Back to GetFilings.com
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, 1996
-----------------
[ ] 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
----------------------
1-956
Duquesne Light Company
----------------------------------------------------
(Exact name of registrant as specified in its charter)
Pennsylvania 25-0451600
------------ ----------
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
411 Seventh Avenue
Pittsburgh, Pennsylvania 15219
-------------------------------
(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
----- ----
DQE is the holder of all shares of outstanding common stock, $1 par value, of
Duquesne Light Company consisting of 10 shares as of February 21, 1997.
[X] 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
-------------------- ---------------------------------------- ----------------------------
Duquesne Light Preferred Stock New York Stock Exchange
Company
Involuntary
Series Liquidation Value
------ -----------------
3.75% $50 per share
4.00% $50 per share
4.10% $50 per share
4.15% $50 per share
4.20% $50 per share
$2.10 $50 per share
8.375% $25 per share (1)
Sinking Fund Debentures, due March 1, 2010 (5%) New York Stock Exchange
(1) Issued by Duquesne Capital, L.P., and the payments of
dividends and payments on liquidation or redemption are
guaranteed by Duquesne Light Company.
TABLE OF CONTENTS
Page
----
PART I
ITEM 1. BUSINESS
General 1
Results of Operations 2
Liquidity and Capital Resources 4
Rate Matters 5
Property, Plan and Equipment (PP&E) 6
Employees 8
Electric Utility Operations 8
Fossil Fuel 9
Nuclear Fuel 9
Nuclear Decommissioning 10
Nuclear Insurance 11
Spent Nuclear Fuel Disposal 11
Uranium Enrichment Decontamination and
Decommissioning 11
Environmental Matters 12
Outlook 13
Other 15
Executive Officers of the Registrant 16
ITEM 2. PROPERTIES 17
ITEM 3. LEGAL PROCEEDINGS 18
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF
SECURITY HOLDERS 18
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON
EQUITY AND RELATED SHAREHOLDER
MATTERS 18
ITEM 6. SELECTED FINANCIAL DATA 18
ITEM 7. MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS 19
ITEM 8. CONSOLIDATED FINANCIAL STATEMENTS
AND SUPPLEMENTARY DATA 19
ITEM 9. CHANGES IN AND DISAGREEMENTS
WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE 19
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS
OF THE REGISTRANT 19
ITEM 11. EXECUTIVE COMPENSATION 19
ITEM 12. SECURITY OWNERSHIP OF CERTAIN
BENEFICIAL OWNERS AND MANAGEMENT 19
ITEM 13. CERTAIN RELATIONSHIPS AND
RELATED TRANSACTIONS 19
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT
SCHEDULES AND REPORTS ON FORM 8-K 20
SCHEDULE II 32
SIGNATURES 33
REPORT OF INDEPENDENT CERTIFIED
PUBLIC ACCOUNTANTS 34
FINANCIAL STATEMENTS 35
SELECTED FINANCIAL DATA 59
GLOSSARY 60
Part I
Item 1. Business.
General
- -------------------------------------------------------------------------------
Part I of this Annual Report, Form 10-K (Report) should be read in
conjunction with Duquesne Light Company's audited consolidated financial
statements, which are set forth on pages 35 through 58 in Part IV of this
Report. Explanations of certain financial and operating terms used in this
Report are set forth in a GLOSSARY on page 60 of this Report.
Duquesne Light Company (Duquesne) is a wholly owned subsidiary of DQE,
an energy services holding company. Duquesne is engaged in the production,
transmission, distribution and sale of electric energy. Duquesne has one wholly
owned subsidiary, Monongahela Light and Power which currently holds energy-
related lease investments.
Service Territory
Duquesne provides electric service to customers in Allegheny County,
including the City of Pittsburgh, Beaver County and Westmoreland County. This
represents approximately 800 square miles in southwestern Pennsylvania, located
within a 500-mile radius of one-half of the population of the United States and
Canada. The population of the area served by Duquesne, based on 1990 census
data, is approximately 1,510,000, of whom 370,000 reside in the City of
Pittsburgh. In addition to serving approximately 580,000 direct customers,
Duquesne also sells electricity to other utilities.
Regulation
Duquesne is subject to the accounting and reporting requirements of
the United States Securities and Exchange Commission (SEC). In addition,
Duquesne's operations are subject to regulation by the Pennsylvania Public
Utility Commission (PUC) and the Federal Energy Regulatory Commission (FERC)
under the Federal Power Act with respect to rates for interstate sales,
transmission of electric power, accounting and other matters.
The Electricity Generation Customer Choice and Competition Act
(Customer Choice Act) went into effect in Pennsylvania on January 1, 1997. This
legislation provides for a gradual deregulation of the generation of
electricity, while maintaining regulation of the transmission and distribution
of electricity and related services to customers. (See "Rate Matters" and
"Competition" discussions on pages 5 and 13.)
Duquesne's operations are also subject to regulation by the Nuclear
Regulatory Commission (NRC) under the Atomic Energy Act of 1954, as amended,
with respect to the operation of its jointly owned/leased nuclear power plants,
Beaver Valley Unit 1 (BV Unit 1), Beaver Valley Unit 2 (BV Unit 2) and Perry
Unit 1.
Duquesne's consolidated financial statements report regulatory assets
and liabilities in accordance with Statement of Financial Accounting Standards
No. 71, Accounting for the Effects of Certain Types of Regulation (SFAS No. 71),
and reflect the effects of the current ratemaking process. In accordance with
SFAS No. 71, Duquesne's consolidated financial statements reflect regulatory
assets and liabilities consistent with cost-based, pre-competition ratemaking
regulations. The regulatory assets represent probable future revenue to Duquesne
because provisions for these costs are currently included, or are expected to be
included, in charges to electric utility customers through the ratemaking
process.
Duquesne's operations or a portion of such operations could cease to
meet the SFAS No. 71 criteria for various reasons, including a change in the
FERC regulations or the competition-related changes in the PUC regulations
described above. (See "Rate Matters" and "Competition" discussions on pages 5
and 13.) Duquesne believes its electricity generating assets and related
regulatory assets continue to satisfy these criteria in light of the transition
to competitive generation under the Customer Choice Act. Should any portion of
Duquesne's operations be deemed to no longer meet the SFAS No. 71 criteria,
Duquesne may be required to write off any above-market cost assets, the recovery
of which is uncertain, and any regulatory assets or liabilities for those
operations that no longer meet these requirements.
1
Results of Operations
- -------------------------------------------------------------------------------
Sales of Electricity to Customers
The decrease in 1996 total operating revenues was $3.0 million, as
compared to 1995. Comparing 1995 total operating revenues to 1994, there was an
increase of $11.2 million. Operating revenues are derived from Duquesne's sales
of electricity. The PUC authorizes rates for electricity sales which are cost-
based and are designed to recover Duquesne's operating expenses and investment
in electric utility assets and to provide a return on the investment. (See "Rate
Matters" and "Competition" discussions on pages 5 and 13.)
Electric Utility Sales by Customer Class (Kilowatt-Hours in Millions):
- ---------------------------------------------------------------------
1996 1995 1994
- ----------------------------------------------------------------
Residential 3,321 3,378 3,219
Commercial 5,836 5,827 5,662
Industrial 3,285 3,237 3,256
Miscellaneous 83 84 84
- ----------------------------------------------------------------
Sales to Electric Utility Customers 12,525 12,526 12,221
- ----------------------------------------------------------------
Sales to Other Utilities 3,310 2,975 3,212
- ----------------------------------------------------------------
Total Sales 15,835 15,501 15,433
=================================================================
Sales to residential and commercial customers are strongly influenced
by weather conditions. Warmer summer and colder winter seasons lead to increased
customer use of electricity for cooling and heating. Commercial sales are also
affected by regional economic development. Sales to industrial customers are
influenced by national and global economic conditions. Customer revenues
fluctuate as a result of changes in sales volume and changes in fuel and other
energy costs.
Net Customer Revenues
Net customer revenues, reflected on the statement of consolidated
income, decreased $8.3 million or 0.8 percent in 1996 compared to 1995. The
variance can be attributed primarily to decreased residential customer kilowatt-
hour (KWH) sales of 1.7 percent due to unseasonably warm summer temperatures in
1995, as compared to 1996, resulting in decreased revenues of $8.9 million.
Industrial KWH sales volume in 1996 increased when compared to the prior year
because of a self-generation outage experienced in 1996 by one of Duquesne's
large industrial customers. Sales to Duquesne's 20 largest customers accounted
for approximately 14 percent of customer revenues in 1996, 1995 and 1994.
In 1995 as compared to 1994, net customer revenues increased by $7.8
million, or 0.7 percent. The increase is the net result of higher KWH sales to
residential customers by 4.9 percent in response to extreme 1995 summer
temperatures, partially offset by lower fuel and other energy costs per KWH, the
benefits of which are passed through to the customers in the form of lower
rates. Revenues from electric sales to residential customers in 1995 exceeded
1994 residential revenues by $13.0 million.
Sales to Other Utilities
Short-term sales to other utilities are regulated by the FERC and are
made at market rates. Fluctuations in electricity sales to other utilities are
related to Duquesne's customer energy requirements, the energy market and
transmission conditions, and the availability of Duquesne's generating stations.
Duquesne's electricity sales to other utilities in 1995 were less than 1996 and
1994 due to the timing of generating station outages and the fluctuating level
of sales to Duquesne's electric utility customers. Future levels of short-term
sales to other utilities will be affected by Duquesne's sale of its ownership
interest in the Ft. Martin Power Station (Ft. Martin), the possible sale of
other generating stations, market rates, and by the outcome of Duquesne's FERC
filings requesting firm transmission access. (See "Mitigation Plan" and
"Transmission Access" discussions on pages 5 and 15.)
2
Other Operating Revenues
Duquesne's non-KWH revenues comprise other operating revenues in
Duquesne's statement of consolidated income. Other operating revenues are
primarily comprised of revenues from joint owners of BV Unit 1 and BV Unit 2 for
their shares of the administrative and general costs of operating these units.
Other operating revenues, therefore, fluctuate depending on the timing of
scheduled refueling and maintenance outages at Beaver Valley Power Station
(BVPS) when significant costs are incurred. Both BV Unit 1 and BV Unit 2
underwent refueling outages in 1996 and 1995. BV Unit 2 experienced an extended
outage of 107 days during 1996 due to unanticipated repairs to two residual heat
removal pumps and reactor head vent valves, resulting in a $3.0 million increase
in other operating revenues during 1996. There were no refueling outages in
1994; accordingly, other operating revenues increased $5.7 million in 1995 when
compared to 1994.
Operating Expenses
Fuel and purchased power expense fluctuations generally result from
changes in the cost of fuel, the mix between coal and nuclear generation, the
total KWHs sold, and generating station availability. Because of the Energy Cost
Rate Adjustment Clause (ECR), changes in fuel and purchased power costs did not
impact earnings in 1996, 1995 and 1994.
Fuel and purchased power expense increased in 1996 compared to 1995
as a result of a 33 percent increase in purchased power prices. This increase
was partially offset by lower nuclear fuel costs. Fuel and purchased power
expense decreased in 1995 compared to 1994 due to lower nuclear fuel costs, a
more favorable generation mix and a 2.7 percent decline in KWH generation.
Other operating expense increased $2.8 million when comparing 1996 to
1995. The increase was the result of a one-time lease charge. In 1995, other
operating expense decreased $18.7 million when compared to 1994. This 1995
reduction reflects ongoing cost savings efforts.
Depreciation and amortization expense increased $25.7 million in 1996
when compared to 1995 primarily due to the increase in Duquesne's composite
depreciation rate from 3.5 percent to 4.25 percent effective May 1, 1996. During
the third quarter of 1996, Duquesne completed recovery of its investment in
Perry Unit 2, the construction of which was abandoned by Duquesne in 1986. The
resultant decrease in amortization expense was offset by Duquesne's increase in
depreciation, as well as $9 million that was expensed related to the
depreciation portion of deferred rate synchronization costs in conjunction with
Duquesne's Mitigation Plan. Depreciation and amortization expense increased
$27.6 million in 1995, primarily due to the change in Duquesne's composite
depreciation rate from 3.0 percent to 3.5 percent effective January 1, 1995.
Duquesne did not seek a rate increase to recover the additional costs. (See
"Mitigation Plan" discussion on page 5.)
Income taxes decreased in 1996 when compared to 1995 by $6.9 million,
primarily due to reduced taxable income. In 1995, taxable income was greater
than in 1994, resulting in increased income taxes of $1.8 million.
Other Income and (Deductions)
The increase of $22.9 million in other income and deductions, when
comparing 1996 to 1995, was primarily the result of income from long-term
investments made during late 1995 and 1996. Other income and deductions
decreased $10.3 million in 1995 when compared to 1994 primarily due to increases
in income taxes related to other income.
Interest Charges
Duquesne achieved reductions of $8.4 million and $3.8 million in
interest charges in 1996 and 1995, respectively. The decreases were primarily
due to the retirement of long-term debt during 1995. Interest expense in 1997
will be influenced by fluctuations in short-term rates and any new financing.
3
Monthly Income Preferred Securities Dividend Requirements
The Monthly Income Preferred Securities Dividend Requirements reflect
the payment of $7.9 million in dividends in 1996 related to preferred stock
issued in May 1996.
Dividends on Preferred and Preference Stock
The decreases of $1.3 million and $0.7 million in 1996 and 1995 in
dividends on preferred and preference stock were primarily due to the retirement
of preferred stock in 1995.
Liquidity and Capital Resources
- -------------------------------------------------------------------------------
Capital Expenditures
Duquesne spent approximately $88.5 million in 1996, $78.7 million in
1995 and $94.3 million in 1994 for construction. Duquesne's capital expenditures
for construction focus on improving and/or expanding electric production,
transmission and distribution systems. Duquesne estimates that it will spend,
excluding allowance for funds used during construction (AFC) and nuclear fuel,
approximately $110 million, $110 million and $95 million for construction during
1997, 1998 and 1999. These estimates also exclude any potential expenditures for
reliability enhancements to the Brunot Island (BI) Unit 3 combustion turbine.
(See "Mitigation Plan" discussion on page 5.) Duquesne expects that funds
generated from operations will continue to be sufficient to fund a large part of
its capital needs.
Long-Term Investments
Duquesne's long-term investments consist of Duquesne's holdings of
DQE common stock, investments in affordable housing, lease investments, and
Duquesne's nuclear decommissioning trusts. Investing activities decreased in
1996, after increasing in 1995, when compared to 1994. Duquesne invested $1.5
million and $5.4 million in affordable housing funds during 1996 and 1995. Other
investments in 1996 totaled approximately $2.7 million. In addition, Duquesne
invested $57.5 million in lease investments during 1995.
Financing
Duquesne expects to meet its current obligations and debt maturities
through the year 2001 with funds generated from operations and through new
financings. At December 31, 1996, Duquesne was in compliance with all of its
debt covenants.
On May 14, 1996, Duquesne Capital L.P., a Delaware special-purpose
limited partnership the sole general partner of which is Duquesne, issued $150
million principal amount of 8-3/8 percent Cumulative Monthly Income Preferred
Securities (MIPS), Series A, with a stated liquidation value of $25.00. A
portion of the proceeds was used to retire $50 million of long-term debt
maturing May 15, 1996. Duquesne intends to continue to apply the remaining
proceeds to the purchase or redemption of outstanding securities and for general
corporate purposes.
In November 1997, $50 million of mortgage bonds will mature. Duquesne
expects to retire these bonds with available cash or to refinance the bonds.
Short-Term Borrowings
At December 31, 1996, Duquesne had a $150 million extendible revolving
credit arrangement expiring in October 1997. Interest rates can, in accordance
with the option selected at the time of the borrowing, be based on prime,
Eurodollar or certificate of deposit rates. Commitment fees are based on the
unborrowed amount of the commitment. The credit facility contains a two-year
repayment period for any amount outstanding at the expiration of the revolving
credit period. At December 31, 1996 and 1995, there were no short-term
borrowings outstanding.
4
Sale of Accounts Receivable
Duquesne and an unaffiliated corporation have an agreement that
entitles Duquesne to sell, and the corporation to purchase, on an ongoing basis,
up to $50 million of accounts receivable. Duquesne had no receivables sold at
December 31, 1996. At December 31, 1995, Duquesne had sold $7 million of
receivables to the unaffiliated corporation. The accounts receivable sales
agreement, which expires in June 1997, is one of many sources of funds available
to Duquesne. Duquesne has not determined, but may attempt to extend the
agreement or to replace the facility with a similar arrangement or to eliminate
it upon expiration.
Nuclear Fuel Leasing
Duquesne finances its acquisitions of nuclear fuel through a leasing
arrangement under which it may finance up to $75 million of nuclear fuel. As of
December 31, 1996, the amount of nuclear fuel financed by Duquesne under this
arrangement totaled approximately $35 million. Duquesne plans to continue
leasing nuclear fuel to fulfill its requirements at least through September
1998, the remaining term of the leasing arrangement.
Rate Matters
- -------------------------------------------------------------------------------
Customer Choice Act
Under the Customer Choice Act, which went into effect on January 1,
1997, Pennsylvania has become a leader in customer choice. The Customer Choice
Act will enable Pennsylvania's electric utility customers to purchase
electricity at market prices from a variety of electric generation suppliers
(customer choice). Electric utility restructuring will be accomplished through a
two-stage process consisting of a pilot period (running through 1998) and a
phase-in period (1999 through 2001). The pilot period will give utilities an
opportunity to examine a wide range of technical and administrative details
related to competitive markets, including metering, billing, and cost and design
of unbundled electric services. Duquesne filed a pilot program with the PUC on
February 27, 1997, which proposes unbundling transmission, distribution,
electricity and competitive transition charges and offers participating
customers the same options that will be available in a competitive generation
market.
The pilot program will comprise approximately 5 percent of Duquesne's
residential, commercial and industrial demand beginning September 1, 1997.
Customers participating in the pilot will have two basic options. First,
customers can choose to continue taking bundled service from Duquesne under
approved tariffs. Second, customers can choose unbundled service with their
electricity provided by an alternative electric generation supplier. All
customers that choose unbundled electric service will be subject to unbundled
distribution charges approved by the PUC and unbundled transmission charges
pursuant to Duquesne's FERC-approved tariff. Each customer that elects unbundled
service also will be required to pay a non-bypassable access fee (competitive
transition charge) that provides Duquesne with a reasonable opportunity to
recover transition costs.
Duquesne must file a restructuring plan with the PUC by August 1, 1997
setting forth its proposals for the transition to customer choice and the
recovery of transition costs. (See "Competition" discussion on page 13.) The
phase-in to competition begins on January 1, 1999 when 33 percent of consumers
will have customer choice (including consumers covered by the pilot program); 66
percent of consumers will have customer choice by January 1, 2000; and all
consumers will have customer choice by January 1, 2001. Although the Customer
Choice Act will give customers their choice of electric generation suppliers,
delivery of the electricity from the generation supplier to the customer will
remain the responsibility of the existing franchised utility. Delivery of
electricity (including transmission, distribution and customer service) will
continue to be regulated in substantially the current manner.
Mitigation Plan
Duquesne has taken a number of steps to mitigate its potential
transition costs. (See "Competition" discussion on page 13.) In addition to the
steps taken during the last 10 years to prepare for competition, effective
January 1, 1995, Duquesne accelerated its rate of depreciation on its fixed
nuclear assets without seeking a rate increase to recover the additional costs.
On October 31, 1996, the sale of Duquesne's ownership interest in
5
Ft. Martin was completed. Ft. Martin Unit 1 was owned 50 percent by Duquesne and
50 percent by its operator, Allegheny Power System (APS). The sale and a plan,
to be funded in part by the proceeds of the Ft. Martin transaction, were
approved by the PUC on May 23, 1996. Under the approved plan, Duquesne will not
increase its base rates for a period of five years through May 2001. In
addition, Duquesne recorded in October 1996 a one-time reduction of
approximately $130 million in the book value of Duquesne's nuclear plant
investment. The proceeds from the sale are expected to be used to fund
reliability enhancements to the BI Unit 3 combustion turbine and to reduce
Duquesne's capitalization. The approved plan also provides for incremental
increases of $25 million in depreciation and amortization expense in 1996, 1997
and 1998 related to Duquesne's nuclear investment, as well as additional annual
contributions to its nuclear plant decommissioning funds of $5 million, without
any increase in existing electric rates. Also, Duquesne will record an annual $5
million credit to the ECR during the plan period to compensate Duquesne's
customers for lost profits from any short-term power sales foregone by the sale
of its ownership interest in Ft. Martin. In addition, Duquesne will cap energy
costs, beginning April 1, 1997 through the remainder of the plan period, at a
historical five-year average of 1.47 cents per KWH. In accordance with the
approved plan, Duquesne has expensed $9 million related to the depreciation
portion of the deferred rate synchronization costs associated with BV Unit 2 and
Perry Unit 1. Duquesne's approved plan provides for the amortization of the
remaining deferred rate synchronization costs over a 10-year period. At December
31, 1996, the unamortized portion of these costs totaled $41.4 million, net of
deferred fuel savings related to the two units. (See "Deferred Rate
Synchronization Costs" below.) Finally, Duquesne's approved plan also provides
for annual assistance of $0.5 million to low-income customers.
Deferred Rate Synchronization Costs
In 1987, the PUC approved Duquesne's petition to defer initial
operating and other costs of BV Unit 2 and Perry Unit 1. Duquesne deferred the
costs incurred from November 1987, when the units went into commercial
operation, until March 1988, when a rate order was issued. In its rate order,
the PUC postponed ruling on whether these costs would be recoverable from
Duquesne's electric utility customers. Duquesne is not earning a return on the
deferred costs. (See "Mitigation Plan" discussion on page 5.)
Energy Cost Rate Adjustment Clause (ECR)
Through the ECR, Duquesne recovers (to the extent that such amounts
are not included in base rates) nuclear fuel, fossil fuel and purchased power
expenses and, also through the ECR, passes to its customers the profits from
short-term power sales to other utilities (collectively, ECR energy costs).
On Duquesne's statement of consolidated income, these ECR revenues are
included as a component of operating revenues. For ECR purposes, Duquesne defers
fuel and other energy expenses for recovery, or refunding, in subsequent years.
The deferrals reflect the difference between the amount that Duquesne is
currently collecting from customers and its actual ECR energy costs. The PUC
annually reviews Duquesne's ECR energy costs for the fiscal year April through
March, compares them to previously projected ECR energy costs, and adjusts the
ECR for over- or under-recoveries and for two PUC-established coal cost
standards. (See "Fossil Fuel" discussion on page 9.)
Under the Customer Choice Act, Duquesne may replace the ECR effective
April 1, 1997 by rolling its ECR energy costs into its base rates. The effect of
this change would be to provide to Duquesne an opportunity to further mitigate
its deferred energy costs based upon its ability to manage its energy costs.
Under Duquesne's PUC-approved Mitigation Plan, the level of energy cost recovery
is capped at 1.47 cents per KWH through May 2001. To the extent that projections
do not support recovery of previously deferred costs through this pricing
mechanism, these costs would become transition costs subject to recovery through
a competitive transition charge (CTC). (See "Competition" discussion on page
13.)
Property, Plant and Equipment (PP&E)
- -------------------------------------------------------------------------------
Investment in PP&E and Accumulated Depreciation
Duquesne's total investment in property, plant and equipment and the
related accumulated depreciation balances for major classes of property at
December 31, 1996 and 1995, are as follows:
6
PP&E and Related Accumulated Depreciation at December 31
- -------------------------------------------------------------------------------
(Amounts in Thousands of Dollars)
1996 1995
----------------------------------------------------------------------------
Accumulated Net Accumulated Net
Investment Depreciation Investment Investment Depreciation Investment
----------------------------------------------------------------------------
Electric Production $2,467,786 $1,092,928 $1,374,858 $2,501,974 $ 885,389 $1,616,585
Electric Transmission 299,895 114,406 185,489 296,953 110,242 186,711
Electric Distribution 1,176,738 374,180 802,558 1,143,111 347,399 795,712
Electric General 324,366 168,470 155,896 314,844 141,133 173,711
Property Held for Future Use 190,821 82,737 108,084 216,633 94,283 122,350
Property Held Under Capital Leases 99,608 47,670 51,938 133,381 74,874 58,507
Other 49,559 10,909 38,650 45,114 19,787 25,327
- ------------------------------------------------------------------------------------------------------------------
Total $4,608,773 $1,891,300 $2,717,473 $4,652,010 $1,673,107 $2,978,903
==================================================================================================================
Joint Interests in Generating Units
Duquesne has various contracts with Ohio Edison Company, Pennsylvania
Power Company, The Cleveland Electric Illuminating Company (CEI) and The Toledo
Edison Company, with respect to several jointly owned/leased generating units,
that include provisions for coordinated maintenance responsibilities, limited
and qualified mutual back-up in the event of outages, and certain capacity and
energy transactions.
In September 1995, Duquesne commenced arbitration against CEI, seeking
damages, termination of the Operating Agreement for Eastlake Unit 5 (Eastlake)
and partition of the parties' interests in Eastlake through a sale and division
of the proceeds. The arbitration demand alleged, among other things, the
improper allocation by CEI of fuel and related costs; the mismanagement of the
administration of the Saginaw coal contract in connection with the closing of
the Saginaw mine, which historically supplied coal to Eastlake; and the
concealment by CEI of material information. In October 1995, CEI commenced an
action against Duquesne in the Court of Common Pleas, Lake County, Ohio seeking
to enjoin Duquesne from taking any action to effect a partition on the basis of
a waiver of partition covenant contained in the deed to the land underlying
Eastlake. CEI also seeks monetary damages from Duquesne for alleged unpaid joint
costs in connection with the operation of Eastlake. Duquesne removed the action
to the United States District Court for the Northern District of Ohio, Eastern
Division, where it is now pending. Currently, the parties are engaged in
settlement discussions. To provide the parties with the opportunity to settle
their claims, the court has postponed litigation proceedings until April 1,
1997.
Joint Interests in Nuclear Power Stations
- -----------------------------------------------------------------------------
Beaver Valley Perry
Unit 1 Unit 2 Unit 1
- -----------------------------------------------------------------------------
Duquesne * 47.50% *13.74%(c) 13.74%
Ohio Edison Company 35.00% 41.88% 30.00%
Pennsylvania Power Company (a) 17.50% -- 5.24%
CEI (b) --% 24.47% * 31.11%
Toledo Edison Company (b) --% 19.91% 19.91%
- -----------------------------------------------------------------------------
*Denotes Operator
(a) Subsidiary of Ohio Edison Company
(b) Subsidiary of Centerior Energy Corporation
(c) In 1987, Duquesne sold and leased back its 13.74 percent interest in BV Unit
2; the sale was exclusive of transmission and common facilities. The total
sales price of $537.9 million was the appraised value of Duquesne's interest
in the property. Duquesne subsequently leased back its interest in the unit
for a term of 29.5 years. The lease provides for semi-annual payments and is
accounted for as an operating lease. Duquesne is responsible under the terms
of the lease for all costs related to its interest in the unit.
7
Joint Interests in Fossil Power Stations
- -------------------------------------------------------------------------------
Bruce Mansfield
Sammis ------------------------- Eastlake
Unit 7 Unit 1 Unit 2 Unit 3 Unit 5
- -------------------------------------------------------------------------------
Duquesne 31.20% 29.30% 8.00% 13.74% 31.20%
Ohio Edison Company * 48.00% 60.00% 39.30% 35.60% --
Pennsylvania Power Company (a) 20.80% * 4.20% * 6.80% * 6.28% --
CEI (b) -- 6.50% 28.60% 24.47% *68.80%
Toledo Edison Company (b) -- -- 17.30% 19.91% --
- -------------------------------------------------------------------------------
*Denotes Operator
(a) Subsidiary of Ohio Edison Company
(b) Subsidiary of Centerior Energy Corporation
On September 13, 1996, Ohio Edison Company and Centerior Energy
Corporation entered into an agreement and plan of merger to form First Energy
Corporation. The regulatory approval process for the proposed merger is expected
to take approximately 12 to 18 months.
Property Held for Future Use
In 1986, the PUC approved Duquesne's request to remove Phillips Power
Station (Phillips) and a portion of BI from service and from rate base. In
accordance with Duquesne's Mitigation Plan, 112 MWs related to BI Units 2a and
2b were moved from property held for future use to electric plant in service in
1996. Duquesne expects to recover its investment in BI Units 3 and 4, which
remain in property held for future use through future electricity sales.
Duquesne believes its investment in BI will be necessary in order to meet future
business needs. A portion of the proceeds of the sale of Ft. Martin is expected
to be used to fund reliability enhancements to the BI Unit 3 combustion turbine.
The reliability enhancements are contingent upon the projects meeting a least-
cost test versus other potential sources of peaking capacity. (See "Mitigation
Plan" discussion on page 5.) Duquesne is analyzing the effects of customer
choice on its future generating requirements. Duquesne is planning to seek
recovery of its investment and associated costs of Phillips through a CTC. (See
"Competition" discussion on page 13.) In the event that market demand,
transmission access or rate recovery do not support the utilization of these
plants, Duquesne may have to write off part or all of these investments and
associated costs. At December 31, 1996, Duquesne's net of tax investment in
Phillips and BI held for future use was $53.6 million and $17.2 million.
Employees
- -------------------------------------------------------------------------------
At December 31, 1996, Duquesne had 3,413 employees, including 1,157
employees at the Duquesne-operated BVPS. In November 1996, Duquesne reached an
agreement on a three-year contract extension through September 30, 2001 with the
International Brotherhood of Electrical Workers, which represents approximately
2,000 of Duquesne's employees.
Electric Utility Operations
- -------------------------------------------------------------------------------
Duquesne's fossil plants operated at 76 percent availability in 1996
and 1995. Duquesne's nuclear plants operated at 76 percent availability in 1996
and 83 percent in 1995. The timing and duration of scheduled maintenance and
refueling outages, as well as the duration of forced outages, affect the
availability of power stations. Duquesne normally experiences its peak demand in
the summer. The 1996 customer system peak demand of 2,463 MW occurred on August
7, 1996.
Duquesne's plan for optimizing generation resources is designed to
reduce under-utilized generating capacity and employ cost-effective sources of
peaking capacity. The sale of Duquesne's ownership interest in Ft. Martin
reduced in-service capacity by 276 MW. In conjunction with the sale, Duquesne
returned 112 MW of peaking capacity at BI to electric plant in service.
Additionally, through potential reliability enhancements to the BI Unit 3
combustion turbine, Duquesne could return to service another 56 MW of oil-fired
peaking capacity. (See "Property Held for Future Use" discussion above.)
8
Duquesne has a 13.74 percent ownership interest in Perry Unit 1, a
nuclear generating unit located in Ohio and operated by CEI. CEI management has
advised Duquesne that the Perry Course of Action (PCA), an action plan submitted
to the NRC in 1993, was completed at the end of the unit's fifth refueling
outage in the spring of 1996. Perry Unit 1 has followed the PCA with the Perry
Plan for Excellence, which is the long-term phase of the unit's performance
improvement program. Duquesne will continue to monitor closely the status of the
performance improvement program.
Fossil Fuel
- -------------------------------------------------------------------------------
Duquesne believes that sufficient coal for its coal-fired generating
units will be available from various sources to satisfy its requirements for the
foreseeable future. During 1996, approximately 2.4 million tons of coal were
consumed at Duquesne's two wholly owned coal-fired stations, Cheswick Power
Station (Cheswick) and Elrama Power Station (Elrama).
Duquesne owns Warwick Mine, an underground mine located approximately
83 river miles from Pittsburgh. At December 31, 1996, Duquesne's net investment
in the mine was $11.4 million. Duquesne estimates that, at December 31, 1996,
its economically recoverable coal reserves at Warwick Mine were in excess of 1.5
million tons. The unaffiliated contract operator at Warwick Mine notified
Duquesne that its financial circumstances and geologic conditions caused it to
cease operations late in 1996. Therefore, Duquesne is pursuing its remedies and
is currently negotiating to retain an operator for the mine as a smaller sized
operation. Additionally, Duquesne will continue to purchase coal on the open
market. This change should not impact Duquesne's ability to recover all of its
investment in Warwick Mine, the $2.6 million of unrecovered system-wide cost of
coal which excludes the Bruce Mansfield Power Station (Bruce Mansfield), or to
accrue funds for future liabilities. It is anticipated that this effort will be
successfully completed by March 31, 2000 when the system-wide coal cost cap
expires. The current estimated liability for mine closing, including final site
reclamation, mine water treatment and certain labor liabilities is $47.6
million, and Duquesne has recorded a liability on the consolidated balance sheet
of approximately $20.2 million toward these costs.
During 1996, 69 percent of Duquesne's coal supplies were provided by
contracts including Warwick Mine, with the remainder satisfied through purchases
on the spot market. Duquesne had four long-term contracts in effect at December
31, 1996 that, in combination with spot market purchases, are expected to
furnish an adequate future coal supply. Duquesne does not anticipate any
difficulty in replacing or renewing these contracts as they expire from 1997
through 2002. At December 31, 1996, Duquesne's wholly owned and jointly owned
generating units had on hand an average coal supply of 45 days.
The PUC has established two market price coal cost standards for
Duquesne. One applies only to coal delivered at Bruce Mansfield. The other, the
system-wide coal cost standard, applies to coal delivered to the remainder of
Duquesne's system. Both standards are updated monthly to reflect prevailing
market prices of similar coal. The PUC has directed Duquesne to defer recovery
of the delivered cost of coal to the extent that such cost exceeds generally
prevailing market prices for similar coal, as determined by the PUC. The PUC
allows deferred amounts to be recovered from customers when the delivered costs
of coal fall below such PUC-determined prevailing market prices. Duquesne's
obligations to pay certain debt service costs associated with the Bruce
Mansfield coal supply will end on January 1, 2000. The Bruce Mansfield coal
cost-capping mechanism does not expire until the recovery of all deferrals has
been resolved. Duquesne believes that Bruce Mansfield deferrals may increase
through the end of this decade and then be reduced to zero by the end of the
year 2002. The unrecovered cost of Bruce Mansfield coal was $9.6 million and the
unrecovered cost of the remainder of the system-wide coal was $2.6 million at
December 31, 1996. Duquesne believes that all deferred coal costs will be
recovered.
Nuclear Fuel
- -------------------------------------------------------------------------------
The cycle of production and utilization of nuclear fuel consists of
(1) mining and milling of uranium ore and processing the ore into uranium
concentrates, (2) converting uranium concentrates to uranium hexafluoride, (3)
enriching the uranium hexafluoride, (4) fabricating fuel assemblies, (5)
utilizing the nuclear fuel in the generating station reactor and (6) storing and
disposing of spent fuel.
9
Adequate supplies of uranium and conversion services are under
contract for Duquesne's requirements for its jointly owned/leased nuclear units
through June and December 1997, respectively. Enrichment services are supplied
under a 1984 United States Enrichment Corporation Utility Services Contract
entered into for a period of 30 years by Duquesne for joint interests in Perry
Unit 1, BV Unit 1 and BV Unit 2. Under the terms and conditions of this
contract, Duquesne is committed to 100 percent of its enrichment needs through
1999; Duquesne has terminated, at zero cost, all of its enrichment services
requirements for fiscal years 2000 through 2005. Duquesne continues to review
the need for further enrichment services for the years 2006 through 2014 and may
terminate these future years' services under the contract. Fuel fabrication
contracts are in place to supply reload requirements for the next 18-month cycle
for BV Unit 1 and BV Unit 2 and the next fifteen 18-month cycles for Perry Unit
1. Duquesne will make arrangements for future uranium supply and related
services, as required.
Each utility company is responsible for financing its proportionate
share of the costs of nuclear fuel for each nuclear unit in which it has an
ownership or leasehold interest. Duquesne's nuclear fuel costs, which are
amortized to reflect fuel consumed, are charged to fuel expense and are
currently recovered through rates. Duquesne estimates that, over the next three
years, the expenditures for new fuel will exceed the amortization of nuclear
fuel consumed by approximately $4.4 million. The actual nuclear fuel costs to be
financed and amortized will be influenced by such factors as changes in interest
rates; lengths of the respective fuel cycles; reload cycle design; and changes
in nuclear material costs and services, the prices and availability of which are
not known at this time. Such costs may also be influenced by other events not
presently foreseen.
Nuclear Decommissioning
- -------------------------------------------------------------------------------
The PUC ruled that recovery of the decommissioning costs for BV Unit
1 could begin in 1977, and that recovery for BV Unit 2 and Perry Unit 1 could
begin in 1988. Duquesne expects to decommission BV Unit 1, BV Unit 2 and Perry
Unit 1 no earlier than the expiration of each plant's operating license in 2016,
2027 and 2026. At the end of its operating life, BV Unit 1 may be placed in safe
storage until BV Unit 2 is ready to be decommissioned, at which time the units
may be decommissioned together.
Based on site-specific studies finalized in 1992 for BV Unit 2, and
in 1994 for BV Unit 1 and Perry Unit 1, Duquesne's share of the total estimated
decommissioning costs, including removal and decontamination costs, currently
being used to determine Duquesne's cost of service, is $122 million for BV Unit
1, $35 million for BV Unit 2, and $67 million for Perry Unit 1. A study will be
performed in 1997 to update Duquesne's estimated decommissioning costs of BV
Unit 1 and BV Unit 2.
On July 18, 1996, the PUC issued a Proposed Policy Statement Regarding
Nuclear Decommissioning Cost Estimation and Cost Recovery for the purpose of
obtaining comments from the public. The proposed policy includes guidelines for
a site-specific study to estimate the cost of decommissioning. Guidelines
require that studies be performed at least every five years, address
radiological and non-radiological costs, and include a contingency factor of not
more than 10 percent. Under the proposed policy, annual decommissioning funding
levels are based on an annuity calculation recognizing inflation in the cost
estimates and earnings on fund assets. With respect to the transition to a
competitive generation market, the Customer Choice Act requires that utilities
include a plan to mitigate any shortfall in decommissioning trust fund payments
for the life of the facility with any future decommissioning filings. Consistent
with this requirement, Duquesne has increased its nuclear decommissioning
funding by $5 million under the PUC-approved plan for the sale of Duquesne's
ownership interest in Ft. Martin. (See "Mitigation Plan" discussion on page 5.)
These additional annual contributions bring the total annual funding to
approximately $9 million. Also, on October 17, 1996, the PUC adopted an
Accounting Order filed by Duquesne to recognize the increased funding as part of
Duquesne's cost of service. Duquesne expects to receive approval from the
Internal Revenue Service (IRS) for qualification of 100 percent of additional
nuclear decommissioning trust funding for BV Unit 2 and Perry Unit 1, and 79
percent for BV Unit 1.
Duquesne records nuclear decommissioning expense under the category of
depreciation and amortization expense and accrues a liability, equal to that
amount, for nuclear decommissioning costs. Funding for nuclear decommissioning
costs is deposited in external, segregated trust accounts and may be invested in
a portfolio of corporate common stock and debt securities, municipal bonds,
certificates of deposit and United States government securities. Trust fund
earnings increase the fund balance and the recorded liability. The market value
of the aggregate trust fund balances at December 31, 1996 totaled approximately
$33.7 million. On Duquesne's consolidated balance sheet, the decommissioning
trusts have been reflected in other long-term investments, and the related
liability has been recorded as other non-current liabilities.
10
Nuclear Insurance
- -------------------------------------------------------------------------------
The Price-Anderson Amendments to the Atomic Energy Act of 1954 limit
public liability from a single incident at a nuclear plant to $8.9 billion. The
maximum available private primary insurance of $200 million has been purchased
by Duquesne. Additional protection of $8.7 billion would be provided by an
assessment of up to $79.3 million per incident on each nuclear unit in the
United States. Duquesne's maximum total possible assessment, $59.4 million,
which is based on its ownership or leasehold interests in three nuclear
generating units, would be limited to a maximum of $7.5 million per incident per
year. This assessment is subject to indexing for inflation and may be subject to
state premium taxes. If funds prove insufficient to pay claims, the United
States Congress could impose other revenue-raising measures on the nuclear
industry.
Duquesne's share of insurance coverage for property damage,
decommissioning and decontamination liability is $1.2 billion. Duquesne would be
responsible for its share of any damages in excess of insurance coverage. In
addition, if the property damage reserves of Nuclear Electric Insurance Limited
(NEIL), an industry mutual insurance company that provides a portion of this
coverage, are inadequate to cover claims arising from an incident at any United
States nuclear site covered by that insurer, Duquesne could be assessed
retrospective premiums totaling a maximum of $7.3 million.
In addition, Duquesne participates in a NEIL program that provides
insurance for the increased cost of generation and/or purchased power resulting
from an accidental outage of a nuclear unit. Subject to the policy limit, the
coverage provides for 100 percent of the estimated incremental costs per week
during the 52-week period starting 21 weeks after an accident and 80 percent of
such estimate per week for the following 104 weeks, with no coverage thereafter.
If NEIL's losses for this program ever exceed its reserves, Duquesne could be
assessed retrospective premiums totaling a maximum of $3.5 million.
Spent Nuclear Fuel Disposal
- -------------------------------------------------------------------------------
The Nuclear Waste Policy Act of 1982 established a policy for
handling and disposing of spent nuclear fuel and a policy requiring the
establishment of a final repository to accept spent nuclear fuel. Electric
utility companies have entered into contracts with the United States Department
of Energy (DOE) for the permanent disposal of spent nuclear fuel and high-level
radioactive waste in compliance with this legislation. The DOE has indicated
that its repository under these contracts will not be available for acceptance
of spent nuclear fuel before 2010. On July 23, 1996, the U.S. Court of Appeals
for the District of Columbia Circuit, in response to a suit brought by 25
electric utilities and 18 states and state agencies, unanimously ruled that the
DOE has a legal obligation to begin taking spent nuclear fuel by January 31,
1998. The DOE has not yet established an interim or permanent storage facility,
and has indicated that it will be unable to begin acceptance of spent nuclear
fuel for disposal by January 31, 1998. Further, Congress is considering
amendments to the Nuclear Waste Policy Act of 1982 that could give the DOE
authority to proceed with the development of a federal interim storage facility.
In the event the DOE does not begin accepting spent nuclear fuel, existing on-
site spent nuclear fuel storage capacities at BV Unit 1, BV Unit 2 and Perry
Unit 1 are expected to be sufficient until 2016 (end of operating license), 2013
and 2011, respectively.
On January 31, 1997, Duquesne joined 35 other electric utilities and 46
states, state agencies and regulatory commissions in filing a suit in the U.S.
Court of Appeals for the District of Columbia against the DOE. The suit requests
the court to suspend the utilities' payments into the Nuclear Waste Fund and to
place future payments into an escrow account until the DOE fulfills its
obligation to accept spent nuclear fuel. Significant additional expenditures for
the storage of spent nuclear fuel at BV Unit 2 and Perry Unit 1 could be
required if the DOE does not fulfill its obligation to accept spent nuclear
fuel.
Uranium Enrichment Decontamination and Decommissioning
- -------------------------------------------------------------------------------
Nuclear reactor licensees in the United States are assessed annually
for the decontamination and decommissioning of DOE uranium enrichment
facilities. Assessments are based on the amount of uranium a utility had
processed for enrichment prior to enactment of the National Energy Policy Act of
1992 (NEPA) and are to be paid by such utilities over a 15-year period. At
December 31, 1996, Duquesne's liability for contributions was approximately $9.3
million (subject to an inflation adjustment). Contributions, when made, are
currently recovered from customers through the ECR.
11
Environmental Matters
- -------------------------------------------------------------------------------
The Comprehensive Environmental Response, Compensation and Liability
Act of 1980 and the Superfund Amendments and Reauthorization Act of 1986
(Superfund) established a variety of informational and environmental action
programs. The United States Environmental Protection Agency (EPA) informed
Duquesne of its potential involvement in three hazardous waste sites. Duquesne
reached agreements to make de minimus financial payments in 1995 related to two
sites in order to resolve any associated liability. Related to the remaining
site, Duquesne believes that available defenses, along with other factors
(including overall limited involvement, low estimated remediation costs and
other solvent, potentially responsible parties) will limit any potential
liability that Duquesne may have for cleanup costs. Duquesne believes that any
settlement or associated costs related to the remaining site will not have a
materially adverse effect on its financial position, results of operations or
cash flows.
As required by Title V of the Clean Air Act Amendments (Clean Air Act),
Duquesne filed comprehensive air operating permit applications for Cheswick,
Elrama, BI and Phillips during the last half of 1995. These applications are
still pending approval. Duquesne also filed its Title IV Phase II Clean Air Act
compliance plan with the PUC on December 27, 1995.
Although Duquesne believes it has satisfied all of the Phase I Acid
Rain Program requirements of the Clean Air Act, Phase II Acid Rain Program
requires significant additional reductions of sulfur dioxide (SO\\2\\) and
oxides of nitrogen (NO\\X\\) by the year 2000. Duquesne currently has 662 MW of
nuclear capacity and 1,187 MW of coal capacity equipped with SO\\2\\ emission-
reducing equipment (including 300 MW of property held for future use at
Phillips). Through the year 2000, Duquesne is considering a combination of
compliance methods that include fuel switching; increased use of, and
improvements in, SO\\2\\ emission-reducing equipment; low NO\\X\\ burner
technology; and the purchase of emission allowances for those remaining stations
not in compliance.
In addition to the Title IV Acid Rain Program requirements, Duquesne is
responsible for additional NO\\X\\ reduction requirements to meet Ozone Ambient
Air Quality Standards under Title I of the Clean Air Act. Flue gas conditioning
and post-combustion NO\\X\\ reduction technologies may be employed if
economically justified. Also, Duquesne is examining and developing innovative
emissions technologies designed to reduce costs. Duquesne continues to work with
the operators of its jointly owned stations to implement cost-effective
compliance strategies to meet these requirements.
Duquesne is closely monitoring other potential future air quality
programs and air emission control requirements that could result from more
stringent ambient air quality and emission standards for SO\\2\\ and NO\\X\\
particulates and other by-products of coal combustion. Duquesne expects the
Pennsylvania Department of Environmental Protection (DEP) to finalize in 1997 a
regulation to implement the additional NO\\X\\ control requirements that were
recommended by the Ozone Transport Commission. The estimated costs to comply
with this program have been included in Duquesne's capital cost estimates
through the year 2000. Since other potential programs are in various stages of
discussion and consideration, it is impossible to make reasonable estimates of
the potential costs and impacts, if any. Duquesne currently estimates that
additional capital costs to comply with Clean Air Act requirements through the
year 2000 will be approximately $20 million.
Duquesne has developed, patented and installed low NO\\X\\ burner
technology for the Elrama boilers. These cost-effective NO\\X\\ reduction
systems installed on the Elrama roof-fired boilers were specified as the
benchmark for the industry for this class of boilers in the EPA's final Group II
rulemaking. Duquesne is also currently evaluating additional low-cost,
developmental NO\\X\\ reduction technologies at Cheswick and Elrama. An
Artificial Neural Network control system enhancement, co-sponsored by the
Electric Power Research Institute and Duquesne, will be demonstrated at
Cheswick. The Gas Research Institute and Duquesne are sponsoring a targeted
natural gas reburn demonstration at Elrama. Both demonstrations were initiated
in 1996 and will be completed in 1997.
In 1992, the DEP issued Residual Waste Management Regulations
governing the generation and management of non-hazardous residual waste, such as
coal ash. Duquesne is assessing the sites it utilizes and has developed
compliance strategies that are currently under review by the DEP. Capital costs
of $2.5 million were incurred by Duquesne in 1996 to comply with these DEP
regulations. Based on information currently available, an additional $2.8
million will be spent in 1997. The additional capital cost of compliance through
the year 2000 is estimated, based on current information, to be $15 million.
This estimate is subject to the results of groundwater assessments and DEP final
approval of compliance plans.
12
Duquesne is involved in various other environmental matters. Duquesne
believes that such matters, in total, will not have a materially adverse effect
on its financial position, results of operations or cash flows.
Outlook
- -------------------------------------------------------------------------------
Competition
The electric utility industry continues to undergo fundamental change
in response to open transmission access and increased availability of energy
alternatives. Under historical PUC ratemaking, regulated electric utilities were
granted exclusive geographic franchises to sell electricity in exchange for
making investments and incurring obligations to serve customers under the then-
existing regulatory framework. Through the ratemaking process, those prudently
incurred costs were recovered from customers, along with a return on the
investment. Additionally, certain operating costs were approved for deferral for
future recovery from customers. As a result of this historical ratemaking
process, utilities have assets recorded on their balance sheets at above-market
costs and have commitments to purchase power at above-market prices (transition
costs).
In Pennsylvania, under the Customer Choice Act which became effective
on January 1, 1997, consumers in a utility's traditional franchised territory
will ultimately be able to purchase electricity at market prices from a variety
of electric generation suppliers. Before the phase-in to customer choice begins
in 1999, the PUC expects utilities to take vigorous steps to mitigate transition
costs as much as possible without increasing the price they currently charge
customers. The PUC will determine what portion of a utility's remaining
transition costs will be recoverable from customers through a CTC. This charge
will be paid by consumers who choose alternative generation suppliers as well as
customers who choose their franchised utility. The CTC could last as long as
2005, providing a utility a total of up to nine years to recover transition
costs. An overall four-and-one-half year price cap will be imposed on the
transmission and distribution charges of electric utility companies.
Additionally, electric utility companies may not increase the generation price
component of prices as long as transition costs are being recovered, with
certain exceptions. If a utility ultimately is unable to recover its transition
costs within this pricing structure and timeframe, the costs will be written
off.
Duquesne has already been effective in mitigating its exposure to
transition costs. As the following table demonstrates, generating plant,
decommissioning and related regulatory asset costs have been reduced by
approximately $400 million during the past two years. These reductions have
resulted from a variety of strategies, such as selling generating assets,
accelerating recovery of fixed costs, increasing nuclear decommissioning charges
and reducing capitalized costs. Duquesne expects to continue these steps to
address its remaining transition costs. The Customer Choice Act provides another
option to mitigate transition costs. With PUC approval, utilities are permitted
to issue transition bonds with a maturity of 10 years or less. Proceeds can be
used to reduce transition costs. Duquesne is currently reviewing this
alternative as well as others to further mitigate its transition costs. (See
"Regulation" and "Rate Matters" discussions on pages 1 and 5.)
Potential Transition Costs
- -------------------------------------------------------------------------------
December 31, January 1,
1996 1995
(Amounts in Millions of Dollars)
- -------------------------------------------------------------------------------
Nuclear plant $ 910.5 $1,149.0
Generation-related regulatory assets 417.9 495.8
BV Unit 2 lease 399.1 401.0
Unfunded generating plant decommissioning 299.5 371.0
Phillips 78.3 78.3
Warwick Mine 15.3 25.0
Purchase power contracts -- --
- -------------------------------------------------------------------------------
Total $2,120.6 $2,520.1
===============================================================================
Any estimate of transition costs, including those in the table above,
is forward-looking and is highly dependent on estimates of the future market
prices for electric power. Higher market prices for electricity reduce
transition cost exposure, while lower market prices increase exposure. As part
of its transition filing, Duquesne is
13
proposing to make a long-term sale of electricity during the transition period
to determine the market rate for power. In addition to market-related impacts,
any estimate of the ultimate level of transition costs also depends on, among
other things, the extent to which such costs are deemed recoverable by the PUC,
the ongoing level of Duquesne's costs of operations, regional and national
economic conditions, and growth of Duquesne's sales. Duquesne anticipates making
its transition filing, including the identification of potential transition
costs, as required by the PUC by August 1, 1997. The PUC is expected to rule on
Duquesne's ability to recover these costs through a CTC by May 1, 1998. Duquesne
believes, based upon prior rulings of the PUC, that it is entitled to recover
substantially all of its transition costs, but cannot predict the outcome of
this regulatory process. In the event that the PUC rules that any or all of
these transition costs cannot be recovered through a CTC mechanism or Duquesne
fails to satisfy the requirements of SFAS No. 71, these costs will be written
off. As Duquesne has substantial exposure to transition costs relative to its
size, significant transition cost write-offs could have a materially adverse
effect on Duquesne's financial position, results of operations and cash flows.
Various financial covenants and restrictions could be violated if substantial
write-off of assets or recognition of liabilities occurs.
In addition to the mitigation of transition costs, Duquesne has been
preparing for competition in a variety of ways. Duquesne has been building its
financial strength through the retirement and refinancing of long-term debt. In
1995, Duquesne's restrictive first mortgage bond indenture was replaced with a
new indenture with more flexible provisions. In 1996, Duquesne issued MIPS to
further add to its financial flexibility and creditworthiness.
Duquesne has better positioned its business for competition through
improving operations and enhancing customer relations. In recognition of
impending industry competition and in an effort to optimize its generation
resources, in 1989 Duquesne signed a contract with Delmarva Power for a bulk
power sale for a period of 20 years. This initiative would have resulted in the
refurbishment and return to service of Duquesne's cold-reserved generating
stations. Following the plan's failure to receive regulatory approval, in 1990
Duquesne announced a second long-term power sale initiative to restart these
power plants. This plan would have provided significant impetus to economic
development in Pennsylvania as well as providing Duquesne's customers with
substantial benefits in the form of lower rates. Duquesne's efforts to upgrade
and maintain the cold-reserved units have enabled Duquesne to utilize the BI
units to meet peak demand during periods of extreme weather in recent years and
have enabled the BI units to more quickly return to service as part of the Ft.
Martin sale. In 1991, Duquesne reorganized into strategic business units along
market lines and instituted cost reduction targets for capital, operation and
maintenance, and inventory expenditures. Workforce reductions were achieved
primarily through attrition. Since 1989 Duquesne has reduced its number of
employees by 25 percent. Recently, Duquesne signed a three-year contract
extension with its bargaining unit employees through September 2001. Throughout
the period, Duquesne has been aggressively reducing its fuel costs, achieving a
13 percent reduction in the unit cost of fuel since 1990. These measures have
enabled Duquesne to reduce its rates by nearly 36 percent, in real terms, since
1990. When considering the price freeze component of Duquesne's Mitigation Plan,
prices will have declined by nearly 50 percent in real terms during the decade
of the 1990s. From a customer relations standpoint, Duquesne negotiated long-
term contracts with more than 30 key industrial and commercial customers and was
recognized in 1996 for its economic development efforts in attracting major new
industrial expansions. In 1995, Duquesne became one of the first electric
utilities in the country to offer a full customer service guarantee and also
guaranteed to match any competing electricity supplier's price for new
businesses or for the expansion of existing businesses. Duquesne also is
offering to customers increased bill-paying options, including an advanced
technology service that enables customers to electronically receive and pay
their electric bills. This service assists major customers just as its earlier
Electricheck option helped smaller commercial and residential customers.
Additionally, Duquesne will be positioned to offer customers a wide range of new
services with the Customer Advanced Reliability System (CARS). Utility customers
will be linked to CARS by encoder receiver transmitters contained in new or
retrofitted electric meters. Data communications offered by this technology are
expected to result in improved reliability, security, and customer satisfaction.
At the national level, in 1996 the FERC issued two related final
rules that address the terms on which electric utilities will be required to
provide wholesale suppliers of electric energy with non-discriminatory access to
the utility's wholesale transmission system. The first rule, Order No. 888,
requires each public utility that owns, controls or operates interstate
transmission facilities to file a tariff offering unbundled transmission
services containing non-rate terms that conform to the FERC's pro forma tariff.
Order No. 888 also allows full recovery of prudently incurred costs from
departing customers. FERC deferred to state regulators with respect to retail
access, recovery of retail transition costs and the scope of state regulatory
jurisdiction. The second rule, Order No. 889, prohibits transmission owners and
their affiliates from gaining preferential access to information concerning
transmission and establishes a code of conduct to ensure the complete separation
of a utility's wholesale power marketing and transmission operation functions.
14
Finally, the FERC simultaneously issued a new Notice of Proposed
Rulemaking (NOPR) on Capacity Reservation Open Access Transmission Tariffs
(CRT), which would require all market participants to reserve firm capacity
rights between designated receipt and delivery points. If adopted, the CRT would
replace the open access pro forma tariff implemented in Order No. 888. (See
"Transmission Access" discussion below.)
Duquesne is aware of the foregoing state and federal regulatory and
business uncertainties and is attempting to position itself to effectively
operate in a more competitive environment.
Transmission Access
In March 1994, Duquesne submitted, pursuant to the Federal Power Act,
two separate "good faith" requests for transmission service with APS and the
Pennsylvania-New Jersey-Maryland Interconnection Association (PJM Companies).
Because of a lack of progress on pricing and other issues, Duquesne subsequently
filed with the FERC applications for transmission service. In May 1995, the FERC
instructed APS and the PJM Companies to provide transmission service to Duquesne
and directed the parties to negotiate specific rates, terms and conditions. No
terms were agreed to, and briefs were filed with the FERC outlining the areas of
disagreement. The matter is now pending before the FERC. In July 1996, Duquesne
filed with the FERC a request for acceptance of a capacity reservation tariff to
replace the previously filed FERC Order No. 888 pro forma tariff. (See
"Competition" discussion on page 13.) Duquesne's tariff proposes to adopt
marginal cost pricing for transmission service on Duquesne's transmission
system. In February 1997, the FERC rejected Duquesne's tariff filing, but
permitted Duquesne to request a hearing to determine whether Duquesne's tariff
is just and reasonable as well as consistent with or superior to the Order No.
888 pro forma tariff. Duquesne has requested such a hearing.
Duquesne is currently evaluating the impact of FERC regulatory
actions on these proceedings. Duquesne cannot predict the final outcome of these
proceedings.
Beaver Valley Power Station (BVPS) Steam Generators
BVPS's two units are equipped with steam generators designed and
built by Westinghouse Electric Corporation (Westinghouse). Similar to other
Westinghouse nuclear plants, outside diameter stress corrosion cracking (ODSCC)
has occurred in the steam generator tubes of both units. The units continue to
have the capability to operate at 100 percent reactor power although 15 percent
of BV Unit 1 and 2 percent of BV Unit 2 steam generator tubes have been removed
from service. Material acceleration in the rate of ODSCC could lead to a loss in
plant efficiency and significant repairs or replacement of BV Unit 1 steam
generators. The total replacement cost of the BV Unit 1 steam generators is
estimated at $125 million, $59 million of which would be Duquesne's
responsibility. The earliest that the BV Unit 1 steam generators could be
replaced during a scheduled refueling outage is the fall of 2000.
Other
- -------------------------------------------------------------------------------
Retirement Plan Measurement Assumptions
Duquesne increased the discount rate used to determine the projected
benefit obligation on Duquesne's retirement plans at December 31, 1996 to 7.5
percent. The assumed change in future compensation levels and assumed rate of
return on plan assets were also increased to reflect current market and economic
conditions. The effects of these changes on Duquesne's retirement plan
obligations are reflected in the amounts shown in "Employee Benefits," Note N to
the consolidated financial statements, on page 55. The resulting change in
related expenses for subsequent years is not expected to be material.
Except for historical information contained herein, the matters
discussed in this Annual Report on Form 10-K, are forward-looking statements
that involve risks and uncertainties including, but not limited to, economic,
competitive, governmental and technological factors affecting Duquesne's
operations, markets, products, services and prices, and other factors discussed
in Duquesne's filings with the Securities and Exchange Commission.
----------------------------------
15
Executive Officers of the Registrant
Set forth below are the names, ages as of March 1, 1997, positions and
brief accounts of the business experience during the past five years of the
executive officers of Duquesne.
Name Age Office
- ------------------ ---- --------------------------------------------------------
David D. Marshall 44 President and Chief Executive Officer since August 1996.
President and Chief Operating Officer from February
1995 to August 1996. Executive Vice President from
February 1992 to February 1995, Assistant to the
President from October 1990 to February 1992, and
Vice President - Corporate Development from August
1987 to February 1992.
Gary L. Schwass 51 Senior Vice President since February 1995 and Chief
Financial Officer since July 1989. Vice President -
Finance from May 1988 to February 1995.
James E. Cross 50 President, Generation Group since September 1996.
Senior Vice President - Nuclear since February 1995.
Vice President - Nuclear from September 1994 to
February 1995. Formerly Vice President, Thermal
Operations, and Chief Nuclear Officer of Portland
General Electric from May 1993 to September 1994;
and Vice President and Chief Nuclear Officer of
Portland General Electric from December 1991 to
May 1993.
Dianna L. Green 50 Senior Vice President - Customer Operations since
April 1995. Senior Vice President - Administration
from February 1995 to April 1995. Vice President -
Administrative Services from August 1988 to
February 1995.
Gary R. Brandenberger 59 Vice President - Power Supply since August 1986.
William J. DeLeo 46 Vice President - Marketing and Corporate
Performance since April 1995. Vice President -
Corporate Performance and Information Services
from January 1991 to April 1995.
Victor A. Roque 50 Vice President since April 1995 and General Counsel
since November 1994. Previously Vice President,
General Counsel and Secretary for Orange and
Rockland Utilities from April 1989 to November 1994.
Donald J. Clayton 42 Treasurer since January 1995. Assistant Treasurer
from May 1990 to January 1995.
Morgan K. O'Brien 36 Controller and Principal Accounting Officer since
October 1995. Assistant Controller from
December 1993 to October 1995. Manager,
Corporate Taxes, from September 1991 to
December 1993.
16
Item 2. Properties.
Duquesne's properties consist of electric generating stations,
transmission and distribution facilities, and supplemental properties and
appurtenances, comprising as a whole an integrated electric utility system,
located in Allegheny, Beaver and Westmoreland counties in southwestern
Pennsylvania.
Duquesne owns all or a portion of the following generating units
except Beaver Valley Unit 2, which is leased.
Duquesne's
Share of Net Plant Output
Capacity Year Ended
(Megawatts) December 31, 1996
Name and Location Type Summer Winter (Megawatt-hours)
- ------------------ ---- ------ ----- -----------------
Cheswick Coal 562 570 3,101,155
Springdale, Pa.
Elrama Coal 474 487 2,572,107
Elrama, Pa.
Sammis Unit 7 (1) Coal 187 187 1,058,157
Stratton, Ohio
Eastlake Unit 5 (1) Coal 186 186 972,750
Eastlake, Ohio
Beaver Valley Unit 1 (1) Nuclear 385 385 2,713,594
Shippingport, Pa.
Beaver Valley Unit 2 (1) Nuclear 113 113 674,893
Shippingport, Pa.
Perry Unit 1 (1) Nuclear 161 164 1,026,442
North Perry, Ohio
Bruce Mansfield Unit 1 (1) Coal 228 228 965,248
Shippingport, Pa.
Bruce Mansfield Unit 2 (1) Coal 62 62 285,792
Shippingport, Pa.
Bruce Mansfield Unit 3 (1) Coal 110 110 480,342
Shippingport, Pa.
Ft. Martin Unit 1 (2) Coal 276 276 1,215,111
Brunot Island
Brunot Island, Pa. Oil 166 178 (6,846)
----- ----- ----------
Total 2,910 2,946 15,058,745
==========
Property held for future use:
Brunot Island Oil 92 128
Phillips Coal 300 300
----- -----
Total 3,302 3,374
===== =====
(1) Amounts represent Duquesne's share of the unit which is owned by Duquesne in
common with one or more other electric utilities (or, in the case of Beaver
Valley Unit 2, leased by Duquesne).
(2) Amount represents Duquesne's share of the unit, which was sold on October
31, 1996.
Duquesne owns 24 transmission substations (including interests in
common in the step-up transformers at Sammis Unit 7; Eastlake Unit 5; Bruce
Mansfield Unit 1; Beaver Valley Unit 1; Beaver Valley Unit 2; Perry Unit 1;
Bruce Mansfield Unit 2; and Bruce Mansfield Unit 3) and 562 distribution
substations. Duquesne has 714 circuit-miles of transmission lines, comprising
345,000, 138,000 and 69,000 volt lines. Street lighting and distribution
circuits of 23,000 volts and less include approximately 50,000 miles of lines
and cable.
17
Duquesne owns the Warwick Mine, including 4,849 acres owned in fee of
unmined coal lands and mining rights, located on the Monongahela River in Greene
County, Pennsylvania, approximately 83 river miles from Pittsburgh. (See Item 1.
BUSINESS. "Fossil Fuel" discussion on page 9.)
Additional information relating to Item 2. PROPERTIES, is set forth
in Note D, "Property, Plant and Equipment," of the consolidated financial
statements for year ended December 31, 1996, on page 42. The information is
incorporated here by reference.
Item 3. Legal Proceedings.
Rate-Related Legal Proceedings, Property, Plant and Equipment-Related Legal
Proceedings and Environmental Legal Proceedings
- --------------------------------------------------------------------------------
Eastlake Unit 5
In September 1995, Duquesne commenced arbitration against CEI, seeking
damages, termination of the Operating Agreement for Eastlake Unit 5 (Eastlake)
and partition of the parties' interests in Eastlake through a sale and division
of the proceeds. The arbitration demand alleged, among other things, the
improper allocation by CEI of fuel and related costs; the mismanagement of the
administration of the Saginaw coal contract in connection with the closing of
the Saginaw mine, which historically supplied coal to Eastlake; and the
concealment by CEI of material information. In October 1995, CEI commenced an
action against Duquesne in the Court of Common Pleas, Lake County, Ohio seeking
to enjoin Duquesne from taking any action to effect a partition on the basis of
a waiver of partition covenant contained in the deed to the land underlying
Eastlake. CEI also seeks monetary damages from Duquesne for alleged unpaid joint
costs in connection with the operation of Eastlake. Duquesne removed the action
to the United States District Court for the Northern District of Ohio, Eastern
Division, where it is now pending. Currently, the parties are engaged in
settlement discussions. To provide the parties with the opportunity to settle
their claims, the court has postponed litigation proceedings until April 1,
1997.
Proceedings involving Duquesne's rates are reported in Item 1.
BUSINESS "Rate Matters." Proceedings involving Property, Plant and Equipment are
reported in Item 1. BUSINESS "Property, Plant and Equipment." Proceedings
involving environmental matters are reported in Item 1. BUSINESS "Environmental
Matters."
Item 4. Submission of Matters to a Vote Of Security Holders.
Not applicable.
Part II
Item 5. Market for Registrant's Common Equity and Related Shareholder Matters.
Duquesne's common stock is not publicly traded. Effective July 7, 1989,
Duquesne became a wholly owned subsidiary of DQE, the holding company formed as
part of a shareholder-approved restructuring. As a result of the restructuring,
Duquesne's shareholders received DQE common stock in exchange for their shares
of Duquesne common stock, which were cancelled. DQE owns all of Duquesne's
outstanding common stock, which consists of 10 shares. As such, this item is not
applicable to Duquesne because all its common equity is held solely by DQE.
During 1996 and 1995, Duquesne declared quarterly dividends on its common stock
totaling $276 million and $144 million, respectively.
Item 6. Selected Financial Data.
Selected financial data for Duquesne for each of the six years in the
period ended December 31, 1996, are set forth on page 59. The financial data is
incorporated here by reference.
18
Item 7. Management's Discussion and Analysis of Financial Condition and Results
of Operations.
Management's discussion and analysis of financial condition and
results of operations are set forth in Item 1. BUSINESS. The discussion and
analysis are incorporated here by reference.
Item 8. Consolidated Financial Statements and Supplementary Data.
The Consolidated Balance Sheet of Duquesne Light Company and its
subsidiary as of December 31, 1996 and 1995, and the related Statements of
Consolidated Income, Retained Earnings and Cash Flows for each of the three
years in the period ended December 31, 1996, together with the Independent
Auditors' Report dated January 28, 1997, are set forth in pages 34 to 58 of this
Report. The consolidated financial statements and report are incorporated here
by reference. Quarterly financial information is included on page 58 in Note O
to Duquesne's consolidated financial statements and is incorporated here by
reference.
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.
All directors of DQE are also directors of Duquesne. Information
relating to DQE's and Duquesne's board of directors is set forth on page 6 of
the 1996 DQE Annual Report to Shareholders filed here as part of this Report in
Exhibit 99.2. The information is incorporated here by reference. Information
relating to the executive officers of the Registrant is set forth in Part I of
this Report under the caption "Executive Officers of the Registrant."
Item 11. Executive Compensation.
The information relating to executive compensation is set forth in
Exhibit 99.1, filed as part of this Report. The information is incorporated here
by reference.
Item 12. Security Ownership of Certain Beneficial Owners and Management.
DQE is the beneficial owner and holder of all shares of outstanding
Common Stock, $1 par value, of Duquesne Light, consisting of 10 shares as of
February 21, 1997. Information relating to the ownership of equity securities of
DQE and Duquesne Light by directors and executive officers of Duquesne Light is
set forth in Exhibit 99.1, filed as part of this Report. The information is
incorporated here by reference.
Item 13. Certain Relationships and Related Transactions.
None.
19
Part IV
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K.
(a)(1) The following information is set forth here on pages 34 through 58:
Report of Independent Certified Public Accountants.
Statement of Consolidated Income for the Three Years Ended December 31, 1996.
Consolidated Balance Sheet, December 31, 1996 and 1995.
Statement of Consolidated Cash Flows for the Three Years Ended
December 31, 1996.
Statement of Consolidated Retained Earnings for the Three Years Ended
December 31, 1996.
Notes to Consolidated Financial Statements.
(a)(2) The following financial statement schedule and the related
Report of Independent Certified Public Accountants (See pages 32 and 34.) are
filed here as a part of this Report:
Schedule for the Three Years Ended December 31, 1996:
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 financial statements.
(a)(3) Exhibits are set forth in the Exhibits Index on pages 21
through 31, and incorporated here by reference. Documents other than those
designated as being filed here are incorporated here by reference. Previously
filed 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, 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(d)(10)(iii), of Regulation S-K.
(b) Reports on Form 8-K filed during the twelve months ended December
31, 1996:
(1) May 13, 1996 - The following event was reported:
Item 7. Statement re: Calculation of Ratio of Earnings to Combined
Fixed Charges and Preferred and Preference Stock Dividend
Requirements.
No financial statements were filed with this report.
20
Exhibits Index
Exhibit Method of
No. Description Filing
-------- -------------------------------------------------- ----------------------------
3.1 Restated Articles of Duquesne Light Company, as Exhibit 3.1 to the Form 10-K
amended through December 19, 1991 and as currently Annual Report of Duquesne
in effect. Light Company for the year
ended December 31, 1991.
3.2 By-Laws of Duquesne Light Company, as amended Filed here.
through December 18, 1996 and as currently in effect.
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. Filed here.
4.4 Amended and Restated Agreement of Limited Partnership Filed here.
of Duquesne Capital L.P., dated as of May 14, 1996.
4.5 Payment and Guarantee Agreement dated as of May 14, Filed here.
1996 by Duquesne Light Company with respect to MIPS.
4.6 Indenture dated as of May 1, 1996 by Duquesne Light Filed here.
Company to the First National Bank of Chicago as
Trustee.
21
Exhibit Method of
No. Description Filing
-------- --------------------------------------------------------- -------------------------
Agreements relating to Jointly Owned Generating Units:
10.1 Administration Agreement dated as of September 14, 1967. Exhibit 5.8 to Registration
Statement (Form S-7)
No. 2-43106.
10.2 Transmission Facilities Agreement dated as of September Exhibit 5.9 to Registration
14, 1967. Statement (Form S-7)
No. 2-43106.
10.3 Operating Agreement dated as of September 21, 1972 Exhibit 5.1 to Registration
for Eastlake Unit No. 5. Statement (Form S-7)
No. 2-48164.
10.4 Memorandum of Agreement dated as of July 1, 1982 re Exhibit 10.14 to the Form 10-K
reallocation of rights and liabilities of the companies Annual Report of Duquesne
under uranium supply contracts. Light Company for the year
ended December 31, 1987.
10.5 Operating Agreement dated August 5, 1982 as of Exhibit 10.17 to the Form 10-K
September 1, 1971 for Sammis Unit No. 7. Annual Report of Duquesne
Light Company for the year
ended December 31, 1988.
10.6 Memorandum of Understanding dated as of March 31, Exhibit 10.19 to the Form 10-K
1985 re implementation of company-by-company Annual Report of DQE for the
management of uranium inventory and delivery. year ended December 31, 1989.
10.7 Restated Operating Agreement for Beaver Valley Unit Exhibit 10.23 to the Form 10-K
Nos. 1 and 2 dated September 15, 1987. Annual Report of Duquesne
Light Company for the year
ended December 31, 1987.
10.8 Operating Agreement for Perry Unit No. 1 dated Exhibit 10.24 to the Form 10-K
March 10, 1987. Annual Report of Duquesne
Light Company for the year
ended December 31, 1987.
10.9 Operating Agreement for Bruce Mansfield Units Nos. 1, Exhibit 10.25 to the Form 10-K
2 and 3 dated September 15, 1987 as of June 1, 1976. Annual Report of Duquesne
Light Company for the year
ended December 31, 1987.
10.10 Basic Operating Agreement, as amended January 1, 1993. Exhibit 10.10 to the Form 10-K
Annual Report of Duquesne
Light Company for the year
ended December 31, 1993.
10.11 Amendment No. 1 dated December 23, 1993 to Exhibit 10.11 to the Form 10-K
Transmission Facilities Agreement (as of January 1, 1993). Annual Report of Duquesne
Light Company for the year
ended December 31, 1993.
22
Exhibit Method of
No. Description Filing
-------- --------------------------------------------------- ------------------------------
10.12 Microwave Sharing Agreement (as amended Exhibit 10.12 to the Form 10-K
January 1, 1993) dated December 23, 1993. Annual Report of Duquesne
Light Company for the year
ended December 31, 1993.
10.13 Agreement (as of September 1, 1980) dated Exhibit 10.13 to the Form 10-K
December 23, 1993 for termination or construction Annual Report of Duquesne
of certain agreements. Light Company for the year
ended December 31, 1993.
10.14 Fort Martin Power Station Asset Purchase Agreement Exhibit 10.17 to the Form 10-K
dated as of November 28, 1995. Annual Report of Duquesne
Light Company for the year
ended December 31, 1995.
Agreements relating to the Sale and Leaseback
of Beaver Valley Unit No. 2:
10.15 Order of the Pennsylvania Public Utility Commission Exhibit 28.2 to the Form 10-Q
dated September 25, 1987 regarding the application Quarterly Report of Duquesne
of the Duquesne Light Company under Section 1102(a)(3) Light Company for the quarter
of the Public Utility Code for approval in connection ended September 30, 1987.
with the sale and leaseback of its interest in
Beaver Valley Unit No. 2.
10.16 Order of the Pennsylvania Public Utility Commission Exhibit 10.28 to the Form 10-K
dated October 15, 1992 regarding the Securities Annual Report of Duquesne
Certificate of Duquesne Light Company for the Light Company for the year
assumption of contingent obligations under ended December 31, 1992.
financing agreements in connection with the
refunding of Collateralized Lease Bonds.
x10.17 Facility Lease dated as of September 15, 1987 between Exhibit (4)(c) to Registration
The First National Bank of Boston, as Owner Trustee Statement (Form S-3)
under a Trust Agreement dated as of September 15, 1987 No. 33-18144.
with the limited partnership Owner Participant named
therein, Lessor, and Duquesne Light Company, Lessee.
y10.18 Facility Lease dated as of September 15, 1987 between Exhibit (4)(d) to Registration
The First National Bank of Boston, as Owner Trustee Statement (Form S-3)
under a Trust Agreement dated as of September 15, No. 33-18144.
1987, with the corporate Owner Participant named
therein, Lessor, and Duquesne Light Company, Lessee.
x10.19 Amendment No. 1 dated as of December 1, 1987 to Exhibit 10.30 to the Form 10-K
Facility Lease dated as of September 15, 1987 between Annual Report of Duquesne
The First National Bank of Boston, as Owner Trustee Light Company for the year
under a Trust Agreement dated as of September 15, 1987 ended December 31, 1987.
with the limited partnership Owner Participant named
therein, Lessor, and Duquesne Light Company, Lessee.
23
Exhibit Method of
No. Description Filing
-------- ------------------------------------------------------ -----------------------------------
y10.20 Amendment No. 1 dated as of December 1, 1987 to Exhibit 10.31 to the Form 10-K
Facility Lease dated as of September 15, 1987 between Annual Report of Duquesne
The First National Bank of Boston, as Owner Trustee Light Company for the year
under a Trust Agreement dated as of September 15, ended December 31, 1987.
1987 with the corporate Owner Participant named
therein, Lessor, and Duquesne Light Company, Lessee.
x10.21 Amendment No. 2 dated as of November 15, 1992 to Exhibit 10.33 to the Form 10-K
Facility Lease dated as of September 15, 1987 between Annual Report of Duquesne
The First National Bank of Boston, as Owner Trustee Light Company for the year
under a Trust Agreement dated as of September 15, 1987 ended December 31, 1992.
with the limited partnership Owner Participant named
therein, Lessor, and Duquesne Light Company, Lessee.
y10.22 Amendment No. 2 dated as of November 15, 1992 to Exhibit 10.34 to the Form 10-K
Facility Lease dated as of September 15, 1987 between Annual Report of Duquesne
The First National Bank of Boston, as Owner Trustee Light Company for the year
under a Trust Agreement dated as of September 15, ended December 31, 1992.
1987 with the corporate Owner Participant named
therein, Lessor, and Duquesne Light Company, Lessee.
x10.23 Amendment No. 3 dated as of October 13, 1994 to Exhibit 10.25 to the Form 10-K
Facility Lease dated as of September 15, 1987 between Annual Report of Duquesne
The First National Bank of Boston, as Owner Trustee Light Company for the year
under a Trust Agreement dated as of September 15, 1987 ended December 31, 1994.
with the limited partnership Owner Participant named
therein, Lessor, and Duquesne Light Company, Lessee.
y10.24 Amendment No. 3 dated as of October 13, 1994 to Exhibit 10.26 to the Form 10-K
Facility Lease dated as of September 15, 1987 between Annual Report of Duquesne
The First National Bank of Boston, as Owner Trustee Light Company for the year
under a Trust Agreement dated as of September 15, 1987 ended December 31, 1994.
with the corporate Owner Participant named therein,
Lessor, and Duquesne Light Company, Lessee.
x10.25 Participation Agreement dated as of September 15, Exhibit (28)(a) to Registration
1987 among the limited partnership Owner Statement (Form S-3)
Participant named therein, the Original Loan No. 33-18144.
Participants listed in Schedule 1 thereto, as Original
Loan Participants, DQU Funding Corporation, as Funding
Corp, The First National Bank of Boston, as Owner
Trustee, Irving Trust Company, as Indenture Trustee and
Duquesne Light Company, as Lessee.
y10.26 Participation Agreement dated as of September 15, 1987 Exhibit (28)(b) to Registration
among the corporate Owner Participant named therein, Statement (Form S-3)
the Original Loan Participants listed in Schedule 1 No. 33-18144.
thereto, as Original Loan Participants, DQU Funding
Corporation, as Funding Corp, The First National Bank
of Boston, as Owner Trustee, Irving Trust Company, as
Indenture Trustee and Duquesne Light Company, as
Lessee.
24
Exhibit Method of
No. Description Filing
-------- ------------------------------------------------------- --------------------------------
x10.27 Amendment No. 1 dated as of December 1, 1987 to Exhibit 10.34 to the Form 10-K
Participation Agreement dated as of September 15, 1987 Annual Report of Duquesne
among the limited partnership Owner Participant named Light Company for the year
therein, the Original Loan Participants listed therein, ended December 31, 1987.
as Original Loan Participants, DQU Funding
Corporation, as Funding Corp, The First National Bank
of Boston, as Owner Trustee, Irving Trust Company, as
Indenture Trustee and Duquesne Light Company, as Lessee.
y10.28 Amendment No. 1 dated as of December 1, 1987 to Exhibit 10.35 to the Form 10-K
Participation Agreement dated as of September 15, 1987 Annual Report of Duquesne
among the corporate Owner Participant named therein, Light Company for the year
the Original Loan Participants listed therein, ended December 31, 1987.
as Original Loan Participants, DQU Funding Corporation,
as Funding Corp, The First National Bank of Boston, as
Owner Trustee, Irving Trust Company, as Indenture
Trustee and Duquesne Light Company, as Lessee.
x10.29 Amendment No. 2 dated as of March 1, 1988 to Exhibit (28)(c)(3) to
Participation Agreement dated as of September 15, 1987 Registration Statement
among the limited partnership Owner Participant named (Form S-3) No. 33-54648.
therein, DQU Funding Corporation, as Funding Corp,
The First National Bank of Boston, as Owner Trustee,
Irving Trust Company, as Indenture Trustee and
Duquesne Light Company, as Lessee.
y10.30 Amendment No. 2 dated as of March 1, 1988 to Exhibit (28)(c)(4) to
Participation Agreement dated as of September 15, 1987 Registration Statement
among the corporate Owner Participant named therein, (Form S-3) No. 33-54648.
DQU Funding Corporation, as Funding Corp,
The First National Bank of Boston, as Owner Trustee,
Irving Trust Company, as Indenture Trustee and
Duquesne Light Company, as Lessee.
x10.31 Amendment No. 3 dated as of November 15, 1992 to Exhibit 10.41 to the Form 10-K
Participation Agreement dated as of September 15, 1987 Annual Report of Duquesne
among the limited partnership Owner Participant named Light Company for the year
therein, DQU Funding Corporation, as Funding Corp, ended December 31, 1992.
DQU II Funding Corporation, as New Funding Corp,
The First National Bank of Boston, as Owner Trustee,
The Bank of New York, as Indenture Trustee and
Duquesne Light Company, as Lessee.
y10.32 Amendment No. 3 dated as of November 15, 1992 to Exhibit 10.42 to the Form 10-K
Participation Agreement dated as of September 15, 1987 Annual Report of Duquesne
among the corporate Owner Participant named therein, Light Company for the year
DQU Funding Corporation, as Funding Corp, ended December 31, 1992.
DQU II Funding Corporation, as New Funding Corp,
The First National Bank of Boston, as Owner Trustee,
The Bank of New York, as Indenture Trustee and
Duquesne Light Company, as Lessee.
25
Exhibit Method of
No. Description Filing
-------- ------------------------------------------------- -----------------------------------
x10.33 Amendment No. 4 dated as of October 13, 1994 to Exhibit 10.35 to the Form 10-K
Participation Agreement dated as of September 15, 1987 Annual Report of Duquesne
among the limited partnership Owner Participant named Light Company for the year
therein, DQU Funding Corporation, as Funding Corp, ended December 31, 1994.
DQU II Funding Corporation, as New Funding Corp,
The First National Bank of Boston, as Owner Trustee,
The Bank of New York, as Indenture Trustee and
Duquesne Light Company, as Lessee.
y10.34 Amendment No. 4 dated as of October 13, 1994 to Exhibit 10.36 to the Form 10-K
Participation Agreement dated as of September 15, 1987 Annual Report of Duquesne
among the corporate Owner Participant named therein, Light Company for the year
DQU Funding Corporation, as Funding Corp, DQU II ended December 31, 1994.
Funding Corporation, as New Funding Corp,
The First National Bank of Boston, as Owner Trustee,
The Bank of New York, as Indenture Trustee and
Duquesne Light Company, as Lessee.
z10.35 Ground Lease and Easement Agreement dated as of Exhibit (28)(e) to Registration
September 15, 1987 between Duquesne Light Company, Statement (Form S-3)
Ground Lessor and Grantor, and The First National Bank No. 33-18144.
of Boston, as Owner Trustee under a Trust Agreement
dated as of September 15, 1987 with the limited
partnership Owner Participant named therein,
Tenant and Grantee.
z10.36 Assignment, Assumption and Further Agreement dated as Exhibit (28)(f) to Registration
of September 15, 1987 among The First National Bank of Statement (Form S-3)
Boston, as Owner Trustee under a Trust Agreement dated No. 33-18144.
as of September 15, 1987 with the limited partnership
Owner Participant named therein, The Cleveland Electric
Illuminating Company, Duquesne Light Company, Ohio
Edison Company, Pennsylvania Power Company and The
Toledo Edison Company.
z10.37 Additional Support Agreement dated as of September 15, Exhibit (28)(g) to Registration
1987 between The First National Bank of Boston, as Statement (Form S-3)
Owner Trustee under a Trust Agreement dated as of No. 33-18144.
September 15, 1987 with the limited partnership Owner
Participant named therein, and Duquesne Light Company.
z10.38 Indenture, Bill of Sale, Instrument of Transfer and Exhibit (28)(h) to Registration
Severance Agreement dated as of October 2, 1987 Statement (Form S-3)
between Duquesne Light Company, Seller, and The First No. 33-18144.
National Bank of Boston, as Owner Trustee under a Trust
Agreement dated as of September 15, 1987 with the
limited partnership Owner Participant named therein,
Buyer.
z10.39 Tax Indemnification Agreement dated as of September 15, Exhibit 28.1 to the Form 8-K
1987 between the Owner Participant named therein and Current Report of Duquesne
Duquesne Light Company, as Lessee. Light Company dated
November 20, 1987.
26
Exhibit Method of
No. Description Filing
-------- ------------------------------------------------- -------------------------------
z10.40 Amendment No. 1 dated as of November 15, 1992 to Exhibit 10.48 to the Form 10-K
Tax Indemnification Agreement dated as of September 15, Annual Report of Duquesne
1987 between the Owner Participant named therein and Light Company for the year
Duquesne Light Company, as Lessee. ended December 31, 1992.
z10.41 Amendment No. 2 dated as of October 13, 1994 to Tax Exhibit 10.43 to the Form 10-K
Indemnification Agreement dated as of September 15, 1987 Annual Report of Duquesne
between the Owner Participant named therein and Light Company for the year
Duquesne Light Company, as Lessee. ended December 31, 1994.
z10.42 Extension Letter dated December 8, 1992 from Exhibit 10.49 to the Form 10-K
Duquesne Light Company, each Owner Participant, The Annual Report of Duquesne
First National Bank of Boston, the Lease Indenture Light Company for the year
Trustee, DQU Funding Corporation and DQU II ended December 31, 1992.
Funding Corporation addressed to the New Collateral
Trust Trustee extending their respective representations
and warranties and covenants set forth in each of the
Participation Agreements.
x10.43 Trust Indenture, Mortgage, Security Agreement and Exhibit (4)(g) to Registration
Assignment of Facility Lease dated as of September 15, Statement (Form S-3)
1987 between The First National Bank of Boston, as No. 33-18144.
Owner Trustee under a Trust Agreement dated as of
September 15, 1987 with the limited partnership Owner
Participant named therein, and Irving Trust Company,
as Indenture Trustee.
y10.44 Trust Indenture, Mortgage, Security Agreement and Exhibit (4)(h) to Registration
Assignment of Facility Lease dated as of September 15, Statement (Form S-3)
1987 between The First National Bank of Boston, as No. 33-18144.
Owner Trustee under a Trust Agreement dated as of
September 15, 1987 with the corporate Owner
Participant named therein, and Irving Trust Company,
as Indenture Trustee.
x10.45 Supplemental Indenture No. 1 dated as of December 1, Exhibit 10.45 to the Form 10-K
1987 to Trust Indenture, Mortgage, Security Agreement Annual Report of Duquesne
and Assignment of Facility Lease dated as of Light Company for the year
September 15, 1987 between The First National Bank ended December 31, 1987.
of Boston, as Owner Trustee under a Trust Agreement
dated as of September 15, 1987 with the limited
partnership Owner Participant named therein, and Irving
Trust Company, as Indenture Trustee.
y10.46 Supplemental Indenture No. 1 dated as of December 1, Exhibit 10.46 to the Form 10-K
1987 to Trust Indenture, Mortgage, Security Agreement Annual Report of Duquesne
and Assignment of Facility Lease dated as of Light Company for the year
September 15, 1987 between The First National Bank of ended December 31, 1987.
Boston, as Owner Trustee under a Trust Agreement
dated as of September 15, 1987 with the corporate
Owner Participant named therein, and Irving Trust
Company, as Indenture Trustee.
27
Exhibit Method of
No. Description Filing
-------- ------------------------------------------------------- -------------------------------
x10.47 Supplemental Indenture No. 2 dated as of November 15, Exhibit 10.54 to the Form 10-K
1992 to Trust Indenture, Mortgage, Security Agreement Annual Report of Duquesne
and Assignment of Facility Lease dated as of September 15, Light Company for the year
1987 between The First National Bank of Boston, as ended December 31, 1992.
Owner Trustee under a Trust Agreement dated as of
September 15, 1987 with the limited partnership Owner
Participant named therein, and The Bank of New York,
as Indenture Trustee.
y10.48 Supplemental Indenture No. 2 dated as of November 15, Exhibit 10.55 to the Form 10-K
1992 to Trust Indenture, Mortgage, Security Agreement Annual Report of Duquesne
and Assignment of Facility Lease dated as of September 15, Light Company for the year
1987 between The First National Bank of Boston, as ended December 31, 1992.
Owner Trustee under a Trust Agreement dated as of
September 15, 1987 with the corporate Owner
Participant named therein, and The Bank of New York,
as Indenture Trustee.
10.49 Reimbursement Agreement dated as of October 1, 1994 Exhibit 10.51 to the Form 10-K
among Duquesne Light Company, Swiss Bank Annual Report of Duquesne
Corporation, New York Branch, as LOC Bank, Union Light Company for the year
Bank, as Administrating Bank, Swiss Bank ended December 31, 1994.
Corporation, New York Branch, as Administrating Bank
and The Participating Banks Named Therein.
10.50 Collateral Trust Indenture dated as of November 15, 1992 Exhibit 10.58 to the Form 10-K
among DQU II Funding Corporation, Duquesne Light Annual Report of Duquesne
Company and The Bank of New York, as Trustee. Light Company for the year
ended December 31, 1992.
10.51 First Supplemental Indenture dated as of November 15, Exhibit 10.59 to the Form 10-K
1992 to Collateral Trust Indenture dated as of Annual Report of Duquesne
November 15, 1992 among DQU II Funding Corporation, Light Company for the year
Duquesne Light Company and The Bank of New York, as ended December 31, 1992.
Trustee.
x10.52 Refinancing Agreement dated as of November 15, 1992 Exhibit 10.60 to the Form 10-K
among the limited partnership Owner Participant Annual Report of Duquesne
named therein, as Owner Participant, DQU Funding Light Company for the year
Corporation, as Funding Corp, DQU II Funding ended December 31, 1992.
Corporation, as New Funding Corp, The First
National Bank of Boston, as Owner Trustee, The Bank
of New York, as Indenture Trustee, The Bank of New
York, as Collateral Trust Trustee, The Bank of New York,
as New Collateral Trust Trustee, and Duquesne Light
Company, as Lessee.
28
Exhibit Method of
No. Description Filing
-------- --------------------------------------------------------- -------------------------------
y10.53 Refinancing Agreement dated as of November 15, 1992 Exhibit 10.61 to the Form 10-K
among the corporate Owner Participant named therein, Annual Report of Duquesne
as Owner Participant, DQU Funding Corporation, Light Company for the year
as Funding Corp, DQU II Funding Corporation, ended December 31, 1992.
as New Funding Corp, The First National Bank of Boston,
as Owner Trustee, The Bank of New York, as Indenture
Trustee, The Bank of New York, as Collateral Trust Trustee,
The Bank of New York, as New Collateral Trust Trustee,
and Duquesne Light Company, as Lessee.
x10.54 Addendum dated December 8, 1992 to Refinancing Exhibit 10.62 to the Form 10-K
Agreement dated as of November 15, 1992 among the Annual Report of Duquesne
limited partnership Owner Participant named therein, Light Company for the year
as Owner Participant, DQU Funding Corporation, as ended December 31, 1992.
Funding Corp, DQU II Funding Corporation, as New
Funding Corp, The First National Bank of Boston, as
Owner Trustee, The Bank of New York, as Indenture
Trustee, The Bank of New York, as Collateral Trust Trustee,
The Bank of New York, as New Collateral Trust Trustee,
and Duquesne Light Company, as Lessee.
y10.55 Addendum dated December 8, 1992 to Refinancing Exhibit 10.63 to the Form 10-K
Agreement dated as of November 15, 1992 among the Annual Report of Duquesne
corporate Owner Participant named therein, as Light Company for the year
Owner Participant, DQU Funding Corporation, as ended December 31, 1992.
Funding Corp, DQU II Funding Corporation, as New
Funding Corp, The First National Bank of Boston, as
Owner Trustee, The Bank of New York, as Indenture
Trustee, The Bank of New York, as Collateral Trust Trustee,
The Bank of New York, as New Collateral Trust Trustee,
and Duquesne Light Company, as Lessee.
Other Agreements:
10.56 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.
10.57 Incentive Compensation Program for Certain Executive Exhibit 10.2 to the Form 10-K
Officers of Duquesne Light Company, as amended to Annual Report of DQE for the
date. year ended December 31, 1992.
10.58 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.
10.59 Duquesne Light Company Outside Directors' Filed here.
Retirement Plan, as amended to date.
10.60 Duquesne Light/DQE Charitable Giving Program. Exhibit 10.6 to the Form 10-K
Annual Report of DQE for the
year ended December 31, 1992.
29
Exhibit Method of
No. Description Filing
-------- ------------------------------------------------- -----------------------------------
10.61 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.
10.62 Employment Agreement dated as of December 15, Exhibit 10.5 to the Form 10-K
1992 between DQE, Duquesne Light Company and Annual Report of DQE for the
Wesley W. von Schack. year ended December 31, 1992.
10.63 First Amendment dated as of October 25, 1994 to Exhibit 10.8 to the Form 10-K
Employment Agreement dated as of December 15, Annual Report of DQE for the
1992 between DQE, Duquesne Light Company and year ended December 31, 1994.
Wesley W. von Schack.
10.64 Resignation Agreement between DQE and Duquesne Exhibit 10.1 to the Form 10-Q
Light Company and Wesley W. von Schack. Quarterly Report of DQE for
the quarter ended
September 30, 1996.
10.65 Employment Agreement dated as of August 30, 1994 Exhibit 10.9 to the Form 10-K
between DQE, Duquesne Light Company and Annual Report of DQE for the
David D. Marshall. year ended December 31, 1994.
10.66 First Amendment dated as of June 27, 1995 to Exhibit 10.68 to the Form 10-K
Employment Agreement dated as of August 30, 1994 Annual Report of Duquesne
between DQE, Duquesne Light Company and Light Company for the year
David D. Marshall. ended December 31, 1995.
10.67 Employment Agreement dated as of August 30, 1994 Duquesne Light Company
between DQE, Duquesne Light Company and Exhibit 10.10 to the Form 10-K
Gary L. Schwass. Annual Report of DQE for the
year ended December 31, 1994.
10.68 Employment Agreement dated as of August 30, 1994 Exhibit 10.68 to the Form 10-K
between Duquesne Light Company and Dianna L. Annual Report of DQE for the
Green. year ended December 31, 1994.
10.69 First Amendment dated as of June 27, 1995 to Exhibit 10.71 to the Form 10-K
Employment Agreement dated as of August 30, 1994 Annual Report of Duquesne
between Duquesne Light Company and Dianna L. Light Company for the year
Green. ended December 31, 1995.
10.70 Employment Agreement dated as of October 14, 1996 Filed here.
between Duquesne Light Company and James E. Cross.
10.71 Non-Competition and Confidentiality Agreement dated Exhibit 10.14 to the Form 10-K
as of October 3, 1996 by and among DQE, Inc., Duquesne Annual Report of DQE for the
Light Company and David D. Marshall, together with a year ended December 31, 1996.
schedule listing substantially identical agreements with
Dianna L. Green, Victor A. Roque, James D. Mitchell
and James E. Cross.
12.1 Calculation of Ratio of Earnings to Fixed Charges. Filed here.
21.1 Subsidiaries of registrant:
Duquesne has no significant subsidiaries.
30
Exhibit Method of
No. Description Filing
-------- ------------------------------------------------- ----------------------------------
23.1 Independent Auditors' Consent. Filed here.
27.1 Financial Data Schedule. Filed here.
99.1 Executive Compensation of Duquesne Light Company Filed here.
Executive Officers for 1996 and Security Ownership
of Duquesne Light Company Directors and
Executive Officers as of February 21, 1997.
99.2 Directors of DQE and Duquesne Light Company. Filed here.
x An additional document, substantially identical in all material respects to
this Exhibit, has been entered into relating to one additional limited
partnership Owner Participant. Although the additional document may differ in
some respects (such as name of the Owner Participant, dollar amounts and
percentages), there are no material details in which the document differs from
this Exhibit.
y Additional documents, substantially identical in all material respects to
this Exhibit, have been entered into relating to four additional corporate Owner
Participants. Although the additional documents may differ in some respects
(such as names of the Owner Participants, dollar amounts and percentages), there
are no material details in which the documents differ from this Exhibit.
z Additional documents, substantially identical in all material respects to
this Exhibit, have been entered into relating to six additional Owner
Participants. Although the additional documents may differ in some respects
(such as names of the Owner Participants, dollar amounts and percentages), there
are no material details in which the documents differ from this Exhibit.
Copies of the exhibits listed above will be furnished, upon request, to
holders or beneficial owners of any class of Duquesne's stock as of February 21,
1997, subject to payment in advance of the cost of reproducing the exhibits
requested.
------------------------------
31
SCHEDULE II
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
For the Years Ended December 31, 1996, 1995 and 1994
(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, 1996
Reserve Deducted from the Asset
to which it applies:
Allowance for uncollectible accounts $17,920 $10,582 $4,080 (A) $14,288 (B) $18,294
------- ------- ------ ------- -------
Year Ended December 31, 1995
Reserve Deducted from the Asset
to which it applies:
Allowance for uncollectible accounts $15,021 $13,430 $3,567 (A) $14,098 (B) $17,920
------- ------- ------ ------- -------
Year Ended December 31, 1994
Reserve Deducted from the Asset
to which it applies:
Allowance for uncollectible accounts $13,282 $11,890 $3,837 (A) $13,988 (B) $15,021
------- ------- ------ ------- -------
Notes: (A) Recovery of accounts previously written off.
(B) Accounts receivable written off.
32
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.
DUQUESNE LIGHT COMPANY
(Registrant)
Date: March 25, 1997 By: /s/ David D. Marshall
-----------------------------
(Signature)
David D. Marshall
President, Chief
Executive Officer and Director
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/ David D. Marshall President, Chief Executive Officer and March 25, 1997
- --------------------------- Director
David D. Marshall
/s/ Gary L. Schwass Senior Vice President and Chief Financial March 25, 1997
- --------------------------- Officer
Gary L. Schwass
/s/ Morgan K. O'Brien Controller and Principal Accounting Officer March 25, 1997
- ---------------------------
Morgan K. O'Brien
/s/ Daniel Berg Director March 25, 1997
- ---------------------------
Daniel Berg
/s/ Doreen E. Boyce Director March 25, 1997
- ---------------------------
Doreen E. Boyce
/s/ Robert P. Bozzone Director March 25, 1997
- ---------------------------
Robert P. Bozzone
/s/ Sigo Falk Director March 25, 1997
- ---------------------------
Sigo Falk
/s/ William H. Knoell Director March 25, 1997
- ---------------------------
William H. Knoell
/s/ Robert Mehrabian Director March 25, 1997
- ---------------------------
Robert Mehrabian
/s/ Thomas J. Murrin Director March 25, 1997
- ---------------------------
Thomas J. Murrin
/s/ Eric W. Springer Director March 25, 1997
- ---------------------------
Eric W. Springer
33
Report of Independent Certified Public Accountants
To the Directors and Stockholder of Duquesne Light Company:
We have audited the accompanying consolidated balance sheet of
Duquesne Light Company (a wholly owned subsidiary of DQE) and its subsidiaries
as of December 31, 1996 and 1995, and the related consolidated statements of
income, retained earnings, and cash flows for each of the three years in the
period ended December 31, 1996. 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 Duquesne's management.
Our responsibility is to express an opinion on these financial statements and
financial statement schedule based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the 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 Duquesne Light Company and
its subsidiaries as of December 31, 1996 and 1995, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1996 in conformity with generally accepted accounting principles.
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.
/s/ Deloitte & Touche LLP
DELOITTE & TOUCHE LLP
Pittsburgh, Pennsylvania
January 28, 1997
34
Statement of Consolidated Income
- -------------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
------------------------------------------------------
Year Ended December 31,
- -------------------------------------------------------------------------------------------------------------------
1996 1995 1994
- -------------------------------------------------------------------------------------------------------------------
Operating Revenues:
Sales of Electricity:
Residential $ 405,392 $ 414,291 $ 401,246
Commercial 494,919 497,187 495,734
Industrial 190,723 190,689 195,852
Provision for doubtful accounts (10,582) (13,430) (11,890)
- -------------------------------------------------------------------------------------------------------------------
Net customer revenues 1,080,452 1,088,737 1,080,942
Utilities 58,292 55,963 58,295
- -------------------------------------------------------------------------------------------------------------------
Total Sales of Electricity 1,138,744 1,144,700 1,139,237
Other 38,081 35,084 29,387
- -------------------------------------------------------------------------------------------------------------------
Total Operating Revenues 1,176,825 1,179,784 1,168,624
- -------------------------------------------------------------------------------------------------------------------
Operating Expenses:
Fuel 204,655 208,546 222,420
Purchased power 32,269 23,422 21,715
Other operating 253,109 250,322 269,001
Maintenance 78,386 81,516 79,488
Depreciation and amortization 216,338 190,679 163,114
Taxes other than income taxes 84,625 86,349 85,839
Income taxes 85,364 92,313 90,491
- -------------------------------------------------------------------------------------------------------------------
Total Operating Expenses 954,746 933,147 932,068
- -------------------------------------------------------------------------------------------------------------------
Operating Income 222,079 246,637 236,556
- -------------------------------------------------------------------------------------------------------------------
Other Income and (Deductions):
Interest and dividend income 12,216 7,923 6,503
Income taxes 2,356 (581) 6,300
Allowance for equity funds used during construction -- 721 1,295
Other 9,991 (6,404) (2,151)
- -------------------------------------------------------------------------------------------------------------------
Total Other Income 24,563 1,659 11,947
- -------------------------------------------------------------------------------------------------------------------
Income Before Interest and Other Charges 246,642 248,296 248,503
- -------------------------------------------------------------------------------------------------------------------
Interest Charges:
Interest on long-term debt 88,478 95,391 101,027
Other interest 1,632 2,599 1,095
Allowance for borrowed funds used during construction (1,249) (764) (1,068)
- -------------------------------------------------------------------------------------------------------------------
Total Interest Charges 88,861 97,226 101,054
- -------------------------------------------------------------------------------------------------------------------
Monthly Income Preferred Securities Dividend Requirements 7,921 -- --
- -------------------------------------------------------------------------------------------------------------------
Net Income 149,860 151,070 147,449
Dividends on Preferred and Preference Stock 4,045 5,320 6,046
- -------------------------------------------------------------------------------------------------------------------
Earnings for Common Stock $ 145,815 $ 145,750 $ 141,403
===================================================================================================================
See notes to consolidated financial statements.
35
Consolidated Balance Sheet
- -------------------------------------------------------------------------------------
(Thousands of Dollars)
--------------------------
As of December 31,
--------------------------
Assets 1996 1995
- -------------------------------------------------------------------------------------
Property, Plant and Equipment:
Electric plant in service $ 4,272,623 $ 4,262,670
Construction work in progress 45,059 38,134
Property held under capital leases 99,608 133,381
Property held for future use 190,821 216,633
Other 662 1,192
- -------------------------------------------------------------------------------------
Gross property, plant and equipment 4,608,773 4,652,010
Less: Accumulated depreciation and amortization (1,891,300) (1,673,107)
- -------------------------------------------------------------------------------------
Total Property, Plant and Equipment -- Net 2,717,473 2,978,903
- -------------------------------------------------------------------------------------
Long-Term Investments:
Investment in DQE Common Stock 59,319 66,757
Other investments 102,948 102,648
- -------------------------------------------------------------------------------------
Total Long-Term Investments 162,267 169,405
- -------------------------------------------------------------------------------------
Current Assets:
Cash and temporary cash investments 154,414 2,490
- -------------------------------------------------------------------------------------
Receivables:
Electric customer accounts receivable 92,475 103,821
Other utility receivables 18,635 22,441
Other receivables 12,829 11,842
Less: Allowance for uncollectible accounts (18,294) (17,920)
- -------------------------------------------------------------------------------------
Receivables less allowance for uncollectible accounts 105,645 120,184
Less: Receivables sold -- (7,000)
- -------------------------------------------------------------------------------------
Total Receivables -- Net 105,645 113,184
- -------------------------------------------------------------------------------------
Materials and supplies (at average cost):
Coal 19,097 25,454
Operating and construction 52,669 53,298
- -------------------------------------------------------------------------------------
Total Materials and Supplies 71,766 78,752
- -------------------------------------------------------------------------------------
Other current assets 8,828 7,955
- -------------------------------------------------------------------------------------
Total Current Assets 340,653 202,381
- -------------------------------------------------------------------------------------
Other Non-Current Assets:
Regulatory assets 636,816 678,700
Other 39,877 38,276
- -------------------------------------------------------------------------------------
Total Other Non-Current Assets 676,693 716,976
- -------------------------------------------------------------------------------------
Total Assets $ 3,897,086 $ 4,067,665
=====================================================================================
See notes to consolidated financial statements.
36
Consolidated Balance Sheet
- --------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
-----------------------
As of December 31,
- --------------------------------------------------------------------------------------------------------------
Capitalization and Liabilities 1996 1995
- --------------------------------------------------------------------------------------------------------------
Capitalization:
Common stock (authorized -- 90,000,000 shares, issued and outstanding -- 10 shares) $ -- $ --
Capital surplus 825,540 837,265
Retained earnings 163,884 294,069
- --------------------------------------------------------------------------------------------------------------
Total Common Stockholder's Equity 989,424 1,131,334
- --------------------------------------------------------------------------------------------------------------
Non-redeemable preferred stock 63,608 63,608
Non-redeemable Monthly Income Preferred Securities 150,000 --
Non-redeemable preference stock 28,997 29,615
- --------------------------------------------------------------------------------------------------------------
Total preferred and preference stock before deferred ESOP benefit 242,605 93,223
Deferred employee stock ownership plan (ESOP) benefit (19,533) (22,257)
- --------------------------------------------------------------------------------------------------------------
Total Preferred and Preference Stock 223,072 70,966
- --------------------------------------------------------------------------------------------------------------
Long-term debt 1,271,961 1,322,531
- --------------------------------------------------------------------------------------------------------------
Total Capitalization 2,484,457 2,524,831
- --------------------------------------------------------------------------------------------------------------
Obligations Under Capital Leases 28,407 34,546
- --------------------------------------------------------------------------------------------------------------
Current Liabilities:
Current maturities and sinking fund requirements 70,912 71,051
Accounts payable 84,272 76,435
Accrued liabilities 59,020 53,930
Dividends declared 2,371 37,015
Other 4,613 9,191
- --------------------------------------------------------------------------------------------------------------
Total Current Liabilities 221,188 247,622
- --------------------------------------------------------------------------------------------------------------
Non-Current Liabilities:
Deferred income taxes-net 726,517 805,996
Deferred investment tax credits 106,201 115,760
Deferred income 139,075 162,916
Other 191,241 175,994
- --------------------------------------------------------------------------------------------------------------
Total Non-Current Liabilities 1,163,034 1,260,666
- --------------------------------------------------------------------------------------------------------------
Commitments and Contingencies (Note B through N)
- --------------------------------------------------------------------------------------------------------------
Total Capitalization and Liabilities $3,897,086 $4,067,665
==============================================================================================================
See notes to consolidated financial statements.
37
Statement of Consolidated Cash Flows
- --------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
--------------------------------------
Year Ended December 31,
--------------------------------------
1996 1995 1994
- --------------------------------------------------------------------------------------------------------
Cash Flows From Operating Activities:
Net income $ 149,860 $ 151,070 $ 147,449
Principal non-cash charges (credits) to net income:
Depreciation and amortization 216,338 190,679 163,114
Capital lease, nuclear fuel and other amortization 24,006 32,670 36,940
Deferred income taxes and investment tax credits -- net (98,874) (41,410) (33,411)
Phase-in plan revenues and related carrying charges -- -- 28,621
Changes in working capital other than cash (20,872) 30,656) (36,884)
Other 11,182 33,749 45,315
- --------------------------------------------------------------------------------------------------------
Net Cash Provided By Operating Activities 281,640 397,414 351,144
- --------------------------------------------------------------------------------------------------------
Cash Flows Provided By (Used In) Investing Activities:
Sale of generating station 169,100 -- --
Construction expenditures (88,546) (78,656) (94,315)
Long-term investments (4,225) (62,854) (5,317)
Proceeds from disposition of investments 4,203 -- --
Other (700) (4,534) 2,077
- --------------------------------------------------------------------------------------------------------
Net Cash Provided By (Used In) Investing Activities 79,832 (146,044) (97,555)
- --------------------------------------------------------------------------------------------------------
Cash Flows Used In Financing Activities:
Sale of bonds -- -- 114,110
Issuance of preferred stock 150,000 -- --
Decrease in notes payable -- -- (10,990)
Dividends on capital stock (281,015) (150,059) (151,059)
Reductions of long-term obligations:
Preferred and preference stock -- (29,732) (39,958)
Long-term debt (50,812) (56,114) (114,835)
Capital leases (19,326) (26,373) (33,522)
Other (8,395) (2,506) (1,431)
- --------------------------------------------------------------------------------------------------------
Net Cash Used In Financing Activities (209,548) (264,784) (237,685)
- --------------------------------------------------------------------------------------------------------
Net increase (decrease) in cash and temporary cash investments 151,924 (13,414) 15,904
Cash and temporary cash investments at beginning of year 2,490 15,904 --
- --------------------------------------------------------------------------------------------------------
Cash and temporary cash investments at end of year $ 154,414 $ 2,490 $ 15,904
========================================================================================================
Supplemental Cash Flow Information
Cash paid during the year for:
Interest (net of amount capitalized) $ 86,409 $ 95,521 $ 102,944
- --------------------------------------------------------------------------------------------------------
Income taxes $ 165,948 $ 115,504 $ 111,614
- --------------------------------------------------------------------------------------------------------
Non-cash investing and financing activities:
Capital lease obligations recorded $ 13,050 $ 14,961 $ 16,909
Contribution of DQE Common Stock from parent company $ -- $ -- $ 19,531
Preferred stock issued in conjunction with long-term investments $ -- $ 3,000 $ --
=========================================================================================================
See notes to consolidated financial statements.
38
Statement of Consolidated Retained Earnings
- ------------------------------------------------------------------------------------------
(Thousands of Dollars)
------------------------------
Year Ended December 31,
------------------------------
1996 1995 1994
- ------------------------------------------------------------------------------------------
Balance at beginning of year $294,069 $292,319 $294,916
Net Income for the Year 149,860 151,070 147,449
- ------------------------------------------------------------------------------------------
Total 443,929 443,389 442,365
Cash dividends declared:
Preferred stock 2,712 3,870 4,592
Preference stock (net of tax benefit of ESOP dividend) 1,333 1,450 1,454
Common stock 276,000 144,000 144,000
- ------------------------------------------------------------------------------------------
Total Cash Dividends Declared 280,045 149,320 150,046
- ------------------------------------------------------------------------------------------
Balance at end of year $163,884 $294,069 $292,319
==========================================================================================
See notes to consolidated financial statements.
Notes to Consolidated Financial Statements
A. Summary of
Significant
Accounting
Policies
Consolidation
- --------------------------------------------------------------------------------
Duquesne Light Company (Duquesne) is a wholly owned subsidiary of DQE,
an energy services holding company. Duquesne is engaged in the production,
transmission, distribution and sale of electric energy. Duquesne has one wholly
owned subsidiary, Monongahela Light and Power which makes long-term investments.
All material intercompany balances and transactions have been
eliminated in the preparation of the consolidated financial statements of
Duquesne.
Basis of Accounting
- --------------------------------------------------------------------------------
Duquesne is subject to the accounting and reporting requirements of
the United States Securities and Exchange Commission (SEC). In addition,
Duquesne's operations are subject to regulation by the Pennsylvania Public
Utility Commission (PUC) and the Federal Energy Regulatory Commission (FERC)
under the Federal Power Act with respect to rates for interstate sales,
transmission of electric power, accounting and other matters.
Duquesne's consolidated financial statements report regulatory assets
and liabilities in accordance with Statement of Financial Accounting Standards
No. 71, Accounting for the Effects of Certain Types of Regulation (SFAS No. 71),
and reflect the effects of the current ratemaking process. In accordance with
SFAS No. 71, Duquesne's consolidated financial statements reflect regulatory
assets and liabilities consistent with cost-based, pre-competition ratemaking
regulations. (See "Rate Matters," Note F, on page 44.)
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial
statements. The reported amounts of revenues and expenses during the reporting
period may also be affected by the estimates and assumptions management is
required to make. Actual results could differ from those estimates.
Revenues from Sales of Electricity
- --------------------------------------------------------------------------------
Meters are read monthly and electric utility customers are billed on
the same basis. Revenues are recorded in the accounting periods for which they
are billed, with the exception of energy cost recovery revenues. (See "Energy
Cost Rate Adjustment Clause (ECR)" discussion on page 40.)
39
Duquesne's Electric Service Territory
- --------------------------------------------------------------------------------
Duquesne provides electric service to customers in Allegheny County,
including the City of Pittsburgh, Beaver County and Westmoreland County. This
represents approximately 800 square miles in southwestern Pennsylvania, located
within a 500-mile radius of one-half of the population of the United States and
Canada. The population of the area served by Duquesne's operations, based on
1990 census data, is approximately 1,510,000, of whom 370,000 reside in the City
of Pittsburgh. In addition to serving approximately 580,000 direct customers,
Duquesne also sells electricity to other utilities.
Energy Cost Rate Adjustment Clause (ECR)
- --------------------------------------------------------------------------------
Through the ECR, Duquesne recovers (to the extent that such amounts
are not included in base rates) nuclear fuel, fossil fuel and purchased power
expenses and, also through the ECR, passes to its customers the profits from
short-term power sales to other utilities (collectively, ECR energy costs).
Nuclear fuel expense is recorded on the basis of the quantity of electric energy
generated and includes such costs as the fee imposed by the United States
Department of Energy (DOE) for future disposal and ultimate storage and
disposition of spent nuclear fuel. Fossil fuel expense includes the costs of
coal, natural gas and fuel oil used in the generation of electricity.
On Duquesne's statement of consolidated income, these ECR revenues are
included as a component of operating revenues. For ECR purposes, Duquesne
defers fuel and other energy expenses for recovery, or refunding, in subsequent
years. The deferrals reflect the difference between the amount that Duquesne is
currently collecting from customers and its actual ECR energy costs. The PUC
annually reviews Duquesne's ECR energy costs for the fiscal year April through
March, compares them to previously projected ECR energy costs, and adjusts the
ECR for over- or under-recoveries and for two PUC-established coal cost
standards. (See "Deferred Coal Costs" and "Warwick Mine Costs" discussions, Note
F, on pages 45 and 46.)
Over- or under-recoveries from customers are recorded in the
consolidated balance sheet as payable to, or receivable from, customers. At
December 31, 1996 and 1995, $1.8 million and $5.8 million were payable to
customers and shown as other current liabilities.
Under the Electricity Generation Customer Choice and Competition Act
(Customer Choice Act), Duquesne may replace the ECR effective April 1, 1997 by
rolling its ECR energy costs into its base rates. The effect of this change
would be to provide to Duquesne an opportunity to further mitigate its deferred
energy costs based upon its ability to manage its energy costs. Under Duquesne's
PUC-approved Mitigation Plan, the level of energy cost recovery is capped at
1.47 cents per kilowatt-hour (KWH) through May 2001. To the extent that
projections do not support recovery of previously deferred costs through this
pricing mechanism, these costs would become transition costs subject to recovery
through a competitive transition charge (CTC). (See "Customer Choice Act" and
"Mitigation Plan" discussions, Note F, on page 44.)
Maintenance
- --------------------------------------------------------------------------------
Incremental maintenance expense incurred for refueling outages at
Duquesne's nuclear units is deferred for amortization over the period between
refueling outages (generally 18 months). Duquesne accrues, over the periods
between outages, anticipated expenses for scheduled major fossil generating
station outages. Maintenance costs incurred for non-major scheduled outages and
for forced outages are charged to expense as such costs are incurred.
Depreciation and Amortization
- --------------------------------------------------------------------------------
Depreciation of property, plant and equipment, including plant-related
intangibles, is recorded on a straight-line basis over the estimated remaining
useful lives of properties. Amortization of other intangibles is recorded on a
straight-line basis over a five-year period. Depreciation and amortization of
other properties are calculated on various bases.
40
Duquesne records decommissioning costs under the category of
depreciation and amortization expense and accrues a liability, equal to that
amount, for nuclear decommissioning expense. On Duquesne's consolidated balance
sheet, the decommissioning trusts have been reflected in other long-term
investments, and the related liability has been recorded as other non-current
liabilities. (See "Nuclear Decommissioning" discussion, Note J, on page 49.)
Duquesne's composite depreciation rate increased from 3.5 percent to
4.25 percent effective May 1, 1996 and 3.0 percent to 3.5 percent effective
January 1, 1995. Also in 1996, Duquesne expensed $9 million related to the
depreciation portion of deferred rate synchronization costs in conjunction with
Duquesne's Mitigation Plan.
Income Taxes
- --------------------------------------------------------------------------------
Duquesne uses the liability method in computing deferred taxes on all
differences between book and tax bases of assets. 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.
Duquesne recognizes a regulatory asset for the deferred tax liabilities
that are expected to be recovered from customers through rates. (See "Rate
Matters," Note F, and "Income Taxes," Note H, on pages 44 and 46.)
Duquesne reflects the amortization of the regulatory tax receivable
resulting from reversals of deferred taxes as depreciation and amortization
expense. Reversals of accumulated deferred income taxes are included in income
tax expense.
When applied to reduce Duquesne's income tax liability, investment tax
credits related to electric utility property generally are deferred. Such
credits are subsequently reflected, over the lives of the related assets, as
reductions to income tax expense.
Property, Plant and Equipment
- --------------------------------------------------------------------------------
The asset values of Duquesne's properties are stated at original
construction cost, which includes related payroll taxes, pensions and other
fringe benefits, as well as administrative and general 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 properties that are
retired (plus removal costs and less any salvage value) are charged to
accumulated depreciation and amortization.
Substantially all of Duquesne's properties are subject to a first
mortgage lien.
Asset Impairment
- --------------------------------------------------------------------------------
The effects of adopting Statement of Financial Accounting Standards
No. 121, Accounting for the Impairment of Long-Lived Assets and for Long-Lived
Assets to Be Disposed Of (SFAS No. 121), on January 1, 1996 did not have a
material impact on Duquesne's financial position, results of operations or cash
flows, based on the current regulatory structure in which it operates. As
competitive factors influence pricing in the utility industry, this assessment
may change in the future. The general requirements of SFAS No. 121 apply to non-
current assets and require impairment to be considered whenever evidence
suggests that it is no longer probable that future cash flows in an amount at
least equal to the asset book value will result.
41
Stock-Based Compensation
- --------------------------------------------------------------------------------
Statement of Financial Accounting Standards No. 123, Accounting for
Stock-Based Compensation (SFAS No. 123) encourages, but does not require,
companies to record compensation cost for stock-based employee compensation
plans at fair value. Duquesne has chosen to continue to account for stock-based
compensation using the intrinsic value method prescribed in Accounting
Principles Board 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's stock at the
date of the grant over the amount an employee must pay to acquire the stock.
Compensation cost for stock appreciation rights is recorded annually based on
the quoted market price of DQE's stock at the end of the period.
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. Duquesne considers temporary cash investments to be
cash equivalents.
Reclassifications
- -------------------------------------------------------------------------------
The 1995 and 1994 consolidated financial statements have been
reclassified to conform with accounting presentations adopted during 1996.
B. Receivables
Duquesne and an unaffiliated corporation have an agreement that
entitles Duquesne to sell, and the corporation to purchase, on an ongoing basis,
up to $50 million of accounts receivable. Duquesne had no receivables sold at
December 31, 1996. At December 31, 1995, Duquesne had sold $7 million of
receivables to the unaffiliated corporation. The accounts receivable sales
agreement, which expires in June 1997, is one of many sources of funds available
to Duquesne. Duquesne has not determined, but may attempt to extend the
agreement or to replace the facility with a similar arrangement or to eliminate
it upon expiration.
C. Changes
in Working
Capital Other
Than Cash
Changes in Working Capital Other than Cash
- --------------------------------------------------------------------
1996 1995 1994
(Amounts in Thousands of Dollars)
- --------------------------------------------------------------------
Receivables $ 7,539 $ 19,131 $ 6,708
Materials and supplies 1,286 9,994 2,932
Other current assets (873) 7,840 (6,929)
Accounts payable 9,437 15,781 (23,816)
Other current liabilities (38,261) (22,090) (15,779)
- --------------------------------------------------------------------
Total $(20,872) $ 30,656 $(36,884)
====================================================================
D. Property,
Plant and
Equipment
In addition to its wholly owned generating units, Duquesne, together
with other electric utilities, has an ownership or leasehold interest in certain
jointly owned units. Duquesne is required to pay its share of the construction
and operating costs of the units. Duquesne's share of the operating expenses of
the units is included in the statement of consolidated income.
42
Generating Units at December 31, 1996
- --------------------------------------------------------------------------------------------
Generating Net Utility Fuel
Unit Capability Plant Source
(Megawatts) (Millions of Dollars)
- --------------------------------------------------------------------------------------------
Cheswick 570 $ 120.2 Coal
Elrama (a) 487 98.0 Coal
Eastlake Unit 5 186 39.4 Coal
Sammis Unit 7 187 49.5 Coal
Bruce Mansfield Unit 1 (a) 228 65.5 Coal
Bruce Mansfield Unit 2 (a) 62 18.9 Coal
Bruce Mansfield Unit 3 (a) 110 49.8 Coal
Beaver Valley Unit 1 (b) 385 215.9 Nuclear
Beaver Valley Unit 2 (c)(d) 113 14.3 Nuclear
Beaver Valley Common Facilities 153.2
Perry Unit 1 (e) 164 398.5 Nuclear
Brunot Island (f) 178 23.1 Fuel Oil
- --------------------------------------------------------------------------------------------
Total 2,670 1,246.3
Property held for future use:
Brunot Island (f) 128 28.5 Fuel Oil
Phillips (a) 300 78.3 Coal
- --------------------------------------------------------------------------------------------
Total Generating Units 3,098 $1,353.1
============================================================================================
(a) The unit is equipped with flue gas desulfurization equipment.
(b) The Nuclear Regulatory Commission (NRC) has granted a license to operate
through January 2016.
(c) On October 2, 1987, Duquesne sold its 13.74 percent interest in Beaver
Valley Unit 2 and leased it back; the sale was exclusive of transmission
and common facilities. Amounts shown represent facilities not sold and
subsequent leasehold improvements.
(d) The NRC has granted a license to operate through May 2027.
(e) The NRC has granted a license to operate through March 2026.
(f) A portion of the proceeds of the sale of the Ft. Martin Power Station is
expected to be used to fund reliability enhancements to the Brunot Island
(BI) Unit 3 combustion turbine. The reliability enhancements are
contingent upon the projects meeting a least-cost test versus other
potential sources of peaking capacity. BI Units 2a and 2b were moved from
property held for future use to electric plant in service in 1996, in
accordance with Duquesne's Mitigation Plan. (See "Mitigation Plan"
discussion, Note F, on page 44.)
E. Long-Term
Investments
At December 31, 1996 and 1995, the fair market value of Duquesne's
investment in DQE common stock was $59.3 million and $66.8 million. At December
31, 1996 and 1995, the cost of Duquesne's investment in DQE common stock was
$40.3 million and $43.9 million.
Duquesne makes equity investments in affordable housing. At
December 31, 1996, Duquesne had investments in eight affordable housing
developments.
Deferred income primarily relates to Duquesne's lease investments.
Deferred amounts will be recognized as income over the lives of the underlying
lease investments over periods generally not exceeding five years.
Duquesne's other investments are primarily in assets of nuclear
decommissioning trusts and marketable securities. In accordance with SFAS No.
115, these investments are classified as available-for-sale and are stated at
market value. The amount of unrealized holding gains related to marketable
securities at both December 31, 1996 and 1995 are $19.0 million and $22.9
million ($11.1 million and $13.4 million net of tax).
43
F. Rate Matters
Customer Choice Act
- -------------------------------------------------------------------------------
Under the Customer Choice Act, which went into effect on January 1,
1997, Pennsylvania has become a leader in customer choice. The Customer Choice
Act will enable Pennsylvania's electric utility customers to purchase
electricity at market prices from a variety of electric generation suppliers
(customer choice). Electric utility restructuring will be accomplished through a
two-stage process consisting of a pilot period (running through 1998) and a
phase-in period (1999 through 2001). Before the phase-in to customer choice
begins in 1999, the PUC expects utilities to take vigorous steps to mitigate
transition costs as much as possible without increasing the price they currently
charge customers. The PUC will determine what portion of a utility's remaining
transition costs will be recoverable from customers through a CTC. This charge
will be paid by consumers who choose alternative generation suppliers as well as
customers who choose their franchised utility. The CTC could last as long as
2005, providing a utility a total of up to nine years to recover transition
costs. An overall four-and-one-half year price cap will be imposed on the
transmission and distribution charges of electric utility companies.
Additionally, electric utility companies may not increase the generation price
component of prices as long as transition costs are being recovered, with
certain exceptions. If a utility ultimately is unable to recover its transition
costs within this pricing structure and timeframe, the costs will be written
off.
Mitigation Plan
- -------------------------------------------------------------------------------
Duquesne has taken a number of steps to mitigate its potential
transition costs. In addition to the steps taken during the last 10 years to
prepare for competition, effective January 1, 1995, Duquesne accelerated its
rate of depreciation on its fixed nuclear assets without seeking a rate increase
to recover the additional costs. On October 31, 1996, the sale of Duquesne's
ownership interest in the Ft. Martin Power Station (Ft. Martin) was completed.
Ft. Martin Unit 1 was owned 50 percent by Duquesne and 50 percent by its
operator, Allegheny Power System. The sale and a plan, to be funded in part by
the proceeds of the Ft. Martin transaction, were approved by the PUC on May 23,
1996. Under the approved plan, Duquesne will not increase its base rates for a
period of five years through May 2001. In addition, Duquesne recorded in October
1996 a one-time reduction of approximately $130 million in the book value of
Duquesne's nuclear plant investment. The proceeds from the sale are expected to
be used to fund reliability enhancements to the BI Unit 3 combustion turbine and
to reduce Duquesne's capitalization. The approved plan also provides for
incremental increases of $25 million in depreciation and amortization expense in
1996, 1997 and 1998 related to Duquesne's nuclear investment, as well as
additional annual contributions to its nuclear plant decommissioning funds of $5
million, without any increase in existing electric rates. Also, Duquesne will
record an annual $5 million credit to the ECR during the plan period to
compensate Duquesne's customers for lost profits from any short-term power sales
foregone by the sale of its ownership interest in Ft. Martin. In addition,
Duquesne will cap energy costs, beginning April 1, 1997 through the remainder of
the plan period, at a historical five-year average of 1.47 cents per KWH. In
accordance with the approved plan, Duquesne has expensed $9 million related to
the depreciation portion of the deferred rate synchronization costs associated
with Beaver Valley Unit 2 (BV Unit 2) and Perry Unit 1. Duquesne's approved plan
provides for the amortization of the remaining deferred rate synchronization
costs over a 10-year period. At December 31, 1996, the unamortized portion of
these costs totaled $41.4 million, net of deferred fuel savings related to the
two units. (See "Deferred Rate Synchronization Costs" discussion on page 45.)
Finally, Duquesne's approved plan also provides for annual assistance of $0.5
million to low-income customers.
Regulatory Assets
- -------------------------------------------------------------------------------
As a result of the application of SFAS No. 71, Duquesne records
regulatory assets on its consolidated balance sheet. The regulatory assets
represent probable future revenue to Duquesne because provisions for these costs
are currently included, or are expected to be included, in charges to electric
utility customers through the ratemaking process.
A company's electric utility operations or a portion of such operations
could cease to meet the SFAS No. 71 criteria for various reasons, including a
change in the FERC regulations or the competition-related changes in the PUC
regulations. (See "Customer Choice Act" discussion above.) Duquesne currently
believes its electricity generating assets and related regulatory assets
continue to satisfy these criteria in
44
light of the transition to competitive generation under the Customer Choice Act.
Should any portion of Duquesne's electric utility operations be deemed to no
longer meet the SFAS No. 71 criteria, Duquesne may be required to write off any
above-market cost assets, the recovery of which is uncertain, and any regulatory
assets or liabilities for those operations that no longer meet these
requirements.
Regulatory Assets at December 31
- ----------------------------------------------------------------------------------------------------
1996 1995
(Amounts in Thousands of Dollars)
- ----------------------------------------------------------------------------------------------------
Regulatory tax receivable (Note H) $394,131 $414,543
Unamortized debt costs (Note K)(a) 93,299 98,776
Deferred rate synchronization costs (see below) 41,446 51,149
Beaver Valley Unit 2 sale/leaseback premium (Note I)(b) 30,059 31,564
Deferred employee costs (c) 29,589 31,218
Deferred nuclear maintenance outage costs (Note A) 13,462 6,776
Deferred coal costs (see below) 12,191 12,753
DOE decontamination and decommissioning receivable (Note J) 9,779 10,687
Extraordinary property loss (d) - 8,300
Other 12,860 12,934
- ----------------------------------------------------------------------------------------------------
Total Regulatory Assets $636,816 $678,700
====================================================================================================
(a) The premiums paid to reacquire debt prior to scheduled maturity dates are
deferred for amortization over the life of the debt issued to finance the
reacquisitions.
(b) The premium paid to refinance the BV Unit 2 lease was deferred for
amortization over the life of the lease.
(c) Includes amounts for recovery of accrued compensated absences and accrued
claims for workers' compensation.
(d) During the third quarter of 1996, Duquesne completed recovery of its
investment in Perry Unit 2.
Deferred Rate Synchronization Costs
- -------------------------------------------------------------------------------
In 1987, the PUC approved Duquesne's petition to defer initial
operating and other costs of BV Unit 2 and Perry Unit 1. Duquesne deferred the
costs incurred from November 1987, when the units went into commercial
operation, until March 1988, when a rate order was issued. In its rate order,
the PUC postponed ruling on whether these costs would be recoverable from
Duquesne's customers. Duquesne is not earning a return on the deferred costs.
(See "Mitigation Plan" discussion on page 44.)
Deferred Coal Costs
- -------------------------------------------------------------------------------
The PUC has established two market price coal cost standards for
Duquesne. One applies only to coal delivered at the Bruce Mansfield Power
Station (Bruce Mansfield). The other, the system-wide coal cost standard,
applies to coal delivered to the remainder of Duquesne's system. Both standards
are updated monthly to reflect prevailing market prices of similar coal. The PUC
has directed Duquesne to defer recovery of the delivered cost of coal to the
extent that such cost exceeds generally prevailing market prices for similar
coal, as determined by the PUC. The PUC allows deferred amounts to be recovered
from customers when the delivered costs of coal fall below such PUC-determined
prevailing market prices.
In 1990, the PUC approved a joint petition for settlement that
clarified certain aspects of the system-wide coal cost standard. Duquesne has
exercised options to extend the coal cost standard through March 2000. The
unrecovered cost of Bruce Mansfield coal was $9.6 million and $8.4 million, and
the unrecovered cost of the remainder of the system-wide coal was $2.6 million
and $4.4 million at December 31, 1996 and 1995. Duquesne believes that all
deferred coal costs will be recovered.
45
Warwick Mine Costs
- -------------------------------------------------------------------------------
The 1990 joint petition for settlement also recognized costs at
Duquesne's Warwick Mine, which had been excluded from rate base since 1981, and
allowed for recovery of such costs, including the costs of ultimately closing
the mine. (See "Deferred Coal Costs" discussion on page 45.) In 1990, Duquesne
entered into an agreement under which an unaffiliated company will operate the
mine until March 2000 and sell the coal produced. Production began in late 1990.
The contract operator at Warwick Mine notified Duquesne that its financial
circumstances and geologic conditions caused it to cease operations late in
1996. Therefore, Duquesne is pursuing its remedies and is currently negotiating
to retain an operator for the mine as a smaller sized operation. Additionally,
Duquesne will continue to purchase coal on the open market. In the past year,
the Warwick Mine supplied slightly less than one-fifth of the coal used in the
production of electricity at Duquesne's wholly owned and jointly owned plants.
This change should not impact Duquesne's ability to recover all of its
investment in Warwick Mine, the $2.6 million of unrecovered system-wide cost of
coal which excludes Bruce Mansfield, or to accrue funds for future liabilities.
It is anticipated that this effort will be successfully completed by March 31,
2000 when the system-wide coal cost cap expires.
Costs at the Warwick Mine and Duquesne's investment in the mine are
expected to be recovered through the cost of coal in the ECR. Recovery is
subject to the system-wide coal cost standard and the cap agreed to as part of
Duquesne's Mitigation Plan. Duquesne also has an opportunity to earn a return on
its investment in the mine through the cost of coal during the period of the
system-wide coal cost standard, including extensions. At December 31, 1996,
Duquesne's net investment in the mine was $11.4 million. The current estimated
liability for mine closing, including final site reclamation, mine water
treatment and certain labor liabilities, is $47.6 million, and Duquesne has
recorded a liability on the consolidated balance sheet of approximately $20.2
million toward these costs.
Property Held for Future Use
- -------------------------------------------------------------------------------
In 1986, the PUC approved Duquesne's request to remove Phillips Power
Station (Phillips) and a portion of Brunot Island (BI) from service and from
rate base. In accordance with Duquesne's Mitigation Plan, 112 MWs related to BI
Units 2a and 2b were moved from property held for future use to electric plant
in service in 1996. Duquesne expects to recover its investment in BI Units 3 and
4, which remain in property held for future use through future electricity
sales. Duquesne believes its investment in BI will be necessary in order to meet
future business needs. A portion of the proceeds of the sale of Ft. Martin is
expected to be used to fund reliability enhancements to the BI Unit 3 combustion
turbine. The reliability enhancements are contingent upon the projects meeting a
least-cost test versus other potential sources of peaking capacity. (See
"Mitigation Plan" discussion on page 44.) Duquesne is analyzing the effects of
customer choice on its future generating requirements. Duquesne is planning to
seek recovery of its investment and associated costs of Phillips through a CTC.
In the event that market demand, transmission access or rate recovery do not
support the utilization of these plants, Duquesne may have to write off part or
all of these investments and associated costs. At December 31, 1996, Duquesne's
net of tax investment in Phillips and BI held for future use was $53.6 million
and $17.2 million.
G. Short-Term
Borrowing and
Revolving
Credit
Arrangements
At December 31, 1996, Duquesne had a $150 million extendible revolving
credit arrangement expiring in October 1997. Interest rates can, in accordance
with the option selected at the time of the borrowing, be based on prime,
Eurodollar or certificate of deposit rates. Commitment fees are based on the
unborrowed amount of the commitment. The credit facility contains a two-year
repayment period for any amount outstanding at the expiration of the revolving
credit period. At December 31, 1996 and 1995, there were no short-term
borrowings outstanding.
H. Income Taxes
Since DQE's formation in 1989, Duquesne has filed consolidated federal
income tax returns with its parent and other companies in the affiliated group.
The annual federal corporate income tax returns have been audited by the
Internal Revenue Service (IRS) for the tax years through 1992. The tax years
1993 through 1996 remain subject to IRS review. Duquesne does not believe that
final settlement of the federal income tax returns for the years 1991 through
1996 will have a materially adverse effect on its financial position, results of
operations or cash flows.
46
Deferred Tax Assets (Liabilities) at December 31
- -----------------------------------------------------------------------------------------------
1996 1995
(Amounts in Thousands of Dollars)
- -----------------------------------------------------------------------------------------------
Investment tax credits unamortized $ 44,067 $ 48,033
Gain on sale/leaseback of BV Unit 2 61,131 64,124
Tax benefit -- long-term investments 139,075 164,582
Other 19,144 41,509
- -----------------------------------------------------------------------------------------------
Deferred tax assets 263,417 318,248
- -----------------------------------------------------------------------------------------------
Property depreciation (785,950) (871,539)
Regulatory assets (150,346) (172,008)
Loss on reacquired debt unamortized (33,331) (35,340)
Other (20,307) (45,357)
- -----------------------------------------------------------------------------------------------
Deferred tax liabilities (989,934) (1,124,244)
- -----------------------------------------------------------------------------------------------
Net Deferred Tax Liabilities $ (726,517) $ (805,996)
===============================================================================================
Income Taxes
- -------------------------------------------------------------------------------------------------------
1996 1995 1994
(Amounts in Thousands of Dollars)
- -------------------------------------------------------------------------------------------------------
Currently payable: Federal $ 95,524 $ 103,271 $ 90,157
State 29,325 30,453 33,000
Deferred -- net: Federal (30,950) (28,381) (20,058)
State (697) (5,778) (7,232)
Investment tax credits deferred -- net (7,838) (7,252) (5,376)
- -------------------------------------------------------------------------------------------------------
Total Included in Operating Expenses 85,364 92,313 90,491
- -------------------------------------------------------------------------------------------------------
Included in other income and deductions:
Currently payable: Federal 42,323 2,199 (5,961)
State 14,710 (1,619) 406
Deferred -- net: Federal (43,493) 442 (99)
State (14,176) 137 (39)
Investment tax credits (1,720) (578) (607)
- -------------------------------------------------------------------------------------------------------
Total Included in Other Income and Deductions (2,356) 581 (6,300)
- -------------------------------------------------------------------------------------------------------
Total Income Tax Expense $ 83,008 $ 92,894 $ 84,191
- -------------------------------------------------------------------------------------------------------
Total income taxes differ from the amount computed by applying the
statutory federal income tax rate to income before income taxes.
Income Tax Expense Reconciliation
- ------------------------------------------------------------------------------------------------
1996 1995 1994
(Amounts in Thousands of Dollars)
- ------------------------------------------------------------------------------------------------
Computed federal income tax at statutory rate $ 81,504 $ 85,387 $ 81,074
Increase (decrease) in taxes resulting from:
State income taxes, net of federal income tax benefits 18,955 15,076 16,988
Amortization of deferred investment tax credits (9,559) (7,831) (5,983)
Revenue requirement adjustment to regulatory taxes -- -- (12,178)
Other (7,892) 262 4,290
- ------------------------------------------------------------------------------------------------
Total Income Tax Expense $ 83,008 $ 92,894 $ 84,191
================================================================================================
47
Duquesne leases nuclear fuel, a portion of a nuclear generating plant,
certain office buildings, computer equipment, and other property and equipment.
Capital Leases at December 31
- -----------------------------------------------------------------------------------------------------------------------------------
1996 1995
(Amounts in Thousands of Dollars)
- -----------------------------------------------------------------------------------------------------------------------------------
Nuclear fuel $ 79,103 $ 112,573
Electric plant 20,505 20,808
- -----------------------------------------------------------------------------------------------------------------------------------
Total 99,608 133,381
Less: Accumulated amortization (47,670) (74,874)
- -----------------------------------------------------------------------------------------------------------------------------------
Property Held Under Capital Leases -- Net (a) $ 51,938 $ 58,507
===================================================================================================================================
(a) Includes $2,618 in 1996 and $2,910 in 1995 of capital leases with
associated obligations retired.
In 1987, Duquesne sold and leased back its 13.74 percent interest in BV
Unit 2; the sale was exclusive of transmission and common facilities. The total
sales price of $537.9 million was the appraised value of Duquesne's interest in
the property. Duquesne subsequently leased back its interest in the unit for a
term of 29.5 years. The lease provides for semi-annual payments and is accounted
for as an operating lease. Duquesne is responsible under the terms of the lease
for all costs of its interest in the unit. In December 1992, Duquesne
participated in the refinancing of collateralized lease bonds to take advantage
of lower interest rates and reduce the annual lease payments. The bonds were
originally issued in 1987 for the purpose of partially financing the lease of BV
Unit 2. In accordance with the BV Unit 2 lease agreement, Duquesne paid the
premiums of approximately $36.4 million as a supplemental rent payment to the
lessors. This amount was deferred and is being amortized over the remaining
lease term. At December 31, 1996, the deferred balance was approximately $30.1
million.
Leased nuclear fuel is amortized as the fuel is burned and charged to
fuel and purchased power expense on the statement of consolidated income. The
amortization of all other leased property is based on rental payments made.
These lease-related expenses are charged to operating expenses on the statement
of consolidated income.
Summary of Rental Payments
- ----------------------------------------------------------------------
1996 1995 1994
(Amounts in Thousands of Dollars)
- ----------------------------------------------------------------------
Operating leases $ 59,503 $ 57,617 $ 56,437
Amortization of capital leases 19,378 26,705 33,596
Interest on capital leases 3,703 4,332 4,996
- ----------------------------------------------------------------------
Total Rental Payments $ 82,584 $ 88,654 $ 95,029
======================================================================
48
Future Minimum Lease Payments
- ------------------------------------------------------------------------------------------------------------------------------------
Operating Leases Capital Leases
Year Ended December 31, (Amounts in Thousands of Dollars)
- ------------------------------------------------------------------------------------------------------------------------------------
1997 $ 57,001 $ 24,186
1998 56,876 11,380
1999 56,869 6,516
2000 56,830 4,166
2001 56,745 2,481
2002 and thereafter 846,852 18,555
- ------------------------------------------------------------------------------------------------------------------------------------
Total Minimum Lease Payments $1,131,173 $ 67,284
- ------------------------------------------------------------------------------------------------------------------------------------
Less: Amount representing interest (17,964)
- ------------------------------------------------------------------------------------------------------------------------------------
Present value of minimum lease payments for capital
leases (a) $ 49,320
====================================================================================================================================
(a) Includes current obligations of $20.9 million at December 31, 1996.
Future minimum lease payments for capital leases are related
principally to the estimated use of nuclear fuel financed through leasing
arrangements and building leases. Future minimum lease payments for operating
leases are related principally to BV Unit 2 and certain corporate offices.
Future payments due to Duquesne, as of December 31, 1996, under
subleases of certain corporate office space are approximately $4.5 million in
1997, $4.6 million in 1998 and $18.5 million thereafter.
J. Commitments
and
Contingencies
Construction
- -------------------------------------------------------------------------------
Duquesne estimates that it will spend, excluding AFC and nuclear fuel,
approximately $110 million, $110 million and $95 million for construction during
1997, 1998 and 1999. These estimates also exclude any potential expenditures for
reliability enhancements to the BI Unit 3 combustion turbine. (See "Mitigation
Plan" discussion, Note F, on page 44.)
Nuclear-Related Matters
- -------------------------------------------------------------------------------
Duquesne has an ownership interest in three nuclear units, two of
which it operates. The operation of a nuclear facility involves special risks,
potential liabilities, and specific regulatory and safety requirements. Specific
information about risk management and potential liabilities is discussed below.
Nuclear Decommissioning. The PUC ruled that recovery of the
decommissioning costs for Beaver Valley Unit 1 (BV Unit 1) could begin in 1977,
and that recovery for BV Unit 2 and Perry Unit 1 could begin in 1988. Duquesne
expects to decommission BV Unit 1, BV Unit 2 and Perry Unit 1 no earlier than
the expiration of each plant's operating license in 2016, 2027 and 2026. At the
end of its operating life, BV Unit 1 may be placed in safe storage until BV Unit
2 is ready to be decommissioned, at which time the units may be decommissioned
together.
Based on site-specific studies finalized in 1992 for BV Unit 2, and
in 1994 for BV Unit 1 and Perry Unit 1, Duquesne's share of the total estimated
decommissioning costs, including removal and decontamination costs, currently
being used to determine Duquesne's cost of service, is $122 million for BV Unit
1, $35 million for BV Unit 2, and $67 million for Perry Unit 1. A study will be
performed in 1997 to update Duquesne's estimated decommissioning costs of BV
Unit 1 and BV Unit 2.
On July 18, 1996, the PUC issued a Proposed Policy Statement Regarding
Nuclear Decommissioning Cost Estimation and Cost Recovery for the purpose of
obtaining comments from the public. The proposed policy includes guidelines for
a site-specific study to estimate the cost of decommissioning. Guidelines
require that studies be performed at least every five years, address
radiological and non-radiological costs, and include a contingency factor of not
more than 10 percent. Under the proposed policy, annual decommissioning funding
levels are based on an annuity calculation recognizing inflation in the cost
49
estimates and earnings on fund assets. With respect to the transition to a
competitive generation market, the Customer Choice Act requires that utilities
include a plan to mitigate any shortfall in decommissioning trust fund payments
for the life of the facility with any future decommissioning filings. Consistent
with this requirement, Duquesne has increased its nuclear decommissioning
funding by $5 million under the PUC-approved plan for the sale of Duquesne's
ownership interest in Ft. Martin. (See "Mitigation Plan" discussion, Note F, on
page 44.) These additional annual contributions bring the total annual funding
to approximately $9 million. Also, on October 17, 1996, the PUC adopted an
Accounting Order filed by Duquesne to recognize the increased funding as part of
Duquesne's cost of service. Duquesne expects to receive approval from the IRS
for qualification of 100 percent of additional nuclear decommissioning trust
funding for BV Unit 2 and Perry Unit 1, and 79 percent for BV Unit 1.
Funding for nuclear decommissioning costs is deposited in external,
segregated trust accounts and may be invested in a portfolio of corporate common
stock and debt securities, municipal bonds, certificates of deposit and United
States government securities. Trust fund earnings increase the fund balance and
the recorded liability. The market value of the aggregate trust fund balances at
December 31, 1996 totaled approximately $33.7 million.
Nuclear Insurance. The Price-Anderson Amendments to the Atomic Energy
Act of 1954 limit public liability from a single incident at a nuclear plant to
$8.9 billion. The maximum available private primary insurance of $200 million
has been purchased by Duquesne. Additional protection of $8.7 billion would be
provided by an assessment of up to $79.3 million per incident on each nuclear
unit in the United States. Duquesne's maximum total possible assessment, $59.4
million, which is based on its ownership or leasehold interests in three nuclear
generating units, would be limited to a maximum of $7.5 million per incident per
year. This assessment is subject to indexing for inflation and may be subject to
state premium taxes. If funds prove insufficient to pay claims, the United
States Congress could impose other revenue-raising measures on the nuclear
industry.
Duquesne's share of insurance coverage for property damage,
decommissioning and decontamination liability is $1.2 billion. Duquesne would be
responsible for its share of any damages in excess of insurance coverage. In
addition, if the property damage reserves of Nuclear Electric Insurance Limited
(NEIL), an industry mutual insurance company that provides a portion of this
coverage, are inadequate to cover claims arising from an incident at any United
States nuclear site covered by that insurer, Duquesne could be assessed
retrospective premiums totaling a maximum of $7.3 million.
In addition, Duquesne participates in a NEIL program that provides
insurance for the increased cost of generation and/or purchased power resulting
from an accidental outage of a nuclear unit. Subject to the policy limit, the
coverage provides for 100 percent of the estimated incremental costs per week
during the 52-week period starting 21 weeks after an accident and 80 percent of
such estimate per week for the following 104 weeks, with no coverage thereafter.
If NEIL's losses for this program ever exceed its reserves, Duquesne could be
assessed retrospective premiums totaling a maximum of $3.5 million.
Beaver Valley Power Station (BVPS) Steam Generators. BVPS's two units
are equipped with steam generators designed and built by Westinghouse Electric
Corporation (Westinghouse). Similar to other Westinghouse nuclear plants,
outside diameter stress corrosion cracking (ODSCC) has occurred in the steam
generator tubes of both units. BV Unit 1, which was placed in service in 1976,
has required removal of approximately 15 percent of its steam generator tubes
from service through a process called "plugging." However, BV Unit 1 continues
to have the capability to operate at 100 percent reactor power and has the
ability to return tubes to service by repairing them through a process called
"sleeving." To date, no tubes at either BV Unit 1 or BV Unit 2 have been
sleeved. BV Unit 2, which was placed in service 11 years after BV Unit 1, has
not yet exhibited the degree of ODSCC experienced at BV Unit 1. Approximately 2
percent of BV Unit 2's tubes are plugged; however, it is too early in the life
of the unit to determine the extent to which ODSCC may become a problem.
50
Duquesne has undertaken certain measures, such as increased
inspections, water chemistry control and tube plugging, to minimize the
operational impact of and to reduce susceptibility to ODSCC. Although Duquesne
has taken these steps to allay the effects of ODSCC, the inherent potential for
future ODSCC in steam generator tubes of the Westinghouse design still exists.
Material acceleration in the rate of ODSCC could lead to a loss of plant
efficiency, significant repairs or the possible replacement of the BV Unit 1
steam generators. The total replacement cost of the BV Unit 1 steam generators
is currently estimated at $125 million. Duquesne would be responsible for $59
million of this total, which includes the cost of equipment removal and
replacement steam generators but excludes replacement power costs. The earliest
that the BV Unit 1 steam generators could be replaced during a scheduled
refueling outage is the fall of 2000.
BV Unit 1 completed its 11th refueling outage on May 11, 1996. The
outage lasted 49 days and was the shortest refueling outage in the history of
the unit. During the outage, various inspections of the unit's steam generators
were made, including examinations using a new "Plus Point" probe. As a result of
these inspections, Duquesne returned to service tubes that had previously been
plugged. Following the refueling outage, 85 percent of the steam generator tubes
were in service, approximately 1 percent more than at the beginning of the
outage.
BV Unit 2 completed its sixth refueling outage on December 16, 1996.
The outage lasted 107 days due to unanticipated repairs to two residual heat
removal pumps and reactor head vent valves. Various inspections of the unit's
steam generators, including inspections using the Plus Point probe, were
completed. Upon completion of the outage, approximately 98 percent of the unit's
steam generator tubes remained in service.
Duquesne continues to explore all viable means of managing ODSCC,
including new repair technologies, and plans to continue to perform 100 percent
tube inspections during future refueling outages, which occur at, approximately,
18-month intervals for each unit. Duquesne will continue to monitor and evaluate
the condition of the BVPS steam generators.
Spent Nuclear Fuel Disposal. The Nuclear Waste Policy Act of 1982
established a policy for handling and disposing of spent nuclear fuel and a
policy requiring the establishment of a final repository to accept spent nuclear
fuel. Electric utility companies have entered into contracts with the DOE for
the permanent disposal of spent nuclear fuel and high-level radioactive waste in
compliance with this legislation. The DOE has indicated that its repository
under these contracts will not be available for acceptance of spent nuclear fuel
before 2010. On July 23, 1996, the U.S. Court of Appeals for the District of
Columbia Circuit, in response to a suit brought by 25 electric utilities and 18
states and state agencies, unanimously ruled that the DOE has a legal obligation
to begin taking spent nuclear fuel by January 31, 1998. The DOE has not yet
established an interim or permanent storage facility, and has indicated that it
will be unable to begin acceptance of spent nuclear fuel for disposal by January
31, 1998. Further, Congress is considering amendments to the Nuclear Waste
Policy Act of 1982 that could give the DOE authority to proceed with the
development of a federal interim storage facility. In the event the DOE does not
begin accepting spent nuclear fuel, existing on-site spent nuclear fuel storage
capacities at BV Unit 1, BV Unit 2 and Perry Unit 1 are expected to be
sufficient until 2016 (end of operating license), 2013 and 2011, respectively.
On January 31, 1997, Duquesne joined 35 other electric utilities and 46
states, state agencies and regulatory commissions in filing a suit in the U.S.
Court of Appeals for the District of Columbia against the DOE. The suit requests
the court to suspend the utilities' payments into the Nuclear Waste Fund and to
place future payments into an escrow account until the DOE fulfills its
obligation to accept spent nuclear fuel. Significant additional expenditures for
the storage of spent nuclear fuel at BV Unit 2 and Perry Unit 1 could be
required if the DOE does not fulfill its obligation to accept spent nuclear
fuel.
51
Uranium Enrichment Decontamination and Decommissioning. Nuclear
reactor licensees in the United States are assessed annually for the
decontamination and decommissioning of DOE uranium enrichment facilities.
Assessments are based on the amount of uranium a utility had processed for
enrichment prior to enactment of the National Energy Policy Act of 1992 (NEPA)
and are to be paid by such utilities over a 15-year period. At December 31,
1996, Duquesne's liability for contributions was approximately $9.3 million
(subject to an inflation adjustment). Contributions, when made, are currently
recovered from customers through the ECR.
Fossil Decommissioning
- -------------------------------------------------------------------------------
In Pennsylvania, current ratemaking does not allow utilities to
recover future decommissioning costs through depreciation charges during the
operating life of fossil-fired generating stations. In 1996, the Financial
Accounting Standard Board issued an exposure draft, Accounting for Certain
Liabilities Related to Closure or Removal of Long-Lived Assets. The primary
effect of this exposure draft would be to change the way Duquesne accounts for
nuclear and fossil decommissioning costs. The exposure draft calls for recording
the present value of estimated future cash flows to decommission Duquesne's
nuclear and fossil power plants as an increase to asset balances and as a
liability. This amount is currently estimated to be $299.5 million. Duquesne
will seek to recover these costs through a CTC.
Guarantees
- -------------------------------------------------------------------------------
Duquesne and the other owners of Bruce Mansfield have guaranteed
certain debt and lease obligations related to a coal supply contract for Bruce
Mansfield. At December 31, 1996 Duquesne's share of these guarantees was $20.3
million. The prices paid for the coal by the companies under this contract are
expected to be sufficient to meet debt and lease obligations to be satisfied in
the year 2000. (See "Deferred Coal Costs" discussion, Note F, on page 45.) The
minimum future payments to be made by Duquesne solely in relation to these
obligations are $5.9 million in 1997, $5.6 million in 1998, $5.3 million in
1999, and $4.2 million in 2000. Duquesne's total payments for coal purchased
under the contract were $26.9 million in 1996, $28.9 million in 1995, and $23.3
million in 1994.
Residual Waste Management Regulations
- -------------------------------------------------------------------------------
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. Duquesne is
assessing the sites it utilizes and has developed compliance strategies that are
currently under review by the DEP. Capital costs of $2.5 million were incurred
by Duquesne in 1996 to comply with these DEP regulations. Based on information
currently available, an additional $2.8 million will be spent in 1997. The
additional capital cost of compliance through the year 2000 is estimated, based
on current information, to be $15 million. This estimate is subject to the
results of groundwater assessments and DEP final approval of compliance plans.
Employees
- -------------------------------------------------------------------------------
In November 1996, Duquesne reached an agreement on a three-year
contract extension through September 30, 2001 with the International Brotherhood
of Electrical Workers (IBEW), which represents approximately 2,000 of Duquesne's
employees.
Other
- -------------------------------------------------------------------------------
Duquesne is involved in various other legal proceedings and
environmental matters. Duquesne believes that such proceedings and matters, in
total, will not have a materially adverse effect on its financial position,
results of operations or cash flows.
52
K. Long-Term
Debt
The pollution control notes arise from the sale of bonds by public
authorities for the purposes of financing construction of pollution control
facilities at Duquesne's plants or refunding previously issued bonds. Duquesne
is obligated to pay the principal and interest on these bonds. For certain of
the pollution control notes, there is an annual commitment fee for an
irrevocable letter of credit. Under certain circumstances, the letter of credit
is available for the payment of interest on, or redemption of, all or a portion
of the notes.
Long-Term Debt At December 31
- ---------------------------------------------------------------------------------------------------------------
Principal Outstanding
Interest (Amounts in Thousands of Dollars)
Rate Maturity 1996 1995
- ---------------------------------------------------------------------------------------------------------------
First mortgage bonds 4.75%-8.75% 1997-2025 $ 853,000 (a) $ 903,000 (b)
Pollution control notes (c) 2009-2030 417,985 417,985
Sinking fund debentures 5% 2010 4,891 5,703
Less: Unamortized debt discount
and premium -- net (3,915) (4,157)
- ---------------------------------------------------------------------------------------------------------------
Total Long-Term Debt $1,271,961 $1,322,531
===============================================================================================================
(a) Excludes $50.0 million related to current maturities on November 15, 1997.
(b) Excludes $50.0 million related to a current maturity on May 15, 1996.
(c) The pollution control notes have adjustable interest rates. The interest
rates at year-end averaged 3.7 percent in 1996 and 3.9 percent in 1995.
At December 31, 1996, sinking fund requirements and maturities of
long-term debt outstanding for the next five years were $50.0 million in 1997,
$75.1 million in 1998, $75.4 million in 1999, $100.4 million in 2000, and $0.4
million in 2001.
Total interest costs incurred were $94.6 million in 1996, $103.3
million in 1995, and $107.7 million in 1994. Interest costs attributable to
long-term debt and other interest were $90.1 million, $98.0 million and $102.1
million in 1996, 1995 and 1994, respectively. Interest costs incurred also
include $4.5 million, $5.3 million and $5.6 million attributable to capital
leases in 1996, 1995 and 1994, respectively. Of these amounts, $0.8 million in
1996, $1.0 million in 1995, and $0.6 million in 1994 were capitalized as AFC.
Debt discount or premium and related issuance expenses are amortized over the
lives of the applicable issues.
During 1994, Duquesne's BV Unit 2 lease arrangement was amended to
reflect an increase in federal income tax rates. At the same time, the
associated letter of credit securing the lessor's equity interest in the unit
was increased from $188 million to $194 million and the term of the letter of
credit was extended to 1999. If certain specified events occur, the letter of
credit could be drawn down by the owners, the leases could terminate, and
collateralized lease bonds ($391.8 million at December 31, 1996) would become
direct obligations of Duquesne.
At December 31, 1996 and 1995, Duquesne was in compliance with all of
its debt covenants.
At December 31, 1996, the fair value of Duquesne's 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 to Duquesne for debt of the same remaining maturities, was $1,321.6
million. The principal amount included in Duquesne's consolidated balance sheet
is $1,325.9 million.
53
L. Preferred and
Preference
Stock
Preferred and Preference Stock at December 31
- -----------------------------------------------------------------------------------------------------
(Shares and Amounts in Thousands)
-----------------------------------------------------
1996 1995
Call Price ----------------------------------------
Per Share Shares Amount Shares Amount
Preferred Stock Series:
3.75% (a) (b) (c) $51.00 148 $ 7,407 148 $ 7,407
4.00% (a) (b) (c) 51.50 550 27,486 550 27,486
4.10% (a) (b) (c) 51.75 120 6,012 120 6,012
4.15% (a) (b) (c) 51.73 132 6,643 132 6,643
4.20% (a) (b) (c) 51.71 100 5,021 100 5,021
$2.10 (a) (b) (c) 51.84 159 8,039 159 8,039
9.00% (d) -- -- 3,000 -- 3,000
8.375% (e) -- 6,000 150,000 -- --
- ----------------------------------------------------------------------------------------------------
Total Preferred Stock 7,209 213,608 1,209 63,608
- ----------------------------------------------------------------------------------------------------
Preference Stock Series: (f)
Plan Series A (c) (g) 37.18 817 28,997 834 29,615
- ----------------------------------------------------------------------------------------------------
Total Preference Stock 817 28,997 834 29,615
- ----------------------------------------------------------------------------------------------------
Deferred ESOP benefit (19,533) (22,257)
- ----------------------------------------------------------------------------------------------------
Total Preferred and Preference Stock $223,072 $ 70,966
====================================================================================================
(a) Preferred stock: 4,000,000 authorized shares; $50 par value; cumulative
(b) $50 per share involuntary liquidation value
(c) Non-redeemable
(d) 500 authorized shares; 10 issued $300,000 par value; involuntary
liquidation value $300,000 per share; mandatory redemption beginning
August 2000
(e) Cumulative Monthly Income Preferred Securities Series A: 6,000,000
authorized shares; $25 involuntary liquidation value
(f) Preference stock: 8,000,000 authorized shares; $1 par value cumulative
(g) $35.50 per share involuntary liquidation value
Holders of Duquesne'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's board of directors until all dividends have been paid.
Holders of Duquesne's preference stock are entitled to receive 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's
directors until all dividends have been paid. At December 31, 1996, Duquesne had
made all dividend payments. Preferred and preference dividends were $12.0
million, $5.3 million and $6.0 million in 1996, 1995 and 1994. Total preferred
and preference stock had involuntary liquidation values of $242.5 million and
$93.1 million, which exceeded par by $28.2 million and $28.8 million at December
31, 1996 and 1995.
In December 1991, Duquesne established an Employee Stock Ownership
Plan (ESOP) to provide matching contributions for a 401(k) Retirement Savings
Plan for Management Employees. (See "Employee Benefits," Note N, on page 55.)
Duquesne issued and sold 845,070 shares of preference stock, plan series A to
the trustee of the ESOP. As consideration for the stock, Duquesne 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,
1996, $19.5 million of preference stock issued in connection with the
establishment of the ESOP had been offset, for financial statement purposes, by
the recognition of a deferred ESOP benefit. Dividends on the preference stock
and cash contributions from Duquesne are used to repay the ESOP note. Duquesne
made cash contributions of approximately $1.4 million for 1996, $1.6 million for
1995, and $2.2 million for 1994. These cash contributions were the difference
between the ESOP debt service and the amount of dividends on ESOP shares ($2.3
million in 1996 and 1995, and $2.4 million in 1994). As shares of preference
stock are allocated to the accounts of participants in the ESOP, Duquesne
recognizes compensation expense, and the amount of the deferred compensation
benefit is amortized.
54
Duquesne recognized compensation expense related to the 401(k) plans of $2.3
million in 1996, $2.3 million in 1995, and $1.8 million in 1994. Outstanding
preferred and preference stock is generally callable, on notice of not less than
30 days, at stated prices plus accrued dividends.
M. Common Stock
and Capital
Surplus
Common Stock and Capital Surplus
- -----------------------------------------------------------------------
Capital Surplus 1996 1995 1994
Year Ended December 31, (Amounts in Thousands of Shares)
- -----------------------------------------------------------------------
Premium on common stock $825,814 $837,539 $823,886
Capital stock expense (274) (274) (693)
- -----------------------------------------------------------------------
Total Capital Surplus $825,540 $837,265 $823,193
=======================================================================
In July 1989, Duquesne became a wholly owned subsidiary of DQE, the
holding company formed as part of a shareholder-approved restructuring. As a
result of the restructuring, DQE common stock replaced all outstanding shares of
Duquesne common stock, except for 10 shares which DQE holds.
DQE or its predecessor, Duquesne, has continuously paid dividends on
common stock since 1953. Dividends may be paid on DQE common stock to the extent
permitted by law and as declared by its board of directors. However, in
Duquesne's Restated Articles of incorporation, provisions relating to preferred
and preference stock may restrict the payment of Duquesne's common dividends. No
dividends or distributions may be made on Duquesne's common stock if Duquesne
has not paid dividends or sinking fund obligations on its preferred or
preference stock. Further, the aggregate amount of Duquesne's common stock
dividend payments or distributions may not exceed certain percentages of net
income if the ratio of common stockholder's equity to total capitalization is
less than specified percentages. As all of Duquesne's common stock is owned by
DQE, to the extent that Duquesne cannot pay common dividends, DQE may not be
able to pay dividends to its common shareholders. No part of the retained
earnings of Duquesne was restricted at December 31, 1996.
N. Employee
Benefits
Retirement Plans
- -------------------------------------------------------------------------------
Duquesne maintains retirement plans to provide pensions for all
eligible employees. Upon retirement, an 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. Duquesne's
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 (ERISA) but that does not exceed
the maximum tax-deductible amount for the year. Pension costs charged to expense
or construction were $11.9 million for 1996, $6.1 million for 1995, and $8.9
million for 1994.
55
Funded Status of the Retirement Plans and Amounts Recognized on the Consolidated Balance Sheet at
December 31
- -----------------------------------------------------------------------------------------------------------------------
1996 1995
(Amounts in Thousands of Dollars)
- ------------------------------------------------------------------------------------------------------------------------
Actuarial present value of benefits rendered to date:
Vested benefits $413,109 $378,344
Non-vested benefits 22,551 19,110
- ------------------------------------------------------------------------------------------------------------------------
Accumulated benefits obligation based on compensation to date 435,660 397,454
Additional benefits based on estimated future salary levels 61,438 53,757
- ------------------------------------------------------------------------------------------------------------------------
Projected benefits obligation 497,098 451,211
Fair market value of plan assets 525,871 490,870
- ------------------------------------------------------------------------------------------------------------------------
Projected benefits obligation under plan assets $ 28,773 $ 39,659
========================================================================================================================
Unrecognized net gain $128,382 $124,794
Unrecognized prior service cost (43,790) (37,535)
Unrecognized net transition liability (13,853) (15,665)
Net pension liability per consolidated balance sheet (41,966) (31,935)
- ------------------------------------------------------------------------------------------------------------------------
Total $ 28,773 $ 39,659
========================================================================================================================
Assumed rate of return on plan assets 8.25% 8.00%
- ------------------------------------------------------------------------------------------------------------------------
Discount rate used to determine projected benefits obligation 7.50% 7.00%
- ------------------------------------------------------------------------------------------------------------------------
Assumed change in compensation levels 5.25% 5.00%
- ------------------------------------------------------------------------------------------------------------------------
Pension assets consist primarily of common stocks, United States
obligations and corporate debt securities.
Components of Pension Cost
- ---------------------------------------------------------------------------------------------------------------
1996 1995 1994
(Amounts in Thousands of Dollars)
- ---------------------------------------------------------------------------------------------------------------
Service cost (benefits earned during the year) $ 12,209 $ 9,953 $ 12,482
Interest on projected benefits obligation 32,597 30,063 28,221
Return on plan assets (58,173) (99,246) 1,967)
Net amortization and deferrals 25,312 65,316 (33,783)
- ---------------------------------------------------------------------------------------------------------------
Net Pension Cost $ 11,945 $ 6,086 $ 8,887
===============================================================================================================
Retirement Savings Plan and Other Benefit Options
- -------------------------------------------------------------------------------
Duquesne sponsors separate 401(k) retirement plans for its management
and bargaining unit employees.
The 401(k) Retirement Savings Plan for Management Employees provides
that Duquesne will match employee contributions to a 401(k) account up to a
maximum of 6 percent of an employee's eligible salary. Duquesne's match consists
of a $0.25 base match per eligible contribution dollar and an additional $0.25
incentive match per eligible contribution dollar, if Board-approved targets are
achieved. The 1996 incentive target for management was accomplished. Duquesne is
funding its matching contributions to the 401(k) Retirement Savings Plan for
Management Employees with payments to an ESOP established in December 1991. (See
"Preferred and Preference Stock," Note L, on page 54.)
The 401(k) Retirement Savings Plan for IBEW Represented Employees
provides that, beginning in 1995, Duquesne will match employee contributions to
a 401(k) account up to a maximum of 4 percent of an employee's eligible salary.
Duquesne's match consists of a $0.25 base match per eligible contribution dollar
and an additional $0.25 incentive match per eligible contribution dollar, if
certain targets are met. In 1996, these incentive targets were not met by
Duquesne's union-represented employees.
56
DQE's shareholders have approved a long-term incentive plan through
which Duquesne may grant management employees options to purchase, during the
years 1987 through 2006, up to a total of 7.5 million shares of DQE's common
stock at prices equal to the fair market value of such stock on the dates the
options were granted. At December 31, 1996, approximately 3.1 million of these
shares were available for future grants.
As of December 31, 1996, 1995 and 1994, active grants totaled
1,698,000; 2,159,000; and 2,118,000 shares. Exercise prices of these options
ranged from $8.2084 to $30.875 at December 31, 1996, and from $8.2084 to $27.625
at December 31, 1995, and from $8.2084 to $23.0833 at December 31, 1994.
Expiration dates of these grants ranged from 1997 to 2006 at December 31, 1996;
from 1997 to 2005 at December 31, 1995; and from 1997 to 2004 at December 31,
1994. As of December 31, 1996, 1995 and 1994, stock appreciation rights (SARs)
had been granted in connection with 984,000; 1,202,000; and 1,190,000 of the
options outstanding. During 1996, 715,000 SARs were exercised; 267,000 options
were exercised at prices ranging from $8.2084 to $20.3334; and 150 options were
cancelled. During 1995, 367,000 SARs were exercised; 133,000 options were
exercised at prices ranging from $8.2084 to $21.6667; and 28,000 options were
cancelled. During 1994, 1,254,000 SARs were exercised; 339,000 options were
exercised at prices ranging from $8.2084 to $18.9167; and 80,000 options were
cancelled. Of the active grants at December 31, 1996, 1995 and 1994, 668,000;
929,000; and 918,000 were not exercisable.
Other Post-Retirement Benefits
- -------------------------------------------------------------------------------
In addition to pension benefits, Duquesne provides certain health care
benefits and life insurance for some retired employees. Substantially all of
Duquesne's full-time employees may, upon attaining the age of 55 and meeting
certain service requirements, become eligible for the same benefits available to
retired employees. Participating retirees make contributions, which are adjusted
annually, to the health care plan. The life insurance plan is non-contributory.
Company-provided health care benefits terminate when covered individuals become
eligible for Medicare benefits or reach age 65, whichever comes first. Duquesne
funds actual expenditures for obligations under the plans on a "pay-as-you-go"
basis. Duquesne has the right to modify or terminate the plans.
Duquesne accrues the actuarially determined costs of the aforementioned
post-retirement benefits over the period from the date of hire until the date
the employee becomes fully eligible for benefits. Duquesne has elected to
amortize the transition liability over 20 years.
Components of Post-Retirement Cost
- ----------------------------------------------------------------------------------------------
1996 1995
(Amounts in Thousands of Dollars)
- ----------------------------------------------------------------------------------------------
Service cost (benefits earned during the period) $1,182 $1,315
Interest cost on accumulated benefit obligation 2,046 2,340
Amortization of the transition obligation over 20 years 1,700 1,700
Other (812) (582)
- ----------------------------------------------------------------------------------------------
Total Post-Retirement Cost $4,116 $4,773
==============================================================================================
The accumulated post-retirement 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.
57
Funded Status of Post-Retirement Plan at December 31
- -----------------------------------------------------------------------------------------------------------------
1996 1995
(Amounts in Thousands of Dollars)
- -----------------------------------------------------------------------------------------------------------------
Actuarial present value of benefits:
Retirees $ 8,840 $ 7,359
Fully eligible active plan participants 3,829 3,187
Other active plan participants 26,352 21,935
- -----------------------------------------------------------------------------------------------------------------
Accumulated post-retirement benefit obligation 39,021 32,481
Fair market value of plan assets -- __
- -----------------------------------------------------------------------------------------------------------------
Accumulated benefit obligation in excess of plan assets $(39,021) $(32,481)
=================================================================================================================
Unrecognized net actuarial gains $ 2,874 $ 8,427
Unrecognized net transition liability (27,198) (28,898)
Post-retirement liability per consolidated balance sheet (14,697) (12,010)
- -----------------------------------------------------------------------------------------------------------------
Total $(39,021) $(32,481)
=================================================================================================================
Discount rate used to determine projected benefit obligation 7.50% 7.00%
- -----------------------------------------------------------------------------------------------------------------
Health care cost trend rates:
For year beginning January 1 6.96% 8.80%
Ultimate rate in the year 2000 6.00% 5.50%
- -----------------------------------------------------------------------------------------------------------------
Effect of a one percent increase in health care cost trend
rates:
On accumulated projected benefit obligation $ 2,920 $ 3,228
On aggregate of annual service and interest costs $ 391 $ 435
- -----------------------------------------------------------------------------------------------------------------
O. 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 Duquesne's
service territory.]
- ----------------------------------------------------------------------------------------------------------------------------------
1996 First Quarter Second Quarter Third Quarter Fourth Quarter
- ----------------------------------------------------------------------------------------------------------------------------------
Operating Revenues (a) $290,857 $284,522 $320,275 $281,171
Operating Income (a) 54,584 50,161 69,738 47,596
Net Income 36,749 32,571 50,852 29,688
==================================================================================================================================
1995 First Quarter Second Quarter Third Quarter Fourth Quarter
- ----------------------------------------------------------------------------------------------------------------------------------
Operating Revenues (a) $286,616 $274,669 $337,156 $281,343
Operating Income (a) 57,542 55,705 76,001 57,389
Net Income 33,371 32,441 52,787 32,471
==================================================================================================================================
(a) Restated to conform with presentations adopted during 1996.
----------------------------------
Except for historical information contained herein, the matters discussed in
this Annual Report on Form 10-K, are forward-looking statements that involve
risks and uncertainties including, but not limited to, economic, competitive,
governmental and technological factors affecting Duquesne's operations, markets,
products, services and prices, and other factors discussed in Duquesne's filings
with the Securities and Exchange Commission.
58
SELECTED FINANCIAL DATA
- ---------------------------------------------------------------------------------------------------------
Amounts in Thousands of Dollars 1996 1995 1994 1993 1992 1991
- ---------------------------------------------------------------------------------------------------------
INCOME STATEMENT ITEMS
Total operating revenues $1,176,825 $1,179,784 $1,168,624 $1,160,685 $1,150,380 $1,173,105
Operating income $ 222,079 $ 246,637 $ 236,556 $ 240,168 $ 258,367 $ 270,559
Net income $ 149,860 $ 151,070 $ 147,449 $ 147,362 $ 149,768 $ 143,133
Earnings for common stock $ 145,815 $ 145,750 $ 141,403 $ 138,174 $ 140,357 $ 132,332
- ---------------------------------------------------------------------------------------------------------
BALANCE SHEET ITEMS
Property, plant and equipment-net $2,717,473 $2,978,903 $3,068,519 $3,123,948 $3,018,641 $3,037,454
Total assets $3,897,086 $4,067,665 $4,149,867 $4,388,103 $3,718,092 $3,802,626
- ---------------------------------------------------------------------------------------------------------
Capitalization:
Common stockholder's equity $ 989,424 $1,131,334 $1,115,512 $1,100,671 $1,107,609 $1,064,104
Non-redeemable preferred and
preference stock 223,072 70,966 95,345 124,736 123,430 121,906
Redeemable preferred and
preference stock -- -- -- 8,392 8,579 15,437
Long-term debt 1,271,961 1,322,531 1,368,930 1,416,705 1,413,001 1,420,726
- ---------------------------------------------------------------------------------------------------------
Total capitalization $2,484,457 $2,524,831 $2,579,787 $2,650,504 $2,652,619 $2,622,173
=========================================================================================================
59
Glossary of Terms Following are explanations of certain financial and
operating terms used in our report.
Competitive Transition Charge (CTC)/
Intangible Transition Charge (ITC)
- --------------------------------------------------------------------------------
During the electric utility restructuring from the traditional regulatory
framework to customer choice, utilities will have the opportunity to recover
transition costs from customers through a surcharge, or competitive transition
charge. Alternatively, if the utility gains PUC approval and securitizes
its transition costs, it may then charge an intangible transition charge.
Customer Choice
- --------------------------------------------------------------------------------
The Pennsylvania Customer Choice Act (see "Customer Choice Act" discussion
on page 5) will give customers the right to contract for electricity at
market prices from PUC-approved electric generation suppliers.
Decommissioning Costs
- --------------------------------------------------------------------------------
Decommissioning costs are expenses to be incurred in connection with the
entombment, decontamination, dismantlement, removal and disposal of structures,
systems and components of a power plant that has permanently ceased the
production of electric energy.
Deferred Energy Costs
- --------------------------------------------------------------------------------
In conjunction with the Energy Cost Rate Adjustment Clause, Duquesne records
deferred energy costs to offset differences between actual energy costs
and the level of energy costs currently recovered from its rate-regulated
electric utility customers.
Demand
- --------------------------------------------------------------------------------
Demand is the amount of electricity delivered to consumers at any instant
or averaged over a period of time.
Energy Cost Rate Adjustment Clause (ECR)
- --------------------------------------------------------------------------------
Duquesne recovers through the ECR, to the extent that such amounts are
not included in base rates, the cost of nuclear fuel, fossil fuel and purchased
power costs and passes to its customers the profits from short-term power
sales to other utilities.
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 natural gas and
electricity.
Kilowatt (KW)
- --------------------------------------------------------------------------------
A kilowatt is equal to 1,000 watts. A watt is the rate at which electricity
is generated or consumed. A kilowatt-hour (KWH) is a measure of the quantity
of electricity generated or consumed in one hour.
Peak Demand
- --------------------------------------------------------------------------------
Peak demand is the amount of electricity required during periods of highest
usage. Peak periods fluctuate by season and generally occur in the morning
hours in winter and in late afternoon during the summer.
Pennsylvania Public Utility Commission (PUC)
- --------------------------------------------------------------------------------
The PUC is the Pennsylvania governmental body that regulates all utilities
(electric, gas, telephone, water, etc.) and is made up of five members
nominated by the governor and confirmed by the senate.
Regulatory Assets
- --------------------------------------------------------------------------------
Regulatory assets are costs that Duquesne would otherwise have charged
to expense which are capitalized or deferred because these costs are currently
being recovered or because it is probable that the PUC and the FERC will
allow recovery of these costs through the ratemaking process. For example,
under traditional regulation, tax benefits associated with electric generating
assets were required to be immediately passed on to a utility's customers.
These same benefits later would be incurred as a tax cost, which the utility
would expect to collect from its customers under the traditional regulatory
framework.
Transition Costs
- --------------------------------------------------------------------------------
Transition or stranded costs are the net present value of a utility's
known or measurable costs related to electric generation that are recoverable
under the current regulatory framework, but which may not be recoverable
in a competitive generation market and which will remain following mitigation
efforts taken by such utility to recover the costs. Examples of potential
transition costs include regulatory assets; the unfunded portion of
decommissioning costs; costs of employee severance, retraining, early
retirement, and outplacement; and generation-related costs, including the
associated capital costs. The PUC will determine the level of transition
costs a utility may recover.
Unbundled Electric Service
- --------------------------------------------------------------------------------
Electric utilities traditionally have been obligated to serve customers
from the generation through the delivery of electricity. Under the Pennsylvania
Customer Choice Act, electric service will be unbundled. Although customer
choice will give consumers their choice of electric generation suppliers,
delivery of the electricity from the generation supplier to the consumer
will remain the responsibility of the existing franchised utility.
60