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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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, 2001
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or
[_] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the Transition Period From ____________ to ____________
Commission File Number
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1-10290
DQE, Inc.
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(Exact name of registrant as specified in its charter)
Pennsylvania 25-1598483
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(State or other jurisdiction of (I.R.S. Employer Identification No.)
incorporation or organization)
411 Seventh Avenue
Pittsburgh, Pennsylvania 15219
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(Address of principal executive offices)(Zip Code)
Registrant's telephone number, including area code: (412) 393-6000
Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
the preceding 12 months and (2) has been subject to such filing requirements for
the past 90 days. Yes X No____
---
Aggregate market value of DQE Common Stock held by non-affiliates as of March
11, 2002 was $1,223,172,777. There were 56,209,926 shares of DQE Common Stock
outstanding as of March 11, 2002.
[_] 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.
Securities registered pursuant to Section 12(b) of the Act:
Name of each exchange
Registrant Title of each class on which registered
------------ --------------------- -----------------------
DQE Common Stock (no par value) New York Stock Exchange
Philadelphia Stock Exchange
Chicago Stock Exchange
8 3/8% Public Income Notes due 2039 New York Stock Exchange
(Issued by DQE Capital Corporation)
Guaranties Of DQE Capital Corporation's New York Stock Exchange
Public Income Notes
Securities registered pursuant to Section 12(g) of the Act:
Registrant Title of each class
---------- --------------------
DQE Preferred Stock, Series A (Convertible)
DOCUMENTS INCORPORATED BY REFERENCE
Part of Form 10-K
Into Which Document
Description Is Incorporated
----------- -----------------------
Proxy Statement for DQE Annual Part III
Meeting of Shareholders to be
held on June 26, 2002
TABLE OF CONTENTS
Page
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GLOSSARY
PART I
ITEM 1. BUSINESS
Corporate Structure 1
Employees 2
Property, Plant and Equipment 2
Environmental Matters 3
Other 3
Executive Officers of the Registrant 5
ITEM 2. PROPERTIES 6
ITEM 3. LEGAL PROCEEDINGS 6
ITEM 4. SUBMISSION OF MATTERS TO A
VOTE OF SECURITY HOLDERS 6
PART II
ITEM 5. MARKET FOR REGISTRANT'S
COMMON EQUITY AND RELATED
SHAREHOLDER MATTERS 7
ITEM 6. SELECTED FINANCIAL DATA 7
ITEM 7. MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS 7
Results of Operations 7
Liquidity and Capital Resources 16
Rate Matters 19
ITEM 7A. QUANTITATIVE AND QUALITATIVE
DISCLOSURES ABOUT MARKET RISK 20
ITEM 8. CONSOLIDATED FINANCIAL STATEMENTS
AND SUPPLEMENTARY DATA;
INDEPENDENT AUDITORS' REPORT 21
ITEM 9. CHANGES IN AND DISAGREEMENTS
WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE 50
PART III
ITEM 10. DIRECTORS AND EXECUTIVE
OFFICERS OF THE REGISTRANT 50
ITEM 11. EXECUTIVE COMPENSATION 50
ITEM 12. SECURITY OWNERSHIP OF
CERTAIN BENEFICIAL OWNERS
AND MANAGEMENT 50
ITEM 13. CERTAIN RELATIONSHIPS AND
RELATED TRANSACTIONS 50
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT
SCHEDULES AND REPORTS ON
FORM 8-K 50
SCHEDULE II
SIGNATURES
GLOSSARY OF TERMS
With Pennsylvania at the forefront of the national trend toward electric utility
industry restructuring, a number of unique terms have developed and are used in
this report. Certain of these restructuring-specific terms are defined below.
COMPETITIVE TRANSITION CHARGE (CTC) -- During the electric utility restructuring
from the traditional Pennsylvania regulatory framework to customer choice,
electric utilities have the opportunity to recover transition costs from
customers through this usage-based charge.
CUSTOMER CHOICE -- The Pennsylvania Electricity Generation Customer Choice and
Competition Act (see "Rate Matters") gives consumers the right to contract for
electricity at market prices from PUC-approved electric generation suppliers.
FEDERAL ENERGY REGULATORY COMMISSION (FERC) -- The FERC is an independent five-
member commission within the United States Department of Energy. Among its many
responsibilities, the FERC sets rates and charges for the wholesale
transportation and sale of electricity.
PENNSYLVANIA PUBLIC UTILITY COMMISSION (PUC) -- The governmental body that
regulates all utilities (electric, gas, telephone, water, etc.) that do business
in Pennsylvania.
PROVIDER OF LAST RESORT -- Under Pennsylvania's Customer Choice Act, the local
distribution utility is required to provide electricity for customers who do not
choose an alternative generation supplier, or whose supplier fails to deliver.
(See "Rate Matters.")
REGIONAL TRANSMISSION ORGANIZATION (RTO) -- Organization formed by transmission-
owning utilities to put transmission facilities within a region under common
control.
REGULATORY ASSETS -- Pennsylvania ratemaking practices grant regulated utilities
exclusive geographic franchises in exchange for the obligation to serve all
customers. Under this system, certain prudently incurred costs are approved by
the PUC for deferral and future recovery, with a return from customers. These
deferred costs are capitalized as regulatory assets by the regulated utility.
TRANSITION COSTS -- Transition costs are the net present value of a utility's
known or measurable costs related to electric generation that are recoverable
through the CTC.
TRANSMISSION AND DISTRIBUTION -- Transmission is the flow of electricity from
generating stations over high voltage lines to substations where voltage is
reduced. Distribution is the flow of electricity over lower voltage facilities
to the ultimate customer (businesses and homes).
PART I
ITEM 1. BUSINESS.
CORPORATE STRUCTURE
Part I of this Annual Report on Form 10-K should be read in conjunction with
our audited consolidated financial statements, which are set forth in Part II,
Item 8 of this Report.
DQE, Inc. delivers essential products and related services, including
electricity, water and communications, to more than one million customers
throughout the United States. Our subsidiaries are Duquesne Light Company;
AquaSource, Inc.; DQE Energy Services, LLC; DQE Financial Corp.; DQE
Enterprises, Inc.; DQE Communications, Inc.; ProAm, Inc.; Cherrington Insurance,
Ltd.; and DQE Capital Corporation.
Duquesne Light, our largest operating subsidiary, is an electric utility
engaged in the transmission and distribution of electric energy.
AquaSource is a water resource management company that acquires, develops and
manages water and wastewater systems and complementary businesses.
DQE Energy Services is an energy facilities management company that provides
energy outsourcing solutions including development, operation and maintenance of
energy and alternative fuel facilities.
DQE Financial owns and operates landfill gas collection and processing
systems, and is an investment and portfolio management organization focused on
structured finance and alternative energy investments.
DQE Enterprises manages electronic commerce, energy services and technologies,
and communications investment portfolios.
Our other business lines include the following: propane distribution,
communications systems, and financing and insurance services for DQE and various
affiliates.
See Note R to our consolidated financial statements for information on our
business segments.
Back-to-Basics Strategy
In the second half of 2001, following the completion of our strategic review
process, we announced our new management team and a change in our strategic
direction. Our Back-to-Basics strategy features a more concentrated focus on
core electric utility operations and complementary businesses, such as energy
services. We currently are exploring opportunities to sell, in an orderly
manner, certain non-complementary assets. In addition, cost reductions as a
result of restructuring are expected to enhance profitability at DQE and
Duquesne Light. While the magnitude of the impairment and restructuring charges
we reported in 2001 is significant ($205.6 million, after tax), we believe we
are now better positioned to implement our Back-to-Basics strategy in 2002 and
beyond. Our plan is to grow earnings more steadily, with less volatility, over
the next few years. The cornerstone of this strategy will be a focus on seeking
growth through a disciplined investment and management approach. All new
investment opportunities will be expected to have a strong and clear
relationship to our core electric business, as well as the ability to create
sustained value.
Service Areas
Duquesne Light's electric utility operations provide service to approximately
586,000 direct customers in southwestern Pennsylvania (including in the City of
Pittsburgh), a territory of approximately 800 square miles.
AquaSource's water utility operations currently provide service to more than
520,000 water and wastewater customer connections in 18 states.
ProAm, our propane delivery business, provides service to over 70,000
customers in seven states.
Our other business lines have operations and investments in several states and
Canada.
Regulation
DQE and Duquesne Light are subject to the accounting and reporting
requirements of the Securities and Exchange Commission (SEC). Duquesne Light's
electric delivery business is also subject to regulation by the Pennsylvania
Public Utility Commission (PUC) and the Federal Energy Regulatory Commission
(FERC) with respect to rates for delivery of electric power, accounting and
other matters. Additionally, AquaSource's water utility operations are subject
to regulation by various authorities within the states where they operate as to
rates, accounting and other matters.
Business Segments
For the purposes of complying with Statement of Financial Accounting Standards
(SFAS) No. 131, "Disclosures about Segments of an Enterprise and Related
Information," we are required to disclose information about our business
segments separately. This information is set forth in Note R to our consolidated
financial statements.
Forward-looking Statements
We use forward-looking statements in this report. Statements that are not
historical facts are forward-looking statements, and are based on beliefs and
assumptions of our management, and on information
1
currently available to management. Forward-looking statements include statements
preceded by, followed by or using such words as "believe," "expect,"
"anticipate," "plan," "estimate" or similar expressions. Such statements speak
only as of the date they are made, and we undertake no obligation to update
publicly any of them in light of new information or future events. Actual
results may materially differ from those implied by forward-looking statements
due to known and unknown risks and uncertainties, some of which are discussed
below.
. DQE cash flow, earnings, earnings growth and dividends will depend on the
performance of our subsidiaries, on the effectiveness of the divestiture
of non-core businesses, and board policy.
. Demand for electric, water and telecommunications utility services and
landfill gas, the availability of appropriate investment opportunities in
those industries, changing market conditions and weather conditions could
affect earnings levels at DQE and each subsidiary.
. The number of customers who choose to receive electric generation through
the provider of last resort arrangement with Orion will affect Duquesne
Light's earnings, as will the life of the arrangement.
. Customer energy demand, fuel costs and plant operations will affect DQE
Energy Services' earnings.
. The outcome of the shareholder litigation initiated against both DQE and
AquaSource may affect our performance.
. Stock market volatility and business conditions with respect to energy
technology and electronic commerce may affect our ability to monetize our
non-core energy technology and electronic commerce portfolio.
. Market conditions and demand for services affect our ability to monetize
our non-core and financial investments, and unregulated businesses.
. The tragic events of September 11, 2001 have created broad uncertainty in
the global economy, and we continue to assess the impact on our
businesses, including but not limited to DQE Financial.
. Overall performance by DQE and our affiliates could be affected by
economic, competitive, regulatory, governmental (including tax) and
technological factors affecting operations, markets, products, services
and prices, as well as the factors discussed in our SEC filings made to
date.
EMPLOYEES
At December 31, 2001, DQE and its subsidiaries had 2,538 employees. Duquesne
Light is party to a labor contract with the International Brotherhood of
Electrical Workers, which represents the majority of Duquesne Light's 1,302
employees. Duquesne Light is engaged in negotiations to extend the contract,
which currently expires in September 2002.
PROPERTY, PLANT AND EQUIPMENT
Investment in PP&E and Accumulated Depreciation
Our total investment in property, plant and equipment (PP&E) and the related
accumulated depreciation balances for major classes of property at December 31,
2001 and 2000 are as follows:
PP&E and Related Accumulated Depreciation at December 31,
- --------------------------------------------------------------------------------
(Millions of Dollars)
2001
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Accumulated Net
Investment Depreciation Investment
- ----------------------------------------------------------------------------
Electric delivery $ 1,926.6 $ 616.5 $ 1,310.1
Water distribution 312.9 99.6 213.3
Propane distribution 44.2 3.8 40.4
Other 164.3 39.8 124.5
- ----------------------------------------------------------------------------
Total $ 2,448.0 $ 759.7 $ 1,688.3
============================================================================
(Millions of Dollars)
2000
-------------------------------------------------
Accumulated Net
Investment Depreciation Investment
- ----------------------------------------------------------------------------
Electric delivery $ 1,910.5 $ 612.5 $ 1,298.0
Water distribution 241.4 45.5 195.9
Propane distribution 41.9 2.1 39.8
Other 202.5 42.3 160.2
- ----------------------------------------------------------------------------
Total $ 2,396.3 $ 702.4 $ 1,693.9
============================================================================
Electric delivery PP&E includes: (1) high voltage transmission wires used in
delivering electricity from generating stations to substations; (2) substations
and transformers; (3) lower voltage distribution wires used in delivering
electricity to customers; (4) related poles and equipment; and (5) internal
telecommunication equipment, vehicles and office equipment. Water distribution
PP&E includes water systems and water treatment facilities. The propane
distribution PP&E includes storage tanks and delivery vehicles. The other PP&E
is comprised of various buildings and land, alternative fuel facilities,
landfill gas recovery equipment and property related to our other business
lines.
2
ENVIRONMENTAL MATTERS
Various federal and state authorities regulate DQE and our subsidiaries with
respect to air and water quality and other environmental matters. FirstEnergy
Corporation assumed environmental compliance obligations with respect to the
generation plants it acquired in the December 1999 power station exchange. Orion
Power MidWest, L.P. assumed the environmental obligations related to all of the
plants it acquired in the April 2000 generation asset sale.
In 1992, the Pennsylvania Department of Environmental Protection (DEP) issued
Residual Waste Management Regulations governing the generation and management of
non-hazardous residual waste, such as coal ash. Following the generation asset
divestiture, Duquesne Light retained certain facilities which remain subject to
these regulations. We have assessed our residual waste management sites, and the
DEP has approved our compliance strategies. We incurred costs of $1.1 million in
2001 to comply with these DEP regulations. We expect the costs of compliance to
be approximately $1.4 million over the next two years with respect to sites we
will continue to own. These costs are being recovered in the CTC, and the
corresponding liability has been recorded for current and future obligations.
Duquesne Light owns, but does not operate, the Warwick Mine, including
approximately 1,200 acres of unmined coal lands and mining rights, located along
the Monongahela River in Greene County, Pennsylvania. This property had been
used in the electricity supply business segment. Duquesne Light's current
estimated liability for closing the Warwick Mine, including final site
reclamation, mine water treatment and certain labor liabilities, is
approximately $35 million. Duquesne Light has recorded a liability for this
amount on the consolidated balance sheet.
AquaSource's water and water-related operations are subject to the federal
Safe Drinking Water Act, which provides for uniform minimum national water
quality standards, as well as governmental authority to specify treatment
processes to be used for drinking water. AquaSource's operations are also
subject to the federal Clean Water Act, which regulates the discharge of
pollutants into waterways. In connection with its acquisition strategy,
AquaSource is aware of various compliance issues at its water and wastewater
facilities, and is communicating and working closely with appropriate regulators
to correct those issues in a timely manner. We do not believe that any of these
compliance issues will have a material effect on DQE's financial position,
results of operations or cash flows.
AquaSource is a party to consent agreements regarding environmental compliance
in three states. In Indiana, AquaSource has entered parallel agreements with the
Indiana Department of Environmental Management and the Indiana Utility
Regulatory Commission to establish a schedule for completing upgrades and
resolving certain historical compliance issues at two wastewater facilities.
AquaSource agreed to make approximately $28 million of capital improvements,
$11.4 million of which have been completed. The agreed-upon improvements are
proceeding on schedule. Neither agreement imposes any compliance-related
penalties or sanctions. AquaSource entered into a consent order with the Florida
Department of Environmental Protection regarding historical compliance issues.
AquaSource planned certain capital improvements in connection with its
acquisition of five wastewater facilities, the completion of which will resolve
the compliance issues. AquaSource and the Texas Natural Resource Conservation
Commission have entered into a consent agreement under which AquaSource will
correct compliance issues at approximately 160 water and wastewater systems over
a four-year period. In lieu of any fines, penalties or other sanctions,
AquaSource agreed to make approximately $30 million in capital improvements to
upgrade these systems, $12.1 million of which have already been completed.
AquaSource is capitalizing all of these expenditures, and will seek recovery of
the charges through future rates, if appropriate.
We are involved in various other environmental matters. We believe that such
matters, in total, will not have a materially adverse effect on our financial
position, results of operations or cash flows.
OTHER
Recent Accounting Pronouncements
In June 2001 the Financial Accounting Standards Board (FASB) issued three new
accounting standards, SFAS No. 141, "Business Combinations," SFAS No. 142,
"Goodwill and Other Intangibles," and SFAS No. 143, "Accounting for Asset
Retirement Obligation."
SFAS No. 141 eliminates the pooling-of-interests method of accounting for
business combinations, with limited exceptions for combinations initiated prior
to July 1, 2001. We do not believe that the adoption of SFAS No. 141 will have a
significant impact on our financial statements.
SFAS No. 142, which became effective January 1, 2002, discontinues the
requirement for amortization of goodwill and indefinite-lived intangible assets,
and instead requires an annual review for the impairment of those assets.
Impairment is to be examined more frequently if certain indicators appear.
Intangible assets
3
with a determinable life will continue to be amortized. As of December 31,
2001, we have goodwill and other intangible assets, net of accumulated
amortization, of approximately $136.6 million and $0.7 million, respectively,
which will be subject to the transitional assessment provisions of SFAS No. 142.
SFAS No. 143 addresses financial accounting and reporting for obligations
associated with the retirement of tangible long-lived assets and the associated
asset retirement costs. Specifically, this standard requires entities to record
the fair value of a liability for an asset retirement obligation in the period
in which it is incurred. The entity is required to capitalize the cost by
increasing the carrying amount of the related long-lived asset. The capitalized
cost is then depreciated over the useful life of the related asset. Upon
settlement of the liability, an entity either settles the obligation for its
recorded amount or incurs a gain or loss. The standard is effective for fiscal
years beginning after June 15, 2002. We are currently evaluating, but have yet
to determine, the impact that the adoption of SFAS No. 143 will have on our
financial statements.
In August 2001 the FASB issued SFAS No. 144, "Accounting for the Impairment or
Disposal of Long-Lived Assets," which replaces SFAS 121, "Accounting for the
Impairment of Long-Lived Assets and Long-Lived Assets to be Disposed Of." The
statement requires that all long-lived assets to be held and used continue to be
evaluated for impairment similar to SFAS No. 121. The statement also requires
that all long-lived assets to be sold be measured at the lower of carrying
amount or fair value less cost to sell, whether reported in continuing
operations or in discontinued operations. Therefore, discontinued operations
will no longer be measured on a net realizable value basis and will not include
amounts for future operating losses. The statement also broadens the reporting
requirements for discontinued operations to include disposal transactions of all
components of an entity (rather than segments of a business). Components of an
entity include operations and cash flows that can be clearly distinguished from
the rest of the entity that will be eliminated from the ongoing operations of
the entity in a disposal transaction. The statement is effective for fiscal
years beginning after December 15, 2001. We are currently evaluating, but have
yet to determine, the impact that the adoption of SFAS No. 144 will have on our
financial statements.
Market Risk
Market risk represents the risk of financial loss that may impact our
consolidated financial position, results of operations, or cash flows due to
adverse changes in market prices and rates.
We manage our interest rate risk by balancing our exposure between fixed and
variable rates, while attempting to minimize our interest costs. Currently, our
variable interest rate debt is approximately $418 million or 35 percent of long-
term debt. This variable rate debt is low-cost, tax-exempt debt. We also manage
our interest rate risk by retiring and issuing debt from time to time and by
maintaining a balance of short-term, medium-term and long-term debt. A 10
percent increase in interest rates would have affected our variable rate debt
obligations by increasing interest expense by approximately $1.1 million, $3.1
million and $1.6 million for the years ended December 31, 2001, 2000 and 1999. A
10 percent reduction in interest rates would have increased the market value of
our fixed rate debt by approximately $40.6 million and $40.3 million as of
December 31, 2001 and 2000. Such changes would not have a significant near-term
effect on our future earnings or cash flows.
Pending Litigation
Information regarding pending litigation is set forth in Item 3, "Legal
Proceedings."
4
EXECUTIVE OFFICERS OF THE REGISTRANT
Set forth below are the names, ages as of March 10, 2002, and positions during
the past five years of our executive officers.
Name Age Office
Morgan K. O'Brien 42 President and Chief Executive Officer since September 2001. Chief Operating
Officer from August 2000 to September 2001. Executive Vice President -
Corporate Development from January 2000 to August 2000. Vice President -
Corporate Development from July 1999 to January 2000. Treasurer from November
1998 to July 1999. Vice President from October 1997 to July 1999. Controller
from October 1995 to July 1999.
Frank A. Hoffmann 50 Executive Vice President since October 2001. President and Treasurer of
AquaSource since July 2000. Vice President -Operations of DQE Systems from
January 2000 to July 2000. Vice President of DQE Systems from May 1999 to
January 2000. General Manager, Marketing and Sales of Duquesne Light from
1995 to May 1999.
Victor A. Roque 55 Executive Vice President since November 1998. General Counsel from November 1994
to October 2001. Secretary from May 2000 to October 2001. Vice President from
April 1995 to November 1998. President of Duquesne Light since October 2001.
Alexis Tsaggaris 53 Executive Vice President since October 2001. President of DQE Energy Services
from August 1995 to October 2001.
Frosina C. Cordisco 50 Vice President since March 2000 and Treasurer since July 1999. Assistant Treasurer
from November 1998 to June 1999. Duquesne Light Company - Treasurer since November
1998; Manager of Electronic Commerce from April 1996 to April 1998. Held financial
positions at various subsidiaries between 1996 and 1999.
William J. DeLeo 51 Vice President - Corporate Compliance and Corporate Secretary since October
2001. Vice President and Chief Administrative Officer from November 1998 to
October 2001. Vice President - Corporate Services at Duquesne Light from November 1998 to
April 2000. Vice President - Marketing and Corporate Performance at Duquesne
Light from April 1995 to November 1998.
David R. High 47 Vice President and General Counsel since October 2001. Deputy General Counsel
and Compliance Officer from June 2000 to October 2001. Associate General
Counsel from September 1999 to June 2000. Associate General Counsel of Duquesne
Light from January 1996 to September 1999.
Stevan R. Schott 39 Vice President and Controller since October 2001. Vice President of Duquesne Light
from August 1999 to October 2001. Controller of DQE Financial from September 1998
to August. Senior Manager, Public Utilities Specialist at Deloitte & Touche LLP
from September 1993 to September 1998.
James E. Wilson 36 Vice President - Corporate Development since October 2001. Vice President and
Controller from March 2000 to October 2001. Controller from July 1999 to March
2000. Assistant Controller from 1996 to July 1999.
5
ITEM 2. PROPERTIES.
Our principal properties consist of Duquesne Light's electric transmission and
distribution facilities and supplemental properties and appurtenances, located
substantially in Allegheny and Beaver counties in southwestern Pennsylvania.
Substantially all of the electric utility properties are subject to a mortgage
lien of an Indenture of Mortgage and Deed of Trust dated as of April 1, 1992.
In April 2000, Duquesne Light sold its generation assets. Duquesne Light owns
9 transmission substations and 561 distribution substations (367 of which are
located on customer-owned land and are used to service only that customer).
Duquesne Light has 592 circuit-miles of transmission lines, comprised of
345,000, 138,000 and 69,000 volt lines. Street lighting and distribution
circuits of 23,000 volts and less include approximately 16,420 circuit-miles of
lines and cable. These properties are used in the electricity delivery business
segment.
AquaSource owns and operates over 450 investor-owned water and wastewater
systems and performs contract services for over 550 additional systems. These
systems are comprised of distribution and collection lines, pump stations,
treatment plants, storage tanks, reservoirs and related facilities. Properties
are adequately maintained and units of property are replaced as and when
necessary. AquaSource owns a substantial acreage of land, the greater part of
which is located in watershed areas and used for the discharge of treated
effluent, with the balance being principally sites of pumping and treatment
plants, storage reservoirs, tanks and standpipes. These properties are used in
our water distribution business segment.
ITEM 3. LEGAL PROCEEDINGS.
In October and November 2001, class action lawsuits were filed by purported
shareholders of DQE against DQE and David Marshall, DQE's former Chairman, in
the U.S. District Court for the Western District of Pennsylvania. The plaintiffs
allege that the defendants violated Sections 10(b) and 20(a) of the Securities
Exchange Act of 1934, and Rule 10b-5 promulgated thereunder, by issuing a series
of materially false and misleading statements between December 6, 2000 and April
30, 2001 concerning investments made by DQE Enterprises, Inc. and their impact
on DQE's current and future financial results. The plaintiffs claim that, as a
result of these statements, the price of DQE securities was artificially
inflated.
In February 2001, 39 former and current employees of AquaSource, all minority
investors in AquaSource, commenced an action against DQE, AquaSource and others
in the District Court of Harris County, Texas. The complaint alleges that the
defendants fraudulently induced the plaintiffs to agree to sell their AquaSource
stock back to AquaSource, and that defendants took actions intended to decrease
the value of the stock. Plaintiffs seek, among other things, an award of actual
damages not to exceed $100 million and exemplary damages not to exceed $400
million.
In the first quarter of 2001, DQE and AquaSource filed counterclaims alleging
that 10 plaintiffs who held key AquaSource management positions engaged in
deceptive practices designed to obtain funding for acquisitions and to make
those acquisitions appear to meet certain return on investment requirements, and
that all plaintiffs were unjustly enriched by such wrongful actions. DQE,
AquaSource and AquaSource Utility, Inc. also filed a counterclaim against two
plaintiffs alleging claims for breach of contract, breach of warranty,
indemnification, fraud, and unjust enrichment in connection with the acquisition
of various water and wastewater companies from such plaintiffs.
Although we cannot predict the ultimate outcome of these cases or estimate the
range of any potential loss that may be incurred in the litigation, we believe
that the lawsuits are entirely without merit, strenuously deny all of the
plaintiffs' allegations of wrongdoing and believe we have meritorious defenses
to the plaintiffs' claims. We intend to vigorously defend these lawsuits.
We are involved in various other legal proceedings and environmental matters.
We believe that the resolution of such proceedings and matters, in total, will
not have a materially adverse effect on our financial position, results of
operations or cash flows.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
On December 20, 2001, we held our Annual Meeting of Stockholders. We solicited
proxies for the Annual Meeting pursuant to Regulation 14 under the Securities
and Exchange Act of 1934, as amended. There was no solicitation in opposition to
management's nominees for directors as listed in the proxy statement dated
October 22, 2001, and all nominees were elected. Two proposals were submitted to
stockholders for a vote at the Annual Meeting.
Proposal 1 was the election of two directors to the board of directors, to
serve until the 2004 Annual Meeting, and until their respective successors have
been chosen and qualified. The vote on this proposal was as follows:
6
Type of Stock For Withhold
------------- --- --------
Doreen E. Boyce Common 43,035,184 1,446,092
Preferred 187,194 0
Morgan K. O'Brien Common 43,627,428 1,446,092
Preferred 187,194 0
The following Directors' terms continue after the Annual Meeting of
Stockholders:
until 2002 - Daniel Berg, Sigo Falk and Eric W. Springer;
until 2003 - Robert P. Bozzone and Steven S. Rogers.
On February 28, 2002, the Board filled three vacancies by electing Charles C.
Cohen, David M. Kelly and John D. Turner. All three will be nominated for
reelection at the 2002 Annual Meeting of Stockholders.
Proposal 2 was the ratification of the appointment, by the board of directors,
of Deloitte & Touche LLP as independent auditors to audit our books for the year
ending December 31, 2001. The vote on this proposal was as follows:
For Against Abstain
--- ------- -------
Common Stock 43,459,206 829,928 488,264
Preferred Stock 187,194 0 0
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED SHAREHOLDER MATTERS.
Information relating to the market for DQE common stock and other matters
related to our holders is set forth in Note P and in Note S hereto, and
incorporated here by reference.
DQE declared quarterly dividends on our common stock totaling $1.68 per share
in 2001. (See "Dividends" discussion.) At February 28, 2002, there were
approximately 56,000 holders of record of our common stock. DQE common stock is
listed and traded on the New York, Philadelphia and Chicago Stock Exchanges.
ITEM 6. SELECTED FINANCIAL DATA.
Selected financial data for each year of the six-year period ended December
31, 2001, are set forth on page 49 and incorporated here by reference.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
RESULTS OF OPERATIONS
Overall Performance
2001 Compared to 2000
Our basic loss for common shareholders was $153.9 million or $2.75 per share
in 2001, compared to basic earnings available for common shareholders of $154.4
million or $2.44 per share in 2000. Basic earnings available for common
shareholders decreased by $308.3 million, due principally to the impact of a
number of one-time charges recorded in 2001. Impairment charges totaling $185.7
million after tax were recorded in 2001 relating to the impairment of
investments and long-lived assets. In addition, restructuring charges of $19.9
million after tax were recorded in 2001 as discussed below.
AquaSource (the water distribution business segment) recorded a second quarter
$99.7 million after tax impairment charge following a determination that
AquaSource's potential future performance would result in lower returns than
originally anticipated. The impairment charge primarily related to contract
operations and construction. The assets determined to be impaired consisted of
$79.4 million of goodwill, $26.4 million of property, plant and equipment, and
$3.4 million of other assets.
DQE Financial (the Financial business segment) recorded a fourth quarter $43.7
million after tax impairment charge relating to four landfill gas sites. DQE
Financial has a twenty-year lease for the gas rights to New York City's Fresh
Kills landfill, where debris from the World Trade Center is being transported.
The excess weight resting on top of the landfill has caused damage to the gas
collection system, as well as reduced available gas flows. Additional security
at the site has caused construction delays. Management has determined that the
Fresh Kills investment has been impaired. DQE Financial also recognized a charge
due to asset abandonments or impairment at the three other landfill gas sites.
The remaining impairment charges recorded in 2001 were $42.3 million after tax
relating primarily to energy technology investments. During 2001, we formalized
plans to monetize DQE Enterprises (the Enterprises business segment) as
opportunities present themselves. This business is not consistent with our focus
on our core regulated utility businesses, and opportunities related to these
investments have not developed as expected due to market conditions. During
2001, DQE Enterprises sold two investments and recognized an
7
impairment charge to write off all or parts of eleven other investments,
resulting in a $36.1 million after tax impairment charge.
During the fourth quarter of 2001, as part of our Back-to-Basics strategy, we
initiated a restructuring plan to improve operational effectiveness and
efficiency, and to reduce operational expenses on a company-wide basis. Through
the restructuring plan, we have reorganized to focus on our core regulated
utility businesses and opportunities related to those investments. In the fourth
quarter of 2001, we recorded an after tax restructuring charge of $19.9 million,
consisting of $13.2 million at DQE (the "all other" category), and $6.7 million
at Duquesne Light (the electricity delivery business segment). The restructuring
charge included costs related to (1) the consolidation and reduction of certain
administrative and back-office functions through an involuntary termination
plan, (2) the abandonment of certain leased office facilities to relocate
employees to one centralized location, and (3) other lease costs related to
abandoned office facilities.
Another factor affecting 2001 results was the $33.3 million decline in
earnings relating to the CTC business segment (see discussion below). In
addition, gains from investment dispositions totaled $16.6 million in 2001,
compared to $69.5 million in 2000. This decline is principally due to the
recognition in 2000 of a gain on the sale of DQE Energy Services' alternative
fuel facilities (Energy Services business segment). In addition, 2000 results
were positively impacted by the $15.5 million cumulative effect of a change in
accounting principle relating to unbilled revenues.
2000 Compared to 1999
Our basic earnings were $154.4 million or $2.44 per share in 2000, compared to
$199.8 million or $2.65 per share in 1999. Basic earnings available for common
shareholders decreased by $45.4 million, or 22.7 percent, due primarily to the
sale of our generation assets. We applied net proceeds from the sale to reduce
the level of our transition costs. As we earned a return on our unrecovered
transition costs, this reduction in the level of transition costs resulted in
decreased earnings.
Other factors affecting 2000 results included a number of transaction-related
gains and charges. In the fourth quarter of 2000, we recorded an $8 million
after-tax charge related to the then-pending sale of our bottled water business.
We also recorded a charge for the shutdown of a coal-bed methane project.
Offsetting these charges were gains from the sale of certain non-strategic
investments and the cumulative effect of a change in accounting principle for
unbilled revenues. Additionally affecting earnings per share, in conjunction
with the generation asset sale, we undertook a strategy to aggressively
repurchase our common stock on the open market. Our average shares of
outstanding common stock declined by approximately 12 million, or 16 percent.
During 2000, we repurchased approximately 16 million shares for approximately
$650 million.
Critical Accounting Policies and Estimates
The preparation of financial statements in conformity with accounting
principles generally accepted in the United States of America requires us to
make estimates and assumptions with respect to values and conditions that affect
the reported amounts of assets and liabilities, and disclosure of contingent
assets and liabilities, at the date of the financial statements. The reported
amounts of revenues and expenses during the reporting period also may be
affected by the estimates and assumptions we are required to make. We evaluate
these estimates on an ongoing basis, using historical experience, consultation
with experts and other methods we consider reasonable in the particular
circumstances. Nevertheless, actual results may differ significantly from our
estimates.
In preparing our financial statements and related disclosures, we have adopted
the following accounting policies which management believes are particularly
important to the financial statements and that require the use of estimates and
assumptions in the financial preparation process.
Accounting for the Effects of Regulation. Our subsidiaries, Duquesne Light and
AquaSource, prepare their financial statements in accordance with the provisions
of SFAS No. 71, "Accounting for the Effects of Certain Types of Regulation,"
which differs in certain respects from the application of accounting principles
generally accepted in the United States of America by non-regulated businesses.
In general, SFAS No. 71 recognizes that accounting for rate-regulated
enterprises should reflect the economic effects of regulation. As a result, a
regulated utility is required to defer the recognition of costs (a regulatory
asset) if it is probable that, through the rate-making process, there will be a
corresponding increase in future rates. Accordingly, we defer certain costs,
which will be amortized over future periods. To the extent that collection of
such costs is no longer probable as a result of changes in regulation or our
competitive position, the associated regulatory assets are charged to expense.
Unbilled Energy and Water Revenues. We generally record revenues related to
the sale of energy and water when delivery is made to our customers. However,
the determination of such sales to individual customers is based on the reading
of their meters, which we read on a systematic basis throughout the month. At
the end of each month, we estimate the amounts delivered to customers since the
date of the last meter reading and
8
record the corresponding unbilled revenue. We estimate this unbilled revenue
each month based on daily volumes, estimated customer usage by class, delivery
losses and applicable customer rates based on regression analyses reflecting
significant historical trends and experience. Customer accounts receivable as of
December 31, 2001 include unbilled revenues of $44.9 million.
Impairment of Long-Lived Assets and Investments. We evaluate long-lived assets
(including other intangibles and related goodwill) of identifiable business
activities and investments for impairment when events or changes in
circumstances indicate, in management's judgment, that the carrying value of
such assets may not be recoverable. In addition to those long-lived assets and
investments for which impairment charges were recorded (see Note C), others were
reviewed for which no impairment was required. For long-lived assets to be held
and used, these computations used judgments and assumptions inherent in
management's estimate of undiscounted future cash flows to determine
recoverability of the assets. It is possible that a computation under a "held
for sale" situation for certain of these long-lived assets could result in a
significantly different assessment because of market conditions, specific
transaction terms or a buyer's different viewpoint of future cash flows. For
investments, we considered our investee's cash on-hand, fundraising abilities,
customers, contracts and overall ability to continue as a going concern.
Contingent Liabilities. We establish reserves for estimated loss contingencies
when it is management's assessment that a loss is probable and the amount can be
reasonably estimated. Revisions to contingent liabilities are reflected in
income in the period in which different facts or information become known, or
circumstances change, that affect the previous assumptions with respect to the
likelihood or amount of loss. Reserves for contingent liabilities are based upon
management's assumptions and estimates, advice of legal counsel, or other third
parties regarding the probable outcomes of the matter. Should the ultimate
outcome differ from the assumptions and estimates, revisions to the estimated
reserves for contingent liabilities would be recognized. Such contingent
liabilities for DQE include, but are not limited to, restructuring liabilities
(see Note D), income tax matters (see Note I), and other commitments and
contingencies (see Note K).
Dividends
Once all dividends on our Preferred Stock, Series A (Convertible), $100
liquidation preference per share (DQE preferred stock), have been paid,
dividends may be paid on our common stock as permitted by law and as declared by
the board of directors. However, because we own all of Duquesne Light's common
stock, if Duquesne Light cannot pay common dividends, we may not be able to pay
dividends on our common stock or DQE preferred stock. Payments of dividends on
Duquesne Light's common stock may be restricted by Duquesne Light's obligations
to holders of preferred and preference stock pursuant to Duquesne Light's
articles of incorporation and by obligations of a Duquesne Light subsidiary to
holders of its securities (see Note N). No dividends or distributions may be
made on Duquesne Light's common stock if Duquesne Light has not paid dividends
or sinking fund obligations on its preferred or preference stock. Further, the
aggregate amount of Duquesne Light's common stock dividend payments or
distributions may not exceed certain percentages of net income if the ratio of
total common shareholder's equity to total capitalization is less than specified
percentages.
We have continuously paid dividends on common stock since 1953. Our annualized
dividends per share, paid quarterly, were $1.68, $1.68 and $1.60 for the years
2001, 2000 and 1999, respectively. Most recently, in the first quarter of 2002
the board declared a quarterly dividend of $0.42 per share (payable on April 1,
2002 to holders of record on March 11, 2002). The board of directors regularly
evaluates our dividend policy and sets the amount each quarter. The level of
dividends will continue to be influenced by many factors such as, among other
things, our earnings, financial condition and cash flows from subsidiaries, as
well as general economic and competitive conditions. The board also has to
consider the impact of the downgrade in the ratings of certain of our securities
and the effectiveness of the divestiture of non-complementary assets. (See
"Future Capital Requirements and Availability" and "Rate Matters.")
Results Of Operations by Business Segment
We report the results of our business segments, determined by products,
services and regulatory environment as follows: (1) Duquesne Light's
transmission and distribution of electricity (electricity delivery business
segment), (2) Duquesne Light's supply of electricity (electricity supply
business segment), (3) Duquesne Light's collection of transition costs (CTC
business segment), (4) AquaSource's management of water systems (water
distribution business segment), (5) DQE Energy Services' development, operation
and maintenance of energy and alternative fuel facilities (Energy Services
business segment), (6) DQE Financial's collection and processing of landfill gas
and the management of structured finance and alternative
9
energy investments (Financial business segment), and (7) DQE Enterprises'
management of electronic commerce, energy services and technologies, and
communications investment portfolios (Enterprises business segment).
With the completion of our generation asset sale in April 2000, the
electricity supply business segment is now comprised solely of provider of last
resort service. We also report an "all other" category to include our other
subsidiaries below the quantitative threshold for disclosure, and corporate
administrative functions, financing, and insurance services for our various
affiliates.
We have restated prior periods where appropriate to present segment
information consistent with the manner that is currently utilized by management.
Note R shows the financial results of each principal business segment in tabular
form. Following is a discussion of these results.
2001 Compared to 2000
Electricity Delivery Business Segment. The electricity delivery business
segment contributed $37.7 million to net income in 2001, consisting of $44.4
million before a restructuring charge of $6.7 million, as previously discussed.
This is compared to $43.4 million in 2000, which included $7.3 million after tax
related to the cumulative effect of a change in accounting principle for
unbilled revenues. Excluding these one-time charges in both years, net income
from the electricity delivery business segment was $8.3 million higher in 2001,
primarily due to lower operating expenses resulting from the cost reduction
initiatives that were begun in 2000.
Operating revenues for this business segment are primarily derived from the
delivery of electricity. Sales to residential and commercial customers are
primarily influenced by weather conditions. Warmer summer and colder winter
seasons lead to increased customer use of electricity for cooling and heating.
Commercial sales also are affected by regional development. Sales to
residential, commercial and industrial customers are influenced by national and
global economic conditions.
Operating revenues increased by $3.5 million or 1.1 percent compared to 2000.
Residential sales increased 2.1 percent, primarily due to warmer summer weather
in 2001. Commercial sales increased 1.3 percent, due to an increase in the
number of commercial customers, while industrial sales decreased 8.3 percent,
due to decreased consumption by steel manufacturers, including one major
customer who has filed for protection under Chapter 11 of the U.S. Bankruptcy
Code. The following table sets forth kilowatt-hours (KWH) delivered to electric
utility customers.
KWH Delivered
--------------------------------
(In Millions)
--------------------------------
2001 2000 Change
- --------------------------------------------------------------------------
Residential 3,584 3,509 2.1%
Commercial 6,241 6,162 1.3%
Industrial 3,283 3,581 (8.3)%
- --------------------------------------------------------------
KWH Sales 13,108 13,252 (1.1)%
Cumulative effect of a change
in accounting principle -- 483
- --------------------------------------------------------------
Total Sales 13,108 13,735 (4.6)%
==========================================================================
Operating expenses for the electricity delivery business segment are primarily
made up of costs to operate and maintain the transmission and distribution
system; meter reading, billing and collection costs; customer service;
administrative expenses; and non-income taxes, such as gross receipts, property
and payroll taxes. Operating expenses decreased by $19.6 million or 11.7 percent
compared to 2000, due to cost reduction initiatives that were begun in 2000, as
well as a reduction to our employee pension costs. (See Note L.)
Depreciation and amortization expense includes the depreciation of electric
delivery-related plant and equipment. There was an increase of $3.3 million or
5.9 percent compared to 2000 due primarily to net additions to property, plant
and equipment during 2001.
Other income increased $2.4 million or 6.4 percent compared to 2000, primarily
due to increased interest income on a higher cash balance in 2001.
Interest and other charges include interest on long-term debt, other interest
and preferred stock dividends of Duquesne Light. In 2001, there was $8.9 million
or 12.8 percent more interest and other charges allocated to the electricity
business segment compared to 2000. Although Duquesne Light used the generation
asset sale proceeds to retire debt, thus reducing its overall level of interest
expense, all remaining Duquesne Light financing costs after recapitalization are
borne by the electricity delivery business segment.
Electricity Supply Business Segment. In 2001, the electricity supply business
segment reported net income of zero, compared with net income of $0.2 million in
2000. For all of 2001, and for the period from April 29 through December 31,
2000, this segment's financial results reflect our provider of last resort
service arrangement with Orion, which is designed to be income neutral to
Duquesne Light. Included in 2000 was $8.2 million related to the cumulative
effect of a change in accounting principle for unbilled revenues.
10
Operating revenues for this business segment are derived primarily from the
supply of electricity for delivery to retail customers and the supply of
electricity to wholesale customers. Retail energy requirements fluctuate as the
number of customers participating in customer choice changes. Energy
requirements for residential and commercial customers are also influenced by
weather conditions; temperature extremes lead to increased customer use of
electricity for cooling and heating. Commercial energy requirements are also
affected by regional development. Energy requirements for industrial customers
are primarily influenced by national and global economic conditions.
Short-term sales to other utilities are made at market rates. Prior to the
April 2000 generation asset divestiture, fluctuations in such sales were related
to customer energy requirements, the energy market and transmission conditions,
and the availability of generating stations. Following the divestiture,
fluctuations result primarily from excess daily energy deliveries to Duquesne
Light's electricity delivery system.
Operating revenues increased $4.9 million or 1.2 percent compared to 2000. The
increase is due to an increase in the average generation rate charged to
customers, as well as an increase in the percentage of customers who receive
electricity through our provider of last resort service arrangement.
The following table sets forth KWH supplied for customers who had not chosen
an alternative generation supplier.
- ------------------------------------------------------------------------
KWH Supplied
------------------------------------
(In Millions)
------------------------------------
2001 2000 Change
- ------------------------------------------------------------------------
Residential 2,348 2,422 (3.1)%
Commercial 5,367 4,436 21.0 %
Industrial 3,079 3,332 (7.6)%
- -------------------------------------------------------------
KWH Sales 10,794 10,190 5.9 %
Cumulative effect of a change
in accounting principle -- 341
Sales to Other Utilities 363 963 (62.3)%
- -------------------------------------------------------------
Total Sales 11,157 11,494 (2.9)%
========================================================================
Operating expenses for the electricity supply business segment in 2001 consist
of energy costs (i.e., to obtain energy from Orion for our provider of last
resort service) and gross receipts tax, which both fluctuate in direct relation
to operating revenues. In 2000, such operating expenses included energy costs;
costs to operate and maintain the power stations; administrative expenses; and
non-income taxes, such as gross receipts, property and payroll taxes.
Fluctuations in energy costs in 2001 resulted from total KWH supplied through
our provider of last resort arrangement. Fluctuations in energy costs in 2000
generally resulted from changes in the total KWH supplied, the mix between coal
generated power and purchased power, the cost of fuel, and generating station
availability.
Operating expenses increased $10.4 million or 2.5 percent from 2000 as a
result of an increase in the KWH supplied. This increase resulted from higher
purchased power costs (related to our provider of last resort arrangement)
following the generation asset sale, as opposed to the cost of power generated
by our previously owned power stations. The cost under the arrangement is an
average of $0.04 per KWH across all rate classes. (See "Provider of Last
Resort.")
Depreciation and amortization expense in 2000 included the depreciation of the
power stations' plant and equipment through the generation asset sale.
Other income decreased $3.0 million from 2000, because no other income has
been allocated to this business segment since the generation asset sale.
Interest and other charges include interest on long-term debt, other interest,
and preferred stock dividends of Duquesne Light. In 2001, no interest expense
was allocated to this business segment; in 2000, there was $21.2 million of
allocated interest expense. All remaining financing costs following the
generation asset sale are borne by the electricity delivery business segment.
CTC Business Segment. In its final restructuring order issued in the second
quarter of 1998, the PUC determined that Duquesne Light should recover most of
the above-market costs of its generation assets, including plant and regulatory
assets, through the collection of the competitive transition charge (CTC) from
electric utility customers. On January 18, 2001, the PUC issued an order
approving our final accounting for the proceeds of our April 2000 generation
asset sale, including the net recovery of $276 million of sale-related
transaction costs.
For the CTC business segment, operating revenues are derived by billing
electric delivery customers for generation-related transition costs. Duquesne
Light is allowed to earn an 11 percent pre-tax return on the net of tax CTC
balance. As revenues are billed to customers on a monthly basis, we amortize the
CTC balance. The resulting decrease in the CTC balance causes a decline in the
return earned by Duquesne Light.
In 2001, the CTC business segment reported net income of $12.3 million
compared to $45.6 million in 2000, a decrease of $33.3 million or 73.0 percent.
Operating revenues decreased $30.7 million or 9.2 percent, due to a decrease
in the average CTC rate charged to customers from 2000 to 2001.
11
Operating expense consists solely of gross receipts tax, which fluctuates in
direct relation to operating revenues.
Depreciation and amortization expense consists of the amortization of
transition costs. There was an increase of $21.7 million or 8.7 percent compared
to 2000. As a result of the lower average CTC balance, there was less return
earned in 2001. We now anticipate termination of the CTC collection period by
mid-year 2002 for most major rate classes.
Water Distribution Business Segment. The water distribution business segment
had a $100.4 million net loss in 2001, consisting of a $0.7 million net loss
before a one-time impairment charge of $99.7 million, as previously discussed.
This is compared to a $7.9 million net loss in 2000. Excluding the one-time
charge, this was a net increase of $7.2 million or 91.1 percent, primarily due
to lower operating expenses. We sold a water system in December 2000, resulting
in a decrease in operating revenues of $3.0 million and operating expenses of
$1.7 million in 2001 compared to 2000.
Operating revenues for this business segment are derived from the following:
billings related to water and sewer services for utilities, both owned and
contract-operated by AquaSource, and water-related construction and engineering
projects. Customer water use depends on weather conditions.
Operating revenues decreased $3.2 million or 2.9 percent compared to 2000.
This decrease was primarily the result of the water system sale.
Operating expenses for the water distribution segment mainly consist of costs
to operate and maintain the water distribution systems, administrative expenses
and non-income taxes, such as property and payroll taxes. Operating expenses
decreased $28.5 million or 23.5 percent compared to 2000, primarily due to
operating efficiencies, lower administrative costs and the water system sale.
Depreciation and amortization expense includes depreciation of utility
delivery systems and the amortization of goodwill on acquisitions. The $1.1
million, or 6.4 percent decrease, was mainly attributable to the impairment of
goodwill and property, plant and equipment in June 2001.
Other income decreased $7.0 million or 75.3 percent compared to 2000,
primarily due to the gain on the water system sale.
Energy Services Business Segment. In 2001, the Energy Services business
segment reported net income of $6.3 million, compared to net income of $98.2
million in 2000. Net income was $91.9 million higher in 2000, due to the gain on
the sale of DQE Energy Services' alternative fuel facilities.
Operating revenues for this business segment are primarily derived from the
facility management services for industrial, airport and alternative fuel
customers. Operating revenues increased $11.5 million or 58.1 percent compared
to 2000. The increase is due to increased facility management revenues from
three new service contracts.
Operating expenses for the Energy Services business segment consist of the
operating and maintenance costs to manage the facilities. Operating expenses
increased $5.8 million or 26.5 percent from 2000, primarily due to the
additional alternative fuel facility management contracts.
Depreciation and amortization expense decreased $3.2 million or 62.7 percent
in 2001, due to the lack of depreciation on the alternative fuel facilities that
were sold in 2000.
Other income was $154.6 million higher in 2000, due primarily to the gain
recognized on the sale of the alternative fuel facilities in 2000.
Financial Business Segment. The Financial business segment reported a net loss
of $2.6 million in 2001, consisting of $41.1 million of net income prior to
impairment charges of $43.7 million, as previously discussed. This is compared
to net income of $36.8 million in 2000. Excluding the one-time charge in 2001,
net income from the Financial business segment was $4.3 million higher in 2001,
primarily due to increased landfill gas production and higher landfill gas sales
prices.
Operating revenues for this business segment are primarily derived from the
sale of landfill gas. Operating revenues increased $1.9 million or 9.1 percent
compared to 2000. The increase in revenue is due to an increase in landfill gas
production and higher landfill gas sales prices.
Operating expenses for the Financial business segment consist of the various
costs to operate and maintain the landfill gas sites. Operating expenses
increased $2.8 million or 7.0 percent from 2000 due to the increased operating
costs at its landfill gas sites, caused primarily by higher gas production.
Depreciation and amortization expense consists of the depreciation of landfill
gas equipment and gas rights. There was an increase of $0.4 million or 12.1
percent compared to 2000.
Other income consists of income from the leveraged lease and affordable
housing investments, tax credits generated from the landfill and natural gas
investments, and gains recognized on the sales of investments. Other income
increased $0.7 million or 1.0 percent as compared to 2000, due in part to gains
recognized on the sale of affordable housing investments in 2001.
Interest and other charges decreased $3.9 million or 39.4 percent as compared
to 2000 due to the retirement of $85.0 million of medium term notes in 2001, as
well as a full year's effect of debt retirements that occurred in 2000.
12
Enterprises Segment. The Enterprises segment had a $25.3 million net loss in
2001, consisting of $10.8 million of net income before a one-time impairment
charge of $36.1 million, as previously discussed. This is compared to $5.7
million of net income in 2000. Absent the one-time charges, net income from the
Enterprises segment was $5.1 million or 89.5 percent higher in 2001, primarily
due to the approximately $8.4 million after tax gain on the sale of the
Pittsburgh Airport energy facility in July 2001. This sale resulted in a
decrease in operating revenues of $5.8 million and operating expenses of $0.5
million.
Operating revenues for this segment are derived from energy sales and rent
payments from real estate investments. Operating revenues decreased $7.8 million
or 34.5 percent compared to 2000. This decrease is primarily due to the energy
facility sale.
Operating expenses for the Enterprises segment are primarily made up of costs
to maintain the rental properties and the energy facility, administrative
expenses and non-income taxes, such as property and payroll taxes. Operating
expenses decreased $6.6 million or 33.0 percent compared to 2000. The decrease
was mainly attributable to the energy facility sale.
Depreciation and amortization expense for this segment includes depreciation
of buildings and the energy facility and amortization of intangibles. The $1.0
million decrease resulted primarily from the sale of an energy facility and real
estate in 2000 and 2001.
Other income increased $8.3 million or 88.3 percent compared to 2000,
primarily due to the gain on the energy facility sale.
All Other. The all other category had a $79.3 million net loss in 2001,
consisting of a $59.9 million net loss before impairment and abandonment charges
of $6.2 million and a restructuring charge of $13.2 million, as previously
discussed. This is compared to a $66.3 million net loss in 2000. Absent the one-
time charges, this is an improvement of $6.4 million or 9.7 percent.
Operating revenues decreased $15.6 million or 17.5 percent compared to 2000.
The decrease is primarily comprised of a $14.0 million decrease related to the
sale of our bottled water business in May 2001.
In 2001, operating expenses decreased $30.8 million or 27.6 percent, due
primarily to the sale of our bottled water business in May 2001 and
administrative cost reductions.
Depreciation and amortization expense includes the depreciation of plant and
equipment of our other business lines and amortization of certain investments.
Depreciation and amortization increased $9.8 million in 2001, primarily due to a
change in the estimated useful life of software to be replaced in early 2002.
Interest and other charges include interest on long-term debt, other interest
and preferred stock dividends of our other business lines. Interest expense
increased $7.9 million or 19.7 percent, primarily as a result of increased
borrowing used largely to fund subsidiary cash requirements (excluding Duquesne
Light).
2000 Compared to 1999
Electricity Delivery Business Segment. The electricity delivery business
segment contributed $43.4 million to net income in 2000, compared to $38.8
million in 1999, an increase of $4.6 million or 11.9 percent. Included in 2000
is $7.3 million related to the cumulative effect of a change in accounting
principle for unbilled revenues.
Operating revenues increased by $9.1 million or 3.0 percent compared to 1999,
due to an increase in sales to electric utility customers of 1.7 percent in
2000. Residential sales decreased 0.5 percent, primarily due to milder weather
conditions in 2000. Commercial sales increased 2.3 percent, due to an increase
in the number of commercial customers. Industrial sales increased 2.9 percent,
due to increased consumption by steel manufacturers. The following table sets
forth kilowatt-hours (KWH) delivered to electric utility customers.
- ----------------------------------------------------------------------------
KWH Delivered
------------------------------------
(In Millions)
------------------------------------
2000 1999 Change
- ----------------------------------------------------------------------------
Residential 3,509 3,526 (0.5)%
Commercial 6,162 6,024 2.3%
Industrial 3,581 3,481 2.9%
- -------------------------------------------------------------
KWH Sales 13,252 13,031 1.7%
Cumulative effect of a change
in accounting principle 483 -- --%
- -------------------------------------------------------------
Total Sales 13,735 13,031 5.4%
============================================================================
Operating expenses decreased by $11.4 million or 6.4 percent compared to 1999,
due to cost reduction initiatives we began in 2000; cost savings related to the
implementation of our automated Customer Advanced Reliability System (CARS); and
a reduction in employee pension costs.
Depreciation and amortization expense includes the depreciation of electric
delivery-related plant and equipment. There was an increase of $5.9 million or
11.7 percent compared to 1999. The increase is primarily attributed to more
fixed assets plant being allocated to the delivery business in 2000, and the
CARS system.
In 2000, there was $23.6 million or 51.4 percent more interest and other
charges allocated to the electricity delivery business segment compared to 1999.
All remaining financing costs following the generation asset sale are borne by
the electricity delivery business segment.
13
Electricity Supply Business Segment. In 2000, the electricity supply business
segment reported net income of $0.2 million compared to $11.6 million in 1999, a
decrease of $11.4 million or 98.3 percent. Included in 2000 is $8.2 million
related to the cumulative effect of a change in accounting principle for
unbilled revenues.
Operating revenues decreased by $103.1 million or 19.5 percent compared to
1999. The decrease in revenues can be attributed primarily to a 71.2 percent
decrease in sales to other utilities in 2000 compared to 1999. Subsequent to our
generation asset sale, energy sales to other utilities are not significant. The
following table sets forth KWH supplied for customers who had not chosen an
alternative generation supplier.
- ---------------------------------------------------------------------------
KWH Supplied
-----------------------------------
(In Millions)
-----------------------------------
2000 1999 Change
- ---------------------------------------------------------------------------
Residential 2,422 2,533 (4.4)%
Commercial 4,436 3,811 16.4 %
Industrial 3,332 2,581 29.1 %
- --------------------------------------------------------------
KWH Sales 10,190 8,925 14.2 %
Cumulative effect of a change
in accounting principle 341 -- -- %
Sales to Other Utilities 963 3,347 (71.2)%
- --------------------------------------------------------------
Total Sales 11,494 12,272 (6.3)%
===========================================================================
Operating expenses decreased $37.5 million or 8.2 percent from 1999, as a
result of reduced maintenance costs due to 1999 generation station outages and
reduced nonfuel operating expenses associated with the December 1999 power
station exchange. Partially offsetting these decreases was an increase in
purchased power costs, related to our provider of last resort arrangement with
Orion following the generation asset sale. The cost under the arrangement is an
average of $0.04 per KWH across all rate classes. (See "Provider of Last
Resort.") During 1999, the average production cost, including both fuel and non-
fuel operating and maintenance costs, was approximately $0.025 per KWH.
Depreciation and amortization expense includes the depreciation of the power
stations' plant and equipment through the date of the April 2000 generation
asset sale, and accrued nuclear decommissioning costs during 1999. There was a
decrease of $24.1 million or 91.6 percent compared to 1999, due to the sale of
the power stations' plant and equipment and the absence of nuclear
decommissioning costs in 2000.
Other income decreased $8.1 million or 73.0 percent compared to 1999,
primarily due to less income being allocated to this business segment in 2000
following the generation asset sale.
Interest and other charges include interest on long-term debt, other interest
and preferred stock dividends of Duquesne Light. In 2000 there was a $22.7
million or 51.7 percent decrease in interest and other charges compared to 1999.
The decrease reflects a lower level of interest expense at Duquesne Light from
the retirement of debt with generation asset sale proceeds, and less interest
expense allocated to this business segment in 2000 due to the generation asset
sale.
CTC Business Segment. In 2000, the CTC business segment reported net income of
$45.6 million compared to $96.6 million in 1999, a decrease of $51.0 million or
52.8 percent.
Operating revenues increased by $11.1 million or 3.4 percent compared to 1999.
The increase in revenues can be attributed to a 1.7 percent increase in sales to
electric utility customers from 1999.
Depreciation and amortization expense increased by $154.0 million or 161.1
percent compared to 1999. By applying the $967 million of net proceeds from the
generation asset sale to reduce transition costs, Duquesne Light earned a
significantly lower return in 2000 compared to 1999. As a result, there was
higher CTC amortization in 2000 as compared to 1999. In addition, we recorded
$13.8 million of CTC amortization included in the cumulative effect of a change
in accounting principle for unbilled revenues in 2000.
Interest and other charges include interest on long-term debt, other interest,
and preferred stock dividends of Duquesne Light. In 1999 there was $45.4 million
of interest and other charges allocated to this business segment, while none was
allocated in 2000.
Water Distribution Business Segment. The water distribution business segment
had a $7.9 million net loss in 2000, compared to $10.8 million of net income in
1999, a decrease of $18.7 million.
Operating revenues increased by $10.5 million or 10.3 percent during 2000. The
increase is the result of a full year of operations from 1999 acquisitions,
increased third-party construction revenues, and the rate increase for water and
sewer charges related to AquaSource's rate change applications in Texas. The
rate increase became effective as of July 17, 2000. (See "AquaSource Rate
Applications.")
Operating expenses increased by $42.0 million or 52.9 percent compared to
1999. This increase is a result of a full year of operations from the 1999
acquisitions, higher contractor costs related to business integration
initiatives, and higher repair and maintenance costs.
14
Depreciation and amortization expense increased by $5.1 million or 42.1
percent compared to 1999. This increase was attributable to a higher depreciable
asset base in 2000 and a full year of goodwill amortization on 1999
acquisitions.
Other income increased $4.9 million or 111.4 percent compared to 1999,
primarily due to a $4.9 million gain on the disposition of certain water system
investments in 2000.
Energy Services Business Segment. In 2000, the Energy Services business
segment reported net income of $98.2 million, compared to a net loss of $6.3
million in 1999. Net income in 2000 was positively impacted by the gain on the
sale of DQE Energy Services' alternative fuel facilities.
Operating revenues increased $2.8 million or 16.5 percent compared to 1999.
The increase in revenue is due to significantly increased alternative fuel
facilities revenues prior to the sale of the facilities.
Operating expenses decreased $7.1 million or 24.5 percent from 1999 due to the
realization of operational efficiencies and the sale of the alternative fuel
facilities in September 2000.
Depreciation and amortization expense increased $1.7 million or 50.0 percent
in 2000 due to capital improvements incurred during 1999 and 2000.
Other income increased $159.9 million in 2000 due to the gain recognized on
the sale of the alternative fuel facilities.
Financial Business Segment. In 2000, the Financial business segment reported
net income of $36.8 million, compared to $47.0 million in 1999, a decrease of
$10.2 million or 21.7 percent. This decrease is due primarily to the shutdown of
a coal-bed methane project in December 2000, as well as a reduction in the gains
recognized from the sales of affordable housing investments in 2000.
Operating revenues decreased $1.1 million or 5.0 percent compared to 1999, due
to decreased landfill gas production and lower landfill gas sales prices, offset
in part by revenues generated from new investments in landfill gas rights and
reserves.
Operating expenses increased $15.5 million or 63.5 percent from 1999 due to a
$6.2 million reserve recorded against uncollectible landfill gas receivables,
higher equipment maintenance costs, and operating costs associated with new
investments in landfill gas rights and reserves.
Depreciation and amortization expense increased $1.0 million or 43.5 percent
compared to 1999 due to new investments in landfill gas rights and reserves.
Other income decreased $4.4 million or 6.0 percent as compared to 1999,
primarily due to a charge recorded in 2000 related to the shutdown of a coal-bed
methane project.
Interest and other charges decreased $4.2 million or 29.8 percent due to the
retirement of debt in 2000.
Enterprises Business Segment. The Enterprises business segment contributed
$5.7 million to net income in 2000 compared to $11.1 million in 1999, a decrease
of $5.4 million or 48.6 percent, primarily due to the recognition of gains in
1999 from the dispositions of property.
Operating revenues decreased $0.6 million or 2.6 percent in 2000.
In 2000, operating expenses decreased $1.3 million or 6.1 percent from 1999.
Depreciation and amortization expense decreased $0.9 million or 20.9 percent
in 2000 due to the property sales in 1999.
Other income in 2000 was $13.3 million or 58.6 percent lower than in 1999,
primarily due to the recognition of gains on dispositions of properties in 1999.
Gains on warrant exchanges in 2000 partially offset this decrease.
Interest and other charges decreased $1.6 million or 69.6 percent in 2000, due
to the reduction of debt through the use of asset sale proceeds.
All Other. The all other category had a $66.3 million net loss in 2000
compared to a net loss of $5.7 million in 1999, a decrease of $60.6 million.
Operating revenues increased in 2000 by $57.9 million compared to 1999. This
increase was primarily the result of increased revenues from our propane
delivery business (the result of a full year of operations from 1999
acquisitions) and telecommunications leases.
In 2000, operating expenses increased $79.2 million over 1999. This increase
was primarily the result of increased expenses from our propane delivery
business (the result of a full year of operations from 1999 acquisitions).
In 2000, depreciation and amortization expense increased by $4.2 million
primarily due to the acquisition of propane delivery companies during 1999.
Other income primarily includes long-term investment income and interest and
dividend income related to our other business lines. Other income in 2000 was
$21.5 million lower than in 1999. This decrease was primarily due to a charge
recorded in 2000 for the then-pending sale of our bottled water business and a
gain recorded in 1999 related to the sale of an investment.
Interest and other charges include interest on long-term debt, other interest,
and preferred stock dividends of our other business lines. An increase of $33.9
million in 2000 was the result of increased borrowing activity by DQE Capital,
the proceeds of which funded interim capital requirements prior to the
generation asset sale.
15
LIQUIDITY AND CAPITAL RESOURCES
SEC Statement on Disclosure
On January 22, 2002, the SEC issued a statement encouraging expanded
disclosure of certain items: off-balance sheet arrangements, contract trading
activities, and transactions with related parties.
Except for the matters discussed in Note G and Note K to our consolidated
financial statements, we have no other material off-balance sheet arrangements.
We are not involved in any commodity contract trading activities. We have no
material related party transactions.
Future Capital Availability
We expect to meet our current obligations and debt maturities through 2005
with funds generated from operations, through new financings, and short-term
borrowings.
All of our electric utility customers are now buying their generation directly
from alternative suppliers or indirectly from Orion through the Duquesne Light
provider of last resort service arrangement. Although we bill provider of last
resort customer revenues, we pass them on (net of gross receipts tax) to Orion.
In addition, the bill for an average residential provider of last resort
customer is expected to decrease, ultimately, by 16 percent with the final CTC
collection. This decrease reflects the additional cost of electric capacity
required by regional transmission organization (RTO) membership and the
additional cost of RNR recovery (defined below). Duquesne Light also agreed to
freeze its generation rates through 2004 and its transmission and distribution
rates through 2003. However, Duquesne Light expects to realize a 0.5 cent per
KWH margin through its extended provider of last resort arrangement. The margin
ultimately realized will depend on, among other items, the number of customers
who use the provider of last resort service from time to time, as well as the
life of the extended arrangement with Orion. (See "Rate Matters.")
We maintain two separate revolving credit agreements, one for $200 million and
one for $150 million, both expiring in October 2002. We may convert the $150
million revolver into a term loan facility for a one-year period, for any
amounts then outstanding upon expiration of the revolving credit period.
Interest rates on both facilities can, in accordance with the option selected at
the time of the borrowing, be based on one of several indicators, including
prime and Eurodollar rates. Commitment fees are based on the unborrowed amount
of the commitment. We plan to extend both facilities prior to their expiration.
At December 31, 2001 no borrowings were outstanding.
Under our credit facilities, we are subject to financial covenants requiring
each of DQE and Duquesne Light to maintain a maximum debt-to-capitalization
ratio of 65 percent. In addition, DQE is required to maintain a minimum cash
coverage ratio of 2-to-1. At December 31, 2001 we were in compliance with these
covenants, having debt-to-capitalization ratios of approximately 64.3 percent at
DQE and approximately 58.8 percent at Duquesne Light, and a cash coverage ratio
of approximately 2.6 percent at DQE. We plan to reduce our debt-to-
capitalization ratio in 2002 by reducing debt with asset sale proceeds and
increasing equity through new securities issuances.
On October 29, 2001, Duquesne Light filed a shelf registration statement for
up to $400 million of first mortgage bonds with the SEC. Duquesne Light expects
to refinance existing debt using this shelf registration. Duquesne Light's
ability to issue such debt will depend on, among other things, market demand and
interest rates.
In the first quarter of 2002, Moody's Investor Service, Standard & Poor's and
Fitch Ratings assessed our short and long-term credit profiles. The ratings
reflect the agencies' opinion of our overall financial strength. Ratings impact
our ability to access capital markets for investment and capital requirements,
as well as the relative costs related to such liquidity capability. In general,
the agencies reduced our long term credit ratings, although staying within the
range considered to be investment grade. The agencies maintained the existing
credit ratings for Duquesne Light's short term debt. However Moody's and Fitch
reduced DQE Capital's short-term debt rating by one level, thereby restricting
DQE Capital from accessing the short term commercial paper market. DQE Capital
is exploring alternative ways to fund its short term liquidity needs. This
ratings downgrade does not limit our ability to access our revolving credit
facilities; it does, however, impact the cost of maintaining the credit
facilities and the cost of any new debt. These ratings are not a recommendation
to buy, sell or hold any securities of DQE or our subsidiaries, may be subject
to revisions or withdrawal by the agencies at any time, and should be evaluated
independently of each other and any other rating that may be assigned to our
securities.
Financing
In January 2002, we refinanced $150 million of matured DQE Capital Corporation
floating rate notes through the issuance of commercial paper, primarily at
Duquesne Light. This commercial paper may, in turn, be refunded through other
debt instruments available to us. In addition, $100 million of our first
mortgage bonds mature in 2003, and will be funded with cash generated from
operations, through new financings and short-term borrowings.
In 2001, $85.0 million of term loan debt matured. In addition, we paid $3.9
million of current maturities. We
16
also repurchased approximately 10,000 shares of DQE preferred stock for
approximately $830,000.
At December 31, 2001, we had $151.4 million of current debt maturities, and no
commercial paper borrowings outstanding. During 2001, the maximum amount of bank
loans and commercial paper borrowings outstanding was $55 million, the amount of
average daily borrowings was $22.7 million, and the weighted average daily
interest rate was 4.79 percent.
During 2000 we repurchased approximately 16 million shares of our common stock
on the open market for approximately $650 million, and approximately 248,000
shares of DQE preferred stock for approximately $20.8 million. These repurchases
were part of a recapitalization program following the generation asset
divestiture. We invested $150 million in capital expenditures, $84 million in
long-term investments and $43 million in acquisitions. We also paid
approximately $100 million in dividends on capital stock.
At December 31, 2000, we had $92.0 million of current debt maturities and no
commercial paper borrowings outstanding. During 2000, the maximum amount of bank
loans and commercial paper borrowings outstanding was $373.3 million, the amount
of average daily borrowings was $34.4 million, and the weighted average daily
interest rate was 6.1 percent.
During 1999, we invested $196 million in acquisitions, $147 million in capital
expenditures, and $90 million in nuclear decommissioning and other long-term
investments. In connection with the power station exchange, we paid
approximately $234 million in termination costs and $43 million in related taxes
to cancel the Beaver Valley Unit 2 lease.
At December 31, 1999, we had $343 million of commercial paper borrowings
outstanding, and $469 million of current debt maturities. During 1999, the
maximum amount of bank loans and commercial paper borrowings outstanding was
$368.9 million, the amount of average daily borrowings was $46.3 million, and
the weighted average daily interest rate was 5.6 percent.
Capital Expenditures
We spent approximately $162.2 million, $150.0 million and $147.2 million in
2001, 2000 and 1999 for capital expenditures. Approximately $59.1 million, $91.8
million and $100.3 million in 2001, 2000 and 1999 was spent for electric utility
construction, and approximately $39.5 million, $44.8 million and $27.2 million
in 2001, 2000 and 1999 was spent for water utility construction. The remaining
capital expenditures were related to our other business lines and other
investments. We estimate that we will spend, excluding allowance for funds used
during construction (AFC), approximately $70.0 million for electric utility
construction in each of the years 2002, 2003 and 2004; and $53.0 million, $25.0
million and $19.0 million for water utility construction in 2002, 2003 and 2004.
Additionally, our other business lines will spend approximately $10.0 million,
$8.0 million and $8.0 million for construction in 2002, 2003 and 2004.
Acquisitions and Dispositions
In the first quarter of 2002, we sold a significant portion of our remaining
affordable housing portfolio, receiving proceeds of approximately $17.0 million,
which approximated book value.
We sold our bottled water assets on May 15, 2001. The sale resulted in an
after tax loss of $15.0 million, of which $10.0 million had been recorded in
December 2000.
On July 16, 2001, the Allegheny County Airport Authority purchased the
Pittsburgh International Airport energy facility from a DQE Enterprises
subsidiary, and entered into a 15-year operations and maintenance agreement
regarding the facility with DQE Energy Services. The transaction resulted in an
approximately $8.4 million after tax gain, or $0.15 per share.
In total, we received approximately $39 million in proceeds for these
two dispositions and other non-strategic investments in 2001.
In the fourth quarter of 2001, we sold a portion of our affordable housing
portfolio, receiving proceeds of approximately $34.0 million, which approximated
book value. We sold an office building, receiving proceeds of $18.5 million,
which approximated book value. We also sold 50,000 shares of AquaSource Class A
Common Stock to an unrelated third party, in exchange for approximately $4.0
million of services.
Also during 2001, AquaSource acquired four water companies for approximately
$0.9 million.
In 2000, Duquesne Light completed the sale of our generation assets to Orion
for approximately $1.7 billion dollars ($1.55 billion net of Federal tax
payments).
We also received $287 million of proceeds from the sale of a water utility
system and various other non-strategic investments, including affordable housing
investments and DQE Energy Services' alternative fuel facilities. The
alternative fuel transaction includes a seven-year contract to operate several
of the facilities.
During 2000, Duquesne Light purchased from Itron, Inc. the CARS system, the
automated electronic meter reading system developed by Itron for use with our
electricity utility customers. We had previously leased these assets.
Additionally, AquaSource received final regulatory approval pending from 1999 to
acquire 13 water and water-related companies for approximately $11 million.
In 1999, we invested $196 million and issued $9 million of DQE preferred stock
in the acquisition of water and propane companies. AquaSource acquired 46 water
and water-related companies and DQE Systems
17
acquired 18 propane delivery companies. Also during 1999, we completed the power
station exchange with FirstEnergy, which included the assumption of $359.2
million of sale leaseback obligation bonds in conjunction with the termination
of the Beaver Valley Unit 2 lease. We also disposed of several non-strategic
real estate and lease investments, resulting in proceeds of $143 million.
Long-Term Investments
We estimate that we will spend approximately $18 million, $20 million and $35
million for long-term investments in 2002, 2003 and 2004, mainly for energy
services projects and landfill gas investments.
We have historically made long-term investments in the following areas:
leases, affordable housing, electronic commerce, energy services and
technologies, communications, and landfill and coal-bed methane gas rights and
reserves. In 1999, we also invested in deposits in nuclear decommissioning funds
related to Duquesne Light's nuclear-powered plants. However, due in part to weak
equity markets, we significantly reduced our level of long-term investing
activities in 2001 compared to previous years. In 2001, we invested
approximately $7 million in electronic commerce and energy services and
technologies.
Our long-term investing activities during 2000 totaled $84 million, and
included investments in landfill and natural gas reserves; affordable housing
investments; and electronic commerce, energy services and technologies, and
communications investments.
During 1999, Duquesne Light invested approximately $60 million in the nuclear
decommissioning trust funds, in order to fully fund the decommissioning
liability, prior to transferring both the trust funds and the liability to
FirstEnergy in the power station exchange. Cash related to this funding was
collected during the year through the CTC component of customer bills. Other
long-term investing activities during 1999, primarily engaged in by our other
business lines, totaled $30 million and included landfill gas rights and
reserves; a joint venture that designs, engineers and constructs landfill gas
collection systems; affordable housing partnerships; and various electronic
commerce, energy services and technologies, and communications investments.
Contractual Obligations and Commercial Commitments
We have certain contractual obligations and commercial commitments that extend
beyond 2002, as set forth in the following tables:
Payments Due By Period
- --------------------------------------------------------------------------------------------------------------------------
(In Millions)
---------------------------------------------------------------------
2002 2003 2004 2005 2006 After
---------------------------------------------------------------------
Long-Term Debt, Including Current Maturities $ 151.4 $ 100.9 $ 101.4 $ 1.5 $ 1.6 $ 999.2
Capital Lease Obligations 0.7 0.7 0.7 0.7 0.7 0.9
Operating Leases 5.7 5.7 5.5 3.8 3.8 20.3
- --------------------------------------------------------------------------------------------------------------------------
Total Contractual Cash Obligations $ 157.8 $ 107.3 $ 107.6 $ 6.0 $ 6.1 $ 1,020.4
==========================================================================================================================
Other Commercial Commitments
- -------------------------------------------------------------------------------------------------------------------------
(In Millions)
-------------------------------------------------------------------
Less than More than
1 year 1-3 years 4-5 years 5 years Total
-------------------------------------------------------------------
Revolving Credit Agreements (a) $ 200.0 $ 150.0 $ -- $ -- $ 350.0
Standby Letters of Credit (a) 74.6 -- -- -- 74.6
Surety Bonds (b)
Commercial 85.7 -- -- -- 85.7
Contract 26.7 -- -- -- 26.7
Guarantees (See Note K) -- -- -- 83.3 83.3
- -------------------------------------------------------------------------------------------------------------------------
Total Commercial Commitments $ 387.0 $ 150.0 $ -- $ 83.3 $ 620.3
=========================================================================================================================
(a) Revolving Credit Agreements and Letters of Credit are typically for a 364-
day period and are renewed annually. See "Short-Term Borrowing and Revolving
Credit Arrangements," Note H.
(b) Surety bonds are renewed annually. Some of the commercial bonds cover
regulatory and contractual obligations which exceed a one-year period.
18
RATE MATTERS
Competition and the Customer Choice Act
The Pennsylvania Electricity Generation Customer Choice and Competition Act
(Customer Choice Act) enables electric utility customers to purchase electricity
at market prices from a variety of electric generation suppliers. As of December
31, 2001 and February 28, 2002, approximately 78.1 percent and 78.4 percent
measured on a KWH basis, respectively, and approximately 76.8 percent and 75.5
percent on a non-coincident peak load basis, respectively, of Duquesne Light's
customers received electricity through our provider of last resort service
arrangement with Orion. The remaining customers are provided with electricity
through alternative generation suppliers. As alternative generation suppliers
enter and exit the retail supply business, the number of customers participating
in our provider of last resort service will fluctuate.
Customers who select an alternative generation supplier pay for generation
charges set competitively by that supplier, and pay Duquesne Light a competitive
transition charge (discussed below) and transmission and distribution charges.
Electricity delivery (including transmission, distribution and customer service)
remains regulated in substantially the same manner as under historical
regulation.
Customer choice and electricity generation deregulation impact traditional
Pennsylvania tax revenues. In order for the state's total revenues to remain
unchanged, a revenue neutral reconciliation tax (RNR) is applied to recover a
shortfall or refund any excess revenues on an annual basis. On November 30,
2001, the Pennsylvania Department of Revenue published an increased RNR rate of
15 mills, effective January 1, 2002, in order to recover a current shortfall.
Pennsylvania electric distribution companies, such as Duquesne Light, are
permitted to recover this cost from consumers on a current basis. On December
21, 2001, the PUC approved Duquesne Light's request for the recovery of
approximately $13 million of costs it will incur in 2002 due to the RNR. Since
January 2002, Duquesne Light's customer bills have reflected an approximate two
percent increase.
Regional Transmission Organization
FERC Order No. 2000 calls on transmission-owning utilities such as Duquesne
Light to join regional transmission organizations (RTOs). Duquesne Light is
committed to ensuring a stable, plentiful supply of electricity for its
customers. Toward that end, Duquesne Light anticipates joining the PJM West RTO,
which is currently in the final stages of approval before the FERC. In late 2001
and early 2002, Duquesne Light entered into agreements under which FirstEnergy
Solutions and Orion will supply the electric capacity required to meet Duquesne
Light's anticipated capacity credit obligations in PJM West through 2004. These
agreements are subject to, among other conditions, regulatory approval which we
will be seeking. We will also be seeking to recover the cost of capacity under
these agreements from customers, as contemplated by the PUC's order approving
the extension of our provider of last resort arrangement.
Duquesne Light's participation in the PJM West RTO is conditioned upon
regulatory approval of the agreements, as well as satisfactory recovery of
associated costs. Notwithstanding any such additional costs, customer bills are
expected to decrease as the CTC is collected for each customer class. (See
"Competitive Transition Charge" and "Provider of Last Resort" discussions
below.) Duquesne's inclusion in this RTO will put the region's transmission
facilities under common control to enhance reliability to customers.
Competitive Transition Charge
In its final restructuring order issued in the second quarter of 1998, the PUC
determined that Duquesne Light should recover most of the above-market costs of
its generation assets, including plant and regulatory assets, through the
collection of the competitive transition charge (CTC) from electric utility
customers. On January 18, 2001, the PUC approved our final accounting for the
proceeds of our April 2000 generation asset sale, including the net recovery of
$276 million of sale-related transaction costs. Applying the net generation
asset sale proceeds to reduce transition costs, we now anticipate termination of
the CTC collection period by mid-year 2002 for most major rate classes.
Ultimately, the bill is expected to decrease approximately 16 percent for an
average residential customer who takes provider of last resort service from
Duquesne Light pursuant to the second agreement with Orion discussed below. This
decrease reflects the additional cost of electric capacity required by RTO
membership and the additional cost of RNR recovery. (See "Regional Transmission
Organization" and "Competition and Customer Choice Act" discussions above.) The
transition costs, as reflected on the consolidated balance sheet, are being
amortized over the same period that the CTC revenues are being recognized.
For regulatory purposes, the unrecovered balance of transition costs that
remained following the generation asset sale was approximately $141.9 million
($86.6 million net of tax) at December 31, 2001, on which Duquesne Light is
allowed to earn an 11 percent pre-tax return. This amount includes recovery of
an additional $10 million approved by the PUC in early 2002 relating to the
December 1999 power station exchange. A lower amount is shown on the balance
sheet due to the accounting for unbilled revenues.
19
Provider of Last Resort
Although no longer a generation supplier, as the provider of last resort for
all customers in its service territory, Duquesne Light must provide electricity
for any customer who does not choose an alternative generation supplier, or
whose supplier fails to deliver. As part of the generation asset sale, Orion
agreed to supply Duquesne Light with all of the electric energy necessary to
satisfy Duquesne Light's provider of last resort obligations during the CTC
collection period. In December 2000, the PUC approved a second agreement that
extends Orion's provider of last resort arrangement (and the PUC-approved rates
for the supply of electricity) beyond the final CTC collection through 2004
(POLR II). The agreement also permits Duquesne Light, following CTC collection,
an average margin of 0.5 cents per KWH supplied through this arrangement. Except
for this margin, these agreements, in general, effectively transfer to Orion the
financial risks and rewards associated with Duquesne Light's provider of last
resort obligations. While we retain the collection risk for the electricity
sales, a component of our regulated delivery rates is designed to cover the cost
of a normal level of uncollectible accounts.
Rate Freeze
An overall four-and-one-half-year rate cap from January 1, 1997, was
originally imposed on the transmission and distribution charges of Pennsylvania
electric utility companies under the Customer Choice Act. As part of a
settlement regarding recovery of deferred fuel costs, Duquesne Light agreed to
extend this rate cap for an additional six months through the end of 2001.
Subsequently, in connection with the POLR II agreement described above, Duquesne
Light negotiated a rate freeze for generation, transmission and distribution
rates. The rate freeze fixes new generation rates for retail customers who take
electricity under the extended provider of last resort arrangement, and
continues the transmission and distribution rates for all customers at current
levels through at least 2003. Under certain circumstances, affected interests
may file a complaint alleging that, under these frozen rates, Duquesne Light has
exceeded reasonable earnings, in which case the PUC could make adjustments to
rectify such earnings.
AquaSource Rate Applications
In June 2000, AquaSource filed consolidated, statewide water and sewer rate
change applications with the Texas Natural Resource Conservation Commission
(TNRCC) and 17 municipalities. AquaSource proposed, among other things, to
replace the more than 100 separate tariffs of its acquired companies with a
single water tariff and a single sewer tariff, using uniform system-wide rates.
The proposed rates were charged (subject to refund with interest) pending the
final regulatory approval on each application.
In Texas, certain municipalities have original jurisdiction over water and
sewer rates; in addition, the TNRCC has original jurisdiction over rates in all
other areas, plus appellate jurisdiction over all municipal rate orders.
Thirteen of the municipalities either approved the rate increase, or failed to
act on a timely basis, and the new rates became fully effective as of July 17,
2001. However, three municipalities denied the rate increase, and a fourth
established rates significantly lower than requested. AquaSource appealed these
rate orders to the TNRCC, and the appeals were consolidated with the general
rate case for the areas over which the TNRCC has original jurisdiction. Hearings
were scheduled to begin in late September 2001, but the parties instead entered
into a settlement agreement.
The settlement agreement provides for, among other things, the following: the
establishment of AquaSource's rate base; the establishment of four regional
rates for service areas within the TNRCC's original jurisdiction, and three
separate rates for the four municipalities who appealed; and the phase-in of the
rates beginning January 1 of 2002, 2003 and 2004 (with the first phase being
retroactive to the initial application filing date of July 17, 2000). AquaSource
has also agreed not to file another rate case application for a rate increase
that would be effective prior to July 1, 2004, unless the utility encounters
financial hardship. In addition, the decision on whether AquaSource may recover
costs related to acquiring its companies through its rates has been deferred
until the next rate case. The settlement agreement is expected to be approved by
the TNRCC by mid-year 2002. AquaSource expects the revised rate increase will
result in additional annual water and sewer revenues of approximately $5
million.
In March 2001, AquaSource also filed a rate increase petition with the Indiana
Utility Regulatory Commission (IURC) regarding water and sewer rates for its
Utility Center, Inc. subsidiary (AquaSource's largest regulated subsidiary).
Hearings were held in January 2002. We currently anticipate a final order from
the IURC in the third quarter of 2002. If the petition is approved, annual water
and sewer revenues for Utility Center will increase by approximately $2.7
million.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
The information regarding market risk required by this item is set forth in
Item 1 under the heading "Market Risk."
20
ITEM 8. CONSOLIDATED FINANCIAL
STATEMENTS AND
SUPPLEMENTARY DATA.
INDEPENDENT AUDITORS' REPORT
To the Directors and Shareholders of DQE, Inc.:
We have audited the accompanying consolidated balance sheets of DQE, Inc. and
its subsidiaries as of December 31, 2001 and 2000, and the related consolidated
statements of income, comprehensive income, retained earnings, and cash flows
for each of the three years in the period ended December 31, 2001. Our audits
also included the financial statement schedule listed in the Index at Item 14.
These financial statements and financial statement schedule are the
responsibility of DQE, Inc.'s management. Our responsibility is to express an
opinion on the financial statements and financial statement schedule based on
our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States of America. Those standards 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. An audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating the overall
financial statement presentation. We believe that our audits provide a
reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all
material respects, the financial position of DQE, Inc. and its subsidiaries as
of December 31, 2001 and 2000, and the results of their operations and their
cash flows for each of the three years in the period ended December 31, 2001, in
conformity with accounting principles generally accepted in the United States of
America. Also, in our opinion, such financial statement schedule, when
considered in relation to the basic consolidated financial statements taken as a
whole, presents fairly in all material respects the information set forth
therein.
As discussed in Note A to the consolidated financial statements, DQE, Inc.
changed its method of accounting for unbilled revenues as of January 1, 2000.
/s/ Deloitte & Touche LLP
Pittsburgh, Pennsylvania
January 29, 2002
21
Consolidated Statements of Income
- --------------------------------------------------------------------------------------------------------------------------
(Thousands of Dollars, Except Per Share Amounts)
--------------------------------------------------
Year Ended December 31,
- --------------------------------------------------------------------------------------------------------------------------
2001 2000 1999
- --------------------------------------------------------------------------------------------------------------------------
Operating Revenues:
Electricity sales $ 1,024,732 $ 1,029,247 $ 1,093,537
Water sales 109,045 112,151 101,613
Propane sales 51,751 53,721 9,495
Other 110,554 132,485 136,556
- --------------------------------------------------------------------------------------------------------------------------
Total Operating Revenues 1,296,082 1,327,604 1,341,201
- --------------------------------------------------------------------------------------------------------------------------
Operating Expenses:
Fuel and purchased power 414,309 347,859 225,182
Other operating 336,280 413,531 437,679
Maintenance 23,704 50,623 75,400
Impairment of long-lived assets 176,478 -- --
Restructuring charge 31,085 -- --
Depreciation and amortization 370,931 343,232 196,319
Taxes other than income taxes 60,056 68,070 87,779
- --------------------------------------------------------------------------------------------------------------------------
Total Operating Expenses 1,412,843 1,223,315 1,022,359
- --------------------------------------------------------------------------------------------------------------------------
Operating Income (Loss) (116,761) 104,289 318,842
- --------------------------------------------------------------------------------------------------------------------------
Other Income (Expense):
Investment income 82,980 227,727 152,003
Investment impairment (71,239) -- --
- --------------------------------------------------------------------------------------------------------------------------
Other Income 11,741 227,727 152,003
- --------------------------------------------------------------------------------------------------------------------------
Interest and Other Charges 104,442 123,610 158,707
- --------------------------------------------------------------------------------------------------------------------------
Income (Loss) Before Income Taxes and
Cumulative Effect of Accounting Change (209,462) 208,406 312,138
- --------------------------------------------------------------------------------------------------------------------------
Income Tax Expense (Benefit) (56,081) 70,350 110,722
- --------------------------------------------------------------------------------------------------------------------------
Income (Loss) Before Cumulative
Effect of Accounting Change (153,381) 138,056 201,416
- --------------------------------------------------------------------------------------------------------------------------
Cumulative Effect of Change in
Accounting Principle-- Net -- 15,495 --
- --------------------------------------------------------------------------------------------------------------------------
Net Income (Loss) (153,381) 153,551 201,416
==========================================================================================================================
Dividends on Preferred Stock 516 (806) 1,569
- --------------------------------------------------------------------------------------------------------------------------
Earnings (Loss) Available for Common Stock $ (153,897) $ 154,357 $ 199,847
==========================================================================================================================
Average Number of Common Shares Outstanding
(Thousands of Shares) 55,888 63,348 75,463
==========================================================================================================================
Basic Earnings (Loss) Per Share $ (2.75) $ 2.44 $ 2.65
==========================================================================================================================
Diluted Earnings (Loss) Per Share $ (2.75) $ 2.39 $ 2.62
==========================================================================================================================
Dividends Declared Per Share of Common Stock $ 1.68 $ 1.62 $ 1.54
==========================================================================================================================
See notes to consolidated financial statements.
22
Consolidated Balance Sheets
- --------------------------------------------------------------------------------
(Thousands of Dollars)
----------------------------
As of December 31,
----------------------------
ASSETS 2001 2000
- --------------------------------------------------------------------------------
Current Assets:
Cash and temporary cash investments $ 7,268 $ 15,807
- --------------------------------------------------------------------------------
Receivables:
Electric customer accounts receivable 133,702 134,187
Other electric utility receivables 3,186 16,578
Water customer accounts receivable 23,086 29,898
Other receivables 42,996 67,593
Less: Allowance for uncollectible accounts (9,938) (11,861)
- --------------------------------------------------------------------------------
Total Receivables - Net 193,032 236,395
- --------------------------------------------------------------------------------
Materials and supplies (at average cost) 22,166 24,077
Income tax asset 66,798 91,438
Other current assets 34,585 21,109
- --------------------------------------------------------------------------------
Total Current Assets 323,849 388,826
- --------------------------------------------------------------------------------
Long-Term Investments:
Leveraged leases 470,925 442,608
Gas rights and reserves 55,810 104,664
Affordable housing 21,949 65,885
Available-for-sale securities 13,137 55,979
Other 66,375 107,509
- --------------------------------------------------------------------------------
Total Long-Term Investments 628,196 776,645
- --------------------------------------------------------------------------------
Property, Plant and Equipment:
Electric plant in service 1,877,887 1,854,013
Water plant in service 312,607 239,758
Propane distribution plant 44,242 41,889
Construction work in progress 49,029 59,100
Other 164,286 201,557
- --------------------------------------------------------------------------------
Gross property, plant and equipment 2,448,051 2,396,317
Less: Accumulated depreciation and amortization (759,726) (702,446)
- --------------------------------------------------------------------------------
Total Property, Plant and Equipment - Net 1,688,325 1,693,871
- --------------------------------------------------------------------------------
Other Non-Current Assets:
Transition costs 134,340 396,379
Regulatory assets 267,167 277,333
Other 184,032 311,191
- --------------------------------------------------------------------------------
Total Other Non-Current Assets 585,539 984,903
- --------------------------------------------------------------------------------
Total Assets $ 3,225,909 $ 3,844,245
================================================================================
See notes to consolidated financial statements.
23
Consolidated Balance Sheets
- -------------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
---------------------------------
As of December 31,
---------------------------------
LIABILITIES AND CAPITALIZATION 2001 2000
- -------------------------------------------------------------------------------------------------------------------
Current Liabilities:
Current debt maturities $ 151,354 $ 92,023
Accounts payable 126,745 144,306
Accrued liabilities 60,273 61,015
Dividends declared 26,186 26,037
Other 22,261 27,193
- -------------------------------------------------------------------------------------------------------------------
Total Current Liabilities 386,819 350,574
- -------------------------------------------------------------------------------------------------------------------
Non-Current Liabilities:
Deferred income taxes - net 611,429 803,447
Deferred income 103,504 116,803
Pension trust liability 48,442 69,787
Warwick Mine liability 35,033 40,110
Other 90,626 89,067
- -------------------------------------------------------------------------------------------------------------------
Total Non-Current Liabilities 889,034 1,119,214
- -------------------------------------------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------------------------------------
Commitments and Contingencies (Notes B through Q)
- -------------------------------------------------------------------------------------------------------------------
Capitalization:
Long-Term Debt 1,198,759 1,349,298
- -------------------------------------------------------------------------------------------------------------------
DLC Obligated Mandatorily Redeemable
Preferred Trust Securities 150,000 150,000
- -------------------------------------------------------------------------------------------------------------------
Preferred and Preference Stock
(aggregate involuntary liquidation value of $98,656 and $100,396):
DQE preferred stock 16,352 17,361
Preferred stock of subsidiaries 62,608 62,608
Preference stock of subsidiaries 17,239 18,028
- -------------------------------------------------------------------------------------------------------------------
Total preferred and preference stock before deferred employee
stock ownership plan (ESOP) benefit 96,199 97,997
- -------------------------------------------------------------------------------------------------------------------
Deferred ESOP benefit (3,363) (6,583)
- -------------------------------------------------------------------------------------------------------------------
Total Preferred and Preference Stock 92,836 91,414
- -------------------------------------------------------------------------------------------------------------------
Common Shareholders' Equity:
Common stock - no par value (authorized - 187,500,000
shares; issued - 109,679,154 shares) 994,760 994,834
Retained earnings 759,750 1,007,739
Treasury stock (at cost) (53,770,877 and 53,793,330 shares) (1,246,738) (1,247,287)
Accumulated other comprehensive income 689 28,459
- -------------------------------------------------------------------------------------------------------------------
Total Common Shareholders' Equity 508,461 783,745
- -------------------------------------------------------------------------------------------------------------------
Total Capitalization 1,950,056 2,374,457
- -------------------------------------------------------------------------------------------------------------------
Total Liabilities and Capitalization $ 3,225,909 $ 3,844,245
===================================================================================================================
See notes to consolidated financial statements.
24
Consolidated Statements of Cash Flows
- --------------------------------------------------------------------------------
(Thousands of Dollars)
-----------------------------------------
Year Ended December 31,
-----------------------------------------
2001 2000 1999
- -------------------------------------------------------------------------------------------------------------------
Cash Flows From Operating Activities:
Net income (loss) $ (153,381) $ 153,551 $ 201,416
Principal non-cash charges (credits) to net income:
Depreciation and amortization 370,931 343,232 196,319
Impairment charges 247,717 -- --
Capital lease, nuclear fuel and investment amortization 45,869 35,904 60,470
Restructuring charges 31,085 -- --
Cumulative effect of a change in accounting principle, net -- (15,495) --
Gain on disposition of investments (16,571) (69,533) (44,027)
Investment income (28,312) (33,000) (79,747)
Deferred taxes (96,441) (109,006) 73,461
Changes in working capital other than cash (Note Q) (93,878) 107,407 (58,057)
Other (39,827) (81,903) 5,644
- -------------------------------------------------------------------------------------------------------------------
Net Cash Provided From Operating Activities 267,192 331,157 355,479
- -------------------------------------------------------------------------------------------------------------------
Cash Flows From Investing Activities:
Proceeds from sale of investments, net of federal
income tax payment of $6,628, $52,784 and $17,611 93,113 233,909 125,483
Proceeds from sale of generation assets, net of
federal income tax payment of $157,424 -- 1,547,607 --
Acquisition of water companies (903) (11,059) (133,023)
Acquisition of propane companies -- -- (63,364)
Other acquisitions -- (32,000) --
Funding of nuclear decommissioning trust -- -- (59,861)
Divestiture costs -- (78,752) (47,449)
Long-term investments (6,848) (84,246) (29,671)
Capital expenditures (162,221) (150,046) (147,236)
Other (15,465) (19,080) (11,506)
- -------------------------------------------------------------------------------------------------------------------
Net Cash Provided From (Used in) Investing Activities (92,324) 1,406,333 (366,627)
- -------------------------------------------------------------------------------------------------------------------
Cash Flows From Financing Activities:
Issuance of debt -- 149,746 386,624
Increase in notes payable -- -- 342,804
Beaver Valley lease termination -- -- (277,226)
Reduction of commercial paper -- (342,804) --
Dividends on common and preferred stock (94,608) (99,597) (117,302)
Repurchase of common and preferred stock (281) (665,372) (216,713)
Reductions of long-term obligations:
Capital leases (2,380) (110) (42,423)
Long-term debt (88,902) (814,236) (90,667)
Other 2,764 (3,539) (27,896)
- -------------------------------------------------------------------------------------------------------------------
Net Cash Used in Financing Activities (183,407) (1,775,912) (42,799)
- -------------------------------------------------------------------------------------------------------------------
Net decrease in cash (8,539) (38,422) (53,947)
Cash, beginning of period 15,807 54,229 108,176
- -------------------------------------------------------------------------------------------------------------------
Cash and temporary cash investments at end of year $ 7,268 $ 15,807 $ 54,229
===================================================================================================================
Supplemental Cash Flow Information
- -------------------------------------------------------------------------------------------------------------------
Cash Paid During The Year:
- -------------------------------------------------------------------------------------------------------------------
Interest (net of amount capitalized) $ 109,759 $ 109,918 $ 100,083
- -------------------------------------------------------------------------------------------------------------------
Income taxes $ 27,550 $ 162,748 $ 35,108
- -------------------------------------------------------------------------------------------------------------------
See notes to consolidated financial statements.
25
Consolidated Statements of Comprehensive Income
- ----------------------------------------------------------------------------------------------------
(Thousands of Dollars)
-------------------------------------
Year Ended December 31,
-------------------------------------
2001 2000 1999
- ----------------------------------------------------------------------------------------------------
Net Income (loss) $ (153,381) $ 153,551 $ 201,416
Other comprehensive income (loss):
Unrealized holding gains (losses) arising during the year,
net of tax of $(14,953), $14,337 and $1,081 (27,770) 26,625 1,540
Comprehensive Income (Loss) $ (181,151) $ 180,176 $ 202,956
====================================================================================================
See notes to consolidated financial statements.
Consolidated Statements of Retained Earnings
- ----------------------------------------------------------------------------------------------------
(Thousands of Dollars)
--------------------------------------
As of December 31,
--------------------------------------
2001 2000 1999
- ----------------------------------------------------------------------------------------------------
Balance at beginning of year $ 1,007,739 $ 953,785 $ 869,671
Net income (loss) (153,381) 153,551 201,416
Dividends declared (94,608) (99,597) (117,302)
- ----------------------------------------------------------------------------------------------------
Balance at End of Year $ 759,750 $ 1,007,739 $ 953,785
====================================================================================================
See notes to consolidated financial statements.
Notes to Consolidated Financial Statements
A . A C C O U N T I N G P O L I C I E S
Consolidation
DQE, Inc. delivers essential products and related services, including
electricity, water and communications, to more than one million customers
throughout the United States. Our subsidiaries are Duquesne Light Company;
AquaSource, Inc.; DQE Energy Services, LLC; DQE Financial Corp.; DQE
Enterprises, Inc.; DQE Communications, Inc.; ProAm, Inc.; Cherrington Insurance,
Ltd.; and DQE Capital Corporation.
Duquesne Light, our largest operating subsidiary, is an electric utility
engaged in the transmission and distribution of electric energy.
AquaSource is a water resource management company that acquires, develops
and manages water and wastewater systems.
DQE Energy Services is an energy facilities management company that
provides energy outsourcing solutions including development, operation and
maintenance of energy and alternative fuel facilities.
DQE Financial owns and operates landfill gas collection and processing
systems, and is an investment and portfolio management organization focused on
structured finance and alternative energy investments.
DQE Enterprises manages electronic commerce, energy services and
technologies, and communications investment portfolios.
Our other business lines include the following: propane distribution,
communications systems, and financing and insurance services for DQE and various
affiliates.
The consolidated financial statements include the accounts of DQE and our
wholly and majority owned subsidiaries. The equity method of accounting is used
when we have 20 to 50 percent interest in other companies. Under the equity
method, original investments are recorded at cost and adjusted by our share of
undistributed earnings or losses of these companies. All material intercompany
balances and transactions have been eliminated in the consolidation.
Basis of Accounting
DQE and Duquesne Light are subject to the accounting and reporting
requirements of the Securities and Exchange Commission (SEC). Duquesne Light's
electricity delivery business is also subject to regulation by the Pennsylvania
Public Utility Commission (PUC) and the Federal Energy Regulatory Commission
(FERC) with respect to rates for delivery of electric power, accounting and
other matters. Additionally, AquaSource's water utility operations are regulated
by various authorities within the states where they operate as to rates,
accounting and other matters.
26
As a result of our PUC-approved restructuring plan, the electricity supply
segment does not meet the criteria of Statement of Financial Accounting
Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of
Regulation." Pursuant to the PUC's final restructuring order, and as provided in
the Pennsylvania Electricity Generation Customer Choice and Competition Act
(Customer Choice Act), generation-related transition costs are being recovered
through a competitive transition charge (CTC) collected in connection with
providing transmission and distribution services, and these assets have been
reclassified accordingly. The balance of transition costs was adjusted by
receipt of the generation asset sale proceeds during the second quarter of 2000.
The electricity delivery business segment continues to meet SFAS No. 71
criteria, and accordingly reflects regulatory assets and liabilities consistent
with cost-based ratemaking regulations. The regulatory assets represent probable
future revenue, because provisions for these costs are currently included, or
are expected to be included, in charges to electric utility customers through
the ratemaking process. (See Note B.) These regulatory assets as of December 31,
2001 and 2000 consist of regulatory tax receivables of approximately $225.6
million and $236.7 million, unamortized debt costs of approximately $28.9
million and $30.4 million, and deferred employee costs of approximately $12.7
million and $10.2 million, respectively.
The preparation of financial statements in conformity with accounting
principles generally accepted in the United States of America requires us to
make estimates and assumptions with respect to values and conditions that affect
the reported amounts of assets and liabilities, and disclosure of contingent
assets and liabilities, at the date of the financial statements. The reported
amounts of revenues and expenses during the reporting period also may be
affected by the estimates and assumptions we are required to make. We evaluate
these estimates on an ongoing basis, using historical experience, consultation
with experts and other methods we consider reasonable in the particular
circumstances. Nevertheless, actual results may differ significantly from our
estimates.
Revenues from Utility Sales
Duquesne Light's electric utility operations provide service to
approximately 586,000 direct customers in southwestern Pennsylvania (including
in the City of Pittsburgh), a territory of approximately 800 square miles.
Duquesne Light's meters are read monthly, and electric utility customers are
billed on the same basis. On January 1, 2000, Duquesne Light adopted the policy
of recording unbilled customer revenues to better reflect the revenues generated
from the amount of energy supplied and delivered to electric utility customers
in a given accounting period. Previously, revenues from electric utility
customers were recorded in the accounting period for which they were billed.
Revenues recorded now reflect actual customer usage in an accounting period,
regardless of when billed. The effect of this new policy is reflected on the
income statement, net of tax and associated expenses, as a cumulative effect of
a change in accounting principle in 2000. Basic earnings per share included
$0.25 related to the cumulative effect.
AquaSource's water utility operations currently provide service to more
than 520,000 water and wastewater customer connections in 18 states. AquaSource
records revenues for water customers in the period they are billed, and also
accrues unbilled revenues.
Depreciation and Amortization
Depreciation of property, plant and equipment is recorded on a straight-
line basis over the estimated remaining useful lives of properties. Depreciation
expense of $93.0 million, $93.0 million and $102.0 million was recorded in 2001,
2000 and 1999. Goodwill, representing the excess of the cost over the net
tangible and identifiable assets of acquired businesses, is stated at cost and
is amortized on a straight-line basis over the estimated future periods to be
benefited (25 to 40 years). Goodwill is included in other non-current assets on
the consolidated balance sheet. Amortization of gas rights and reserve
investments and depreciation of related property are on a units of production
method over the total estimated gas reserves. Amortization of interests in
affordable housing partnerships is based upon a method that approximates the
equity method; amortization of certain other leases is on the basis of benefits
recorded over the lives of the investments. Depreciation and amortization of
other properties are calculated on various bases. Amortization of transition
costs represents the difference between CTC revenues billed to customers (net of
gross receipts tax) and the allowed return on our unrecovered net of tax
transition cost balance (11 percent pre-tax).
Income Taxes
We use the liability method in computing deferred taxes on all differences
between book and tax bases of assets and liabilities. These book/tax differences
occur when events and transactions recognized for financial reporting purposes
are not recognized in the same period for tax purposes. The deferred tax
liability or asset is also adjusted in the period of enactment for the effect of
changes in tax laws or rates.
27
For the electricity delivery business segment, we recognize a regulatory
asset for deferred tax liabilities that are expected to be recovered from
customers through rates. (See "Rate Matters," Note B, and "Income Taxes," Note
I.) Reversals of accumulated deferred income taxes are included in income tax
expense.
Other Operating Revenues and Other Income
Other operating revenues include non-kilowatt-hour (KWH) electric utility
revenues, and revenues from our other business lines' operating activities.
ProAm, our propane delivery subsidiary, has more than 70,000 customers in
seven states. ProAm records revenues at the point of sale.
SFAS No. 13, "Accounting for Leases," allows for the recognition of lease
transactions as sales-type leases if certain criteria are met. DQE
Communications, a telecommunications subsidiary, recorded three such
transactions that met the criteria of SFAS No. 13 in 2001. These transactions
resulted in the recognition of approximately $11.0 million of revenues and $5.1
million of net income. In 2000, two transactions resulted in the recognition of
approximately $8.5 million of revenues and $4.9 million of net income.
Investment income primarily is made up of income from long-term
investments, and gains or losses from the disposition of certain assets. The
income is separated from other revenues, as the investment income does not
result from operating activities.
Receivables
Receivables on the balance sheet are comprised of outstanding billings for
electric and water customers and other utilities, and the outstanding billings
of our other business lines. In addition, at December 31, 2001 and 2000,
electric and water customer receivables reflect amounts related to unbilled
revenues of $44.9 million and $54.1 million, respectively.
Property, Plant and Equipment
The asset values of our utility properties are stated at original
construction cost, which includes related payroll taxes, pensions and other
fringe benefits, as well as administrative costs. Also included in original
construction cost is an allowance for funds used during construction (AFC),
which represents the estimated cost of debt and equity funds used to finance
construction.
Additions to, and replacements of, property units are charged to plant
accounts. Maintenance, repairs and replacement of minor items of property are
recorded as expenses when they are incurred. The costs of electricity delivery
business segment properties that are retired (plus removal costs and less any
salvage value) are charged to accumulated depreciation and amortization.
Substantially all of the electric utility properties are subject to a first
mortgage lien.
We review long-lived assets for impairment whenever events or changes in
circumstances indicate that the carrying amount of an asset may not be
recoverable. Recoverability of assets to be held and used is measured by a
comparison of the carrying amount of an asset to future net cash flows expected
to be generated by the asset. If such assets are considered to be impaired, the
impairment recognized is measured by the amount by which the carrying amount of
the assets exceeds the fair value of the assets.
Temporary Cash Investments
Temporary cash investments are short-term, highly liquid investments with
original maturities of three or fewer months. They are stated at market, which
approximates cost. We consider temporary cash investments to be cash
equivalents.
Earnings Per Share
Basic earnings per share are computed on the basis of the weighted average
number of common shares outstanding. Diluted earnings per share are computed on
the basis of the weighted average number of common shares outstanding, plus the
effect of the outstanding Employee Stock Ownership Plan shares, DQE preferred
stock and stock options, unless a net loss occurs as the inclusion of these
shares would be anti-dilutive. The treasury stock method is used in computing
the dilutive effect of stock options. This method assumes any proceeds obtained
upon the exercise of options would be used to purchase common stock at the
average market price during the period. The following table presents the
numerators and denominators used in computing the diluted basic earnings per
share for 2001, 2000 and 1999.
Diluted Earnings Per Share for the Year Ended December 31,
- --------------------------------------------------------------------------------
2001 2000 1999
- --------------------------------------------------------------------------------
(Thousands of Dollars)
Income (loss) before
accounting change $ (153,897) $ 138,862 $ 199,847
Cumulative effect of
accounting change -- net -- 15,495 --
- --------------------------------------------------------------------------------
Earnings (loss) for common (153,897) 154,357 199,847
Dilutive effect of:
ESOP dividends -- 1,568 2,121
Preferred stock dividends -- (806) 1,569
- --------------------------------------------------------------------------------
Diluted Earnings (Loss)
for Common $ (153,897) $ 155,119 $ 203,537
================================================================================
28
- ---------------------------------------------------------------------------
2001 2000 1999
- ---------------------------------------------------------------------------
(Thousands of Shares)
Basic average shares 55,888 63,348 75,463
Dilutive effect of:
ESOP shares -- 872 1,128
DQE preferred stock -- 781 1,066
Stock options -- 1 19
- ---------------------------------------------------------------------------
Diluted average shares 55,888 65,002 77,676
- ---------------------------------------------------------------------------
Diluted earnings (loss) per share:
Before accounting change $ (2.75) $ 2.15 $ 2.62
Accounting change $ -- $ 0.24 $ --
- ---------------------------------------------------------------------------
Diluted Earnings (Loss)
Per Share $ (2.75) $ 2.39 $ 2.62
===========================================================================
Note: In 2001, the incremental shares from assumed conversions are not included
in computing diluted per-share amounts for the loss for common, because the
control number (loss before accounting change) was a loss, not income.
We no longer report comprehensive earnings per share, due to our decision to
monetize DQE Enterprises investments.
Contingent Liabilities
We establish reserves for estimated loss contingencies when it is
management's assessment that a loss is probable and the amount can be reasonably
estimated. Revisions to contingent liabilities are reflected in income in the
period in which different facts or information become known, or circumstances
change, that affect the previous assumptions with respect to the likelihood or
amount of loss. Reserves for contingent liabilities are based upon management's
assumptions and estimates, advice of legal counsel, or other third parties
regarding probable outcomes of the matter. Should the ultimate outcome differ
from the assumptions and estimates, revisions to the estimated reserves for
contingent liabilities would be recognized. Such contingent liabilities for DQE
include, but are not limited to, restructuring liabilities (see Note D), income
tax matters (see Note I), and other commitments and contingencies (see Note K).
Stock-Based Compensation
We account for stock-based compensation using the intrinsic value method
prescribed in APB Opinion No. 25, Accounting for Stock Issued to Employees, and
related interpretations. Accordingly, compensation cost for stock options is
measured as the excess, if any, of the quoted market price of DQE common stock
at the date of the grant over the amount any employee must pay to acquire the
stock. Compensation cost for stock appreciation rights is recorded based on the
quoted market price of the stock at the end of the year.
Derivatives
On January 1, 2001, we adopted SFAS No. 133, "Accounting for Derivative
Instruments and Hedging Activities," the impact of which was not significant to
our financial statements.
Reclassification
The 2000 and 1999 consolidated financial statements have been reclassified to
conform with the 2001 presentation.
Recent Accounting Pronouncements
In June 2001 the Financial Accounting Standards Board (FASB) issued three new
accounting standards, SFAS No. 141, "Business Combinations," SFAS No. 142,
"Goodwill and Other Intangibles," and SFAS No. 143, "Accounting for Asset
Retirement Obligations."
SFAS No. 141 eliminates the pooling-of-interests method of accounting for
business combinations, with limited exceptions for combinations initiated prior
to July 1, 2001. We do not believe that the adoption of SFAS No. 141 will have a
significant impact on our financial statements.
SFAS No. 142, which became effective January 1, 2002, discontinues the
requirement for amortization of goodwill and indefinite-lived intangible assets,
and instead requires an annual review for the impairment of those assets.
Impairment is to be examined more frequently if certain indicators appear.
Intangible assets with a determinable life will continue to be amortized.
Amortization expense relating to goodwill for 2001 was $6.6 million. As of
December 31, 2001, goodwill and other intangible assets, net of accumulated
amortization, of approximately $136.6 million and $0.7 million, respectively,
exist and will be subject to the transitional assessment provisions of SFAS No.
142.
SFAS No. 143 addresses financial accounting and reporting for obligations
associated with the retirement of tangible long-lived assets and the associated
asset retirement costs. Specifically, this standard requires entities to record
the fair value of a liability for an asset retirement obligation in the period
in which it is incurred, if a reasonable estimate of fair value can be made. The
entity is required to capitalize the cost by increasing the carrying amount of
the related long-lived asset. The capitalized cost is then depreciated over the
useful life of the related asset. Upon settlement of the liability, an entity
either settles the obligation for its recorded amount or incurs a gain or loss.
The standard is effective for fiscal years beginning after June 15, 2002. We are
currently evaluating, but have yet to determine, the impact that the adoption of
SFAS No. 143 will have on our financial statements.
In August 2001 the FASB issued SFAS No. 144, "Accounting for the Impairment
or Disposal of Long-Lived Assets," that replaces SFAS 121, "Accounting for the
Impairment of Long-Lived Assets and Long-Lived Assets to be Disposed Of." The
statement requires that all long-lived assets to be held and used continue to be
evaluated for impairment similar to SFAS No. 121. The statement also requires
that all long-lived assets to be sold be measured at the lower of carrying
amount or fair value less cost to sell, whether reported in continuing
operations or in discontinued operations. Therefore, discontinued operations
will no longer be measured on a net realizable value basis and will not include
amounts for future operating losses. The statement also broadens the reporting
requirements for discontinued operations to include disposal transactions of all
components of an entity (rather than segments of a business). Components of an
entity include operations and cash flows that can be clearly distinguished from
the rest of the entity that will be eliminated from the ongoing operations of
the entity in a disposal transaction.
29
The statement is effective for fiscal years beginning after December 15, 2001.
We are currently evaluating, but have yet to determine, the impact that the
adoption of SFAS No. 144 will have on our financial statements.
B. RATE MATTERS
Competition and the Customer Choice Act
The Customer Choice Act enables electric utility customers to purchase
electricity at market prices from a variety of electric generation suppliers. As
of December 31, 2001, approximately 78.1 percent of Duquesne Light's customers
measured on a KWH basis and approximately 76.8 percent on a non-coincident peak
load basis received electricity through our provider of last resort service
arrangement with Orion (discussed below). The remaining customers are provided
with electricity through alternative generation suppliers. As alternative
generation suppliers enter and exit the retail supply business, the number of
customers participating in our provider of last resort service will fluctuate.
Customers who select an alternative generation supplier pay for generation
charges set competitively by that supplier, and pay Duquesne Light a competitive
transition charge (discussed below) and transmission and distribution charges.
Electricity delivery (including transmission, distribution and customer service)
remains regulated in substantially the same manner as under historical
regulation.
Customer choice and electricity generation deregulation impact traditional
Pennsylvania tax revenues. In order for the state's total revenues to remain
unchanged, a revenue neutral reconciliation tax (RNR) is applied to recover a
shortfall or refund any excess revenues on an annual basis. On November 30,
2001, the Pennsylvania Department of Revenue published an increased RNR rate of
15 mills, effective January 1, 2002, in order to recover a current shortfall.
Pennsylvania electric distribution companies, such as Duquesne Light, are
permitted to recover this cost from consumers on a current basis. On December
21, 2001, the PUC approved Duquesne Light's request for the recovery of
approximately $13 million of costs it will incur in 2002 due to the RNR. Since
January 2002, Duquesne Light's customer bills have reflected an approximate two
percent increase.
Regional Transmission Organization
FERC Order No. 2000 calls on transmission-owning utilities such as Duquesne
Light to join regional transmission organizations (RTOs). Duquesne Light is
committed to ensuring a stable, plentiful supply of electricity for its
customers. Toward that end, Duquesne Light anticipates joining the PJM West RTO,
which is currently in the final stages of approval before the FERC.
In late 2001 and early 2002, Duquesne Light entered into agreements under which
FirstEnergy Solutions and Orion will supply the electric capacity required to
meet Duquesne Light's anticipated capacity credit obligations in PJM West
through 2004. These agreements are subject to, among other conditions,
regulatory approval which we will be seeking. We will also be seeking to recover
the cost of capacity under these agreements from customers, as contemplated by
the PUC's order approving the extension of our provider of last resort
arrangement.
Duquesne Light's participation in the PJM West RTO is conditioned upon
regulatory approval of the agreements, as well as satisfactory recovery of
associated costs. Notwithstanding any such additional costs, customer bills are
expected to decrease as the CTC is collected for each customer class. (See
"Competitive Transition Charge" and "Provider of Last Resort" discussions
below.) Duquesne's inclusion in this RTO will put the region's transmission
facilities under common control to enhance reliability to customers.
Competitive Transition Charge
On December 3, 1999, Duquesne Light completed the exchange of its partial
interests in five power plants for three wholly owned power plants from
FirstEnergy Corp. In connection with this exchange, we terminated the Beaver
Valley Unit 2 lease in the fourth quarter of 1999.
On April 28, 2000, Duquesne Light completed the sale of our generation assets
to Orion. Orion purchased all of Duquesne Light's power stations, including
those received from FirstEnergy, for approximately $1.7 billion.
In its final restructuring order issued in the second quarter of 1998, the PUC
determined that Duquesne Light should recover most of the above-market costs of
its generation assets, including plant and regulatory assets, through the
collection of the competitive transition charge (CTC) from electric utility
customers. On January 18, 2001, the PUC approved our final accounting for the
proceeds of our April 2000 generation asset sale, including the net recovery of
$276 million of sale-related transaction costs. Applying the net generation
asset sale proceeds to reduce transition costs, we now anticipate termination of
the CTC collection period by mid-year 2002 for most major rate classes.
Ultimately, the bill is expected to decrease approximately 16 percent for an
average residential customer who takes provider of last resort service from
Duquesne Light pursuant to the second agreement with Orion discussed below. This
decrease reflects the additional cost of electric capacity required by RTO
membership and the additional cost of RNR recovery. (See "Regional Transmission
Organization" and "Competition and Customer Choice Act" discussions above.) The
transition costs, as reflected on the
30
consolidated balance sheet, are being amortized over the same period that the
CTC revenues are being recognized.
For regulatory purposes, the unrecovered balance of transition costs that
remained following the generation asset sale was approximately $141.9 million
($86.6 million net of tax) at December 31, 2001, on which Duquesne Light is
allowed to earn an 11 percent pre-tax return. This amount includes recovery of
an additional $10 million approved by the PUC for recovery in early 2002
relating to the December 1999 power station exchange. A lower amount is shown on
the balance sheet due to the accounting for unbilled revenues.
Provider of Last Resort
Although no longer a generation supplier, as the provider of last resort for
all customers in its service territory, Duquesne Light must provide electricity
for any customer who does not choose an alternative generation supplier, or
whose supplier fails to deliver. As part of the generation asset sale, Orion
agreed to supply Duquesne Light with all of the electric energy necessary to
satisfy Duquesne Light's provider of last resort obligations during the CTC
collection period. In December 2000, the PUC approved a second agreement that
extends Orion's provider of last resort arrangement (and the PUC-approved rates
for the supply of electricity) beyond the final CTC collection through 2004
(POLR II). The agreement also permits Duquesne Light, following CTC collection,
an average margin of 0.5 cents per KWH supplied through this arrangement. Except
for this margin, these agreements, in general, effectively transfer to Orion the
financial risks and rewards associated with Duquesne Light's provider of last
resort obligations. While we retain the collection risk for the electricity
sales, a component of our regulated delivery rates is designed to cover the cost
of a normal level of uncollectible accounts.
Rate Freeze
An overall four-and-one-half-year rate cap from January 1, 1997, was
originally imposed on the transmission and distribution charges of Pennsylvania
electric utility companies under the Customer Choice Act. As part of a
settlement regarding recovery of deferred fuel costs, Duquesne Light agreed to
extend this rate cap for an additional six months through the end of 2001.
Subsequently, in connection with the POLR II agreement described above, Duquesne
Light negotiated a rate freeze for generation, transmission and distribution
rates. The rate freeze fixes new generation rates for retail customers who take
electricity under the extended provider of last resort arrangement, and
continues the transmission and distribution rates for all customers at current
levels through at least 2003. Under certain circumstances, affected interests
may file a complaint alleging that, under these frozen rates, Duquesne Light has
exceeded reasonable earnings, in which case the PUC could make adjustments to
rectify such earnings.
Aquasource Rate Applications
In June 2000, AquaSource filed consolidated, statewide water and sewer rate
change applications with the Texas Natural Resource Conservation Commission
(TNRCC) and 17 municipalities. AquaSource proposed, among other things, to
replace the more than 100 separate tariffs of its acquired companies with a
single water tariff and a single sewer tariff, using uniform system-wide rates.
The proposed rates were charged (subject to refund with interest) pending the
final regulatory approval on each application.
In Texas, certain municipalities have original jurisdiction over water and
sewer rates; in addition, the TNRCC has original jurisdiction over rates in all
other areas, plus appellate jurisdiction over all municipal rate orders.
Thirteen of the municipalities either approved the rate increase, or failed to
act on a timely basis, and the new rates became fully effective as of July 17,
2001. However, three municipalities denied the rate increase, and a fourth
established rates significantly lower than requested. AquaSource appealed these
rate orders to the TNRCC, and the appeals were consolidated with the general
rate case for the areas over which the TNRCC has original jurisdiction. Hearings
were scheduled to begin in late September 2001, but the parties instead entered
into a settlement agreement.
The settlement agreement provides for, among other things, the following: the
establishment of AquaSource's rate base; the establishment of four regional
rates for service areas within the TNRCC's original jurisdiction, and three
separate rates for the four municipalities who appealed; and the phase-in of the
rates beginning January 1 of 2002, 2003 and 2004 (with the first phase being
retroactive to the initial application filing date of July 17, 2000). AquaSource
has also agreed not to file another rate case application for a rate increase
that would be effective prior to July 1, 2004, unless the utility encounters
financial hardship. In addition, the decision on whether AquaSource may recover
costs related to acquiring its companies through its rates has been deferred
until the next rate case. The settlement agreement is expected to be approved by
the TNRCC by mid-year 2002. AquaSource expects the revised rate increase will
result in additional annual water and sewer revenues of approximately $5
million.
In March 2001, AquaSource also filed a rate increase petition with the
Indiana Utility Regulatory Commission (IURC) regarding water and sewer rates for
its Utility Center, Inc. subsidiary (AquaSource's largest regulated subsidiary).
Hearings were held in January 2002. We currently anticipate a final order from
the IURC in the third quarter of 2002. If the petition is approved, annual water
and sewer revenues for Utility Center will increase by approximately $2.7
million.
31
C. IMPAIRMENT CHARGES
Our new management team has evaluated AquaSource's future direction and the
capabilities of its operating platforms. This evaluation determined that the
company's potential future performance would result in lower returns than
originally anticipated. AquaSource therefore recorded a second quarter 2001 pre-
tax impairment charge of $109.2 million, or $99.7 million after tax, to write
down various aspects of its business, primarily related to contract operations
and construction. The assets determined to be impaired consisted of $79.4
million of goodwill, $26.4 million of property, plant and equipment, and $3.4
million of other assets. Our remaining investment in AquaSource, excluding
working capital after the impairment charge, is approximately $303.8 million as
of December 31, 2001.
DQE Financial has a twenty-year lease for the gas rights to New York City's
Fresh Kills landfill, where debris from the World Trade Center is being
transported. The excess weight resting on top of the landfill has caused damage
to the gas collection system as well as reduced available gas flows. Additional
security has caused construction delays. Management has determined that the
Fresh Kills investment has been impaired. DQE Financial also recognized a charge
due to asset abandonments or impairment at three other landfill gas sites. These
asset impairments resulted in a non-cash, pre-tax charge of $67.3 million, or
$43.7 million after tax in 2001.
We determined the value of the AquaSource and DQE Financial impairments by
projecting the undiscounted future cash flows generated by the specific assets
over the assets' expected lives. To the extent that the undiscounted future cash
flows did not exceed the book carrying value of the assets, the future cash
flows were discounted back at our cost of borrowing to determine the carrying
value of the assets. The impairment charge recorded is the difference between
the previous book carrying value and the carrying value determined by this
process.
During 2001, we formalized plans to monetize our DQE Enterprises business as
opportunities present themselves. This business is not consistent with our focus
on our core regulated utility businesses, and opportunities related to these
investments have not developed as expected due to market conditions. During
2001, Enterprises sold two investments and recognized an impairment charge to
write off all or parts of eleven other investments, resulting in a non-cash,
pre-tax charge of $61.7 million, or $36.1 million after tax.
We determined the value of the impairment of each of these investments by
analyzing their business prospects. This analysis included an evaluation of the
business' cash on-hand, its fundraising abilities, its number of customers and
contracts, and its overall ability to continue as a going concern. In addition,
we obtained an independent external valuation for certain of the businesses.
D. RESTRUCTURING CHARGE
During the fourth quarter of 2001, as part of our Back-to-Basics strategy, we
initiated a restructuring plan to improve operational effectiveness and
efficiency, and to reduce operational expenses on a company-wide basis. Through
the restructuring plan, we have reorganized to focus on our core regulated
utility businesses and opportunities related to these investments. In the fourth
quarter of 2001, we recorded a pre-tax restructuring charge of $31.1 million.
The restructuring charge included costs related to (1) the consolidation and
reduction of certain administrative and back-office functions through an
involuntary termination plan, (2) the abandonment of certain leased office
facilities to relocate employees to one centralized location, and (3) other
lease costs related to abandoned office facilities.
The following is a summary of the restructuring charge that was reflected as a
separately stated charge against operating income for the year ended December
31, 2001.
Restructuring Charge for the Year Ended December 31,
- --------------------------------------------------------------------------
(Thousands of Dollars)
--------------------------
2001
- --------------------------------------------------------------------------
Employee termination benefits $ 20,106
Facilities consolidation:
Future minimum lease payments 7,952
Other lease costs 3,027
- --------------------------------------------------------------------------
Total Restructuring Charge $ 31,085
==========================================================================
The employee-related termination benefits of $20.1 million primarily include
severance costs for approximately 200 management, professional and
administrative personnel.
The facilities consolidation involved relocation to our existing leased space
in downtown Pittsburgh. In December 2001, we extended the lease at this facility
to December 2011.
We accrued liabilities related to these restructuring actions in the period in
which we committed to execute the restructuring plan and communicated the plan
to employees. The following table summarizes the components of the accrued
restructuring liability for the period ended December 31, 2001.
32
Restructuring Liability at December 31,
- ------------------------------------------------------------------------------
(Thousands of Dollars)
-------------------------
2001
- ------------------------------------------------------------------------------
Beginning balance $ 28,774
Charges paid/incurred (4,294)
- ------------------------------------------------------------------------------
Ending Balance $ 24,480
==============================================================================
We believe that the remaining provision is adequate to complete the
restructuring plan. We also expect that the remaining restructuring liabilities
will be paid and/or incurred on a monthly basis throughout 2006.
E. ACQUISITIONS AND DISPOSITIONS
We sold our bottled water assets on May 15, 2001. The sale resulted in an
after tax loss of $15.0 million, of which $10.0 million had been recorded in
December 2000.
On July 16, 2001, the Allegheny County Airport Authority purchased the
Pittsburgh International Airport energy facility from a DQE Enterprises
subsidiary, and entered into a 15-year operations and maintenance agreement
regarding the facility with DQE Energy Services. The transaction resulted in an
approximate $8.4 million after-tax gain, or $0.15 per share.
In total, we received approximately $39 million in proceeds for these two
dispositions and other non-strategic investments in 2001. Also during 2001,
AquaSource acquired four water companies for approximately $0.9 million.
In the fourth quarter of 2001, we sold a significant portion of our remaining
affordable housing portfolio, receiving proceeds of approximately $34.0 million,
which approximated book value. We sold an office building, receiving proceeds of
$18.5 million, which approximated book value. We also sold 50,000 shares of
AquaSource Class A Common Stock to an unrelated third party, in exchange for
approximately $4.0 million of services.
During 2000, AquaSource invested approximately $11 million to acquire the
stock or assets of water and water-related companies through the purchase method
of accounting. These acquisitions were related to agreements entered into in
1999, and were consummated upon final regulatory approval in early 2000. There
were no additional acquisitions in 2000, as we implemented our integration
strategy to streamline and consolidate the water distribution business.
Additionally, Duquesne Light purchased the Customer Advanced Reliability
System (CARS) from Itron, Inc., which had developed this automated electronic
meter reading system for use with our electric utility customers. We had
previously leased these assets.
On April 28, 2000, Duquesne Light completed the sale of our generation assets
to Orion for approximately $1.7 billion. (See Note B.)
In 2000, we also received $287 million of proceeds from the sale of a water
utility system and various other non-strategic investments, including affordable
housing investments and DQE Energy Services' alternative fuel facilities. The
alternative fuel transaction includes a seven-year contract to operate several
of the facilities.
F. PROPERTY, PLANT AND EQUIPMENT
In April 2000, Duquesne Light sold its generation assets. Duquesne Light owns
9 transmission substations and 561 distribution substations (367 of which are
located on customer-owned land and are used to service only those customers).
Duquesne Light has 592 circuit-miles of transmission lines, comprised of
345,000, 138,000 and 69,000 volt lines. Street lighting and distribution
circuits of 23,000 volts and less include approximately 16,420 circuit-miles of
lines and cable. These properties are used in the electricity delivery business
segment.
AquaSource owns and operates over 450 investor-owned water and wastewater
systems and performs contract services for over 550 additional systems. These
systems are comprised of distribution and collection lines, pump stations,
treatment plants, storage tanks, reservoirs and related facilities. Properties
are adequately maintained, and units of property are replaced as and when
necessary. AquaSource owns a substantial acreage of land, the greater part of
which is located in watershed areas and used for the discharge of treated
effluent, with the balance being principally sites of pumping and treatment
plants, storage reservoirs, tanks and standpipes. These properties are used in
our water distribution business segment.
G. LONG - TERM INVESTMENTS
We have historically made equity investments in affordable housing,
alternative fuel and gas reserve partnerships as a limited partner. At December
31, 2001, we had investments in 5 affordable housing funds, 1 alternative fuel
partnership and 2 natural gas reserve sites. Additionally, we maintain
investments in landfill gas rights at 26 landfills. We are the lessor in 7
leveraged lease arrangements involving mining equipment, a waste-to-energy
facility, high-speed service ferries and natural gas processing equipment. These
leases expire in various years beginning in 2011 through 2037. The recorded
residual value of the equipment at the end of the lease terms is approximately
one percent of the original cost. Our aggregate investment
33
represents 20 percent of the aggregate original cost of the property, and is
either leased to a creditworthy lessee or is secured by guarantees of the
lessee's parent or affiliate. The remaining 80 percent was financed by non-
recourse debt, provided by lenders who have been granted, as their sole remedy
in the event of default by the lessees, an assignment of rentals due under the
leases and a security interest in the leased property. This debt amounted to
$866.2 million and $887.4 million at December 31, 2001 and 2000.
Net Leveraged Lease Investments At December 31,
- ---------------------------------------------------------------------------
(Thousands of Dollars)
-------------------------
2001 2000
- ---------------------------------------------------------------------------
Rentals receivable -- net $ 612,121 $ 612,872
Estimated residual value 11,510 11,510
Less: Unearned income (152,706) (181,774)
- ---------------------------------------------------------------------------
Leveraged lease investments 470,925 442,608
Less: Deferred taxes (340,088) (291,117)
- ---------------------------------------------------------------------------
Net Leveraged
Lease Investments $ 130,837 $ 151,491
===========================================================================
Our other investments include a waste-to-energy facility and other equipment.
Deferred income, as shown on the consolidated balance sheet, primarily relates
to certain gas reserve investments. Deferred amounts will be recognized as
income over the lives of the underlying investments for periods not exceeding 15
years from the time of investment.
We have sales-type leases relating to the leasing of our fiber optic network,
which are included in other long-term investments on the consolidated balance
sheet. Total minimum lease payments receivable totaled $23.0 million and $16.9
million at December 31, 2001 and 2000, respectively. In each year, no amounts
existed for: executory costs such as taxes, maintenance or insurance; allowance
for uncollectibles; or unguaranteed residual values of leased property.
Unearned income of $10.1 million and $6.6 million offset the minimum lease
payments receivable, for a net investment in sales-type leases of $12.9 million
and $10.3 million, at December 31, 2001 and 2000, respectively.
At December 31, 2001, minimum lease payments to be received for the next five
succeeding years were $2.3 million in each of the years 2002 through 2006.
H. SHORT - TERM BORROWING AND REVOLVING CREDIT ARRANGEMENTS
We maintain two separate revolving credit agreements, one for $200 million and
one for $150 million, both expiring in October 2002. We may convert the $150
million revolver into a term loan facility for a one-year period, for any
amounts then outstanding upon expiration of the revolving credit period.
Interest rates on both facilities can, in accordance with the option selected at
the time of the borrowing, be based on one of several indicators, including
prime and Eurodollar rates. Commitment fees are based on the unborrowed amount
of the commitment. At December 31, 2001 and 2000, no borrowings were
outstanding.
Under our credit facilities, we are subject to financial covenants requiring
DQE and Duquesne Light to maintain a maximum debt-to-capitalization ratio of 65
percent. In addition, DQE is required to maintain a minimum cash coverage ratio
of 2-to-1. At December 31, 2001 we were in compliance with these covenants,
having debt-to-capitalization ratios of 64.3 percent at DQE and 58.8 percent at
Duquesne Light and a cash coverage ratio of 2.6 percent at DQE.
During 2001, the maximum amount of bank loans and commercial paper borrowings
outstanding was $55 million, the amount of average daily borrowings was $22.7
million, and the weighted average daily interest rate was 4.79 percent.
I. INCOME TAXES
The annual federal corporate income tax returns have been audited by the
Internal Revenue Service (IRS) and are closed for the tax years through 1993.
The IRS examination of the 1994 tax year has been completed, and the IRS issued
a notice of proposed adjustment increasing our 1994 income tax liability in the
approximate amount of $22.0 million (including penalties and interest) with
respect to certain structured leasing transactions. We have protested and paid
the proposed IRS adjustments for 1994; that protest is currently pending with
the IRS Appeals Office. The IRS is currently auditing our 1995 through 1997 tax
returns, and the tax years 1998 through 2001 remain subject to IRS review. The
IRS has indicated that it is considering proposing adjustments to our reporting
for 1995 through 1997 of the same structured transactions that were the subject
of the 1994 proposed adjustment, as well as other similar transactions. If the
IRS were to propose adjustments to such transactions for the years 1995 through
2001 similar to those made for 1994, we would project that the proposed
assessment of additional tax would be approximately $175.0 million (to which
interest would be, and penalties may be, added). In addition, the IRS has
indicated that it may challenge other structured leasing transactions entered
into during the 1995 through 1997 period but has not yet proposed any
adjustments, and we are unable to quantify what those adjustments might be. In
connection with the sale of
34
50,000 shares of AquaSource Class A Common Stock (see Note E), we are
entitled to a net capital loss carryback resulting in a refund of previously
paid tax of approximately $55.0 million. It is our current intention to apply
this refund during 2002 toward any adjustments ultimately proposed. A tax
benefit for the capital loss carryback has not been recognized. While it is
impossible to predict whether or to what extent any IRS proposed adjustments for
the period 1994 through 2001 will be sustained, we do not believe that the
ultimate resolution of any of our federal income tax liability for the years
1994 through 2001 will have a material adverse effect on our financial position,
results of operations or cash flows.
Deferred Tax Assets (Liabilities) at December 31,
- --------------------------------------------------------------------------------
(Thousands of Dollars)
--------------------------
2001 2000
- --------------------------------------------------------------------------------
Tax benefit -- long term
investments $ 81,230 $ 81,230
Warwick Mine closing costs 14,536 16,643
Capital loss carryover 67,500 --
Restructuring charges and
impairments 57,750 --
Other 45,401 49,545
- --------------------------------------------------------------------------------
Deferred tax assets 266,417 147,418
- --------------------------------------------------------------------------------
Property depreciation (290,339) (291,420)
Leveraged leases (340,088) (291,117)
Transition costs (47,019) (138,733)
Regulatory assets (93,588) (98,236)
Loss on reacquired
debt unamortized (11,972) (12,601)
Other (94,840) (118,758)
- --------------------------------------------------------------------------------
Deferred tax liabilities (877,846) (950,865)
- --------------------------------------------------------------------------------
Net $(611,429) $ (803,447)
================================================================================
Income Tax Expense (Benefit)
- --------------------------------------------------------------------------------
(Thousands of Dollars)
---------------------------------
Year Ended December 31,
---------------------------------
2001 2000 1999
- --------------------------------------------------------------------------------
Current:
Federal $ 37,848 $ 273,912 $ 7,400
State 2,512 12,071 29,861
Deferred:
Federal (93,771) (207,992) 84,376
State (2,670) (7,641) (8,048)
ITC deferred - net -- -- (2,867)
- --------------------------------------------------------------------------------
Income Taxes $(56,081) $ 70,350 $110,722
================================================================================
Total income taxes differ from the amount computed by applying the statutory
federal income tax rate to income before income taxes, as set forth in the
following table.
Income Tax Expense Reconciliation
- --------------------------------------------------------------------------------
(Thousands of Dollars)
------------------------------------
Year Ended December 31,
------------------------------------
2001 2000 1999
- --------------------------------------------------------------------------------
Federal taxes at
statutory rate (35%) $ (73,312) $ 72,942 $109,248
Increase (decrease) in
taxes resulting from:
State income taxes (103) 2,880 14,178
Investment tax benefits (15,749) (9,136) (10,499)
Amortization of
non-deductible
goodwill 29,750 1,925 1,400
Amortization of
deferred ITC -- -- (2,867)
Other 3,333 1,739 (738)
- --------------------------------------------------------------------------------
Total Income Tax
Expense (Benefit) $ (56,081) $70,350 $110,722
================================================================================
J. LEASES
We lease office buildings, computer equipment, and other property and
equipment.
Capital Leases at December 31,
- ------------------------------------------------------------------------------
(Thousands of Dollars)
-----------------------------
2001 2000
- ------------------------------------------------------------------------------
Electric plant $ 10,231 $ 10,231
Less: Accumulated amortization (7,058) (6,486)
- ------------------------------------------------------------------------------
Capital Leases - Net $ 3,173 $ 3,745
==============================================================================
Summary of Rental Expense
- -------------------------------------------------------------------------------
(Thousands of Dollars)
------------------------------
Year Ended December 31,
------------------------------
2001 2000 1999
- -------------------------------------------------------------------------------
Operating leases $ 8,603 $ 18,143 $ 51,723
Amortization of capital leases 305 444 18,889
Interest on capital leases 1,173 1,042 1,512
- -------------------------------------------------------------------------------
Total Rental Payments $10,081 $ 19,629 $ 72,124
===============================================================================
35
Future Minimum Lease Payments
- ----------------------------------------------------------------------------
(Thousands of Dollars)
---------------------------------
Operating Capital
Year Ended December 31, Leases (a) Leases
- ----------------------------------------------------------------------------
2002 $ 5,700 $ 739
2003 5,683 739
2004 5,455 739
2005 3,804 739
2006 and thereafter 24,118 1,479
- ----------------------------------------------------------------------------
Total $ 44,760 $ 4,435
- ----------------------------------------------------------------------------
Less: Amount representing interest (1,262)
- ----------------------------------------------------------------------------
Present value $ 3,173
============================================================================
(a) Includes $8.0 million of projected rent payments expensed as part of the
2001 restructuring charge ($2.6 million, $2.6 million, $2.2 million, $0.4
million and $0.2 million in 2002, 2003, 2004, 2005 and 2006, respectively).
These future cash payments will decrease the restructuring liability.
Future minimum lease payments for operating leases are related principally to
certain corporate offices. Future minimum lease payments for capital leases are
related principally to building leases.
In December 2001, we amended the existing lease at our downtown Pittsburgh
facility and extended the lease term to December 2011. The lease agreement
contains one five-year renewal option.
K. COMMITMENTS AND CONTINGENCIES
Construction, Investments and Acquisitions
We estimate that we will spend, excluding AFC, approximately $70.0 million for
each of 2002, 2003 and 2004 for electric utility construction; and $53.0
million, $25.0 million and $19.0 million for water utility construction in 2002,
2003 and 2004. Additionally, our other business lines will spend approximately
$10.0 million, $8.0 million and $8.0 million for construction in 2002, 2003 and
2004.
Guarantees
As part of our investment portfolio in affordable housing, we have received
fees in exchange for guaranteeing a minimum defined yield to third-party
investors. The notional amount of such guarantees at December 31, 2001 was $83.3
million. A portion of the fees received has been deferred to absorb any required
payments with respect to our guarantees. Based on an evaluation of and recent
experience with the underlying housing projects, we believe that such deferrals
are ample for this purpose.
In connection with DQE Energy Services' sale, through a subsidiary, of its
alternative fuel facilities, DQE agreed to guarantee the subsidiary's obligation
under the sales agreement to indemnify the purchaser against breach of
warranties, representations or covenants. We do not believe this guarantee will
have any material impact on our results of operations, financial position or
cash flows.
Employees
Duquesne Light is renegotiating its labor contract with the International
Brotherhood of Electrical Workers (IBEW), which represents the majority of
Duquesne Light's 1,302 employees. The contract currently expires in September
2002.
Legal Proceedings
In October and November 2001, class action lawsuits were filed by purported
shareholders of DQE against DQE and David Marshall, DQE's former Chairman, in
the U.S. District Court for the Western District of Pennsylvania. The plaintiffs
allege that the defendants violated Sections 10(b) and 20(a) of the Securities
Exchange Act of 1934, and Rule 10b-5 promulgated thereunder, by issuing a series
of materially false and misleading statements between December 6, 2000 and April
30, 2001 concerning investments made by DQE Enterprises, Inc. and their impact
on DQE's current and future financial results. The plaintiffs claim that, as a
result of these statements, the price of DQE securities was artificially
inflated.
In February 2001, 39 former and current employees of AquaSource, all minority
investors in AquaSource, commenced an action against DQE, AquaSource and others
in the District Court of Harris County, Texas. The complaint alleges that the
defendants fraudulently induced the plaintiffs to agree to sell their AquaSource
stock back to AquaSource, and that defendants took actions intended to decrease
the value of the stock. Plaintiffs seek, among other things, an award of actual
damages not to exceed $100 million and exemplary damages not to exceed $400
million.
In the first quarter of 2001, DQE and AquaSource filed counterclaims alleging
that 10 plaintiffs who held key AquaSource management positions engaged in
deceptive practices designed to obtain funding for acquisitions and to make
those acquisitions appear to meet certain return on investment requirements, and
that all plaintiffs were unjustly enriched by such wrongful actions. DQE,
AquaSource and AquaSource Utility, Inc. also filed a counterclaim against two
plaintiffs alleging claims for breach of contract, breach of warranty,
indemnification, fraud, and unjust enrichment in connection with the acquisition
of various water and wastewater companies from such plaintiffs.
Although we cannot predict the ultimate outcome of these cases or estimate the
range of any potential loss that may be incurred in the litigation, we believe
that
36
the lawsuits are entirely without merit, strenuously deny all of the plaintiffs'
allegations of wrongdoing and believe we have meritorious defenses to the
plaintiffs' claims. We intend to vigorously defend these lawsuits.
Other
In 1992, the Pennsylvania Department of Environmental Protection (DEP) issued
Residual Waste Management Regulations governing the generation and management of
non-hazardous residual waste, such as coal ash. Following the generation asset
divestiture, Duquesne Light retained certain facilities which remain subject to
these regulations. We have assessed our residual waste management sites, and the
DEP has approved our compliance strategies. We incurred costs of $1.1 million in
2001 to comply with these DEP regulations. We expect the costs of compliance to
be approximately $1.4 million over the next two years with respect to sites we
will continue to own. These costs are being recovered in the CTC, and the
corresponding liability has been recorded for current and future obligations.
Duquesne Light owns, but does not operate, the Warwick Mine, including
approximately 1,200 acres of unmined coal lands and mining rights, located along
the Monongahela River in Greene County, Pennsylvania. This property had been
used in the electricity supply business segment. Duquesne Light's current
estimated liability for closing the Warwick Mine, including final site
reclamation, mine water treatment and certain labor liabilities, is
approximately $35 million. Duquesne Light has recorded a liability for this
amount on the consolidated balance sheet.
AquaSource is a party to consent agreements regarding environmental compliance
in three states. In Indiana, AquaSource has entered parallel agreements with the
Indiana Department of Environmental Management and the Indiana Utility
Regulatory Commission to establish a schedule for completing upgrades and
resolving certain historical compliance issues at two wastewater facilities.
AquaSource agreed to make approximately $28 million of capital improvements,
$11.4 million of which have been completed. The agreed-upon improvements are
proceeding on schedule. Neither agreement imposes any compliance-related
penalties or sanctions. AquaSource entered into a consent order with the Florida
Department of Environmental Protection regarding historical compliance issues.
AquaSource planned certain capital improvements in connection with its
acquisition of the five subject wastewater facilities, the completion of which
will resolve the compliance issues. AquaSource and the TNRCC have entered into a
consent agreement under which AquaSource will correct compliance issues at
approximately 160 water and wastewater systems in Texas over a four year period.
In lieu of any fines, penalties or other sanctions, AquaSource agreed to make
approximately $30 million in capital improvements to upgrade these systems,
$12.1 million of which have been completed. AquaSource is capitalizing all of
these expenditures, and will seek recovery of the charges through future rates,
if appropriate.
We are involved in various other legal proceedings and environmental matters.
We believe that such proceedings and matters, in total, will not have a
materially adverse effect on our financial position, results of operations or
cash flows.
L. EMPLOYEE BENEFIT
Pension and Postretirement Benefits
We maintain retirement plans to provide pensions for all eligible employees.
Upon retirement, an eligible employee receives a monthly pension based on his or
her length of service and compensation. The cost of funding the pension plan is
determined by the unit credit actuarial cost method. Our policy is to record
this cost as an expense and to fund the pension plans by an amount that is at
least equal to the minimum funding requirements of the Employee Retirement
Income Security Act of 1974, but which does not exceed the maximum tax-
deductible amount for the year. Pension costs charged (credited) to expense or
construction were ($20.7) million for 2001, ($13.1) million for 2000 and $12.8
million for 1999.
In 2001, we approved an amendment to the pension plan for a cost of living
adjustment for benefits for certain retirees. This caused an increase in the
Projected Benefit Obligation of $11.9 million.
In 1999, we offered an early retirement program for certain employees affected
by the generation asset divestiture. The total increase in the projected benefit
obligation to the retirement plans was estimated to be $29.4 million. Of this
amount, $17.4 million was recognized in 1999 as special termination benefits,
while the remaining $12.0 million was reflected in the unrecognized actuarial
gain/loss account. In its January 18, 2001 order approving our final generation
asset sale proceeds accounting, the PUC also approved recovery of costs
associated with the early retirement program. These recovered costs are to be
contributed to the pension plans over future years.
In addition to pension benefits, we provide certain health care benefits and
life insurance for some retired employees. The life insurance plan is non-
contributory. Participating retirees make contributions, which may be adjusted
annually, to the health care plan. Health care benefits terminate when retirees
reach age 65. We fund actual expenditures for obligations under the plans on a
"pay-as-you-go" basis. We have the right to modify or terminate the plans.
We accrue the actuarially determined costs of the aforementioned
postretirement benefits over the period
37
from the date of hire until the date the employee becomes fully eligible for
benefits. We have elected to amortize the transition obligation over a 20-year
period.
Due to significant increases in health care costs over recent years, the
health care trend assumption used in the development of the fiscal 2002 expense
will be increased to better reflect the current cost environment. The health
care trend assumption used in the development of the fiscal 2001 expense was
7.50 percent for fiscal year 2001, decreasing 0.50 percent per year to an
ultimate rate of 6.00 percent (reached in 2004). The health care trend
assumption reflected in the December 31, 2001 SFAS 106 year-end disclosure,
which will also be used in the development of fiscal 2002 expense, is 11.00
percent for fiscal year 2002, decreasing o.50 percent per year to an ultimate
rate of 5.75 percent (reached in 2013). Consistent with previous practice, a 1.5
percent spread between the discount rate (7.25 percent for 2002 expense) and the
ultimate health care cost trend rate will be maintained.
We sponsor several qualified and nonqualified pension plans and other
postretirement benefit plans for our employees. The following tables provide a
reconciliation of the changes in the plans' benefit obligations and fair value
of plan assets over the two-year period ended December 31, 2001, a statement of
the funded status as of December 31, 2001 and 2000, and a summary of assumptions
used in the measurement of our benefit obligation:
Funded Status of the Pension and Postretirement Benefit Plans at December 31,
- ----------------------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
-------------------------------------------------
Pension Postretirement
-------------------------------------------------
2001 2000 2001 2000
- ----------------------------------------------------------------------------------------------------------------------------
Change in benefit obligation:
Benefit obligation at beginning of year $ 555,651 $ 584,374 $ 33,322 $ 58,198
Service cost 5,963 7,039 1,386 1,632
Interest cost 40,031 40,146 2,655 2,916
Actuarial (gain) loss 4,472 (21,993) 12,389 (7,326)
Benefits paid (35,000) (36,810) (3,700) (3,749)
Plan amendments 11,924 -- -- (1,743)
Curtailment gains (344) (17,546) -- (21,948)
Settlements (800) (291) -- --
Special termination benefits -- 732 -- 5,342
- ----------------------------------------------------------------------------------------------------------------------------
Benefit obligation at end of year 581,897 555,651 (46,052) 33,322
- ----------------------------------------------------------------------------------------------------------------------------
Change in plan assets:
Fair value of plan assets at beginning of year 746,300 751,752 -- --
Actual return (loss) on plan assets (35,077) 30,941 -- --
Employer contributions -- -- -- --
Benefits paid (34,465) (36,394) -- --
- ----------------------------------------------------------------------------------------------------------------------------
Fair value of plan assets at end of year 676,758 746,299 -- --
- ----------------------------------------------------------------------------------------------------------------------------
Funded status 94,861 190,648 (46,052) (33,322)
Unrecognized net actuarial (gain) loss (170,724) (279,155) 5,080 (7,309)
Unrecognized prior service cost 24,328 14,439 -- --
Unrecognized net transition obligation 3,093 4,281 7,564 8,251
- ----------------------------------------------------------------------------------------------------------------------------
Accrued benefit cost $ (48,442) $ (69,787) $(33,408) $(32,380)
============================================================================================================================
Weighted-Average Assumptions as of December 31,
- ----------------------------------------------------------------------------------------------------------------------------
Pension Postretirement
---------------------------------------------------
2001 2000 2001 2000
- ----------------------------------------------------------------------------------------------------------------------------
Discount rate used to determine projected
benefits obligation 7.25% 7.50% 7.25% 7.50%
Assumed rate of return on plan assets 7.50% 7.50% --% --%
Assumed change in compensation levels 4.00% 4.25% --% --%
Ultimate health care cost trend rate --% --% 5.75% 6.00%
38
All of our plans for postretirement benefits, other than pensions, have no
plan assets. The aggregate benefit obligation for those plans was $46.1 million
as of December 31, 2001 and $33.3 million as of December 31, 2000. The
accumulated postretirement benefit obligation comprises the present value of the
estimated future benefits payable to current retirees, and a pro rata portion of
estimated benefits payable to active employees after retirement.
Following the early retirement program offered in 1999 (described previously)
the total increase in the projected benefit obligation of the postretirement
benefits was estimated to be $4.4 million. In 1999, this increase was reflected
in the unrecognized actuarial gain/loss account in the preceding table. The
PUC's January 18, 2001 order approved recovery of the postretirement benefits
costs associated with the early retirement program. The recovered costs are to
be used to offset the postretirement benefits for those employees.
Pension assets consist primarily of common stocks (exclusive of DQE common
stock), United States obligations and corporate debt securities.
Components of Net Pension Cost as of December 31,
- ------------------------------------------------------------------------------------------------
(Thousands of Dollars)
------------------------------------
2001 2000 1999
- ------------------------------------------------------------------------------------------------
Components of net pension cost:
Service cost $ 5,963 $ 7,039 $ 15,976
Interest cost 40,031 40,146 40,249
Expected return on plan assets (54,383) (51,270) (45,945)
Amortization of unrecognized net transition obligation 1,188 1,200 1,788
Amortization of prior service cost 1,889 2,017 3,467
Recognized net actuarial gain (15,363) (12,275) (2,753)
- ------------------------------------------------------------------------------------------------
Net pension (gain) cost (20,675) (13,143) 12,782
Curtailment cost (gain) 145 943 (14)
Settlement cost 560 287 78
Special termination benefits -- 732 17,376
- ------------------------------------------------------------------------------------------------
Net Pension (Gain) Cost After Curtailments,
Settlements and Special Termination Benefits $ (19,970) $(11,181) $ 30,222
================================================================================================
Components of Postretirement Cost as of December 31,
- ---------------------------------------------------------------------------------------------------
(Thousands of Dollars)
---------------------------------------
2001 2000 1999
- ---------------------------------------------------------------------------------------------------
Components of postretirement cost:
Service cost $ 1,386 $ 1,632 $ 2,212
Interest cost 2,655 2,916 3,134
Amortization of unrecognized net transition obligation 688 951 1,660
Amortization of prior service costs -- (7) --
Recognized net actuarial gain -- (17) --
- ---------------------------------------------------------------------------------------------------
Net postretirement cost 4,729 5,475 7,006
Curtailment (gain) cost -- (6,377) 2,443
Special termination benefits -- 5,342 --
- ---------------------------------------------------------------------------------------------------
Net Postretirement Cost After Curtailments $ 4,729 $ 4,440 $ 9,449
===================================================================================================
Effect of a One Percent Change in Health Care Cost Trend Rates as of December 31, 2001
- ----------------------------------------------------------------------------------------------------
(Thousands of Dollars)
-------------------------------
One Percent One Percent
Increase Decrease
- ----------------------------------------------------------------------------------------------------
Effect on total of service and interest cost components of
net periodic postretirement health care benefit cost $ 397 $ (349)
Effect on the health care component of the accumulated
postretirement benefit obligation $ 3,462 $ (3,087)
39
Retirement Savings Plan and other Benefit Options
We sponsor separate 401(k) retirement plans for our management and IBEW-
represented employees.
The 401(k) Retirement Savings Plan for Management Employees provides for
employer contributions which vary by DQE subsidiary. These contributions may
include one or more of the following: a participant base match, a participant
incentive match and automatic contributions. In 2001 and 2000, all employees
eligible for an incentive match achieved their incentive targets.
We are funding our automatic and matching contributions to the 401(k)
Retirement Savings Plan for Management Employees with payments to an ESOP
established in December 1991. (See Note O.) The 401(k) Retirement Savings Plan
for IBEW Represented Employees provides that we will match employee
contributions with a base match and an additional incentive match, if certain
targets are met. In 2001 and 2000, all IBEW-represented employees achieved their
incentive targets.
Our shareholders have approved a long-term incentive plan through which we may
grant management employees and directors options to purchase, during the years
1987 through 2006, up to a total of 9.9 million shares of DQE common stock at
prices equal to the fair market value of such stock on the dates the options
were granted.
The following tables summarize the transactions of our stock option plans for
the three-year period ended December 31, 2001, and certain information about
outstanding stock options as of December 31, 2001:
- -------------------------------------------------------------------------------------------------------------------------
(In Thousands)
- -------------------------------------------------------------------------------------------------------------------------
Number of Options Weighted Average Price
-----------------------------------------------------------------
2001 2000 1999 2001 2000 1999
-----------------------------------------------------------------
Options outstanding, beginning of year 1,292 1,031 1,231 $ 39.32 $ 30.28 $ 32.57
Options granted 1,120 697 258 $ 20.92 $ 42.65 $ 39.35
Options exercised (58) (409) (300) $ 37.72 $ 31.81 $ 29.69
Options canceled/forfeited (155) (27) (158) $ 38.07 $ 37.63 $ 39.81
-----------------------------------------------------------------
Options outstanding, end of year 2,199 1,292 1,031 $ 29.90 $ 39.32 $ 30.28
-----------------------------------------------------------------
Options exercisable, end of year 873 770 651 $ 38.18 $ 37.91 $ 33.80
-----------------------------------------------------------------
Shares available for future grants, end of year 2,690 3,091 3,678
-------------------------------
As of December 31, 2001, 2000 and 1999, stock appreciation rights (SARs) had
been granted in connection with 1,036,373; 975,292 and 933,014 of the options
outstanding. During 2001, 2000 and 1999, 58,061; 208,236 and 45,265 SARs were
exercised. During December 2001, 787,300 stock options were granted to employees
with an exercise price of $16.90 per share.
One half of these options become exercisable only if the closing price on the
New York Stock Exchange of DQE's common stock averages $19.56 for 30 consecutive
trading days, with the remainder becoming exercisable under the same terms at a
target price of $22.49 per share. The options vest over an 18 month period from
the date of grant.
- -------------------------------------------------------------------------------------------------------------------
Outstanding Exercisable
- -------------------------------------------------------------------------------------------------------------------
Number Remaining Weighted Number Weighted
of Options Life Average of Options Average
Exercise Price Range (In Thousands) (In Years) Exercise Price (In Thousands) Exercise Price
- -------------------------------------------------------------------------------------------------------------------
Under $20 813 9.9 $ 16.97 -- --
$20 - $30 66 2.8 $ 25.54 66 $ 25.54
$30 - $40 673 4.9 $ 33.36 379 $ 34.98
Over $40 647 5.5 $ 42.93 428 $ 42.68
- -------------------------------------------------------------------------------------------------------------------
Options, End of Year 2,199 873
===================================================================================================================
40
M.LONG-TERM DEBT
Long-Term Debt at December 31.
- ----------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
------------------------------
Interest Principal Outstanding
Rate Maturity 2001 2000
- ----------------------------------------------------------------------------------------------------------------
First mortgage bonds (a) 6.450%-8.375% 2003-2038 $ 643,000 $ 643,000
Pollution control notes Adjustable (b) 2009-2030 417,985 417,985
Floating rate notes 2.9% 2002 - (c) 150,000
Public income notes 8.38% 2039 100,000 100,000
Economic development revenue bonds 5.5%-8.75% 2001-2024 10,190 10,190
Sinking fund debentures 5.00% 2010 2,791 2,791
Miscellaneous 30,713 31,768
Less: Unamortized debt discoun and premium - net (5,920) (6,436)
- ----------------------------------------------------------------------------------------------------------------
Total Long-Term Debt $ 1,198,759 $1,349,298
================================================================================================================
(a) Includes $100 million of first mortgage bonds not callable until 2003.
(b) The pollution control notes have adjustable interest rates. The interest
rates at year-end averaged 1.7 percent in 2001 and 4.7 percent in 2000.
(c) Excludes $150 million that matured on January 15, 2002.
At December 31, 2001, sinking fund requirements and maturities of long-term
debt outstanding for the next five years were $151.4 million in 2002, $100.9
million in 2003, $101.4 million in 2004, $1.5 million in 2005 and $1.6 million
in 2006.
Total interest and other charges were $104.4 million in 2001, $123.6 million
in 2000 and $158.7 million in 1999. Interest costs attributable to debt were
$89.0 million, $109.7 million and $107.7 million in 2001, 2000 and 1999,
respectively. Of the interest costs attributable to debt, $0.6 million in 2001,
$2.0 million in 2000 and $0.8 million in 1999 were capitalized as AFC. Debt
discount or premium and related issuance expenses are amortized over the lives
of the applicable issues. Interest and other charges in 1999 also includes $35.2
million related to the Beaver Valley Unit 2 lease expense.
At December 31, 2001, the fair value of long-term debt, including current
maturities and sinking fund requirements, estimated on the basis of quoted
market prices for the same or similar issues, or current rates offered for debt
of the same remaining maturities, was $1,406.7 million. The principal amount
included in the consolidated balance sheet, excluding unamortized discounts and
premiums, is $1,356.0 million.
At December 31, 2001 and 2000, we were in compliance with all of our debt
covenants.
N. DUQUESNE LIGHT COMPANY OBLIGATED MANDATORILY REDEEMABLE PREFERRED TRUST
SECURITIES
Duquesne Capital L.P., a special-purpose limited partnership of which Duquesne
Light is the sole general partner, has outstanding $150.0 million principal
amount of 8 3/8 percent Monthly Income Preferred Securities, Series A (MIPS),
each with a stated liquidation value of $25.00. At December 31, 2001, there were
six million shares authorized and outstanding. The holders of MIPS are entitled
to distributions at the annual rate of 8 3/8 percent, payable monthly. MIPS
dividends included in interest and other charges were $12.6 million in 2001,
2000 and 1999. Duquesne Capital, at the direction of Duquesne Light, has the
option to redeem the MIPS at any time, in whole or in part. The MIPS are also
subject to mandatory redemption at the maturity of the Debentures referred to
below.
Duquesne Capital applied the proceeds of the sale of the MIPS, together with
certain other funds, to the purchase from Duquesne Light of $151.5 million
principal amount of Duquesne Light's 8 3/8 percent Subordinated Deferrable
Interest Debentures, Series A, due May 31, 2044 (Debentures). The Debentures are
Duquesne Capital's sole assets, and Duquesne Capital has no business activity
other than holding the Debentures. Duquesne Light has guaranteed the payment of
distributions on, and redemption price and liquidation amount in respect of the
MIPS, to the extent that Duquesne Capital has funds available for such payment
from the Debentures. Upon any redemption of the MIPS, the Debentures will be
mandatorily redeemed.
41
O. PREFERRED AND PREFERENCE STOCK
Preferred and Preference Stock at December 31,
- -----------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
----------------------------------------------------------
Call Price 2001 2000
----------------------------------------------------------
Per Share Shares Amount Shares Amount
- -----------------------------------------------------------------------------------------------------------------
Preferred Stock of DQE:
Series A Preferred Stock (a) -- 163,520 $ 16,352 173,611 $ 17,361
- -----------------------------------------------------------------------------------------------------------------
Preferred Stock Series of Subsidiaries:
3.75%(b) $ 51.00 148,000 7,407 148,000 7,407
4.00%(b) 51.50 549,709 27,486 549,709 27,486
4.10%(b) 51.75 119,860 6,012 119,860 6,012
4.15%(b) 51.73 132,450 6,643 132,450 6,643
4.20%(b) 51.71 100,000 5,021 100,000 5,021
$2.10 (b) 51.84 159,400 8,039 159,400 8,039
6.5%(c) -- 15 1,500 15 1,500
6.5%(d) -- 10 500 10 500
- -----------------------------------------------------------------------------------------------------------------
Total Preferred Stock of Subsidiaries 62,608 62,608
- -----------------------------------------------------------------------------------------------------------------
Preference Stock Series of Subsidiaries:
Plan Series A (e) 35.50 558,673 17,239 579,276 18,028
- -----------------------------------------------------------------------------------------------------------------
Deferred ESOP benefit (3,363) (6,583)
- -----------------------------------------------------------------------------------------------------------------
Total Preferred and Preference Stock $ 92,836 $ 91,414
=================================================================================================================
(a) 1,000,000 authorized shares; no par value; convertible; $100 liquidation
preference per share; annual dividends range from 3.6 percent to 4.3
percent.
(b) 4,000,000 authorized shares; $50 par value; cumulative; $50 per share
involuntary liquidation value.
(c) 1,500 authorized shares; $100,000 par value; $100,000 involuntary
liquidation value; holders entitled to 6.5 percent annual dividend each
September; $100,000 redemption price per share in 2018.
(d) 100 authorized shares; $50,000 par value; $50,000 per share involuntary
liquidation value; holders entitled to 6.5 percent annual dividend each
September; $50,000 redemption price per share in 2019.
(e) 8,000,000 authorized shares; $1 par value; cumulative; $35.50 per share
involuntary liquidation value in 2001; $35.78 per share involuntary
liquidation value in 2000.
As of December 31, 2001, 163,520 shares of DQE preferred stock were
outstanding, following the repurchase of 10,091 shares during 2001. These
preferred shares were repurchased below liquidation value, favorably impacting
our earnings available for common shareholders. The accounting for these
transactions, in accordance with accounting principles generally accepted in the
United States of America, enabled us to record a credit to preferred stock
dividends in the period of the repurchase for the amount by which the market
value of the securities exceeded the repurchase price. The DQE preferred stock
ranks senior to DQE's common stock as to the payment of dividends and the
distribution of assets on liquidation, dissolution or winding-up of DQE.
Dividends are paid quarterly on each January 1, April 1, July 1 and October 1.
Holders of DQE preferred stock are entitled to vote on all matters submitted to
a vote of the holders of DQE common stock, voting together with the holders of
common stock as a single class. Each share of DQE preferred stock is entitled to
three votes. Each share of DQE preferred stock is convertible at our option into
the number of shares of DQE common stock computed by dividing the DQE preferred
stock's $100 liquidation value by the five-day average closing sales price of
DQE common stock for the five trading days immediately prior to the conversion
date. Each unredeemed share of DQE preferred stock will automatically be
converted on the first day of the first month commencing after the sixth
anniversary of its issuance.
Holders of Duquesne Light's preferred stock are entitled to cumulative
quarterly dividends. If four quarterly dividends on any series of preferred
stock are in arrears, holders of the preferred stock are entitled to elect a
majority of Duquesne Light's board of directors until all dividends have been
paid. Holders of Duquesne Light's preference stock are entitled to receive
42
cumulative quarterly dividends, if dividends on all series of preferred stock
are paid. If six quarterly dividends on any series of preference stock are in
arrears, holders of the preference stock are entitled to elect two of Duquesne
Light's directors until all dividends have been paid. At December 31, 2001,
Duquesne Light had made all dividend payments. Preferred and preference
dividends of subsidiaries included in interest and other charges were $3.6
million, $3.5 million and $4.1 million in 2001, 2000 and 1999. Total preferred
and preference stock had involuntary liquidation values of $98.7 million and
$100.4 million, which exceeded par by $19.3 million and $20.0 million, at
December 31, 2001 and 2000. Outstanding preferred stock is generally callable on
notice of not less than 30 days, at stated prices plus accrued dividends. The
outstanding preference stock is callable at the liquidation price plus accrued
dividends. None of the remaining Duquesne Light preferred or preference stock
issues has mandatory purchase requirements.
We have an Employee Stock Ownership Plan (ESOP) to provide matching
contributions for a 401(k) Retirement Savings Plan for Management Employees.
(See Note L.) We issued and sold 845,070 shares of preference stock, plan series
A, to the trustee of the ESOP. As consideration for the stock, we received a
note valued at $30 million from the trustee. The preference stock has an annual
dividend rate of $2.80 per share, and each share of the preference stock is
exchangeable for one and one-half shares of DQE common stock. At December 31,
2001, $17.2 million of preference stock issued in connection with the
establishment of the ESOP had been offset, for financial statement purposes, by
a $3.4 million deferred ESOP benefit. Dividends on the preference stock and cash
contributions from DQE are used to fund the repayment of the ESOP note. We made
cash contributions of approximately $1.5 million, $1.0 million and $0.2 million
for 2001, 2000 and 1999. These cash contributions were the difference between
the ESOP debt service and the amount of dividends on ESOP shares ($1.6 million
in 2001, $1.7 million in 2000 and $2.1 million in 1999). As shares of preference
stock are allocated to the accounts of participants in the ESOP, we recognize
compensation expense, and the amount of the deferred compensation benefit is
amortized. We recognized compensation expense related to the 401(k) plans of
$3.1 million in 2001 and $3.6 million in 2000 and 1999.
P. EQUITY
Changes in the Number of Shares of DQE Common Stock
Outstanding as of December 31,
- ----------------------------------------------------------
(Thousands of Shares)
----------------------------
2001 2000 1999
- ----------------------------------------------------------
January 1 55,886 71,766 77,373
Reissuances 39 272 61
Repurchases (17) (16,152) (5,668)
- ----------------------------------------------------------
December 31 55,908 55,886 71,766
==========================================================
We have continuously paid dividends on common stock since 1953. Our annualized
dividends per share were $1.68, $1.68 and $1.60 at December 31, 2001, 2000 and
1999. During 2001, we paid a quarterly dividend of $0.42 per share on January 1,
April 1, July 1 and October 1. During 2000, we paid a quarterly dividend of
$0.40 per share on January 1, April 1 and July 1 and $0.42 per share on October
1. The quarterly dividend declared in the fourth quarter of 2001, payable
January 1, 2002, was $0.42 per share.
Once all dividends on DQE preferred stock have been paid, dividends may be
paid on our common stock as permitted by law and as declared by the board of
directors. Because we own all of Duquesne Light's common stock, if Duquesne
Light cannot pay common dividends, we may not be able to pay dividends on our
common stock or DQE preferred stock. Payments of dividends on Duquesne Light's
common stock may be restricted by Duquesne Light's obligations to holders of its
preferred and preference stock, pursuant to Duquesne Light's Restated Articles
of Incorporation, and by obligations of a Duquesne Light subsidiary to holders
of its preferred securities. No dividends or distributions may be made on
Duquesne Light's common stock if Duquesne Light has not paid dividends or
sinking fund obligations on its preferred or preference stock. Further, the
aggregate amount of Duquesne Light's common stock dividend payments or
distributions may not exceed certain percentages of net income, if the ratio of
total common shareholder's equity to total capitalization is less than specified
percentages. No part of the retained earnings of DQE was restricted at December
31, 2001.
Accumulated Other Comprehensive Income
Balances as of December 31,
- -------------------------------------------------------------
(Thousands of Dollars)
--------------------------
2001 2000
- -------------------------------------------------------------
January 1 $ 28,459 $ 1,834
Unrealized gains (losses), net of
tax of $(14,953) and $14,337 (27,770) 26,625
- -------------------------------------------------------------
December 31 $ 689 $ 28,459
=============================================================
43
Q. SUPPLEMENTAL CASH FLOW DISCLOSURES
Changes in Working Capital Other than Cash (a)
for the Year Ended December 31,
- ----------------------------------------------------------------------------
(Thousands of Dollars)
-----------------------------------
2001 2000 1999
- ----------------------------------------------------------------------------
Receivables $ 33,473 $ (10,582) $ (17,303)
Materials and supplies 1,911 (8,957) 40,347
Other current assets (75,999) (30,600) (67,634)
Accounts payable (56,588) 12,887 (15,859)
Other current liabilities 3,325 144,659 2,392
- ----------------------------------------------------------------------------
Total $(93,878) $ 107,407 $ (58,057)
============================================================================
(a) The amounts shown exclude the effects of acquisitions and dispositions,
impairments and restructuring charges.
Non-cash Investing and Financing Activities for the Year Ended December 31,
- -------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
------------------------------------
2001 2000 1999
- --------------------------------------------------------------------------------------------------------------
Assumption of debt in conjunction with Beaver Valley 2 lease termination $ -- $ -- $ 359,236
Preferred stock issued in conjunction with acquisitions $ -- $ -- $ 8,634
- --------------------------------------------------------------------------------------------------------------
On December 3, 1999, we acquired three power plants and disposed of our
ownership interests in five power plants in the power station exchange with
FirstEnergy. On April 28, 2000, we disposed of our ownership in all of our power
plants, including the aforementioned five, in the generation asset sale to
Orion.
- --------------------------------------------------------------------------------
R. BUSINESS SEGMENTS AND RELATED INFORMATION
We report the results of our business segments, determined by products,
services and regulatory environment as follows: (1) Duquesne Light's
transmission and distribution of electricity (electricity delivery business
segment), (2) Duquesne Light's supply of electricity (electricity supply
business segment), (3) Duquesne Light's collection of transition costs (CTC
business segment), (4) AquaSource's management of water systems (water
distribution business segment), (5) DQE Energy Services' development, operation
and maintenance of energy and alternative fuel facilities (Energy Services
business segment), (6) DQE Financial's collection and processing of landfill gas
and management of structured finance and alternative energy investments
(Financial business segment) and (7) DQE Enterprises' management of electronic
commerce, energy services and technologies, and communications investment
portfolios (Enterprises business segment). With the completion of our generation
asset sale in April 2000, the electricity supply business segment is now
comprised solely of provider of last resort service. We also report an "all
other" category, to include our other subsidiaries below the quantitative
threshold for disclosure, and corporate administrative functions, financing, and
insurance services for our various affiliates. Operating revenues in our "all
other" category are comprised of revenues from our propane delivery and
telecommunications business lines.
44
Business Segments as of December 31,
- ------------------------------------------------------------------------------------------------------------------------------------
(Millions of Dollars)
------------------------------------------------------------------------------------------------------
Electricity Electricity Water Energy All Elimina- Consoli-
Delivery Supply CTC Distribution Services Financial Enterprises Other tions dated
------------------------------------------------------------------------------------------------------
2001
- ------------------------------------------------------------------------------------------------------------------------------------
Operating revenues $ 319.6 $ 430.3 $ 303.7 $ 109.0 $ 31.3 $ 22.7 $ 14.8 $ 73.7 $ (9.0) $1,296.1
Operating expenses 147.9 430.3 13.5 92.9 27.7 42.7 13.4 80.4 (14.4) 834.4
Depreciation and amortization
expense 59.7 -- 271.3 16.1 1.9 3.7 2.4 15.8 -- 370.9
- -----------------------------------------------------------------------------------------------------------------------------------
Operating income (loss) 112.0 -- 18.9 -- 1.7 (23.7) (1.0) (22.5) 5.4 90.8
Other income (expense) (1) 39.7 -- -- 2.3 9.2 69.1 17.7 (17.7) (37.4) 82.9
Interest and other charges (1) 78.4 -- -- 1.1 0.6 6.0 0.1 48.1 (29.9) 104.4
- ------------------------------------------------------------------------------------------------------------------ ----------------
Income (loss) before taxes 73.3 -- 18.9 1.2 10.3 39.4 16.6 (88.3) (2.1) 69.3
Income taxes 28.9 -- 6.6 1.9 4.0 (1.7) 5.8 (28.4) -- 17.1
- -----------------------------------------------------------------------------------------------------------------------------------
Net income (loss) before
impairment
and restructuring charges 44.4 -- 12.3 (0.7) 6.3 41.1 10.8 (59.9) (2.1) 52.2
Impairment charge, net of tax -- -- -- (99.7) -- (43.7) (36.1) (6.2) -- (185.7)
Restructuring charge, net of tax (6.7) -- -- -- -- -- -- (13.2) -- (19.9)
- -----------------------------------------------------------------------------------------------------------------------------------
Net income (loss) $ 37.7 $ -- $ 12.3 $ (100.4) $ 6.3 $ (2.6) $(25.3) $(79.3) $ (2.1) $ (153.4)
===================================================================================================================================
Assets $1,702.5 $ -- $ 134.3 $ 346.5 $ 35.2 $ 623.6 $ 35.2 $348.6 $ -- $3,225.9
===================================================================================================================================
Capital expenditures $ 59.1 $ -- $ -- $ 39.5 $ 1.4 $ 52.7 $ 0.1 $ 9.4 $ -- $3,162.2
===================================================================================================================================
(1) Excludes intercompany interest charges.
45
Business Segments as of December 31,
- ------------------------------------------------------------------------------------------------------------------------------------
(Millions of Dollars)
---------------------------------------------------------------------------------------------------------
Electricity Electricity Water Energy All Elimin- Consoli-
Delivery Supply CTC Distribution Services Financial Enterprises Other ations dated
---------------------------------------------------------------------------------------------------------
2000
- ------------------------------------------------------------------------------------------------------------------------------------
Operating revenues $ 316.1 $ 425.4 $ 334.4 $112.2 $ 19.8 $ 20.8 $ 22.6 $ 89.3 $ (13.0) $1,327.6
Operating expenses 167.5 419.9 14.7 121.4 21.9 39.9 20.0 111.2 (36.4) 880.1
Depreciation and
amortization expense 56.4 2.2 249.6 17.2 5.1 3.3 3.4 6.0 -- 343.2
- ------------------------------------------------------------------------------------------------------------------------------------
Operating income (loss) 92.2 3.3 70.1 (26.4) (7.2) (22.4) (0.8) (27.9) 23.4 104.3
Other income (expense) (1) 37.3 3.0 -- 9.3 163.8 68.4 9.4 (18.6) (44.9) 227.7
Interest and other
charges (1) 69.5 21.2 -- 1.1 0.4 9.9 0.7 40.2 (19.4) 123.6
- ------------------------------------------------------------------------------------------------------------------------------------
Income (loss) before
taxes and cumulative
effect 60.0 (14.9) 70.1 (18.2) 156.2 36.1 7.9 (86.7) (2.1) 208.4
Income taxes 23.9 (6.9) 24.5 (10.3) 58.0 (0.7) 2.2 (20.4) -- 70.3
- ------------------------------------------------------------------------------------------------------------------------------------
Net income (loss) before
cumulative effect $ 36.1 $ (8.0) $ 45.6 $ (7.9) $ 98.2 $ 36.8 $ 5.7 $(66.3) $ (2.1) $ 138.1
Cumulative effect 7.3 8.2 -- -- -- -- -- -- -- 15.5
- ------------------------------------------------------------------------------------------------------------------------------------
Net income (loss) $ 43.4 $ 0.2 $ 45.6 $ (7.9) $ 98.2 $ 36.8 $ 5.7 $(66.3) $ (2.1) $ 153.6
====================================================================================================================================
Assets $1,843.2 $ -- $ 396.4 $494.3 $ 28.8 $689.8 $163.6 $228.1 $ -- $3,844.2
====================================================================================================================================
Capital expenditures $ 85.1 $ 4.7 $ -- $ 44.8 $ 8.0 $ 6.0 $ 0.5 $ 0.9 $ -- $ 150.0
====================================================================================================================================
(1) Excludes intercompany interest charges.
46
Business Segments as of December 31,
- ------------------------------------------------------------------------------------------------------------------------------------
(Millions of Dollars)
--------------------------------------------------------------------------------------------------------
Electricity Electricity Water Energy All Elimin- Consoli-
Delivery Supply CTC Distribution Services Financial Enterprises Other ations dated
---------------------------------------------------------------------------------------------------------
1999
- ------------------------------------------------------------------------------------------------------------------------------------
Operating revenues $ 307.0 $ 528.5 $ 323.3 $101.7 $ 17.0 $ 21.9 $ 23.2 $ 31.4 $ (12.8) $1,341.2
Operating expenses 178.9 457.4 16.6 79.4 29.0 24.4 21.3 32.0 (12.9) 826.1
Depreciation and
amortization expense 50.5 26.3 95.6 12.1 3.4 2.3 4.3 1.8 -- 196.3
- ------------------------------------------------------------------------------------------------------------------------------------
Operating income (loss) 77.6 44.8 211.1 10.2 (15.4) (4.8) (2.4) (2.4) 0.1 318.8
Other income (1) 38.0 11.1 -- 4.4 3.9 72.8 22.7 2.9 (3.8) 152.0
Interest and other
charges (1) 45.9 43.9 45.4 1.4 0.7 14.1 2.3 6.3 (1.3) 158.7
- ------------------------------------------------------------------------------------------------------------------------------------
Income (loss) before
taxes 69.7 12.0 165.7 13.2 (12.2) 53.9 18.0 (5.8) (2.4) 312.1
Income taxes 30.9 0.4 69.1 2.4 (5.9) 6.9 6.9 (0.1) 0.1 110.7
- ------------------------------------------------------------------------------------------------------------------------------------
Net income (loss) $ 38.8 $ 11.6 $ 96.6 $ 10.8 $ (6.3) $ 47.0 $ 11.1 $ (5.7) $ (2.5) $ 201.4
====================================================================================================================================
Assets $1,527.4 $ 425.7 $2,226.8 $404.4 $ 71.9 $730.4 $ 98.5 $115.9 $ -- $5,601.0
====================================================================================================================================
Capital expenditures $ 69.0 $ 30.4 $ -- $ 27.2 $ 6.9 $ -- $ 3.3 $ 10.4 $ -- $ 147.2
====================================================================================================================================
(1) Excludes intercompany interest charges.
47
S. QUARTERLY FINANCIAL
INFORMATION (UNAUDITED)
Summary of Selected Quarterly Financial Data (Thousands of Dollars, Except Per Share Amounts)
- ---------------------------------------------------------------------------------------------------------------------------
[The quarterly data reflect seasonal weather variations in the electric utilty's service territory.]
- ---------------------------------------------------------------------------------------------------------------------------
2001 First Quarter Second Quarter Third Quarter Fourth Quarter
- ---------------------------------------------------------------------------------------------------------------------------
Operating revenues $ 320,514 $ 313,415 $ 351,502 $ 310,651
Operating income (loss) 24,526 (83,271) 25,613 (83,629)
Net income (loss) 12,223 (121,760)(a) 22,720 (66,564)(b)
Basic earnings (loss) per share 0.22 (2.18) 0.40 (1.19)
Stock price:
High 33.15 30.90 22.57 20.36
Low 28.80 21.00 20.36 16.68
===========================================================================================================================
2000 (C) First Quarter Second Quarter Third Quarter Fourth Quarter
- ---------------------------------------------------------------------------------------------------------------------------
Operating revenues $ 310,099 $ 328,643 $ 352,280 $ 336,582
Operating income 50,152 2,722 9,482 41,933
Income before cumulative effect of a
change in accounting principle 42,932 10,409 62,427 22,288
Net income 58,427 10,409 62,427 (d) 22,288
Basic earnings per share:
Before cumulative effect of a change
in accounting principle 0.57 0.19 1.00 0.43
Cumulative effect of a change
in accounting principle 0.25 -- -- --
After cumulative effect of a change
in accounting principle 0.82 0.19 1.00 0.43
Stock price:
High 48.50 45.00 43.02 40.38
Low 37.63 38.00 37.06 30.75
===========================================================================================================================
(a) Second quarter results include impairment charges booked at AquaSource
($99.7 million after tax) and DQE Enterprises ($27.7 million after tax).
(See Note C.) These charges are related to asset and investment write-downs.
(b) Fourth quarter results include impairment charges at DQE Financial and DQE
Enterprises of $43.7 million after tax and $8.4 million after tax,
respectively. (See Note C.) These charges are related to asset and
investment write-downs and asset abandonments. Restructuring charges at DQE
and Duquesne Light of $13.2 million after tax and $6.7 million after tax,
respectively, are also included in fourth quarter results. (See Note D.)
These charges are related to the consolidation and relocation associated
with our Back-to-Basics strategy.
(c) Restated to reflect the cumulative effect of a change in accounting
principle related to unbilled revenues.
(d) Includes gain on sale of alternative fuel facilities.
______________________________________
Selected Financial Data
- --------------------------------------------------------------------------------
(Millions of Dollars Except Per Share Amounts)
- --------------------------------------------------------------------------------------------------------------------------
2001 2000 1999 1998 1997 1996
- --------------------------------------------------------------------------------------------------------------------------
INCOME STATEMENT ITEMS
Total operating revenues $ 1,296.1 $ 1,327.6 $ 1,341.2 $ 1,254.6 $ 1,230.2 $ 1,236.7
Operating income (loss) (116.8) 104.3 318.8 272.4 280.7 303.0
Income (loss) before taxes, cumulative
effect and extraordinary item (209.5) 208.4 312.1 297.6 294.9 266.5
Income taxes (56.1) 70.3 110.7 101.0 95.8 87.4
Cumulative effect of change
in accounting principle -- 15.5 -- -- -- --
Extraordinary item -- -- -- 82.5 -- --
Net income (loss) (153.4) 153.6 201.4 114.1 199.1 179.1
Basic EPS (2.75) 2.44 2.65 1.46 2.57 2.32
- --------------------------------------------------------------------------------------------------------------------------
BALANCE SHEET ITEMS
Property, plant and equipment - net $ 1,688.3 $ 1,693.9 $ 1,820.0 $ 1,715.0 $ 2,662.3 $ 2,817.5
Total assets 3,225.9 3,844.2 5,601.0 5,366.0 4,694.4 4,639.0
- --------------------------------------------------------------------------------------------------------------------------
Capitalization:
Common shareholder's equity 508.5 783.8 1,347.8 1,477.4 1,499.1 1,391.9
Preferred and preference stock 92.8 91.4 122.2 113.6 78.1 73.1
DLC obligated mandatorily redeemable
preferred trust securities 150.0 150.0 150.0 150.0 150.0 150.0
Long-term debt 1,198.8 1,349.3 1,633.1 1,357.7 1,376.1 1,439.7
- --------------------------------------------------------------------------------------------------------------------------
Total capitalization $ 1,950.1 $ 2,374.5 $ 3,253.1 $ 3,098.7 $ 3,103.3 $ 3,054.7
- --------------------------------------------------------------------------------------------------------------------------
Dividends declared per share $ 1.68 $ 1.62 $ 1.54 $ 1.46 $ 1.38 $ 1.30
- --------------------------------------------------------------------------------------------------------------------------
49
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE.
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT.
Information relating to our Directors is set forth in the Proxy Statement
for the DQE Annual Meeting of Stockholders to be held June 26, 2002, which will
be distributed to stockholders in late April 2002. The information is
incorporated here by reference. Information relating to our executive officers
is set forth in Part I of this Report under the caption "Executive Officers of
the Registrant."
ITEM 11. EXECUTIVE COMPENSATION.
Information relating to executive compensation is set forth in the Proxy
Statement for the DQE Annual Meeting of Stockholders to be held June 26, 2002,
which will be distributed to stockholders in late April 2002. The information is
incorporated here by reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT.
Information relating to our equity compensation plans and the ownership of
DQE equity securities by our directors, officers and certain beneficial owners
is set forth in the Proxy Statement for the DQE Annual Meeting of Stockholders
to be held June 26, 2002, which will be distributed to stockholders in late
April 2002. The information is incorporated here by reference.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
Information relating to certain relationships and related transactions is
set forth in the Proxy Statement for the DQE Annual Meeting of Stockholders to
be held June 26, 2002, which will be distributed to stockholders in late April
2002. The information is incorporated here by reference.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K.
(a)(1) The following information is set forth in Part II, Item 8
(Consolidated Financial Statements and Supplementary Data) of this Report. The
following financial statements and Independent Auditors' Report are incorporated
here by reference:
Independent Auditors' Report.
Consolidated Statements of Income for the Three Years Ended December 31,
2001.
Consolidated Balance Sheets, December 31, 2001 and 2000.
Consolidated Statements of Cash Flows for the Three Years Ended December
31, 2001.
Consolidated Statements of Comprehensive Income for the Three Years Ended
December 31, 2001.
Consolidated Statements of Retained Earnings for the Three Years Ended
December 31, 2001.
Notes to Consolidated Financial Statements.
(a)(2) The following financial statement schedule and the related
Independent Auditors' Report are filed here as a part of this Report:
Schedule for the Three Years Ended December 31, 2001:
II - Valuation and Qualifying Accounts.
The remaining schedules are omitted because of the absence of the
conditions under which they are required or because the information called for
is shown in the financial statements or notes to the consolidated financial
statements.
(a)(3) Exhibits are set forth in the Exhibit Index below, incorporated here
by reference. Documents other than those designated as being filed here are
incorporated here by reference. Documents incorporated by reference to a DQE
Annual Report on Form 10-K, a Quarterly Report on Form 10-Q or a Current Report
on Form 8-K are at Securities and Exchange Commission File No. 1-10290.
Documents incorporated by reference to a Duquesne Light Company Annual Report on
Form 10-K, a Quarterly Report on Form 10-Q or a Current Report on Form 8-K are
at Securities and Exchange Commission File No. 1-956. The Exhibits include the
management contracts and compensatory plans or arrangements required to be filed
as exhibits to this Form 10-K by Item 601(10)(iii) of Regulation S-K.
(b) We filed a report on Form 8-K on December 20, 2001 to report on a
presentation made to the financial community.
We filed a report on Form 8-K on February 19, 2002 to report our 2001
year-end earnings release.
50
Exhibits Index
Exhibit Method of
No. Description Filing
2.1 Generation Exchange Agreement by and between Exhibit 2.1 to the Form 8-K
Duquesne Light Company, on the one hand, and Current Report of DQE
The Cleveland Electric Illuminating Company, dated March 26, 1999.
Ohio Edison Company and Pennsylvania Power
Company, on the other, dated as of March 25, 1999.
2.2 Nuclear Generation Conveyance Agreement by and Exhibit 2.2 to the Form 8-K
between Duquesne Light Company, on the one hand, Current Report of DQE
and Pennsylvania Power Company and the Cleveland dated March 26, 1999.
Electric Illuminating Company, on the other, dated
as of March 25, 1999.
2.3 Asset Purchase Agreement, dated as of September 24, Exhibit 2.1 to the Form 8-K
1999, by and between Duquesne Light Company, Current Report of DQE
Orion Power Holdings, Inc., and The Cleveland Electric dated September 24, 1999.
Illuminating Company, Ohio Edison and Pennsylvania
Power Company.
2.4 POLR Agreement, dated as of September 24, 1999 Exhibit 2.2 to the Form 8-K
by and between Duquesne Light Company and Orion Current Report of DQE
Power Holdings, Inc. dated September 24, 1999.
3.1 Articles of Incorporation of DQE effective January 5, Exhibit 3.1 to the Form 10-K
1989. Annual Report of DQE for the
year ended December 31, 1989.
3.2 Articles of Amendment of DQE effective April 27, 1989. Exhibit 3.2 to the Form 10-K
Annual Report of DQE for the
year ended December 31, 1989.
3.3 Articles of Amendment of DQE effective February 8, 1993. Exhibit 3.3 to the Form 10-K
Annual Report of DQE for the
year ended December 31, 1992.
3.4 Articles of Amendment of DQE effective May 24, 1994. Exhibit 3.4 to the Form 10-K
Annual Report of DQE for the
year ended December 31, 1994.
3.5 Articles of Amendment of DQE effective April 20, 1995. Exhibit 3.5 to the Form 10-K
Annual Report of DQE for the
year ended December 31, 1995.
3.6 Statement with respect to the Preferred Stock, Series A Exhibit 3.1 to the Form 10-Q
(Convertible), as filed with the Pennsylvania Department Quarterly Report of DQE for
of State on August 29, 1997. the quarter ended September
30, 1997.
3.7 By-Laws of DQE, as amended through February 28, 2002, Filed here.
and as currently in effect.
51
Exhibit Method of
No. Description Filing
4.1 Indenture dated March 1, 1960, relating to Duquesne Exhibit 4.3 to the Form 10-K
Light Company's 5% Sinking Fund Debentures. Annual Report of DQE for the
year ended December 31, 1989.
4.2 Indenture of Mortgage and Deed of Trust dated as of Exhibit 4.3 to Registration
April 1, 1992, securing Duquesne Light Company's Statement (Form S-3)
First Collateral Trust Bonds. No. 33-52782.
4.3 Supplemental Indentures supplementing the said
Indenture of Mortgage and Deed of Trust -
Supplemental Indenture No. 1. Exhibit 4.4 to Registration
Statement (Form S-3)
No. 33-52782.
Supplemental Indenture No. 2 through Supplemental Exhibit 4.4 to Registration
Indenture No. 4. Statement (Form S-3)
No. 33-63602.
Supplemental Indenture No. 5 through Supplemental Exhibit 4.6 to the Form 10-K
Indenture No. 7. Annual Report of Duquesne
Light Company for the year
ended December 31, 1993.
Supplemental Indenture No. 8 and Supplemental Exhibit 4.6 to the Form 10-K
Indenture No. 9. Annual Report of Duquesne
Light Company for the year
ended December 31, 1994.
Supplemental Indenture No. 10 through Supplemental Exhibit 4.4 to the Form 10-K
Indenture No. 12. Annual Report of Duquesne
Light Company for the year
ended December 31, 1995.
Supplemental Indenture No. 13. Exhibit 4.3 to the Form 10-K
Annual Report of Duquesne
Light Company for the year
ended December 31, 1996.
Supplemental Indenture No. 14. Exhibit 4.3 to the Form 10-K
Annual Report of Duquesne
Light Company for the year
ended December 31, 1997.
Supplemental Indenture No. 15. Exhibit 4.3 to the Form 10-K
Annual Report of Duquesne
Light Company for the year
ended December 31, 1999.
Supplemental Indenture No. 16. Exhibit 4.3 to the Form 10-K
Annual Report of Duquesne
Light Company for the year
ended December 31, 1999.
52
Exhibit Method of
No. Description Filing
Supplemental Indenture No. 17 and Supplemental Exhibit 4.2 to the Duquesne
Indenture No. 18. Light Registration Statement
(Form S-3) No. 333-72408.
4.4 Amended and Restated Agreement of Limited Partnership Exhibit 4.4 to the Form 10-K
of Duquesne Capital L.P., dated as of May 14, 1996. Annual Report of Duquesne
Light Company for the year
ended December 31, 1996.
4.5 Payment and Guarantee Agreement, dated as of May 14, Exhibit 4.5 to the Form 10-K
1996, by Duquesne Light Company with respect to MIPS. Annual Report of Duquesne
Light Company for the year
ended December 31, 1996.
4.6 Indenture, dated as of May 1, 1996, by Duquesne Light Exhibit 4.6 to the Form 10-K
Company to the First National Bank of Chicago as Trustee. Annual Report of Duquesne
Light Company for the year
ended December 31, 1996.
4.7 Indenture, dated as of August 1, 1999, from DQE Capital Exhibit 4.1 to the Form 8-A
Corporation and DQE to The First National Bank of of DQE Capital Corporation and
Chicago, as Trustee. DQE, filed September 16, 1999.
4.8 Form of Note. Exhibit 4.2 to the Form 8-A
of DQE Capital Corporation and
DQE, filed September 16, 1999.
10.1 Deferred Compensation Plan for the Directors of Exhibit 10.1 to the Form 10-K
Duquesne Light Company, as amended to date. Annual Report of DQE for the
year ended December 31, 1992.
10.2 Incentive Compensation Program for Certain Executive Exhibit 10.2 to the Form 10-K
Officers of Duquesne Light Company, as amended to date. Annual Report of DQE for the
year ended December 31, 1992.
10.3 Description of Duquesne Light Company Pension Exhibit 10.3 to the Form 10-K
Service Supplement Program. Annual Report of DQE for the
year ended December 31, 1992.
10.4 Duquesne Light Company Outside Directors' Exhibit 10.59 to the Form 10-K
Retirement Plan, as amended to date. Annual Report of Duquesne
Light Company for the year
ended December 31, 1996.
10.5 DQE, Inc. 1996 Stock Plan for Non-Employee Directors, Exhibit 10.1 to the Form 10-Q
as amended. Quarterly Report of DQE for the
quarter ended September 30,
2000.
10.6 Duquesne Light/DQE Charitable Giving Program, Filed here.
as amended.
53
Exhibit Method Of
No. Description Filing
10.7 Performance Incentive Program for DQE, Inc. and Exhibit 10.7 to the Form 10-K
Subsidiaries. Formerly known as the Duquesne Light Annual Report of DQE for the
Company Performance Incentive Program. year ended December 31, 1996.
10.8 Employment Agreement dated as of September 14, 2001 Filed here.
between DQE and Morgan K. O'Brien.
10.9 Retention Agreement dated as of February 28, 2002 between Filed here.
AquaSource and Frank A. Hoffmann.
10.10 DQE Energy Services, Inc. Equity Participation Plan. Filed here.
10.11 Amendment No. 1 to the DQE Energy Services, Inc. Filed here.
Equity Participation Plan.
10.12 Letter Agreement dated January 25, 2002 terminating Filed here.
the DQE Energy Services, Inc. Equity Participation Plan.
10.13 Non-Competition and Confidentiality Agreement dated as Filed here.
of September 14, 2001, between DQE and Morgan K. O'Brien.
10.14 Composite Non-Competition and Confidentiality Agreement Filed here.
dated as of August 17, 2000 and amended as of February 28,
2002, between AquaSource and Frank A. Hoffmann.
10.15 Non-Competition and Confidentiality Agreement dated as Filed here.
of October 21, 1996 between DQE, Duquesne Light and
Victor A. Roque.
10.16 Non-Competition and Confidentiality Agreement dated as Filed here.
of May 27, 1999 between DQE Energy Services and
Alexis Tsaggaris.
10.17 Non-Competition and Confidentiality Agreement dated as Filed here.
of October 4, 1996 between Duquesne Light and
William J. DeLeo.
10.18 Agreement effective as of September 14, 2001 between Exhibit 10.1 to the Form 10-Q
DQE and David D. Marshall. Quarterly Report of DQE for the
quarter ended September 3o,
2001.
10.19 Form of Stock Purchase Agreement between AquaSource Exhibit 10.71 to the Form 10-K
and each Class B Stockholder, dated February 16, 1999. Annual Report of DQE for the
year ended December 31, 1998.
10.20 Amended and Restated POLR II Agreement by and between Exhibit 10.12 to the Form 10-K
Duquesne Light Company and Orion Power MidWest, L.P., Annual Report of Duquesne
dated as of December 7, 2000. Light Company for the year
ended December 31, 2000.
54
Exhibit Method Of
No. Description Filing
10.21 Capacity Agreement by and between Duquesne Light and Exhibit 10.12 to the Form 10-K
FirstEnergy Solutions Corp. dated as of December 18, 2001. Annual Report of Duquesne
Light Company for the year
ended December 31, 2001.
10.22 Amendment No. 1 to the Capacity Agreement by and between Exhibit 10.13 to the Form 10-K
Duquesne Light and FirstEnergy Solutions Corp. made as of Annual Report of Duquesne
February 15, 2002. Light Company for the year
ended December 31, 2001.
10.23 Capacity Agreement by and between Duquesne Light and Exhibit 10.14 to the Form 10-K
Orion Power Midwest, L.P. dated as of February 15, 2002. Annual Report of Duquesne
Light Company for the year
ended December 31, 2001.
12.1 Ratio of Earnings to Fixed Charges. Filed here.
21.1 Subsidiaries of the registrant. Filed here.
23.1 Independent Auditors' Consent. Filed here.
24.1 Power of Attorney. Filed here.
Copies of the exhibits listed above will be furnished, upon request, to
holders or beneficial owners of any class of our stock as of February 28, 2002,
subject to payment in advance of the cost of reproducing the exhibits requested.
55
SCHEDULE II
Schedule II - VALUATION AND QUALIFYING ACCOUNTS
For the Years Ended December 31, 2001, 2000 and 1999
(Thousands of Dollars)
Column A Column B Column C Column D Column E Column F
--------- -------- -------- ---------- ----------- --------
Additions
--------------------------
Balance at Charged to Charged to Balance
Beginning Costs and Other at End
Description of Year Expenses Accounts Deductions of Year
----------- ---------- --------- ---------- ----------- -------
Year Ended December 31, 2001
Reserve Deducted from the Asset
to which it applies:
Allowance for uncollectible accounts $ 11,861 $ 9,516 $ 2,644 (A) $ 14,083 (B) $ 9,938
---------- -------- ---------- ----------- --------
Year Ended December 31, 2000
Reserve Deducted from the Asset
to which it applies:
Allowance for uncollectible accounts $ 9,280 $ 10,319 $ 2,663 (A) $ 10,401 (B) $ 11,861
---------- -------- ---------- ----------- --------
Year Ended December 31, 1999
Reserve Deducted from the Asset
to which it applies:
Allowance for uncollectible accounts $ 9,415 $ 9,272 $ 3,260 (A) $ 12,667 (B) $ 9,280
---------- -------- ---------- ----------- --------
Notes: (A) Recovery of accounts previously written off.
(B) Accounts receivable written off.
Signatures
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, the registrant has duly caused this report to be signed on its
behalf by the undersigned, thereunto duly authorized.
DQE
(Registrant)
Date: March 28, 2002 By: /s/ Morgan K. O'Brien
------------------------
(Signature)
Morgan K. O'Brien
President and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities and on the dates indicated.
Signature Title Date
/s/ Morgan K. O'Brien President, Chief Executive Officer and Director March 28, 2002
- -----------------------------
Morgan K. O'Brien
/s/ Frosina C. Cordisco Vice President and Treasurer March 28, 2002
- ----------------------------- (Principal Financial Officer)
Frosina C. Cordisco
/s/ Stevan R. Schott Vice President and Controller March 28, 2002
- ----------------------------- (Principal Accounting Officer)
Stevan R. Schott
* Director
- -----------------------------
Daniel Berg
* Director
- -----------------------------
Doreen E. Boyce
* Director
- -----------------------------
Robert P. Bozzone
Director
- -----------------------------
Charles C. Cohen
* Director
- -----------------------------
Sigo Falk
Director
- -----------------------------
David M. Kelly
* Director
- -----------------------------
Steven S. Rogers
* Director
- -----------------------------
Eric W. Springer
Director
- -----------------------------
John D. Turner
*By /s/ Frosina C. Cordisco Attorney-in-Fact March 28, 2002
- -----------------------------