- ------- -------
$57,556 $49,047 $39,465
======= ======= =======
Leveraged Leases
The leveraged leases of Conectiv's subsidiaries included four airplane
leases and two container-ship leases as of December 31, 2000. During 2000, the
leveraged lease of one airplane was sold. During 1999, declines in the esti-
mated 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 investment in leveraged leases as
of December 31, 2000, and 1999 was as follows:
2000 1999
-------- --------
(Dollars in
Thousands)
Rentals receivable (net of principal and interest on
nonrecourse debt)........................................ $ 48,243 $ 66,771
Estimated residual value.................................. 6,752 9,234
Unearned and deferred income.............................. (1,289) (3,844)
-------- --------
Investment in leveraged leases............................ 53,706 72,161
Deferred income tax liability............................. 69,354 87,669
-------- --------
Net investment in leveraged leases........................ $(15,648) $(15,508)
======== ========
NOTE 25. PENSION AND OTHER POSTRETIREMENT BENEFITS
Assumptions
2000 1999 1998
----- ----- -----
Discount rates used to determine projected benefit
obligation as of December 31............................... 7.50% 7.75% 6.75%
Expected long-term rates of return on assets................ 9.50% 9.00% 9.00%
Rates of increase in compensation levels.................... 4.50% 4.50% 4.50%
Health-care cost trend rate on covered charges.............. 8.00% 6.50% 7.00%
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 2004. Increasing the
health-care cost trend rates of future years by one percentage point would in-
crease the accumulated postretirement benefit obligation by $10.1 million and
would increase annual aggregate service and interest costs by $0.9 million.
Decreasing the health-care cost trend rates of future years by one percentage
point would decrease the accumulated postretirement benefit obligation by
$10.5 million and would decrease annual aggregate service and interest costs
by $1.0 million.
II-73
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
---------------------- ------------------
2000 1999 2000 1999
---------- ---------- -------- --------
(Dollars in Thousands)
Benefit obligation at beginning of
year............................. $ 673,095 $ 748,689 $194,031 $232,374
Service cost...................... 18,388 20,288 3,908 5,282
Interest cost..................... 51,856 51,442 14,513 13,839
Plan participants' contributions.. -- -- 511 500
Plan amendment.................... 4,359 -- -- --
Actuarial (gain) loss............. 12,689 (75,244) 5,500 (43,861)
Benefits paid..................... (66,438) (64,671) (16,970) (9,436)
Other............................. 672 (7,409) -- (4,667)
---------- ---------- -------- --------
Benefit obligation at end of
year............................. $ 694,621 $ 673,095 $201,493 $194,031
========== ========== ======== ========
Change in Plan Assets
Other
Postretirement
Pension Benefits Benefits
---------------------- ------------------
2000 1999 2000 1999
---------- ---------- -------- --------
(Dollars in Thousands)
Fair value of assets at beginning
of year.......................... $1,017,844 $ 951,474 $120,072 $ 95,164
Actual return on plan assets...... (3,363) 138,450 166 13,494
Employer contributions............ -- -- 15,945 25,017
Plan participants' contributions.. -- -- 511 500
Benefits paid..................... (66,438) (64,671) (16,970) (9,436)
Other............................. -- (7,409) -- (4,667)
---------- ---------- -------- --------
Fair value of assets at end of
year............................. $ 948,043 $1,017,844 $119,724 $120,072
========== ========== ======== ========
Reconciliation of Funded Status of the Plans
Other
Postretirement
Pension Benefits Benefits
---------------------- ------------------
2000 1999 2000 1999
---------- ---------- -------- --------
(Dollars in Thousands)
Funded status at end of year...... $ 253,422 $ 344,749 $(81,769) $(73,959)
Unrecognized net actuarial
(gain)........................... (181,008) (300,864) (46,246) (63,286)
Unrecognized prior service cost... 7,794 4,129 149 198
Unrecognized net transition
(asset) obligation............... (10,245) (13,009) 37,531 40,659
---------- ---------- -------- --------
Net amount recognized at end of
year............................. $ 69,963 $ 35,005 $(90,335) $(96,388)
========== ========== ======== ========
Based on fair values as of December 31, 2000, the pension plan assets were
comprised of publicly traded equity securities ($606.7 million or 64%) and
fixed income obligations ($341.3 million or 36%). Based on fair values as of
December 31, 2000, the other postretirement benefit plan assets included eq-
uity securities ($77.8 million or 65%) and fixed income obligations ($41.9
million or 35%).
II-74
Components of Net Periodic Benefit Cost
Other Postretirement
Pension Benefits Benefits
---------------------------- -------------------------
2000 1999 1998 2000 1999 1998
-------- -------- -------- ------- ------- -------
(Dollars in Thousands)
Service cost............ $ 18,388 $ 20,288 $ 18,933 $ 3,908 $ 5,282 $ 5,221
Interest cost........... 51,856 51,442 48,291 14,513 13,839 13,636
Expected return on
assets................. (90,037) (83,999) (81,259) (8,645) (6,769) (4,845)
Amortization of:
Transition obligation
(asset).............. (2,764) (2,764) (2,764) 3,128 3,128 3,244
Prior service cost.... 694 406 1,911 49 49 50
Actuarial (gain)...... (13,767) (4,248) (9,165) (3,060) (1,059) (567)
-------- -------- -------- ------- ------- -------
Benefit cost before
items below............ (35,630) (18,875) (24,053) 9,893 14,470 16,739
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....... $(35,630) $(18,875) $(19,990) $ 9,893 $14,470 $32,492
======== ======== ======== ======= ======= =======
Portion of net periodic
benefit cost included
in results of
operations............. $(35,630) $(18,875) $(22,258) $ 9,893 $14,470 $20,440
======== ======== ======== ======= ======= =======
The special termination benefits and curtailment and settlement gains and
losses shown above for 1998 resulted from 1998 Merger-related employee separa-
tion programs discussed in Note 6 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 $4.9 mil-
lion in 2000, $5.6 million in 1999, and $4.9 million in 1998.
NOTE 26. COMMITMENTS AND CONTINGENCIES
Commitments
In 2001, Conectiv's expected total capital expenditures, are estimated to be
approximately $640 million, including $450 million for mid-merit electric gen-
erating facilities, $140 million for the electric and gas delivery businesses,
and $50 million for various other projects.
See Note 23 to the Consolidated Financial Statements for commitments related
to long-term purchased power contracts and Note 24 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 liability for clean-up costs is affected by the activities of
these governmental agencies and private land-owners, the nature of past dis-
posal practices, the activities of others (including whether they are able to
contribute to clean-up costs), and the scientific and other complexities in-
volved in resolving clean up-related issues (including whether a Conectiv sub-
sidiary or a corporate predecessor is responsible for conditions on a particu-
lar parcel). Conectiv's current liabilities included $9.8 million as of Decem-
ber 31, 2000 and $3.0 million as of December 31, 1999 for potential clean-up
and other costs related to sites at which a Conectiv subsidiary is a poten-
tially responsible party or alleged to be a third party contributor, including
the Indian River power plant discussed below. Conectiv does not expect such
future costs to have a material effect on its financial position or results of
operations.
II-75
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 recover oil from the soil.
Remediation costs are expected to be approximately $10 million, including ap-
proximately $3 million of cumulative expenditures which had been incurred as
of December 31, 2000. In addition, DPL paid $350,000 in penalties and $100,000
for an environmental improvement project to the Delaware Department of Natural
Resources and Environmental Control (DNREC) in connection with the oil leak
and another matter related to the Indian River power plant.
Nuclear Insurance
As discussed in Note 14 to the Consolidated Financial Statements, DPL sold
its ownership interests in nuclear electric generating plants on December 29,
2000.
In conjunction with the ownership interests of ACE in Peach Bottom, Salem,
and Hope Creek, ACE could be assessed for a portion of any third-party claims
associated with an incident at any commercial nuclear power plant in the
United States. Under the provisions of the Price Anderson Act, if third-party
claims relating to such an incident exceed $200 million (the amount of primary
insurance), ACE could be assessed up to $30.7 million on an aggregate basis
for such third-party claims. In addition, Congress could impose a revenue-
raising measure on the nuclear industry to pay such claims.
The co-owners of Peach Bottom, Salem, and Hope Creek maintain property in-
surance coverage of approximately $1.8 billion for each unit for loss or dam-
age to the units, including coverage for decontamination expense and premature
decommissioning. An industry mutual insurance company (NEIL) provides replace-
ment power cost coverage to members in the event of a major accidental outage
at a nuclear power plant. Under these coverages, ACE is subject to potential
retrospective loss experience assessments of up to $1.9 million on an aggre-
gate basis.
Under changes in NEIL's by-laws effective December 31, 2000, member account
balances no longer exist. NEIL members who sell their interests in nuclear
electric generating plants after December 31, 2000, may choose either (1) to
continue to receive certain policyholders' distributions from NEIL (if, as,
and when declared) over a 5-year period or (2) to remain a NEIL member by pur-
chasing other insurance products from NEIL and thus remain eligible for poli-
cyholders' distributions (if, as, and when declared) for a longer period. NEIL
members that sold their interests in nuclear generating plants on or before
December 31, 2000 have available the two options discussed above or could also
elect prior to February 28, 2001 a third option, to be paid their member ac-
count balances by NEIL as a result of terminating their NEIL insurance cover-
ages. DPL expects to terminate its NEIL membership and elect to receive cash
of approximately $16 million for its member account balance. If the sale of
ACE's ownership interests in nuclear electric generating plants is completed,
then ACE will be able to choose one of the two options available to it.
Other
On October 24, 2000, the City of Vineland, New Jersey, filed an action in a
New Jersey Superior Court to acquire by eminent domain ACE electric distribu-
tion facilities located within the City limits. The City has offered approxi-
mately $11 million for these assets, including the right to provide electric
service in this area. ACE believes that, properly evaluated, the assets sought
by the City are worth approximately $40 million.
NOTE 27. BUSINESS SEGMENTS
The following information is presented in accordance with SFAS No. 131,
"Disclosures about Segments of an Enterprise and Related Information" (SFAS
No. 131). In accordance 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 segments under SFAS No. 131 are as
II-76
follows: "Energy" includes (a) the generation, purchase, trading and sale of
electricity, including the obligations of DPL and ACE to supply electricity to
customers who do not choose an alternative electricity supplier; (b) gas and
other energy supply and trading activities, (c) power plant operation servic-
es, and (d) district heating and cooling systems operation and construction
services provided by CTS; "Power Delivery" includes activities related to de-
livery of electricity and gas to customers at regulated prices over transmis-
sion and distribution systems; "Telecommunications" represents services pro-
vided by Conectiv Communications Inc. (CCI), including local and long-distance
telephone service and Internet services; "HVAC" represents heating, ventila-
tion, and air conditioning services which were provided by CSI prior to the
sale of this business in the latter-half of 2000.
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 10 to the Consolidated Financial Statements, Conectiv's
electricity supply businesses were deregulated in the third quarter of 1999.
Prior to deregulation, amounts included in billings to electric customers for
electricity supply and delivery services were not separately identified; dur-
ing this period revenues were allocated directly to the Energy and Power De-
livery business segments based on the cost of services provided.
Common services 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 depreciation associated with shared
services' assets is allocated to the business segments; however, the assets
and related capital expenditures are not allocated.
The operating results for business segments are evaluated based on "earnings
before interest and income taxes," which is generally equivalent to Operating
Income, excluding Special Charges (see Note 6 to the Consolidated Financial
Statements) and the gain on the sale of DPL's ownership interests in nuclear
generating plants, plus Other Income, less certain interest charges allocated
to the business segments. "Earnings before interest and income taxes" for the
Energy business segment include the operating results of certain electric gen-
erating plants that are expected to be sold subsequent to receipt of required
regulatory approvals, as discussed in Note 14 to the Consolidated Financial
Statements. The "earnings before interest and income taxes" of "All Other"
business segments include the equity in earnings of the EnerTech funds, dis-
cussed in Note 8 to the Consolidated Financial Statements. "Earnings before
interest and income taxes" for 1998 includes the January and February 1998 op-
erating results of the former Atlantic-owned companies which are excluded from
the 1998 Consolidated Statement of Income under purchase accounting for the
1998 Merger.
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. However, the deferred asset for "Re-
coverable stranded costs" of $988.2 million and $1,030.0 million as of Decem-
ber 31, 2000 and 1999, respectively, and other regulatory assets (and liabili-
ties) are associated with the Power Delivery Business. See Note 17 to the Con-
solidated Financial Statements for additional information about regulatory as-
sets, including "Recoverable stranded costs."
II-77
As of
Year Ended December 31, 2000 December 31, 2000
-------------------------------------------------------- -----------------
Earnings Investments and
Before Interest Capital Property, Plant &
Business Segments Revenues Depreciation and Taxes Expenditures Equipment
- ----------------- ---------- ------------ --------------- ------------ -----------------
(Dollars in Thousands)
Energy.................. $4,905,535 $116,386 $337,499 $184,121 $1,299,061
Power Delivery.......... 772,240 97,234 255,004 142,140 2,230,012
Telecommunications...... 56,071 7,249 (50,189) 52,314 160,119
HVAC.................... 89,594 1,724 (8,864) -- 1,008
All Other............... 7,131 1,433 (2,298) 4,514 97,186
---------- -------- -------- -------- ----------
$5,830,571(1) $224,026(2) $531,152(3) $383,089(4) $3,787,386(5)
========== ======== ======== ======== ==========
- --------
(1) Includes intercompany revenues that are eliminated in consolidation as
follows: Energy business segment--$795,470; Power Delivery Business Seg-
ment--$444; Telecommunications business segment--$5,533.
(2) Excludes $7,226 of goodwill amortization pursuant to the 1998 Merger and
$28,830 of depreciation classified in business segment operating expenses
which are included in consolidated depreciation and amortization expense.
(3) "Earnings before interest and income taxes" less $216,242 of interest ex-
pense and preferred stock dividends, $2,016 of consolidation adjustments,
and $25,162 of special charges plus the $16,612 pre-tax gain on the sale
of DPL's ownership interests in nuclear electric generating plants equals
consolidated income before income taxes and extraordinary item.
(4) Consolidated capital expenditures of $390,540 include $7,451 of shared
services' capital expenditures which are excluded above.
(5) Excludes $267,273 of shared services' property, plant & equipment and cer-
tain investments, all Current Assets ($1,092,261), and all Deferred
Charges and Other Assets ($1,331,075) which are included in total consoli-
dated assets of $6,477,995. Amounts invested in equity method investees as
of December 31, 2000 were $20,750 by Energy and $40,556 by All Other busi-
ness segments.
As of
Year Ended December 31, 1999 December 31, 1999
-------------------------------------------------------- -----------------
Earnings Investments and
Before Interest Capital Property, Plant &
Business Segments Revenues Depreciation and Taxes Expenditures Equipment
- ----------------- ---------- ------------ --------------- ------------ -----------------
(Dollars in Thousands)
Energy.................. $3,002,736 $132,538 $271,181 $105,993 $1,242,211
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 22,810
All Other............... 6,470 2,981 34,339 -- 100,227
---------- -------- -------- -------- ----------
$3,945,952(1) $235,583(2) $509,356(3) $277,236(4) $3,704,920(5)
========== ======== ======== ======== ==========
- --------
(1) Includes intercompany revenues that are eliminated in consolidation as
follows: Energy business segment--$195,498; Telecommunications business
segment--$4,482; All Other business segments--$1,075.
(2) Excludes $7,073 of goodwill amortization pursuant to the 1998 Merger and
$28,692 of depreciation classified in business segment operating expenses
which are included in consolidated depreciation and amortization expense.
(3) "Earnings before interest and income taxes" less $182,451 of interest ex-
pense and preferred stock dividends, $105,648 of special charges, and
$1,863 of consolidation adjustments equals consolidated income before in-
come taxes and extraordinary item.
(4) Consolidated capital expenditures of $320,395 include $43,159 of shared
services' capital expenditures which are excluded above.
(5) Excludes $282,735 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.
II-78
As of
December 31,
Year Ended December 31, 1998 1998
-------------------------------------------------------- ---------------
Earnings Investments and
Before Interest Capital Property, Plant
Business Segments Revenues Depreciation and Taxes Expenditures & Equipment
- ----------------- ---------- ------------ --------------- ------------ ---------------
(Dollars in Thousands)
Energy.................. $2,450,274 $130,863 $267,463 $ 50,083 $2,123,982
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) 5,090 178,238
---------- -------- -------- -------- ----------
$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 1998 Merger and $21,643 of depreciation classified in busi-
ness segment operating expenses which are included in consolidated depre-
ciation and amortization expense.
(3) "Earnings before interest and taxes" less $20,914 for the January to Feb-
ruary 1998 "earnings before interest and taxes" of the formerly Atlantic-
owned companies, $27,704 of special charges, $154,044 of interest expense
and preferred stock dividends, and $1,832 of consolidation adjustments
equals consolidated income before income taxes and extraordinary item.
(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.
NOTE 28. 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, and the scheduled downtime and
maintenance of electric generating units.
2000
-------------------------------------------------------
First Second Third Fourth
Quarter Quarter Quarter Quarter Total
---------- ---------- ---------- ---------- ----------
(Dollars in Thousands, Except Per Share Amounts)
Operating Revenues...... $1,045,345 $1,152,384 $1,551,548 $1,279,847 $5,029,124
Operating Income........ 101,946 63,200 204,357 118,331 487,834
Net Income ............. 32,537 18,361 89,616 30,316 170,830
Earnings Per Common
Share.................. 0.41 0.21 1.01 0.35 1.97
Earnings (Loss) Per
Class A Common Share... (0.43) 0.17 1.08 0.24 1.06
As discussed in Note 8 to the Consolidated Financial Statements, Conectiv
recorded investment income in 2000 for equity in the earnings of the EnerTech
funds. This investment income increased (a) net income and earnings per share
of common stock in the second quarter of 2000 by $16.0 million and $0.19, re-
spectively, and (b) net income and earnings per share of common stock in the
third quarter of 2000 by $6.2 million and $0.07,
II-79
respectively. In the fourth quarter of 2000, an investment loss from the
EnerTech funds reduced net income and earnings per share of common stock by
$9.0 million and $0.11, respectively.
As discussed in Note 6 to the Consolidated Financial Statements, Conectiv
recorded special charges in the second quarter of 2000 related to the sale of
businesses which decreased income before extraordinary item and earnings per
share of common stock by $23.4 million and $0.28, respectively.
In the third quarter of 2000, management received a new actuarial estimate
of Conectiv's pension and other postretirement benefit costs for 2000. As a
result of lower than previously estimated annual costs, pre-tax income, net
income, and earnings per common share increased by $3.9 million, $2.3 million,
and $0.03, respectively, for the third quarter of 2000.
As discussed in Note 14 to the Consolidated Financial Statements, in the
fourth quarter of 2000, a gain on the sale of the ownership interests of DPL
in nuclear electric generating plants increased net income by $12.8 million
and earnings per share of Conectiv common stock by $0.15.
1999
--------------------------------------------------
First Second Third Fourth
Quarter Quarter Quarter Quarter Total
-------- -------- ---------- -------- ----------
(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 (1).. -- -- (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 (1).. -- -- (0.83) (1.93) (2.71)
- --------
(1) For information concerning the extraordinary item recorded in the third
and fourth quarters of 1999, see Note 7 to the Consolidated Financial
Statements.
As discussed in Note 6 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.
Investment income from the EnerTech funds 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,
II-80
The total of 2000 and 1999 quarterly earnings per share does not equal an-
nual earnings per share for 2000 and 1999, 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 2000 and
1999 are presented below.
Average Number of Shares Outstanding
------------------------------------
Common Stock Class A Common Stock
-------------- ---------------------
2000 1999 2000 1999
------ ------- ---------- ----------
(Thousands of Shares)
First Quarter.............................. 85,568 100,532 5,742 6,561
Second Quarter............................. 83,777 98,120 5,742 6,408
Third Quarter.............................. 82,701 87,711 5,742 5,743
Fourth Quarter............................. 82,699 86,916 5,742 5,742
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE.
None.
II-81
PART III
Item 10. Directors and Executive Officers of the Registrant
Proposal No. 1--"Election of Directors" is incorporated by reference herein
from the Preliminary Joint Proxy Statement/Prospectus which was initially
filed for New RC, Inc. on Form S-4 with the SEC on March 14, 2001 (Preliminary
Joint Proxy Statement/Prospectus).
Information about Conectiv's executive officers is included under Item 1.
Information about reporting on Form 4, Statement of Changes in Beneficial Own-
ership of Securities, and on Form 5, Annual Statement of Beneficial Ownership
of Securities, is incorporated by reference herein from the "Section 16(a)
Beneficial Ownership Compliance" section of the Preliminary Joint Proxy
Statement/Prospectus.
Item 11. Executive Compensation
The information required by Item 11 of Form 10-K is incorporated herein by
reference from the Preliminary Joint Proxy Statement/Prospectus except that
the Report of the Personnel & Compensation 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 head-
ing "Security Ownership of Directors, Executive Officers and Certain Benefi-
cial Owners" in the Preliminary Joint Proxy Statement/Prospectus and is incor-
porated 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 head-
ing "Personnel & Compensation Committee Interlocks and Insider Participation"
in the Preliminary Joint Proxy Statement/Prospectus 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-29
Consolidated Statements of Income for the years ended December 31,
2000, 1999, and 1998................................................. II-30
Consolidated Statements of Cash Flows for the years ended December 31,
2000, 1999, and 1998................................................. II-31
Consolidated Balance Sheets as of December 31, 2000 and 1999.......... II-32
Consolidated Statements of Changes in Common Stockholders' Equity for
the years ended December 31, 2000, 1999, and 1998.................... II-34
Notes to Consolidated Financial Statements............................ II-36
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 1998 Statement of Income and the 1998 Statement of
Cash Flows do not include 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 21 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 18 and 19, respectively, to the Consolidated Financial Statements
included in Item 8 of Part II.
Cash dividends received by Conectiv from consolidated subsidiaries were
$122.5 million in 2000, $135.7 million in 1999 and $132.4 million in 1998.
As of December 31, Conectiv had guarantees of approximately $249 million,
which included $128 million for debt of Conectiv subsidiaries, $73 million for
energy trading obligations of Conectiv subsidiaries, and $48 million for other
items including construction commitments and the debt of an unconsolidated eq-
uity method investee.
IV-1
CONECTIV
STATEMENTS OF INCOME
Year Ended December 31,
-----------------------------
2000 1999 1998
-------- --------- --------
(Dollars in Thousands)
Operating Expenses.............................. $ 13,465 $ 2,003 $ 1,639
-------- --------- --------
Operating Income................................ (13,465) (2,003) (1,639)
-------- --------- --------
Other Income
Equity in earnings of consolidated
subsidiaries excluding extraordinary item.... 204,110 129,209 156,511
Other income.................................. 2,839 513 624
-------- --------- --------
206,949 129,722 157,135
-------- --------- --------
Interest Expense................................ 40,349 22,557 3,914
-------- --------- --------
Income Before Income Taxes And Extraordinary
Item........................................... 153,135 105,162 151,582
-------- --------- --------
Income Tax Benefit, Excluding Income Taxes
Applicable to Extraordinary Item............... (17,695) (8,416) (1,619)
-------- --------- --------
Income Before Extraordinary Item................ 170,830 113,578 153,201
-------- --------- --------
Equity In Extraordinary Item of Consolidated
Subsidiaries................................... -- (311,718) --
-------- --------- --------
Net Income (Loss)............................... $170,830 $(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,
-------------------------------
2000 1999 1998
--------- --------- ---------
(Dollars in Thousands)
Cash Flows From Operating Activities
Net income (loss)........................... $ 170,830 $(198,140) $ 153,201
Adjustments to reconcile net income to net
cash provided by operating activities
Equity in loss (earnings) of
subsidiaries............................. (204,110) 182,509 (156,511)
Net change in:
Accounts receivable..................... 739 9,742 (16,124)
Taxes accrued........................... (22,604) (4,476) 5,903
Other current assets and liabilities.... 28 (2,992) (4,501)
Dividends received from subsidiaries........ 122,478 135,691 132,357
Other, net.................................. 13,807 2,380 (170)
--------- --------- ---------
Net cash provided by operating
activities............................... 81,168 124,714 114,155
--------- --------- ---------
Cash Flows From Investing Activities
Decrease (increase) in investment in money
pool (1)................................... 127,150 (48,130) (45,456)
Decrease (increase) in notes receivable from
subsidiaries............................... (116,268) 16,452 (168,003)
Capital contributions to subsidiaries....... (55,399) (39,018) (27,496)
Return of invested capital from
subsidiaries............................... 48,570 -- --
Other, net.................................. (173) 143 239
--------- --------- ---------
Net cash provided (used) by investing
activities............................... 3,880 (70,553) (240,716)
--------- --------- ---------
Cash Flows From Financing Activities
Common dividends paid....................... (92,009) (135,134) (130,451)
Common stock issued......................... 187 68 --
Common stock redeemed....................... (54,651) (390,397) (11,135)
Long-term debt issued....................... -- 250,000 --
Long-term debt redeemed..................... -- -- (53,500)
Net change in short-term debt............... 59,315 210,685 339,000
Costs of issuances and refinancings......... (1,373) (4,114) 365
--------- --------- ---------
Net cash provided (used) by financing
activities............................... (88,531) (68,892) 144,279
--------- --------- ---------
Net change in cash and cash equivalents....... (3,483) (14,731) 17,718
Beginning of year cash and cash equivalents... 3,960 18,691 973
--------- --------- ---------
End of year cash and cash equivalents......... $ 477 $ 3,960 $ 18,691
========= ========= =========
- --------
(1) The money pool is a pool of funds that Conectiv subsidiaries invest in or
borrow from, depending on their cash position.
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,
---------------------
2000 1999
---------- ----------
(Dollars in
Thousands)
ASSETS
Current Assets
Cash and cash equivalents.............................. $ 477 $ 3,960
Dividends receivable from subsidiaries................. 22,788 23,536
Accounts receivable.................................... 1,618 600
Taxes receivable....................................... 14,373 --
Investment in money pool (1)........................... 422 136,456
Other.................................................. 19 1,838
---------- ----------
39,697 166,390
---------- ----------
Investments
Investment in subsidiary companies..................... 1,736,901 1,647,529
Notes receivable from subsidiary companies............. 267,446 151,178
Other investments...................................... 1,619 5,675
---------- ----------
2,005,966 1,804,382
---------- ----------
Deferred Charges and Other Assets
Unamortized debt expense............................... 1,149 1,477
Deferred charges....................................... -- 297
---------- ----------
1,149 1,774
---------- ----------
Total Assets............................................. $2,046,812 $1,972,546
========== ==========
- --------
(1) The money pool is a pool of funds that Conectiv subsidiaries invest in or
borrow from, depending on their cash position.
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,
----------------------
2000 1999
---------- ----------
(Dollars in
Thousands)
CAPITALIZATION AND LIABILITIES
Current Liabilities
Short-term debt...................................... $ 605,030 $ 549,685
Taxes accrued........................................ -- 8,231
Dividends payable.................................... 25,565 25,983
Interest accrued..................................... 2,306 --
Other................................................ 2,086 474
---------- ----------
634,987 584,373
---------- ----------
Deferred income taxes.................................. 1,556 --
---------- ----------
Capitalization
Common stock: $0.01 per share par value 150,000,000
shares authorized; shares outstanding--82,859,779 in
2000, and 86,173,169 in 1999........................ 830 863
Class A common stock, $0.01 par value; 10,000,000
shares authorized; shares outstanding--5,742,315 in
2000 and 1999....................................... 57 57
Additional paid-in-capital--common stock............. 1,028,780 1,085,060
Additional paid-in-capital--Class A common stock..... 93,738 93,738
Retained earnings/(Accumulated deficit).............. 42,768 (36,472)
Treasury shares, cost: 130,604 shares in 2000;
167,514 shares in 1999.............................. (2,688) (3,446)
Unearned compensation................................ (1,172) (1,627)
Accumulated other comprehensive income............... (2,044) --
---------- ----------
Total common stockholders' equity.................... 1,160,269 1,138,173
Long-term debt....................................... 250,000 250,000
---------- ----------
1,410,269 1,388,173
---------- ----------
Total Capitalization and Liabilities................... $2,046,812 $1,972,546
========== ==========
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, 2000, 1999, 1998
(Dollars in thousands)
Column B Column C Column D Column E
---------- ------------------------- ---------- ----------
Additions
-------------------------
Balance at Charged to Balance at
beginning cost and Charged to end of
Description of period expenses other accounts Deductions period
----------- ---------- ---------- -------------- ---------- ----------
2000
Allowance for doubtful
accounts............... $11,564 $30,508 -- $10,733(b) $31,339
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
- --------
(a) Consolidation of ACE's balance due to the 1998 Merger discussed in Note 4
to the Consolidated Financial Statements included in Item 8 of Part II.
(b) Accounts receivable written off.
IV-6
(b) Reports on Form 8-K
The following Reports on Form 8-K were filed in the fourth quarter of 2000.
On October 20, 2000, Conectiv filed a Current Report on Form 8-K dated Octo-
ber 3, 2000, reporting on Item 5, Other Events.
3. Exhibits
Exhibit
Number
-------
2-A 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)
2-B Agreement and Plan of Merger, dated as of February 9, 2001, between
Potomac Electric Power Company, New RC, Inc. and Conectiv (filed with
Conectiv's Current Report on Form 8-K dated February 13, 2001)
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 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-C 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-D 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-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 October 26, 1999 (filed herewith)
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 Conectiv Change-in-Control Severance Plan For Certain Executive
Officers (filed herewith)
10-D Conectiv Change-in-Control Severance Plan For Certain Select Employees
(filed herewith)
10-E Form of Change-in-Control Severance Agreement between Conectiv and
certain executives (filed herewith)
IV-7
Exhibit
Number
-------
12 Computation of 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 2000 Conectiv Pro Forma Financial Statements--Generation Asset Sale
and Transfer (filed herewith)
IV-8
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 15, 2001.
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 15, 2001.
Signature Title
--------- -----
/s/ Howard E. Cosgrove Chairman of the Board and
______________________________________ Chief Executive Officer
(Howard E. Cosgrove)
/s/ John C. van Roden Senior Vice President and
______________________________________ Chief Financial Officer
(John C. van Roden)
/s/ James P. Lavin Controller and Chief
______________________________________ Accounting Officer
(James P. Lavin)
/s/ R. Franklin Balotti Director
______________________________________
(R. Franklin Balotti)
/s/ Robert D. Burris Director
______________________________________
(Robert D. Burris)
/s/ George F. MacCormack Director
______________________________________
(George F. MacCormack)
/s/ Bernard J. Morgan Director
______________________________________
(Bernard J. Morgan)
IV-9
Exhibit Index
Exhibit
Number Description
- ----------- ----------------------------------------------------------
3-G Conectiv's By-Laws as amended October 26, 1999
10-C Conectiv Change-in-Control Severance Plan For Certain Executive Officers
10-D Conectiv Change-in-Control Severance Plan For Certain Select Employees
10-E Form of Change-in-Control Severance Agreement between Conectiv and certain executives
12 Ratio of Earnings to Fixed Charges
21 Subsidiaries of the registrant
23 Consent of Public Accountants
27 Financial Data Schedule
99 2000 Conectiv Pro Forma Financial Statements-Generation Asset Sale and Transfer