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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(X) ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1997
OR
( ) TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from ________ to ________
Commission File Number 1-2385
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THE DAYTON POWER AND LIGHT COMPANY
(Exact name of registrant as specified in its charter)
OHIO 31-0258470
(State or other jurisdiction of (I.R.S. Employer Identification No.)
incorporation or organization)
Courthouse Plaza Souththwest, Dayton, Ohio 45402
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: 937-224-6000
Securities registered pursuant to Section 12(b) of the Act: NONE
Securities registered pursuant to Section 12(g) of the Act: NONE
Indicate by check mark if disclosure of delinquent filers
pursuant to Item 405 of Regulation S-K is not contained herein,
and will not be contained, to the best of registrant's knowledge,
in definitive proxy or information statements incorporated by
reference in Part III of this Form 10-K or any amendment to this
Form 10-K. X
---
Indicate by check mark whether the registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the
Securities Exchange Act of 1934 during the preceding 12 months
(or for such shorter period that the registrant was required to
file such reports), and (2) has been subject to such filing
requirements for the past 90 days.
YES X NO
--- ---
Number of shares of registrant's common stock outstanding as of
February 27, 1998, all of which were held by DPL Inc., was 41,172,173.
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PART I
Item 1 - Business*
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THE COMPANY
The Dayton Power and Light Company (the "Company") is a
public utility incorporated under the laws of Ohio in 1911.
Located in West Central Ohio, it furnishes electric service to
485,000 retail customers in a 24 county service area of
approximately 6,000 square miles and furnishes natural gas
service to 301,000 customers in 16 counties. The Company serves
an estimated population of 1.3 million. Principal industries
served include electrical machinery, automotive and other
transportation equipment, non-electrical machinery, agriculture,
paper, and rubber and plastic products. The Company's sales
reflect the general economic conditions and seasonal weather
patterns of the area. In 1997, a 3% decline in electric
residential sales resulted in slightly lower revenue, which
offset a 3% increase in sales to business customers and higher
sales to other public utilities. Gas utility revenues increased
2% in 1997. Sales increases of 3% from higher deliveries to
business customers offset the effects of milder weather. During
1997, cooling degree days were 23% below the twenty year average
and 15% below 1996. Heating degree days in 1997 were 3% above
the thirty year average and 4% below 1996. Sales patterns will
change in future years as weather and the economy fluctuate. The
Company employed 2,592 persons as of December 31, 1997, of which
2,164 are full-time employees and 428 are part-time employees.
All of the outstanding shares of common stock of the Company
are held by DPL Inc., which became the Company's corporate
parent, effective April 21, 1986. Subsidiaries of the Company
include MacGregor Park, Inc., an owner and developer of real
estate and Miami Valley Equipment, Inc., which owns retail sales
and transportation equipment and provides support services to
DPL Inc. and its subsidiaries.
The Company's principal executive and business office is
located at Courthouse Plaza Southwest, Dayton, Ohio 45402 -
telephone (937) 224-6000.
Information relating to industry segments is contained in
Item 8 - Note 12 of Notes to Consolidated Financial Statements on
Page II-24 of this document, which Note is incorporated herein by
reference.
* Unless otherwise indicated, the information given in
"Item 1 - BUSINESS" is current as of March 27, 1998. No
representation is made that there have not been subsequent
changes to such information.
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COMPETITION
The Company competes with privately and municipally owned
electric utilities and rural electric cooperatives, natural gas
suppliers and other alternate fuel suppliers. The Company
competes on the basis of price and service.
Like other utilities, the Company from time to time may have
electric generating capacity available for sale to other
utilities. The Company competes with other utilities to sell
electricity provided by such capacity. The ability of the
Company to sell this electricity will depend on how the Company's
price, terms and conditions compare to those of other utilities.
In addition, from time to time, the Company makes power purchases
from neighboring utilities.
In an increasingly competitive energy environment,
cogenerated power may be used by customers to meet their own
power needs. Cogeneration is the dual use of a form of energy,
typically steam, for an industrial process and for the generation
of electricity. The Public Utilities Regulatory Policies Act of
1978 ("PURPA") provides regulations that govern the purchase of
excess electric energy from cogeneration and small power
production facilities that have obtained qualifying status under
PURPA.
The National Energy Policy Act of 1992, which reformed the
Public Utilities Holding Company Act of 1935, allows the federal
government to mandate access by others to a utility's electric
transmission system and may accelerate competition in the supply
of electricity.
The Company provides transmission and other wholesale
electric service to 12 municipal customers which distribute
electricity within their corporate limits. In 1994, 11 of these
municipal customers signed new 20-year service agreements which
were approved by the Federal Energy Regulatory Commission
("FERC"), in June 1995. The twelfth municipal customer signed a
20-year agreement, approved by FERC in February 1995, that allows
the Company to supply 97% of its power requirements. In addition
to these municipal customers, the Company maintains an
interconnection agreement with one municipality which has the
capability to generate all or a portion of its energy
requirements. Sales to municipalities represented 1.2% of total
electricity sales in 1997.
In October 1994, the Public Utilities Commission of Ohio
("PUCO") initiated roundtable discussions on the introduction of
competition in the electric industry. The "Electric Competition
Series" is a result of the Ohio Energy Strategy issued in April
1994. To date, roundtable discussions have focused largely on
short-term initiatives that are possible under the current regulatory
framework. On February 15, 1996, the PUCO issued guidelines for
interruptible service, including services that accommodate the
attainment and delivery of replacement electricity during periods
when the utility...
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...faces constraints on its own resources. On April 11, 1996,
the PUCO issued an Entry on Rehearing ordering utilities to file
interruptible electric service tariffs. On June 14, 1996, the
Company filed for approval of a non-firm electric service rate
schedule and replacement power rate riders. The Company's
interruptible electric service tariffs were approved on May 1,
1997, and tariffs conforming to this order were subsequently
filed with the PUCO on May 15, 1997.
On February 27, 1997, after rehearing its earlier order on
the subject, the PUCO issued guidelines for the implementation of
conjunctive electric service. These guidelines require all
electric utilities to file tariffs under which different service
locations are aggregated for cost-of-service, rate design, rate
negotiation and billing purposes.
In January 1997, plans were announced to create a 12 member
Joint Committee of the Ohio Senate and House of Representatives
to explore and possibly draft retail wheeling legislation. The
Committee has conducted hearings to gather information from
energy companies, regulators, customers and industry experts.
The Committee co-chairs issued a draft report on January 6, 1998
recommending opening the electric generation market, in the future,
to competition for all Ohio consumers. As part of this restructuring
effort in 1998 and beyond, legislators are also studying related
complex tax issues that must be resolved. Other legislative proposals
at the federal level are pending concerning wholesale and retail
wheeling which are designed to increase competition.
On April 24, 1996, FERC issued orders requiring all electric
utilities that own or control transmission facilities to file
open-access transmission service tariffs. Open-access
transmission tariffs provide third parties with non-
discriminatory transmission service comparable to what the
utility provides itself. In its orders, FERC further stated that
FERC-jurisdictional stranded costs reasonably incurred and costs
of complying with the rules will be recoverable by electric
utilities. In August 1997, the Company refiled its open-access
transmission tariff in compliance with FERC orders. In December
1997, the Company reached an agreement in principle with
intervenors in a pending tariff case and filed a subsequent
tariff case based on an updated test year.
On September 30, 1996, FERC conditionally accepted the
Company's market-based sales tariff which will allow the Company
to sell wholesale generation supply at prices that reflect
current market prices. At the same time, FERC approved the
application and authorization of DPL Energy Inc., a wholly-owned
subsidiary of DPL Inc., to sell and broker wholesale electric
power and also charge market-based prices for such power.
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General deregulation of the natural gas industry has
continued to prompt the influence of market competition as the
driving force behind natural gas procurement. The evolution of
an efficient natural gas spot market in combination with open-
access interstate transportation pipelines has provided the
Company, as well as its end-use customers, with an array of
procurement options. Customers with alternate fuel capability
can continue to choose between natural gas and their alternate
fuel based upon overall performance and economics. Therefore,
demand for natural gas purchased from the Company or purchased
elsewhere and transported to the end-use customer by the Company
could fluctuate based on the economics of each in comparison with
changes in alternate fuel prices. For the Company, price
competition and reliability among both natural gas suppliers and
interstate pipeline sources are major factors affecting
procurement decisions.
CONSTRUCTION AND FINANCING PROGRAM OF THE COMPANY
Construction Program
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Construction additions were $109 million, $124 million, and
$79 million in 1997, 1996 and 1995 respectively. The capital
program for 1998 consists of construction costs of approximately
$100 million, which includes an 82 MW combustion turbine unit.
Construction plans are subject to continuing review and are
expected to be revised in light of changes in financial and
economic conditions, load forecasts, legislative and regulatory
developments and changing environmental standards, among other
factors. The Company's ability to complete its capital projects
and the reliability of future service will be affected by its
financial condition, the availability of external funds at
reasonable cost and adequate and timely rate recovery.
See ENVIRONMENTAL CONSIDERATIONS for a description of
environmental control projects and regulatory proceedings which
may change the level of future construction additions. The
potential impact of these events on the Company's operations
cannot be estimated at this time.
Financing Program
- -----------------
At year-end 1997, cash and temporary cash investments were $12
million, and debt and equity financial assets were $111 million.
Cash and financial assets are held with a view towards investing
in future opportunities in the industry.
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In December 1997, the Company redeemed a series of first
mortgage bonds in the principal amount of $40 million with an
interest rate of 8.0%. The bonds had been scheduled to mature in
2003. Another series of first mortgage bonds in the principal
amount of $40 million matured in 1997. In December 1996, the
Company redeemed a series of first mortgage bonds in the
principal amount of $25 million with an interest rate of 6.75%.
The bonds had been scheduled to mature in 1998. Sinking fund
payments for the five years ended 2002 are $2 million.
In September 1995, a new series of Air Quality Development
Revenue Refunding Bonds was issued in principal amount of
$110 million with an interest rate of 6.1%. Proceeds from the
financing were used to redeem a similar principal amount of First
Mortgage Bonds with an interest rate of 9.5%.
In November 1989, DPL Inc. entered into a revolving credit
agreement ("the Credit Agreement") with a consortium of banks
renewable through 2001 which allows total borrowings by DPL Inc.
and its subsidiaries of $200 million. The Company has authority
from the PUCO to issue short-term debt up to $200 million with a
maximum debt limit of $300 million including loans from DPL Inc.
under the terms of the Credit Agreement. At year-end 1997,
DPL Inc. had $36 million outstanding under this Credit Agreement.
The Company also has $97 million available in short-term lines of
credit. At year-end 1997, the Company had $10 million
outstanding from these lines of credit and $70 million in
commercial paper outstanding.
Under the Company's First and Refunding Mortgage, First
Mortgage Bonds may be issued on the basis of (i) 60% of unfunded
property additions, subject to net earnings, as defined, being at
least two times interest on all First Mortgage Bonds outstanding
and to be outstanding, and (ii) 100% of retired First Mortgage
Bonds. The Company anticipates that it will be able to issue
sufficient First Mortgage Bonds to satisfy its long-term debt
requirements in connection with the financing of its construction
and refunding programs discussed above.
The maximum amount of First Mortgage Bonds which may be issued
in the future will fluctuate depending upon interest rates, the
amounts of bondable property additions, earnings and retired
First Mortgage Bonds. There are no coverage tests for the
issuance of preferred stock under the Company's Amended Articles
of Incorporation.
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ELECTRIC OPERATIONS AND FUEL SUPPLY
The Company's present winter generating capability is
3,264,000 KW. Of this capability, 2,843,000 KW (approximately
87%) is derived from coal-fired steam generating stations and the
balance consists of combustion turbine and diesel-powered peaking
units. Approximately 88% (2,491,000 KW) of the existing steam
generating capability is provided by certain units owned as
tenants in common with The Cincinnati Gas & Electric Company
("CG&E") or with CG&E and Columbus Southern Power Company
("CSP"). Under the agreements among the companies, each company
owns a specified undivided share of each facility, is entitled to
its share of capacity and energy output, and has a capital and
operating cost responsibility proportionate to its ownership
share.
The remaining steam generating capability (371,000 KW) is
derived from a generating station owned solely by the Company.
The Company's all time net peak load was 2,961,000 KW, which
occurred in August 1995. The present summer generating
capability is 3,194,000 KW.
GENERATING FACILITIES
MW Rating
---------------
Operating Company
Station Ownership* Company Location Portion Total
- ------- ---------- --------- -------- ------- -----
Coal Units
- ----------
Hutchings W Company Miamisburg, OH 371 371
Killen C Company Wrightsville, OH 418 624
Stuart C Company Aberdeen, OH 823 2,350
Conesville-Unit 4 C CSP Conesville, OH 129 780
Beckjord-Unit 6 C CG&E New Richmond, OH 210 420
Miami Fort-Units 7&8 C CG&E North Bend, OH 360 1,000
East Bend-Unit 2 C CG&E Rabbit Hash, KY 186 600
Zimmer C CG&E Moscow, OH 365 1,300
Combustion Turbines or Diesel
- -----------------------------
Hutchings W Company Miamisburg, OH 32 32
Yankee Street W Company Centerville, OH 144 144
Monument W Company Dayton, OH 12 12
Tait W Company Dayton, OH 10 10
Sidney W Company Sidney, OH 12 12
Tait Gas Turbine 1 W Company Moraine, OH 95 95
Tait Gas Turbine 2 W Company Moraine, OH 97 97
* W = Wholly Owned
C = Commonly Owned
I-6
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In order to transmit energy to their respective systems from
their commonly owned generating units, the companies have
constructed and own, as tenants in common, 847 circuit miles of
345,000-volt transmission lines. The Company has several
interconnections with other companies for the purchase, sale and
interchange of electricity.
The Company derived over 99% of its electric output from
coal-fired units in 1997. The remainder was derived from units
burning oil or natural gas which were used to meet peak demands.
The Company estimates that approximately 65-85% of its coal
requirements for the period 1998-2002 will be obtained through
long-term contracts, with the balance to be obtained by spot
market purchases. The Company has been informed by CG&E and CSP
through the procurement plans for the commonly owned units
operated by them that sufficient coal supplies will be available
during the same planning horizon.
The prices to be paid by the Company under its long-term
coal contracts are subject to adjustment in accordance with
various indices. Each contract has features that will limit
price escalations in any given year.
The average fuel cost per kWh generated of all fuel burned
for electric generation (coal, gas and oil) for the year was 1.31
cents which represents an increase from 1.29 cents in 1996 and a
decrease from 1.36 cents in 1995. Through the operation of a fuel
cost adjustment clause applicable to electric sales, the increases
and decreases in fuel costs are reflected in customer rates on a
timely basis. See RATE REGULATION AND GOVERNMENT LEGISLATION and
ENVIRONMENTAL CONSIDERATIONS.
GAS OPERATIONS AND GAS SUPPLY
The Company has long-term firm pipeline transportation
agreements with ANR Gas Pipeline Company ("ANR"), Texas Gas
Transmission Corporation ("Texas Gas"), Panhandle Eastern Pipe
Line Company ("Panhandle"), Columbia Gas Transmission Corporation
("Columbia") and Columbia Gulf Transmission Corporation for
varying terms, up to late 2004. Along with firm transportation
services, the Company has approximately 16 billion cubic feet of
firm storage service with various pipelines. The Company also
maintains and operates four propane-air plants with a daily rated
capacity of approximately 70,000 thousand cubic feet ("MCF") of
natural gas.
I-7
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In addition, the Company is interconnected with CNG
Transmission Corporation. Interconnections with interstate
pipelines provide the Company the opportunity to purchase
competitively-priced natural gas supplies and pipeline services.
The Company purchases its natural gas supplies using a portfolio
approach that minimizes price risks and ensures sufficient firm
supplies at peak demand times. The portfolio consists of long-
term, short-term and spot supply agreements. In 1997, firm
agreements provided approximately 50% of total supply, with the
remaining supplies purchased on a spot/short-term basis.
In 1997, the Company purchased natural gas at an average
price of $3.45 per MCF, compared to $3.45 per MCF in 1996 and
$2.79 per MCF in 1995. Through the operation of a natural gas
cost adjustment clause applicable to gas sales, increases and
decreases in the Company's natural gas costs are reflected in
customer rates on a timely basis. SEE RATE REGULATION AND
GOVERNMENT LEGISLATION.
The PUCO supports open access, nondiscriminatory
transportation of natural gas by the state's local distribution
companies for end-use customers. The PUCO has guidelines to
provide a standardized structure for end-use transportation
programs which requires a tariff providing the prices, terms and
conditions for such service. The Company has an approved tariff
and provides transportation service to approximately 300 end-use
customers, delivering a total quantity of nearly 17,000,000 MCF
per year.
RATE REGULATION AND GOVERNMENT LEGISLATION
The Company's sales of electricity and natural gas to retail
customers are subject to rate regulation by the PUCO and various
municipalities. The Company's wholesale electric rates to
municipal corporations and other distributors of electric energy
are subject to regulation by FERC under the Federal Power Act.
Ohio law establishes the process for determining rates
charged by public utilities. Regulation of rates encompasses the
timing of applications, the effective date of rate increases, the
cost basis upon which the rates are based and other related
matters. Ohio law also establishes the Office of the Ohio
Consumers' Counsel (the "OCC"), which has the authority to
represent residential consumers in state and federal judicial and
administrative rate proceedings.
The Company's electric and natural gas rate schedules
contain certain recovery and adjustment clauses subject to
periodic audits by, and proceedings before, the PUCO. Electric
fuel and gas costs are expensed as recovered through rates.
On June 18, 1996, Governor Voinovich signed into law House
Bill 476 which allows for alternate natural gas rate plans and
exemption from PUCO jurisdiction for some gas services, and
establishes a code of conduct for natural gas distribution
companies. Final rules were issued on March 12, 1997.
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Ohio legislation extends the jurisdiction of the PUCO to the
records and accounts of certain public utility holding company
systems, including DPL Inc. The legislation extends the PUCO's
supervisory powers to a holding company system's general
condition and capitalization, among other matters, to the extent
that they relate to the costs associated with the provision of
public utility service. Additionally, the legislation
(i) requires PUCO approval of certain transactions and transfers
of assets between public utilities and entities within the same
holding company system, and (ii) prohibits investments by a
holding company in subsidiaries which are not public utilities in
an amount in excess of 15% of the aggregate capitalization of the
holding company on a consolidated basis at the time such
investments are made.
Regulatory assets recorded during the phase-in of electric
rates are being amortized and recovered in current rates. In
addition, deferred interest charges on the William H. Zimmer
Generating Station are being amortized at $2.8 million per year
over the projected life of the asset.
A 1992 PUCO-approved settlement agreement and a subsequent
stipulation in 1995 allowed accelerated recovery of demand-side
management ("DSM") costs and, thereafter, production plant costs
to the extent that the Company return on equity exceeds a
baseline 13% (subject to upward adjustment). If the return
exceeds the baseline return by one to two percent, one-half of
the excess is used to accelerate recovery of these costs. If the
return is greater than two percent over the baseline, the entire
excess is used for such purpose.
Regulatory deferrals on the balance sheet were:
Dec. 31 Dec. 31
1997 1996
------- -------
--millions--
Phase-in $ 30.6 $ 46.7
DSM 33.6 35.3
Deferred interest - Zimmer 52.5 55.3
Income taxes recoverable
through future revenues 208.2 222.4
------- -------
Total $ 324.9 $ 359.7
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In 1989 the PUCO approved rules for the implementation of a
comprehensive Integrated Resource Planning ("IRP") program for
all investor-owned electric utilities in Ohio. Under this
program, each utility is required to file an IRP as part of its
Long Term Forecast Report ("LTFR"). The IRP requires each
utility to evaluate available demand-side resource options in
addition to supply-side options to determine the most cost-...
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...effective means for satisfying customer requirements. The
rules currently allow a utility to apply for deferred recovery of
DSM program expenditures and lost revenues between LTFR proceedings.
Ultimate recovery of expenditures is contingent on review and
approval of such programs as cost-effective and consistent with
the most recent IRP proceeding. The rules also allow utilities
to submit alternative proposals for the recovery of DSM programs
and related costs.
The Company has in place a percentage of income payment plan
("PIPP") for eligible low-income households as required by the
PUCO. This plan prohibits disconnections for nonpayment of
customer bills if eligible low-income households pay a specified
percentage of their household income toward their utility bill.
The PUCO has approved a surcharge by way of a temporary base rate
tariff rider which allows companies to recover arrearages
accumulated under PIPP.
The Company initiated a competitive bidding process in
January 1993 for the construction of electric peaking capacity
and energy by 1997. Through an Ohio Power Siting Board ("OPSB")
investigative process, the Company's self-built option was
evaluated to be the least cost option. On March 7, 1994, the
OPSB approved the Company's applications for up to three
combustion turbines and two natural gas supply lines for the
proposed site.
On June 1, 1997 and September 15, 1997, respectively, the
Company filed its natural gas and electric LTFR with the PUCO.
An IRP filed as part of the electric LTFR included plans for the
construction of a series of 82 MW combustion turbine generating
units. The first combustion turbine began operation on June 1,
1995, a second unit began operation on December 23, 1996 and a
third unit is currently under construction.
On January 25, 1996, Governor Voinovich reappointed Chairman
Craig A. Glazer to the PUCO for a five year term which commenced
on April 11, 1996 and will extend until April 10, 2001.
On February 7, 1997, Governor Voinovich appointed Judith A.
Jones, a Toledo City Councilwoman, to the PUCO replacing Richard
Fanelly. Her five year term commenced April 11, 1997 and will
extend until April 10, 2002.
On October 15, 1997 PUCO Commissioner David Johnson
announced his resignation effective November 30, 1997.
Commissioner Johnson was serving a term that would have expired
in April 1998. On January 27, 1998, Governor Voinovich appointed
Donald L. Mason, a senior management official with the Ohio
Department of Natural Resources, to replace Commissioner Johnson.
His five year term will expire on April 10, 2003.
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ENVIRONMENTAL CONSIDERATIONS
The operations of the Company, including the commonly owned
facilities operated by the Company, CG&E and CSP, are subject to
federal, state, and local regulation as to air and water quality,
disposal of solid waste and other environmental matters,
including the location, construction and initial operation of new
electric generating facilities and most electric transmission
lines. The Company expended $5 million for environmental control
facilities during 1997. The possibility exists that current
environmental regulations could be revised which could change the
level of estimated construction expenditures. See CONSTRUCTION
AND FINANCING PROGRAM OF THE COMPANY.
Air Quality
- -----------
The Clean Air Act Amendments of 1990 (the "Act") have
limited sulfur dioxide and nitrogen oxide emissions nationwide.
The Act restricts emissions in two phases. Phase I compliance
requirements became effective on January 1, 1995 and Phase II
requirements will become effective on January 1, 2000.
Compliance by the Company has not caused any material changes in
the Company's costs or operations.
The Company's environmental compliance plan ("ECP") was
approved by the PUCO on May 6, 1993. Phase I requirements are
being met by switching to lower sulfur coal at several commonly
owned electric generating facilities and increasing existing
scrubber removal efficiency. Total capital expenditures to
comply with Phase I of the Act were approximately $5.5 million.
Phase II requirements can be met primarily by switching to lower
sulfur coal at all non-scrubbed coal-fired electric generating
units. Overall compliance is projected to have a minimal 1% to 2%
approximate price impact. Costs to comply with the Act are
eligible for recovery in fuel hearings and other regulatory
proceedings.
Land Use
- --------
The Company and numerous other parties have been notified by
the United States Environmental Protection Agency ("U.S. EPA") or
the Ohio Environmental Protection Agency ("Ohio EPA") that it
considers them Potentially Responsible Parties ("PRPs") for clean-
up at four superfund sites in Ohio: the Sanitary Landfill Site
on Cardington Road in Montgomery County, Ohio; the United Scrap
Lead Site in Miami County, Ohio; the Powell Road Landfill in
Huber Heights, Montgomery County, Ohio; and the North Sanitary
(a.k.a. Valleycrest) Landfill in Dayton, Montgomery County, Ohio.
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The Company received notification from the U.S. EPA in July
1987 for the Cardington Road site. The Company has not joined
the PRP group formed at that site because of the absence of any
known evidence that the Company contributed hazardous substances
to this site. The Record of Decision issued by the U.S. EPA
identifies the chosen clean-up alternative at a cost estimate of
$8.1 million. This final resolution will not have a material
effect on the Company's financial position, earnings or cashflow.
The Company received notification from the U.S. EPA in
September 1987 for the United Scrap Lead Site. The Company has
joined a PRP group for this site, which is actively conferring
with the U.S. EPA. The initial Record of Decision issued by the
U.S. EPA estimating clean-up costs at $27.1 million was later
amended to reflect an estimate of clean-up costs at $32 million.
The Company is one of over 200 parties to this site, and its
estimated contribution to the site is less than .01%. Nearly
60 PRPs are actively working to settle the case. The Company
participated in the sponsorship of a study to evaluate
alternatives to the U.S. EPA's clean-up plan. The U.S. EPA
recently approved a proposal for a less expensive clean-up
method for the entire site. This new clean-up is anticipated
to have a total cost of $5.2 million. The final resolution will
not have a material effect on the Company's financial position,
earnings or cashflow.
The Company and numerous other parties received notification
from the U.S. EPA on May 21, 1993 that it considers them PRPs for
clean-up of hazardous substances at the Powell Road Landfill Site
in Huber Heights, Ohio. The Company has joined the PRP group for
the site. On October 1, 1993, the U.S. EPA issued its Record of
Decision identifying a cost estimate of $20.5 million for the
chosen remedy. The Company is one of over 200 PRPs to this site,
and its estimated contribution is less than 1%. In late January
1998, the U.S. EPA approved a settlement that included the
Company. Through the settlement, the Company resolved its
potential liability with no resulting material impact.
The Company and numerous other parties received notification
from the Ohio EPA on July 27, 1994 that it considers them PRPs
for clean-up of hazardous substances at the North Sanitary
Landfill site in Dayton, Ohio. The Company has not joined the
PRP group formed for the site because the available information
does not demonstrate that the Company contributed wastes to the
site. The final resolution will not have a material effect on
the Company's financial position, earnings or cashflow.
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THE DAYTON POWER AND LIGHT COMPANY
OPERATING STATISTICS
ELECTRIC OPERATIONS
Years Ended December 31,
------------------------------
1997 1996 1995
---- ---- ----
Electric Output (millions of kWh)
General -
Coal-fired units 16,246 16,142 15,679
Other units 52 21 29
Power purchases 1,239 1,098 2,115
Exchanged and transmitted power - (1) 1
Company use and line losses (928) (946) (1,010)
---------- ---------- ----------
Total 16,609 16,314 16,814
========== ========== ==========
Electric Sales (millions of kWh)
Residential 4,788 4,924 4,871
Commercial 3,408 3,407 3,425
Industrial 4,749 4,540 4,401
Public authorities and railroads 1,330 1,392 1,378
Private utilities and wholesale 2,334 2,051 2,739
---------- ---------- ----------
Total 16,609 16,314 16,814
========== ========== ==========
Electric Customers at End of Period
Residential 433,563 428,973 425,347
Commercial 43,923 43,381 42,582
Industrial 1,881 1,858 2,017
Public authorities and railroads 5,736 5,651 5,573
Other 42 29 17
---------- ---------- ----------
Total 485,145 479,892 475,536
========== ========== ==========
Operating Revenues (thousands)
Residential $ 409,857 $ 422,876 $ 422,153
Commercial 234,206 236,598 237,799
Industrial 225,775 222,941 224,135
Public authorities and railroads 74,018 78,140 78,225
Private utilities and wholesale 53,598 43,730 57,799
Other 12,523 12,115 9,807
---------- ---------- ----------
Total $1,009,977 $1,016,400 $1,029,918
========== ========== ==========
Residential Statistics
(per customer-average)
Sales - kWh 11,120 11,537 11,518
Revenue $ 951.90 $ 990.89 $ 998.27
Rate per kWh (Month of December)
(cents) 8.10 7.91 8.01
I-13
<PAGE>
THE DAYTON POWER AND LIGHT COMPANY
OPERATING STATISTICS
GAS OPERATIONS
Years Ended December 31,
------------------------------
1997 1996 1995
---- ---- ----
Gas Output (thousands of MCF)
Direct market purchases 43,808 46,696 44,376
Liquefied petroleum gas 66 90 18
Company use and unaccounted for (1,016) (676) (1,594)
Transportation gas received 19,182 17,587 16,870
-------- -------- --------
Total 62,040 63,697 59,670
======== ======== ========
Gas Sales (thousands of MCF)
Residential 29,277 31,087 29,397
Commercial 9,567 9,424 8,307
Industrial 2,520 3,404 2,584
Public authorities 2,153 2,829 3,006
Transportation gas delivered 18,523 16,953 16,376
-------- -------- --------
Total 62,040 63,697 59,670
======== ======== ========
Gas Customers at End of Period
Residential 276,189 272,616 269,694
Commercial 22,298 22,085 21,451
Industrial 1,396 1,331 1,574
Public authorities 1,475 1,463 1,423
-------- -------- --------
Total 301,358 297,495 294,142
======== ======== ========
Operating Revenues (thousands)
Residential $160,279 $156,709 $149,006
Commercial 48,302 44,092 39,047
Industrial 11,867 14,110 11,447
Public authorities 10,311 12,013 12,589
Other 12,948 11,660 9,950
-------- -------- --------
Total $243,707 $238,584 $222,039
======== ======== ========
Residential Statistics
(per customer-average)
Sales - MCF 107.0 114.8 109.8
Revenue $ 585.63 $ 578.68 $ 556.72
Rate per MCF (month of December) $ 5.20 $ 5.13 $ 4.44
<PAGE>
I-14
Item 2 - Properties
- ------------------------------------------------------------------------------
Electric
- --------
Information relating to the Company's electric properties is
contained in Item 1 - BUSINESS, THE COMPANY (page I-1),
CONSTRUCTION AND FINANCING PROGRAM OF THE COMPANY (pages I-4 and
I-5), ELECTRIC OPERATIONS AND FUEL SUPPLY (pages I-6 and I-7) and
Item 8 - Notes 2 and 5 of Notes to Consolidated Financial
Statements on pages II-15 and II-19, respectively, which pages
are incorporated herein by reference.
Gas
- ---
Information relating to the Company's gas properties is
contained in Item 1 - BUSINESS, THE COMPANY (page I-1), and GAS
OPERATIONS AND GAS SUPPLY (pages I-7 and I-8), which pages are
incorporated herein by reference.
Other
- -----
The Company owns a number of area service buildings located
in various operating centers.
Substantially all property and plant of the Company is
subject to the lien of the Mortgage securing the Company's First
Mortgage Bonds.
Item 3 - Legal Proceedings
- ------------------------------------------------------------------------------
Information relating to legal proceedings involving the
Company is contained in Item 1 - BUSINESS, THE COMPANY (page I-
1), COMPETITION (Pages I-2 through I-4), ELECTRIC OPERATIONS AND
FUEL SUPPLY (pages I-6 and I-7), GAS OPERATIONS AND GAS SUPPLY
(pages I-7 and I-8), RATE REGULATION AND GOVERNMENT LEGISLATION
(pages I-8 through I-10), ENVIRONMENTAL CONSIDERATIONS (pages I-
11 and I-12) and Item 8 - Note 2 of Notes to Consolidated
Financial Statements on page II-15, which pages are incorporated
herein by reference.
Item 4 - Submission Of Matters To A Vote Of Security Holders
- ------------------------------------------------------------------------------
None.
I-15
<PAGE>
PART II
Item 5 - Market For Registrant's Common Equity And Related Stockholder Matters
- ------------------------------------------------------------------------------
The Company's common stock is held solely by DPL Inc.
and as a result is not listed for trading on any stock exchange.
The information required by this item of Form 10-K is
set forth in Item 8 - Selected Quarterly Information on page II-
25 and the Financial and Statistical Summary on page II-26, which
pages are incorporated herein by reference.
The Company's Mortgage restricts the payment of dividends on
the Company's Common Stock under certain conditions. In addition,
so long as any Preferred Stock is outstanding, the Company's
Amended Articles of Incorporation contain provisions restricting
the payment of cash dividends on any of its Common Stock if, after
giving effect to such dividend, the aggregate of all such dividends
distributed subsequent to December 31, 1946 exceeds the net income
of the Company available for dividends on its Common Stock subsequent
to December 31, 1946, plus $1,200,000. As of year end, all earnings
reinvested in the business of the Company were available for Common
Stock dividends.
The Credit Agreement requires that the aggregate assets
of the Company and its subsidiaries constitute not less than 60%
of the total consolidated assets of DPL Inc., and that the
Company maintain common shareholder's equity (as defined in the
Credit Agreement) at least equal to $550 million.
Item 6 - Selected Financial Data
- ------------------------------------------------------------------------------
The information required by this item of Form 10-K is
set forth in Item 8 - Financial and Statistical Summary on page
II-26, which page is incorporated herein by reference.
II-1
<PAGE>
Item 7 - Management's Discussion And Analysis Of Financial Condition
And Results Of Operations
- ------------------------------------------------------------------------------
The Dayton Power and Light Company
Performance Highlights 1997 1996 1995
- ------------------------------------------------------------------
CAPITAL INVESTMENT PERFORMANCE:
Capital Structure (millions)
Common shareholder's equity $ 1,280.8 1,217.5 1,190.5
Preferred stock $ 22.9 22.9 22.9
Long-term debt $ 886.0 926.3 991.5
------- ------- -------
Total $ 2,189.7 2,166.7 2,204.9
OPERATING PERFORMANCE:
Electric--
Sales (millions of kWh)
Residential 4,788 4,924 4,871
Commercial 3,408 3,407 3,425
Industrial 4,749 4,540 4,401
Other 3,664 3,443 4,117
------- ------- -------
Total 16,609 16,314 16,814
Revenues (millions)
Residential $ 409.9 422.9 422.2
Commercial $ 234.2 236.6 237.8
Industrial $ 225.8 222.9 224.1
Other $ 140.1 134.0 145.8
------- ------- -------
Total $ 1,010.0 1,016.4 1,029.9
Average price per kWh-retail
and wholesale customers
(calendar year) (cents) 6.01 6.16 6.07
Gas--
Sales (thousands of MCF)
Residential 29,277 31,087 29,397
Commercial 9,567 9,424 8,307
Industrial 2,520 3,404 2,584
Other 20,676 19,782 19,382
------- ------- -------
Total 62,040 63,697 59,670
Revenues (millions)
Residential $ 160.3 156.7 149.0
Commercial $ 48.3 44.1 39.0
Industrial $ 11.9 14.1 11.4
Other $ 23.2 23.7 22.6
------- ------- -------
Total $ 243.7 238.6 222.0
Average price per MCF - total
(calendar year) $ 3.93 3.75 3.72
II-2
<PAGE>
Results of Operations
---------------------
The 1997 earnings on common stock are $171 million compared
to $164 million in 1996 and $159 million in 1995.
In 1997, a 3% decline in electric residential sales resulted
in slightly lower revenue, which offset a 3% increase in sales to
business customers and higher sales to other public utilities.
Fuel and purchased power expense decreased 3% primarily related
to lower fuel costs. In 1996, electric revenues decreased 1% as
a result of lower sales to public utilities.
Gas utility revenues increased 2% in 1997. Sales increases
of 3% from higher deliveries to business customers offset the
effects of milder weather. Gas purchased for resale increased 4%
primarily from higher natural gas costs. Gas utility revenues
increased 7% resulting in a 9% increase in gas utility purchases
in 1996.
Operation and maintenance expense decreased 5% in 1997 from
1996 due to cost containment efforts and lower actuarially-determined
benefit expense. Operation and maintenance expense decreased 1% in
1996 from 1995 as a result of reduced electric production and system
maintenance, bond redemption costs and lower compensation and
benefit expense. These decreases were partially offset by higher
insurance and claims costs.
Regulatory assets recorded during the phase-in of electric
rates are being amortized and recovered in current rates. In
addition, deferred interest charges on the William H. Zimmer
Generating Station are being amortized at $3 million per year
over the projected life of the asset.
A 1992 PUCO-approved settlement agreement and a subsequent
stipulation in 1995 allowed accelerated recovery of demand-side
management costs and, thereafter, production plant costs to the
extent that the Company return on equity exceeds a baseline 13%
(subject to upward adjustment). If the return exceeds the
baseline return by one to two percent, one-half of the excess is
used to accelerate recovery of these costs. If the return is
greater than two percent over the baseline, the entire excess is
used for such purpose.
Depreciation and amortization expense increased $4 million
as a result of increased depreciable assets in 1997 and $7 million
in 1996 primarily due to increased depreciable assets and rates.
II-3
<PAGE>
General taxes increased 3% in 1997 and 4% in 1996 as a
result of higher property taxes from additional property.
Interest expense declined $3 million in 1997 primarily due
to the redemption of $25 million of first mortgage bonds late in
1996 and two series of first mortgage bonds totaling $80 million
in 1997. Interest expense declined $5 million in 1996 primarily
from the September 1995 refinancing of $110 million of bonds at a
lower interest rate.
Credit Ratings
- --------------
The Company's senior debt credit ratings are as follows:
Duff & Phelps AA
Moody's Investors Service Aa3
Standard & Poor's AA-
Each rating has been affirmed by its respective rating
agency in 1997. Moody's Investors Service upgraded the Company's
senior debt credit rating three times from 1992-1995. Duff &
Phelps and Standard & Poor's both upgraded the Company's senior
debt credit ratings in 1994. The credit ratings are the highest
the Company has achieved since 1974, and they are all considered
investment grade.
Construction Program and Financing
- ----------------------------------
Construction additions were $109 million, $124 million,
and $79 million in 1997, 1996 and 1995, respectively. The
capital program for 1998 consists of construction costs of
approximately $100 million, which includes an 82 MW combustion
turbine generating unit.
During 1997, total cash provided by operating activities
was $300 million. At year-end 1997, cash and temporary cash
investments were $12 million, and debt and equity financial
assets were $111 million. Cash and financial assets are held
with a view towards investing in future opportunities in the
industry.
In December 1997, the Company redeemed a series of first
mortgage bonds in the principal amount of $40 million with an
interest rate of 8.0%. The bonds had been scheduled to mature
in 2003. Another series of first mortgage bonds in the principal
amount of $40 million matured in 1997. In December 1996, the
Company redeemed a series of first mortgage bonds in the
principal amount of $25 million with an interest rate of 6.75%.
The bonds had been scheduled to mature in 1998. Sinking fund
payments for the five years ending 2002 are $2 million.
II-4
<PAGE>
In September 1995, a new series of Air Quality
Development Revenue Refunding Bonds was issued in the principal
amount of $110 million with an interest rate of 6.1%. Proceeds
from the financing were used to redeem a similar principal amount
of first mortgage bonds with an interest rate of 9.5%.
Issuance of additional amounts of first mortgage bonds
by the Company is limited by provisions of its mortgage. The
amounts and timing of future financings will depend upon market
and other conditions, rate increases, levels of sales and
construction plans. DPL Inc. anticipates that it has sufficient
capacity to issue the Company first mortgage bonds to satisfy its
requirements in connection with its capital program.
In addition, DPL Inc. has a revolving credit agreement,
renewable through 2001, which allows total borrowings by DPL Inc.
and its subsidiaries of $200 million. At year-end 1997, DPL Inc.
had $36 million outstanding under this credit agreement.
The Company also has $97 million available in short-term
lines of credit. At year-end 1997, the Company had $10 million
outstanding from these lines of credit and $70 million in
commercial paper outstanding.
Issues and Financial Risks
- --------------------------
This report contains certain forward-looking statements
regarding plans and expectations for the future. Investors are
cautioned that actual outcomes and results may vary materially
from those projected due to various factors beyond the Company's
control, including abnormal weather, unusual maintenance or
repair requirements, changes in fuel costs, increased
competition, regulatory changes and decisions, changes in
accounting rules and adverse economic conditions.
Like many companies, DP&L is currently evaluating its
computer systems to determine the extent to which modifications
are required to prevent problems in the year 2000. Based on this
on-going effort, the Company at this time does not anticipate
that the year 2000 matter will materially impact its financial
position.
The EPA has notified numerous parties, including the
Company, that they are considered "Potentially Responsible
Parties" for clean-up of four hazardous waste sites in Ohio. The
EPA approved a $20,000 settlement at one site in late January,
1998. The EPA has estimated total costs of $13 million for its
preferred clean up plans at two other sites, and has not
established an estimated cost for the fourth site. The final
resolution of these investigations will not have a material
effect on the Company's financial position, earnings or cash
flow.
II-5
<PAGE>
As a public utility, the Company is subject to processes
which determine the rates it charges for energy services.
Regulators determine which costs are eligible for recovery in
the rate setting process and when the recovery will occur.
They also establish the rate of return on utility investments
which are valued under Ohio law based on historical costs.
The utility industry is subject to inflationary pressures
similar to those experienced by other capital-intensive industries.
Because rates for regulated services under existing rules are
based on historical costs, cash flows may not cover the total
future costs of providing services.
Restructuring of the electric utility industry continued to
evolve in 1997. Legislative proposals have been introduced in
Congress and in Ohio concerning electric wholesale and retail
wheeling which are designed to increase competition. These factors
increase the risk that the Company's production plant and/or
regulatory assets may not be fully recovered in rates.
Ohio continues to take a studied approach to utility
industry restructuring. In 1997, the Ohio legislative leadership
established a special Joint Committee to study the restructuring
issues. The Committee conducted hearings to gather information
from energy companies, regulators, customers and industry
experts. The Committee co-chairs issued a draft report in early
January 1998 recommending opening the electric generation market,
in the future, to competition for all Ohio consumers. As a part
of this restructuring effort in 1998 and beyond, legislators are
also studying related complex tax issues that must be resolved.
In 1996 and 1997, FERC issued orders creating a more
competitive wholesale electric power market. These orders
required all electric utilities that own or control transmission
facilities to file open-access transmission service tariffs.
Open-access transmission tariffs provide third parties
non-discriminatory transmission service comparable to what the
utility provides itself. In its orders, FERC further stated that
FERC-jurisdictional stranded costs reasonably incurred and costs
of complying with the rules will be recoverable by electric
utilities. In December, the Company reached an agreement in
principle with intervenors in a pending tariff case and filed a
subsequent case based on an updated test year.
The PUCO is holding roundtable discussions on competition
in the electric industry focused on short-term initiatives under
the current regulatory framework. Pursuant to a PUCO order
implementing one such initiative, all Ohio electric utilities,
including the Company, filed tariffs in 1996 for interruptible
electric service that accommodates replacement electricity during
periods when the utility faces resource constraints. The Company's
tariff was approved in 1997.
II-6
<PAGE>
As another roundtable initiative, in 1996, the PUCO
issued guidelines for conjunctive electric service which required
all utilities to file tariffs under which different service
locations are aggregated for cost-of-service, rate design, rate
eligibility and billing purposes. Although the Company has
appealed these guidelines to the Ohio Supreme Court, the Company
filed its tariff in 1997.
Ohio legislation in 1996 and PUCO rules in 1997 addressed
regulatory reform for the local gas distribution companies. The
legislation provides that natural gas commodity services may be
exempted from PUCO regulation and that the PUCO may allow
alternative ratemaking methodologies in connection with other
regulated services.
Income Statement Highlights
$ in Millions 1997 1996 1995
- ----------------------------------------------------------------
Electric utility:
Revenues $1,010 $1,016 $1,030
Fuel and purchased power 227 234 256
------ ------ ------
Net revenues 783 782 774
Gas utility:
Revenues 244 239 222
Gas purchased for resale 151 145 133
------ ------ ------
Net revenues 93 94 89
Interest and other income 14 9 12
Operation and maintenance expense 256 270 271
Amortization of regulatory assets, net 17 15 15
Income taxes 100 98 98
Earnings on common stock 171 164 159
II-7
<PAGE>
Item 8 - Financial Statements And Supplementary Data
- ------------------------------------------------------------------------------
Index to Consolidated Financial Statements Page No.
- ------------------------------------------ --------
Consolidated Statement of Results of Operations
for the three years in the period ended December 31, 1997 II-9
Consolidated Statement of Cash Flows for the three
years in the period ended December 31, 1997 II-10
Consolidated Balance Sheet as of December 31, 1997 and 1996 II-11 - II-12
Notes to Consolidated Financial Statements II-13 - II-24
Reports of Independent Accountants II-27 - II-28
Index to Supplemental Information Page No.
- --------------------------------- --------
Selected Quarterly Information II-25
Financial and Statistical Summary II-26
II-8
<PAGE>
The Dayton Power and Light Company
CONSOLIDATED STATEMENT OF RESULTS OF OPERATIONS
- ------------------------------------------------------------------------
For the years ended December 31,
$ in millions 1997 1996 1995
- ------------------------------------------------------------------------
INCOME
Utility service revenues--
Electric $1,010.0 $1,016.4 $1,029.9
Gas and other 244.4 242.0 227.6
-------- -------- --------
Total utility service revenues 1,254.4 1,258.4 1,257.5
Other income 13.9 9.3 11.8
-------- -------- --------
Total income 1,268.3 1,267.7 1,269.3
-------- -------- --------
EXPENSES
Fuel and purchased power 227.9 234.9 257.5
Gas purchased for resale 150.7 144.8 133.2
Operation and maintenance (Note 1) 255.9 269.5 271.3
Depreciation and amortization (Note 1) 125.9 122.3 115.4
Amortization of regulatory assets,
net (Note 2) 16.8 15.3 15.4
General taxes 133.5 129.3 124.9
Interest expense 86.0 89.1 94.4
-------- -------- --------
Total expenses 996.7 1,005.2 1,012.1
-------- -------- --------
INCOME BEFORE INCOME TAXES 271.6 262.5 257.2
Income taxes (Notes 1 and 3) 99.6 97.7 97.8
-------- -------- --------
NET INCOME 172.0 164.8 159.4
Preferred dividends (Note 9) 0.9 0.9 0.9
-------- -------- --------
EARNINGS ON COMMON STOCK $ 171.1 $ 163.9 $ 158.5
======== ======== ========
See Notes to Consolidated Financial Statements.
II-9
<PAGE>
The Dayton Power and Light Company
CONSOLIDATED STATEMENT OF CASH FLOWS
- ---------------------------------------------------------------------------
For the years ended December 31,
$ in millions 1997 1996 1995
- ---------------------------------------------------------------------------
OPERATING ACTIVITIES
Cash received from utility customers $1,230.3 $1,231.2 $1,205.9
Other operating cash receipts 12.0 10.7 11.0
Cash paid for:
Fuel and purchased power (235.9) (207.6) (249.8)
Purchased gas (167.2) (163.3) (131.7)
Operation and maintenance labor (81.4) (85.9) (87.5)
Nonlabor operating expenditures (153.5) (194.2) (164.4)
Interest (85.2) (87.8) (92.1)
Income taxes (89.0) (89.1) (106.4)
Property, excise and payroll taxes (130.5) (125.7) (123.9)
-------- -------- --------
Net cash provided by operating
activities (Note 11) 299.6 288.3 261.1
INVESTING ACTIVITIES
Property expenditures (110.9) (116.9) (78.9)
Other activities (48.4) (50.3) -
-------- -------- --------
Net cash used for investing activities (159.3) (167.2) (78.9)
-------- -------- --------
FINANCING ACTIVITIES
Dividends paid on common stock (118.5) (138.3) (132.6)
Dividends paid on preferred stock (0.9) (0.9) (0.9)
Retirement of long-term debt (81.0) (25.4) (126.7)
Issuance of short-term debt 69.8 6.5 -
Issuance of long-term debt - - 108.8
-------- -------- --------
Net cash used for financing activities (130.6) (158.1) (151.4)
-------- -------- --------
Cash and temporary cash investments--
Net change 9.7 (37.0) 30.8
Balance at beginning of period 2.1 39.1 8.3
-------- -------- --------
Balance at end of period $ 11.8 $ 2.1 $ 39.1
======== ======== ========
See Notes to Consolidated Financial Statements.
II-10
<PAGE>
The Dayton Power and Light Company
CONSOLIDATED BALANCE SHEET
- -------------------------------------------------------------------
At December 31,
$ in millions 1997 1996
- -------------------------------------------------------------------
ASSETS
Property $3,587.8 $3,493.2
Less--
Accumulated depreciation and amortization (1,355.8) (1,249.4)
-------- --------
Net property 2,232.0 2,243.8
-------- --------
Current Assets
Cash and temporary cash investments 11.8 2.1
Accounts receivable, less provision for
uncollectible accounts of $4.7 and $5.1
respectively 205.8 193.4
Inventories, at average cost 87.1 75.2
Taxes applicable to subsequent years 91.9 87.3
Other current assets 61.4 54.3
-------- --------
Total current assets 458.0 412.3
-------- --------
Other Assets
Financial assets 111.1 56.0
Income taxes recoverable through future
revenues (Notes 1 and 2) 208.2 222.4
Regulatory assets (Note 2) 116.7 137.3
Other 200.8 171.4
-------- --------
Total other assets 636.8 587.1
-------- --------
TOTAL ASSETS $3,326.8 $3,243.2
======== ========
See Notes to Consolidated Financial Statements.
II-11
<PAGE>
The Dayton Power and Light Company
CONSOLIDATED BALANCE SHEET
(continued)
- -------------------------------------------------------------------
At December 31,
$ in millions 1997 1996
- -------------------------------------------------------------------
CAPITALIZATION AND LIABILITIES
- ------------------------------
Capitalization
Common shareholder's equity-(Note 8)
Common stock $ 0.4 $ 0.4
Other paid-in capital 739.1 738.9
Earnings reinvested in the business 541.3 478.2
-------- --------
Total common shareholder's equity 1,280.8 1,217.5
-------- --------
Preferred stock (Note 9) 22.9 22.9
Long-term debt (Note 7) 886.0 926.3
-------- --------
Total capitalization 2,189.7 2,166.7
-------- --------
Current Liabilities
Accounts payable 124.2 109.6
Accrued taxes 157.8 136.6
Accrued interest 20.7 21.6
Current portion of long-term debt 0.4 40.4
Short-term debt (Note 6) 81.0 11.3
Other 41.9 49.1
-------- --------
Total current liabilities 426.0 368.6
-------- --------
Deferred Credits And Other
Deferred taxes (Note 3) 500.5 513.2
Unamortized investment tax credit 72.2 75.2
Other 138.4 119.5
-------- --------
Total deferred credits and other 711.1 707.9
-------- --------
TOTAL CAPITALIZATION AND LIABILITIES $3,326.8 $3,243.2
======== ========
See Notes to Consolidated Financial Statements.
II-12
<PAGE>
The Dayton Power and Light Company
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. Summary Of Significant Accounting Policies
Principles of Consolidation and Nature of Operations
- ----------------------------------------------------
The Company is a wholly-owned subsidiary of DPL Inc. The
accounts of the Company and its wholly-owned subsidiaries are
included in the accompanying consolidated financial statements.
The consolidated financial statements principally reflect the
results of operations and financial condition of the Company.
DPL Inc. and its other wholly-owned subsidiaries provide certain
administrative services to the Company including leases,
equipment, insurance and other services. These costs (in
millions) were $53.5 in 1997, $52.6 in 1996 and $26.7 in 1995.
The Company is a public utility primarily engaged in the business
of selling electric energy and natural gas to residential,
commercial, industrial and governmental customers in a 6,000
square mile area of West Central Ohio. The majority of the
Company's earnings come from electricity and natural gas sales.
Earnings from other operations currently do not have a material
financial impact on the consolidated results.
Revenues and Fuel
- -----------------
Revenues include amounts charged to customers through fuel and
gas recovery clauses, which are adjusted periodically for
changes in such costs. Related costs that are recoverable or
refundable in future periods are deferred along with the related
income tax effects. Also included in revenues are amounts
charged to customers through a surcharge for recovery of
arrearages from certain eligible low-income households.
The Company records revenue for services provided but not yet
billed to more closely match revenues with expenses. Accounts
receivable on the Consolidated Balance Sheet includes unbilled
revenue of (in millions) $78.3 in 1997 and $58.3 in 1996.
Operation and Maintenance
- -------------------------
Operation and maintenance expenses include $0.6 million in 1997
and $4.7 million in 1995 of redemption premiums and other costs
relating to the refinancing of bond issues.
II-13
<PAGE>
Property, Maintenance and Depreciation
- --------------------------------------
Property is shown at its original cost. Cost includes direct
labor and material and allocable overhead costs.
When a unit of property is retired, the original cost of that
property plus the cost of removal less any salvage value is
charged to accumulated depreciation. Maintenance costs and
replacements of minor items of property are charged to expense.
Depreciation expense is calculated using the straight-line
method, which depreciates the cost of property over its
estimated useful life, at an average rate of 3.5% in 1997 and
1996 and 3.4% in 1995.
Income Taxes
- ------------
Deferred income taxes are provided for all temporary differences
between the financial statement basis and the tax basis of
assets and liabilities using the enacted tax rate. Additional
deferred income taxes and offsetting regulatory assets or
liabilities are recorded to recognize that the income taxes will
be recoverable/refundable through future revenues. Investment
tax credits, previously deferred, are being amortized over the
lives of the related properties.
Consolidated Statement of Cash Flows
- ------------------------------------
The temporary cash investments presented on this Statement
consist of liquid investments with an original maturity of three
months or less.
Reclassifications
- -----------------
Reclassifications have been made in certain prior years' amounts
to conform to the current reporting presentation.
Estimates
- ---------
The preparation of financial statements in conformity with
generally accepted accounting principles requires management to
make estimates and assumptions related to future events.
II-14
<PAGE>
2. Regulatory Matters
The Company applies the provisions of Financial Accounting
Standard (SFAS) No. 71, Accounting for the Effects of Certain
Types of Regulation. This accounting standard provides for
the deferral of costs authorized for the future recovery by
regulators. These costs would be charged to expense without
regulatory authorization. Regulatory assets on the
Consolidated Balance Sheet include:
At December 31,
1997 1996
---- ----
--millions--
Phase-in (a) $ 30.6 $ 46.7
DSM (b) 33.6 35.3
Deferred interest (c) 52.5 55.3
Income taxes recoverable through
future revenues 208.2 222.4
------- -------
Total $ 324.9 $ 359.7
======= =======
(a) Amounts deferred during a 1992-1994 electric rate increase
phase-in (including carrying charges) are being recovered
in current rates.
(b) DSM costs (including carrying charges) from the Company's
cost-effective programs are deferred and are being recovered
at approximately $9 million per year.
The 1992 PUCO-approved agreement for the phase-in plan and
DSM programs, as updated in 1995, allows accelerated recovery of
DSM costs and, thereafter, production plant costs to the extent
that the Company return on equity exceeds a baseline 13% (subject
to upward adjustment). If the return exceeds the baseline return
by one to two percent, one-half of the excess will be used to
accelerate recovery of these costs. If the return is greater
than two percent over the baseline, the entire excess will be
used for such purpose.
(c) Interest charges related to the William H. Zimmer Generating
Station which were previously deferred pursuant to PUCO approval
are being amortized at $2.8 million per year over the projected
life of the asset.
II-15
<PAGE>
3. Income Taxes
For the years ended December 31,
$ in millions 1997 1996 1995
- --------------------------------------------------------------------------
COMPUTATION OF TAX EXPENSE
Federal income tax (a) $ 95.0 $ 91.9 $ 90.0
Increases (decreases) in tax from -
Regulatory assets 3.6 3.3 3.3
Depreciation 11.4 10.7 10.8
Investment tax credit amortized (3.0) (3.0) (3.0)
Other, net (7.4) (5.2) (3.3)
------ ------ ------
Total tax expense $ 99.6 $ 97.7 $ 97.8
====== ====== ======
COMPONENTS OF TAX EXPENSE
Taxes currently payable $102.4 $102.1 $ 93.1
Deferred taxes--
Regulatory assets (4.0) (3.5) (1.7)
Liberalized depreciation and amortization 5.3 7.2 13.9
Fuel and gas costs 5.5 2.5 (3.1)
Other (6.6) ( 6.4) (2.6)
Deferred investment tax credit, net (3.0) ( 4.2) (1.8)
------ ------ ------
Total tax expense $ 99.6 $ 97.7 $ 97.8
====== ====== ======
(a) The statutory rate of 35% applied to pre-tax income.
COMPONENTS OF DEFERRED TAX ASSETS AND LIABILITIES
At December 31,
$ in millions 1997 1996
- -------------------------------------------------
NON-CURRENT LIABILITIES
Depreciation/property basis $(443.0) $(447.9)
Income taxes recoverable (72.4) (77.4)
Regulatory assets (38.6) (45.8)
Investment tax credit 25.3 26.3
Other 28.2 31.6
------- -------
Net non-current liability $(500.5) $(513.2)
======= =======
Net Current Asset (Liability) $ (2.7) $ 1.7
======= =======
II-16
<PAGE>
4. Pensions And Postretirement Benefits
Pensions
- --------
Substantially all Company employees participate in pension plans
paid for by the Company. Employee benefits are based on their
years of service, age at retirement and, for salaried employees,
their compensation. The plans are funded in amounts actuarially
determined to provide for these benefits.
An interest rate of 6.25% was used in developing the amounts in
the following tables. Actual returns on plan assets for 1997,
1996 and 1995 were 11.2%, 12.7% and 25.6%, respectively.
Increases in compensation levels approximating 5% were used for
all years.
The following table presents the components of pension cost
(portions of which were capitalized):
$ in millions 1997 1996 1995
- ---------------------------------------------------------------
Service cost - benefits earned $ 6.3 $ 6.2 $ 6.2
Interest cost 15.2 15.0 14.4
Expected return on plan assets
of 7.5% in each year (19.6) (18.1) (17.8)
Net amortization (3.0) (1.1) (0.9)
----- ----- -----
Net pension cost $(1.1) $ 2.0 $ 1.9
===== ===== =====
The following table sets forth the plans' funded status and
amounts recorded in Other assets on the Consolidated Balance
Sheet at December 31:
$ in millions 1997 1996
- ---------------------------------------------------------
Plan assets at fair value (a) $330.2 $321.4
Actuarial present value of projected
benefit obligation 259.1 255.1
------ ------
Plan assets in excess of projected
benefit obligation 71.1 66.3
Unamortized transition obligation (11.3) (15.5)
Prior service cost 13.9 16.0
Changes in plan assumptions and
actuarial gains and losses (28.3) (22.5)
------ ------
Net pension assets $ 45.4 $ 44.3
====== ======
Vested benefit obligation $203.8 $198.6
Accumulated benefit obligation without
projected wage increases $ 236.4 $237.4
(a) Invested in fixed income investments, equities and
guaranteed investment contracts. In 1996, equities
included $26.5 million of DPL Inc. common stock.
II-17
<PAGE>
Postretirement Benefits
- -----------------------
Qualified employees who retired prior to 1987 and their
dependents are eligible for health care and life insurance
benefits. The unamortized transition obligation associated with
these benefits is being amortized over the approximate average
remaining life expectancy of the retired employees. Active
employees are eligible for life insurance benefits, and this
unamortized transition obligation is being amortized over the
average remaining service period.
The Company has funded the union-eligible health benefit using a
Voluntary Employee Beneficiary Association Trust. Actual returns
on plan assets were 6.0% and 6.7% in 1997 and 1996, respectively.
The following table presents the components of postretirement
benefit cost:
$ in millions 1997 1996 1995
- ---------------------------------------------------------------
Expected return on plan assets of 5.7% $(0.8) $(0.6) $ -
Interest cost 2.2 2.5 3.6
Net amortization (1.1) 2.9 2.9
----- ----- -----
Postretirement benefit cost $ 0.3 $ 4.8 $ 6.5
===== ===== =====
The assumed health care cost trend rate used in measuring the
accumulated postretirement benefit obligation is 9% for 1997 and
decreases to 5% by 2005. A one percentage point increase in each
future year's assumed health care trend rate would increase
postretirement benefit cost by $0.1 million annually and would
increase the accumulated postretirement benefit obligation by
$2.3 million. The weighted average discount rate used in determining
the accumulated postretirement benefit obligation was 6.25%.
The following table sets forth the accumulated postretirement
benefit amounts recorded in Other Deferred Credits on the
Consolidated Balance Sheet at December 31:
$ in millions 1997 1996
- -----------------------------------------------------------
Accumulated postretirement
benefit obligation:
-retirees and dependents $35.4 $40.7
-active employees 1.1 1.1
----- -----
Total 36.5 41.8
Plan assets at fair value (a) 12.1 11.9
----- -----
Projected benefit obligation in excess
of plan assets 24.4 29.9
Unamortized transition obligation (15.9) (18.9)
Actuarial gains and losses 25.5 24.6
----- -----
Accrued postretirement benefit liability $34.0 $35.6
===== =====
(a) Invested in fixed income government obligations and money
market securities.
II-18
<PAGE>
5. Commonly Owned Facilities
The Company owns certain electric generating and transmission
facilities as tenants in common with other Ohio utilities. Each
utility is obligated to pay its ownership share of construction
and operation costs of each facility. As of December 31, 1997,
the Company had $1.6 million of commonly owned facilities under
construction. The Company's share of expenses is included in the
Consolidated Statement of Results of Operations.
The following table presents the Company's share of the commonly
owned facilities at December 31, 1997:
Company
Company Share Investment
--------------------- ---------------
Production Gross Plant in
Ownership Capacity Service
(%) (MW) ($ in millions)
- ---------------------------------------------------------------------
Production Units:
Beckjord Unit 6 50.0 210 55
Conesville Unit 4 16.5 129 30
East Bend Station 31.0 186 150
Killen Station 67.0 418 406
Miami Fort Units 7 & 8 36.0 360 119
Stuart Station 35.0 823 245
Zimmer Station 28.1 365 989
Transmission
(at varying percentages) 67
6. Notes Payable And Compensating Balances
DPL Inc., the Company's parent, has $200 million available
through a revolving credit agreement. This agreement with a
consortium of banks is renewable through 2001. Commitment fees
are approximately $170,000 per year, depending upon the aggregate
unused balance of the loan. At December 31, 1997, DPL Inc. had
$36.0 million in borrowings outstanding under this credit
agreement.
The Company also has $96.6 million available in short-term
informal lines of credit. To support these lines of credit, the
Company is required to maintain average daily compensating
balances of approximately $400,000 and also pay $87,550 per year
in fees. At December 31, 1997, the Company had $10.0 million in
borrowings from these lines of credit.
The Company had $69.7 million and $10.0 million in commercial
paper outstanding at a weighted average interest rate of 6.0% and
6.75% at December 31, 1997 and 1996, respectively.
II-19
<PAGE>
7. Long-Term Debt
At December 31,
$ in millions 1997 1996
- ----------------------------------------------------------------
First mortgage bonds maturing:
2003 8.00% $ - $ 40.0
2022-2026 8.14% (a) 671.0 671.0
Pollution control series maturing
through 2027 - 6.43% (a) 107.2 107.6
------ ------
778.2 818.6
Guarantee of Air Quality Development
Obligations 6.10% Series Due 2030 110.0 110.0
Unamortized debt discount and premium (net) (2.2) (2.3)
------ ------
Total $886.0 $926.3
====== ======
(a) Weighted average interest rates for 1997 and 1996.
The amounts of maturities and mandatory redemptions for first
mortgage bonds and notes are $0.4 million per year in 1998
through 2002. Substantially all property of the Company is
subject to the mortgage lien securing the first mortgage bonds.
During 1997, a $40 million series of first mortgage bonds
matured, and another $40 million series scheduled to mature in
2003 was redeemed.
II-20
<PAGE>
<TABLE>
<CAPTION>
8. Common Shareholder's Equity
Common Stock (a)
------------------- Earnings
Outstanding Other Paid-In Reinvested in
$ in millions Shares Amount Capital the Business Total
- ---------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
1995:
Beginning Balance 41,172,173 $ 0.4 $738.5 $421.4 $1,160.3
Net income 159.4 159.4
Common stock dividends (132.6) (132.6)
Preferred stock dividends (0.9) (0.9)
Other 0.2 4.1 4.3
---------------------------------------------------------
Ending balance 41,172,173 $ 0.4 $738.7 $451.4 $1,190.5
1996:
Net income 164.8 164.8
Common stock dividends (138.3) (138.3)
Preferred stock dividends (0.9) (0.9)
Other 0.2 1.2 1.4
---------------------------------------------------------
Ending balance 41,172,173 $ 0.4 $738.9 $478.2 $1,217.5
1997:
Net income 172.0 172.0
Common stock dividends (118.5) (118.5)
Preferred stock dividends (0.9) (0.9)
Other 0.2 10.5 10.7
---------------------------------------------------------
Ending balance 41,172,173 $ 0.4 $739.1 $541.3 $1,280.8
=========================================================
(a) 50,000,000 shares authorized.
</TABLE>
II-21
<PAGE>
9. Preferred Stock
$25 par value, 4,000,000 shares authorized, no shares
outstanding; and $100 par value, 4,000,000 shares authorized,
228,508 shares without mandatory redemption provisions
outstanding.
Current Current Par Value
Redemption Shares At December 31, 1997 and 1996
Series Rate Price Outstanding ($ in millions)
- --------------------------------------------------------------------------
A 3.75% $102.50 93,280 $ 9.3
B 3.75% $103.00 69,398 7.0
C 3.90% $101.00 65,830 6.6
------- -----
Total 228,508 $22.9
======= =====
The shares may be redeemed at the option of the Company at the
per share prices indicated, plus cumulative accrued dividends.
10. Fair Value Of Financial Instruments
At December 31,
1997 1996
------------------ -------------------
$ in millions Fair Value Cost Fair Value Cost
- ---------------------------------------------------------------------------
$ $ $ $
Assets (a)
Available for sale securities 165.0 133.8 90.1 75.4
Held to maturity securities 57.5 56.7 50.9 50.7
Liabilities (b)
Debt 1,038.7 967.4 1,018.6 976.7
(a) Maturities range from 1998 to 2010.
(b) Includes current maturities.
Financial assets with quoted market prices are carried at market;
the remaining financial assets are carried at cost.
II-22
<PAGE>
11. Reconciliation Of Net Income To Net Cash Provided By Operating Activities
For the years ended December 31,
$ in millions 1997 1996 1995
- ----------------------------------------------------------------------------
Net income $172.0 $164.8 $159.4
Adjustments:
Depreciation and amortization 125.9 122.3 115.4
Deferred income taxes (2.8) (3.3) 4.4
Amortization of regulatory assets, net 16.8 15.3 15.4
Operating expense provisions (26.0) (10.2) (0.4)
Accounts receivable (12.4) (48.9) (44.7)
Accounts payable 16.4 10.0 21.4
Accrued taxes payable 21.2 20.7 (7.6)
Inventory (12.0) 6.5 1.7
Other 0.5 11.1 (3.9)
------ ------ ------
Net cash provided by operating activities $299.6 $288.3 $261.1
====== ====== ======
II-23
<PAGE>
12. Financial Information By Business Segments
For the years ended December 31,
$ in millions 1997 1996 1995
- --------------------------------------------------------------------------
Utility service revenues
Electric $1,010.0 $1,016.4 $1,029.9
Gas 243.7 238.6 222.0
Other 0.7 3.4 5.6
-------- -------- --------
Total utility service revenues 1,254.4 1,258.4 1,257.5
Interest and other income 13.9 9.3 11.8
-------- -------- --------
Total income $1,268.3 $1,267.7 $1,269.3
======== ======== ========
Operating profit before tax
Electric $ 327.0 $ 326.9 $ 335.8
Gas 24.9 23.7 18.9
Other (3.5) (5.7) (4.4)
-------- -------- --------
Total operating profit before tax 348.4 344.9 350.3
Other income, net (a) 9.2 6.7 1.3
Interest expense (86.0) (89.1) (94.4)
-------- -------- --------
Income before income taxes $ 271.6 $ 262.5 $ 257.2
======== ======== ========
Depreciation and amortization
Electric $ 118.4 $ 112.8 $ 108.1
Gas 7.1 6.7 6.4
Other 0.4 2.8 0.9
-------- -------- --------
Total depreciation and amortization $ 125.9 $ 122.3 $ 115.4
======== ======== ========
Construction additions
Electric $ 92.8 $ 109.4 $ 66.6
Gas 16.3 14.1 11.7
Other - - 0.6
-------- -------- --------
Total construction additions $ 109.1 $ 123.5 $ 78.9
======== ======== ========
Assets
Electric $2,733.6 $2,754.3 $2,763.1
Gas 277.1 259.9 223.7
Other (b) 316.1 229.0 217.5
-------- -------- --------
Total assets at year-end $3,326.8 $3,243.2 $3,204.3
======== ======== ========
(a) Includes primarily investment income less bond redemption
costs in 1997 and 1995.
(b) Includes primarily temporary cash investments, debt and
equity financial assets and certain deferred items.
II-24
<PAGE>
SELECTED QUARTERLY INFORMATION
March 31, June 30, September 30, December 31,
$ in millions 1997 1996 1997 1996 1997 1996 1997 1996
- ------------------------------------------------------------------------------
$ $ $ $ $ $ $ $
Utility service
revenues 357.3 369.0 269.8 282.0 283.9 278.2 343.4 329.2
Income before income
taxes 94.6 101.5 51.6 54.2 73.1 67.3 52.3 39.5
Net income 62.2 62.8 33.2 33.1 44.3 41.7 32.3 27.2
Earnings on common
stock 62.0 62.5 33.0 32.9 44.1 41.5 32.0 27.0
Dividends paid 28.9 34.7 29.0 34.7 29.0 34.5 31.6 34.4
II-25
<PAGE>
FINANCIAL AND STATISTICAL SUMMARY
<TABLE>
<CAPTION>
1997 1996 1995 1994 1993
- --------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
For the years ended December 31,
Utility service revenues (millions) $1,254.4 1,258.4 1,257.5 1,190.3 1,153.7
Earnings on common stock (millions) $ 171.1 163.9 158.5 147.7 134.9
Earnings per share of common stock $ 4.16 3.98 3.85 3.59 3.28
Dividends paid (millions) $ 118.5 138.3 132.6 103.7 107.8
Electric sales (millions of kWh)--
Residential 4,788 4,924 4,871 4,465 4,558
Commercial 3,408 3,407 3,425 3,068 3,006
Industrial 4,749 4,540 4,401 4,388 4,089
Other 3,664 3,443 4,117 2,298 3,023
------ ------ ------ ------ ------
Total 16,609 16,314 16,814 14,219 14,676
Gas sales (thousands of MCF)--
Residential 29,277 31,087 29,397 27,911 28,786
Commercial 9,567 9,424 8,307 8,081 8,468
Industrial 2,520 3,404 2,584 3,150 3,056
Other 2,153 2,829 3,006 2,909 3,171
Transported gas 18,523 16,953 16,376 15,147 13,401
------ ------ ------ ------ ------
Total 62,040 63,697 59,670 57,198 56,882
At December 31,
Total assets (millions) $3,326.8 3,243.2 3,204.3 3,147.0 3,211.3
Long-term debt and preferred stock
with mandatory redemption
provisions (millions) $ 886.0 926.3 991.5 1,003.7 1,042.9
First mortgage bond ratings--
Duff & Phelps, Inc. AA AA AA AA AA-
Standards & Poor's Corporation AA- AA- AA- AA- A
Moody's Investors Service Aa3 Aa3 Aa3 A1 A2
Number of Preferred Shareholders 625 684 733 795 1,873
</TABLE>
II-26
<PAGE>
Report of Independent Accountants
---------------------------------
To the Board of Directors of The Dayton Power and Light Company
In our opinion, the consolidated financial statements listed
in the index, appearing under Item 8 on page II-8 of this Form 10-K,
present fairly, in all material respects, the financial position of
The Dayton Power and Light Company (the "Company") and its
subsidiaries at December 31, 1997 and 1996, and the results of
their operations and their cash flows for each of the three years
in the period ended December 31, 1997, in conformity with generally
accepted accounting principles. These consolidated financial
statements are the responsibility of the Company's management; our
responsibility is to express an opinion on these consolidated
financial statements based on our audits. We conducted our audits
of these statements in accordance with generally accepted auditing
standards which require that we plan and perform the audit to obtain
reasonable assurance about whether the consolidated financial
statements are free of material misstatement. An audit includes
examining, on a test basis, evidence supporting the amounts and
disclosures in the consolidated financial statements, assessing the
accounting principles used and significant estimates made by
management, and evaluating the overall financial statement
presentation. We believe that our audits provide a reasonable basis
for the opinion expressed above.
/s/ Price Waterhouse LLP
Price Waterhouse LLP
Dayton, Ohio
January 21, 1998
II-27
<PAGE>
Report of Independent Accountants
on Financial Statement Schedule
---------------------------------
To the Board of Directors of The Dayton Power and Light Company
Our audits of the consolidated financial statements of The Dayton
Power and Light Company and its subsidiaries referred to in our
report dated January 21, 1998 appearing on page II-27 of this
Annual Report on Form 10-K also included an audit of the Financial
Statement Schedule listed in Item 14(a) of this Form 10-K. In our
opinion, this Financial Statement Schedule presents fairly, in all
material respects, the information set forth therein when read in
conjunction with the related consolidated financial statements.
/s/ Price Waterhouse LLP
Price Waterhouse LLP
Dayton, Ohio
January 21, 1998
II-28
<PAGE>
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
- ------------------------------------------------------------------------------
Directors of the Registrant
- ---------------------------
The Board is presently authorized to consist of nine
directors. These nine directors are also directors of DPL Inc.,
the holding company of the Company. Nine directors are to be
elected this year to serve until the Annual Meeting of
Shareholders in 1999 or until their successors are duly elected
and qualified. Should any nominee become unable to accept
nomination or election, the Board will vote for the election of
such other person as a director as the present directors may
recommend in the place of such nominee.
The following information regarding the nominees is
based on information furnished by them:
Director Since
--------------
THOMAS J. DANIS, Age 48 1989
Chairman and Chief Executive Officer,
The Danis Companies, Dayton, Ohio, construction,
real estate and environmental services.
Director: CSR America Inc.
Trustee: Dayton Foundation,
Miami Valley Research Park Foundation.
JAMES F. DICKE, II, Age 52 1990
President, Crown Equipment Corporation, New
Bremen, Ohio, international manufacturer and
distributor of electric lift trucks and material
handling products.
Director: Regional Boys and Girls Clubs of America,
Dayton Art Institute.
Chairman: Trinity University Board of Trustees
Secretary: Culver Educational Foundation.
III-1
<PAGE>
Director Since
--------------
PETER H. FORSTER, Age 55 1979
Chairman, DPL Inc. and The Dayton Power and
Light Company.
Chairman: Miami Valley Research Foundation.
Director: Amcast Industrial Corp.,
Comair Holdings, Inc.
Trustee: F. M. Tait Foundation, Arts Center
Foundation.
ERNIE GREEN, Age 59 1991
President and Chief Executive Officer, Ernie
Green Industries, Dayton, Ohio, automotive
components manufacturer.
Director: Pitney Bowes Inc., WPTD-TV,
Eaton Corp., Fluor Daniel/GTI, Gradall.
JANE G. HALEY, Age 67 1978
President and Chief Executive Officer,
Gosiger, Inc., Dayton, Ohio, national importer
and distributor of machine tools.
Director: Ultra-Met Company, Urbana, Ohio, ONA,
Dayton, Ohio.
Trustee: University of Dayton, Chaminade-Julienne
High School, Dayton, Ohio, Miami Valley Economic
Development Coalition.
Member: Area Progress Council.
ALLEN M. HILL, Age 52 1989
President and Chief Executive Officer, DPL
Inc. and The Dayton Power and Light Company.
Director: Citizens Federal Bank, F.S.B.
Trustee: Dayton Business Committee,
The University of Dayton, Miami Valley Economic
Development Coalition, Air Force Museum Foundation,
National Center for Composite Systems Technology.
III-2
<PAGE>
Director Since
--------------
W AUGUST HILLENBRAND, Age 57 1992
President and Chief Executive Officer,
Hillenbrand Industries, Batesville, Indiana,
a diversified public holding company with
five wholly-owned and autonomously operated
subsidiaries manufacturing caskets, hospital
furniture, hospital supplies, high-tech security
locks and providing funeral planning services.
Director: Forecorp, Inc., Forethought Life
Insurance Company.
Trustee: Denison University, National Committee
for Quality Health Care, Batesville Girl Scouts.
DAVID R. HOLMES, Age 57 1994
Chairman, President and Chief Executive Officer,
The Reynolds and Reynolds Company, Dayton, Ohio,
information management systems.
Director: NCR Corporation, Dayton, Ohio,
Wright Health/Anthem, Dayton, Ohio.
Advisor: J. L. Kellogg Graduate School of Management,
Northwestern University.
Member: Dayton Business Committee, Area Progress
Council, Downtown Dayton Partnership.
BURNELL R. ROBERTS, Age 70 1987
Chairman, Sweetheart Holdings, Inc.
Retired Chairman of the Board and Chief Executive
Officer, The Mead Corporation, Dayton, Ohio,
forest products producer.
Director: Armco, Inc., The Perkin-Elmer Corporation,
Rayonier, Inc., Universal Protective Plastics, Inc.,
Day International Group, Inc.
III-3
<PAGE>
EXECUTIVE OFFICERS OF THE REGISTRANT
(As of March 1, 1998)
Business Experience,
Last Five Years
(Positions with Registrant
Name Age Unless Otherwise Indicated) Dates
- -----------------------------------------------------------------------------
Peter H. Forster 55 Chairman 4/06/92 - 3/01/98
Chairman, DPL Inc. 1/01/97 - 3/01/98
Chairman and Chief 9/26/95 - 1/01/97
Executive Officer, DPL Inc.
Chairman, President and 4/05/88 - 9/26/95
Chief Executive Officer,
DPL Inc.
Allen M. Hill 52 President and Chief 4/06/92 - 3/01/98
Executive Officer
President and Chief 1/01/97 - 3/01/98
Executive Officer, DPL Inc.
President and Chief Operating 9/26/95 - 1/01/97
Officer, DPL Inc.
Paul R. Anderson 55 Controller 4/12/81 - 3/01/98
Stephen P. Bramlage 51 Assistant Vice President 1/01/94 - 3/01/98
Director, Service Operations 10/29/88 - 1/01/94
Jeanne S. Holihan 41 Assistant Vice President 3/17/93 - 3/01/98
Treasurer 11/06/90 - 3/17/93
Thomas M. Jenkins 46 Group Vice President and 5/14/96 - 3/01/98
Treasurer, DPL Inc. and
the Company
Group Vice President 6/27/95 - 5/14/96
Group Vice President and
Treasurer, DPL Inc.
Group Vice President and 5/09/94 - 6/27/95
and Treasurer, DPL Inc.
and the Company
Group Vice President and 11/06/90 - 5/09/94
Treasurer, DPL Inc.
Group Vice President
III-4
<PAGE>
EXECUTIVE OFFICERS OF THE REGISTRANT
(As of March 1, 1998)
Business Experience,
Last Five Years
(Positions with Registrant
Name Age Unless Otherwise Indicated) Dates
- ------------------------------------------------------------------------------
Stephen F. Koziar Jr. 53 Group Vice President 1/31/95 - 3/01/98
and Secretary, DPL Inc.
and the Company
Group Vice President, 12/10/87 - 1/31/95
DPL Inc. and the Company
Judy W. Lansaw 46 Group Vice President, 1/31/95 - 3/01/98
DPL Inc. and the Company
Group Vice President and 12/07/93 - 1/31/95
Secretary, DPL Inc. and
the Company
Vice President and Secretary 8/01/89 - 12/07/93
Secretary, DPL Inc. and
the Company
Arthur G. Meyer 48 Vice President, Legal and 11/21/97 - 3/01/98
Corporate Affairs
Director, Corporate Relations 5/14/96 - 11/21/97
Treasurer 6/27/95 - 5/14/96
Director, Financial Activities 5/09/94 - 6/27/95
Manager, Service Operations 1/31/94 - 5/09/94
Associate General Counsel 7/13/92 - 1/31/94
Bryce W. Nickel 41 Assistant Vice President 1/01/94 - 3/01/98
Director, Service Operations 10/29/89 - 1/01/94
H. Ted Santo 47 Group Vice President 12/08/92 - 3/01/98
III-5
<PAGE>
Item 11 - Executive Compensation
- ------------------------------------------------------------------------------
COMPENSATION OF DIRECTORS
Directors of the Company who are not employees receive
$12,000 annually for services as a director, $600 for attendance
at a Board meeting, and $500 for attendance at a committee
meeting or operating session of DPL Inc. and the Company.
Members of the Executive Committee of DPL Inc. receive $2,000
annually for services on that committee. Each committee chairman
receives an additional $1,600 annually. Directors who are not
employees of the Company also participate in a Directors'
Deferred Stock Compensation Plan (the "Stock Plan") under which a
number of DPL Inc. common shares are awarded to directors each
year. All shares awarded under the Stock Plan are transferred to
a grantor trust (the "Master Trust") maintained by DPL Inc. to
secure its obligations under various directors' and officers'
deferred and incentive compensation plans. Receipt of the shares
or cash equal to the value thereof is deferred until the
participant retires as a director or until such other time as
designated by the participant and approved by the Compensation
and Management Review Committee (the "Committee") of DPL Inc. In
the event of a change of control (as defined in the Stock Plan),
the authority and discretion which is exercisable by the
Committee will be exercised by the trustees of the Master Trust.
In April 1997, each non-employee director was awarded
1,600 shares.
DPL Inc. maintains a Deferred Compensation Plan (the
"Compensation Plan") for non-employee directors of DPL Inc. and
the Company in which payment of directors' fees may be deferred.
The Compensation Plan also includes a supplementary deferred
income program which provides that DPL Inc. will match $5,000
annually of deferred directors' fees for a maximum of ten years.
Under the supplementary program, a $150,000 death benefit is
provided until such director ceases to participate in the
Compensation Plan. Under the standard deferred income program
directors are entitled to receive a lump sum payment or payments
in installments over a period up to 20 years. A director may
elect payment in either cash or common shares. Participants in
the supplementary program are entitled to receive deferred
payments over a ten-year period in equal installments. The
Compensation Plan provides that in the event of a change in
control of DPL Inc., as defined in the Compensation Plan, all
benefits provided under the supplementary deferred income program
become immediately vested without the need for further
contributions by the participants and the discretion which, under
the Compensation Plan, is exercisable by the Chief Executive
Officer of DPL Inc. will be exercised by the trustees of the
Master Trust. If the consent of the Chief Executive Officer of
DPL Inc. is obtained, individuals who have attained the age of 55
and who are no longer directors of DPL Inc. or the Company may
receive a lump sum payment of amounts credited to them under the
supplementary deferred income program.
Mr. Forster has entered into an agreement with DPL Inc.
and the Company pursuant to which Mr. Forster will serve as
Chairman of the Board of DPL Inc. and the Company and will
provide various advisory and consulting services. The term of the
agreement expires on December 31, 1999 (which term is
automatically extended on December 31, 1999 and each December 31
thereafter for an additional year unless either party gives
advance notice of nonrenewal). Under the agreement, Mr. Forster
receives an annual consulting fee of $500,000 (as well as such
bonuses, if any, as may be determined by the Compensation and
III-6
<PAGE>
Management Review Committee in its discretion) and an award
opportunity of 35,000 restricted shares under the Stock Plan.
Commencing in 2000, Mr. Forster will participate in a bonus
program for individuals monitoring and managing DPL Inc.'s
financial assets pursuant to which he will have the opportunity
to receive an annual bonus if there is a positive cumulative cash
return on such financial assets (after recovery of all amounts
invested plus expenses). Payments under the bonus program, if
and as earned, will continue following termination of the
agreement for any reason. Mr. Forster, who retired as Chief
Executive Officer of DPL Inc. effective December 31, 1996,
continues to actively perform significant duties and functions
for DPL Inc. and its subsidiaries under the agreement.
EXECUTIVE OFFICER COMPENSATION
Summary Compensation Table
- --------------------------
Set forth below is certain information concerning the
compensation of the Chief Executive Officer and each of the other
four most highly compensated executive officers of the Company
for the last three fiscal years, for services rendered in all
capacities to the Company and its subsidiaries, DPL Inc., and the
other subsidiaries of DPL Inc.
Long-Term
Compensation
Annual ------------
Compensation Restricted
----------------- Stock Unit All Other
Name and Principal Salary Bonus (1) Awards (2) Compensation (3)
Position Year ($) ($) ($) ($)
- ------------------------------------------------------------------------------
Allen M. Hill 1997 430,000 258,000 834,000 ('98-00) 1,000
President and Chief 1996 377,000 226,000 717,000 ('97-99) 1,000
Executive Officer 1995 363,000 226,000 319,000 ('96-98) 1,000
Peter H. Forster (4) 1997 500,000 150,000 840,000 ('98-00) 70,400
Chairman 1996 597,000 358,000 984,000 ('97-99) 1,000
1995 572,000 344,000 784,000 ('96-98) 1,000
Judy W. Lansaw 1997 240,000 108,000 411,000 ('98-00) 1,000
Group Vice President 1996 214,000 96,000 393,000 ('97-99) 1,000
1995 197,000 89,000 227,000 ('96-98) 1,000
Stephen F. Koziar Jr. 1997 231,000 104,000 234,000 ('98-00) 1,000
Group Vice President 1996 218,000 98,000 216,000 ('97-99) 1,000
and Secretary 1995 209,000 94,000 141,000 ('96-98) 1,000
H. Ted Santo 1997 226,000 102,000 297,000 ('98-00) 1,000
Group Vice President 1996 205,000 92,000 305,000 ('97-99) 1,000
1995 190,000 86,000 168,000 ('96-98) 1,000
III-7
<PAGE>
(1) Amounts in this column represent awards made under the
Management Incentive Compensation Program ("MICP"). Awards
are based on achievement of specific predetermined operating
and management goals in the year indicated and paid in the
year earned or in the following year.
(2) Amounts shown in this column have not been paid, but are
contingent on performance and represent the dollar value of
restricted stock incentive units ("SIU's") awarded to the
named executive officer under the Management Stock Incentive
Plan ("MSIP") based on the closing price of a DPL Inc. common
share on the New York Stock Exchange--Consolidated
Transactions Tape on the date of award. The SIU's awarded
for 1995, 1996 and 1997 vest only to the extent that the
DPL Inc. average return on equity ("ROE") over a three-year
performance period is above the Regulatory Research
Associates industry median.
Depending on the performance of DPL Inc., these SIU's vest in
amounts ranging from 0% to 100% of the target award at an ROE
between 0 and 100 basis points above median ROE and from 100%
to 150% of target award at an ROE between 100 and 200 basis
points above median ROE.
No units vest if the three-year average ROE is below 10%.
Amounts shown for 1995, 1996 and 1997 reflect target awards.
For each SIU which vests, a participant receives the cash
equivalent of one DPL Inc. common share plus dividend
equivalents from the date of award. Prior to payout at
retirement, an individual may elect to convert a portion of
vested SIU's to a cash equivalent and accrue interest
thereon. All payouts of vested SIU's under the MSIP are
deferred until retirement.
(3) Amounts in this column represent employer matching
contributions on behalf of each named executive under the
DP&L Employee Savings Plan made to the DPL Inc. Employee
Stock Ownership Plan.
(4) Annual compensation shown for Mr. Forster for 1997 was paid
pursuant to an agreement with DPL Inc. and the Company. Long
term compensation award opportunities shown for 1996 and 1997
represent the dollar value of restricted shares awarded to
Mr. Forster under the Directors' Stock Plan which are subject
to the same earning and vesting criteria generally applicable
to SIU's. All other compensation shown for 1997 represents
directors fees of $32,600 and the dollar value of the annual
award of 1,600 shares to each non-employee director under
the Directors' Stock Plan.
Certain Severance Pay Agreements
- --------------------------------
DPL Inc. entered into severance pay agreements with
each of Messrs. Hill, Koziar and Santo and Mrs. Lansaw providing
for the payment of severance benefits in the event that the
individual's employment with DPL Inc. or its subsidiaries is
terminated under specified circumstances within three years after
a change in control of DPL Inc. or the Company (generally,
defined as the acquisition of 15% or more of the voting
securities or certain mergers or other business combinations).
The agreements entered into between 1987 and 1991 require the
individuals to remain with DPL Inc. throughout the period during
which any change of control is pending in order to help put in
place the best plan for the shareholders. The principal
severance benefits under each agreement include payment of the
following: (i) the individual's full base salary and accrued
benefits through the date of termination and any awards for any
completed or partial period under the MICP and the individual's
award for the current period under the MICP (or for a completed
period if no award for that period has yet been determined) fixed
at an amount equal to his average annual award for the preceding
three years; (ii) 300%...
III-8
<PAGE>
...of the sum of the individual's annual base salary at the rate in
effect on the date of termination (or, if higher, at the rate in
effect as of the time of the change in control) plus the average
amount awarded to the individual under the MICP for the three
preceding years; (iii) all awarded or earned but unpaid SIU's;
and (iv) continuing medical, life, and disability insurance. In
the event any payments under these agreements are subject to an
excise tax under the Internal Revenue Code of 1986, the payments
will be adjusted so that the total payments received on an after-
tax basis will equal the amount the individual would have
received without imposition of the excise tax. The severance pay
agreements are effective for one year but are automatically
renewed each year unless DPL Inc. or the participant notifies the
other one year in advance of its or his intent not to renew.
DPL Inc. has agreed to secure its obligations under the severance
pay agreements by transferring required payments to the Master
Trust. Mr. Forster's agreement with DPL Inc. and the Company
contains similar severance benefits provisions.
Pension Plans
- -------------
The following table sets forth the estimated total
annual benefits payable under the Company retirement income plan
and the supplemental executive retirement plan to executive
officers at normal retirement date (age 65) based upon years of
accredited service and final average annual compensation
(including base and incentive compensation) for the three highest
years during the last ten:
Total Annual Retirement Benefits for
Years of Accredited Service at Age 65
Final Average -------------------------------------
Annual Earnings 10 Years 15 Years 20-30 Years
--------------- -------- -------- -----------
$ 200,000 $ 52,500 $ 78,500 $ 104,500
400,000 109,500 164,000 218,500
600,000 166,500 249,500 332,500
800,000 223,500 335,000 446,500
1,000,000 280,500 420,500 560,500
1,200,000 337,500 506,000 674,500
1,400,000 394,500 591,500 788,500
The years of accredited service for the named executive
officers are Mr. Hill -- 28 yrs.; Mr. Koziar -- 28 yrs.;
Mrs. Lansaw -- 18 yrs.; and Mr. Santo -- 22 yrs. Years of
service under the retirement income plan are capped at 30 years,
however, the retirement and supplemental plans, taken together,
can provide full benefits after 20 years of accredited service.
Benefits are computed on a straight-life annuity basis, are
subject to deduction for Social Security benefits and may be
reduced by benefits payable under retirement plans of other
employers. For each year an individual retires prior to age 62,
benefits under the supplemental plan are reduced by 3% or 21% for
early retirement at age 55. Mr. Forster ceased to accrue
benefits under the retirement and supplemental plans effective as
of December 31, 1996 upon his retirement as an employee of
DPL Inc. and the Company.
III-9
<PAGE>
Item 12 - Security Ownership Of Certain Beneficial Owners And Management
- ------------------------------------------------------------------------------
The Company's stock is beneficially owned by DPL Inc.
Set forth below is information concerning the beneficial
ownership of shares of Common Stock of DPL Inc. by each director
of the Company as of January 31, 1998.
Amount and Nature of
Name of Director Beneficial Ownership (1)
---------------- ------------------------
Thomas J. Danis 35,799 shares
James F. Dicke, II 92,130 shares
Peter H. Forster 37,416 shares
Ernie Green 34,023 shares
Jane G. Haley 51,672 shares
Allen M. Hill 32,733 shares
W August Hillenbrand 20,683 shares
David R. Holmes 10,888 shares
Burnell R. Roberts 35,924 shares
Set forth below is information concerning the beneficial
ownership of shares of Common Stock of DPL Inc. by each executive
officer of the Company named in the Summary Compensation Table
(other than executive officers who are directors of the Company
whose security ownership is found above) as of January 31, 1998.
Amount and Nature of
Name of Executive Officer Beneficial Ownership (1)
------------------------ ------------------------
Stephen F. Koziar 13,633 shares
H. Ted Santo 3,747 shares
Judy W. Lansaw 3,519 shares
(1) The number of shares shown represents in each instance less
than 1% of the outstanding Common Shares of DPL Inc.
There were 402,572 shares or 0.25% of the total number of
Common Shares beneficially owned by all directors and
executive officers of DPL Inc. and the Company as a group at
January 31, 1998. The number of shares shown for the
directors includes Common Shares transferred to the Master
Trust for non-employee directors pursuant to the Directors'
Deferred Stock Compensation Plan.
Item 13 - Certain Relationships And Related Transactions
- ------------------------------------------------------------------------------
None.
III-10
<PAGE>
PART IV
Item 14 - Exhibits, Financial Statement Schedule And Reports On Form 8-K
- ------------------------------------------------------------------------------
(a) Documents filed as part of the Form 10-K
1. Financial Statements
--------------------
See Item 8 - Index to Financial Statements on page II-8, which
page is incorporated herein by reference.
2. Financial Statement Schedule
----------------------------
For the three years in the period ended December 31, 1997:
Page No.
--------
Schedule II - Valuation and qualifying accounts IV-7
The information required to be submitted in Schedules
I, III, IV and V is omitted as not applicable or not required
under rules of Regulation S-X.
IV-1
<PAGE>
3. Exhibits
--------
The following exhibits have been filed with the Securities
and Exchange Commission and are incorporated herein by reference.
Incorporation by Reference
--------------------------
2 Copy of the Agreement of Merger among Exhibit A to the 1986
DPL Inc., Holding Sub Inc. and the Proxy Statment
Company dated January 6, 1986 (File No. 1-2385)
January 6, 1986
3(a) Regulations and By-Laws of the Company Exhibit 2(e) to
Registration Statement
No. 2-68136 to Form S-16
3(b) Copy of Amended Articles of Exhibit 3(b) to Report
Incorporation of the Company dated on Form 10-K for the year
January 3, 1991 ended December 31, 1991
(File No. 1-2385)
4(a) Copy of Composite Indenture dated as of Exhibit 4(a) to Report
October 1, 1935, between the Company on Form 10-K for the year
and The Bank of New York, Trustee with ended December 31, 1985
all amendments through the Twenty-Ninth (File No. 1-2385)
Supplemental Indenture
4(b) Copy of the Thirtieth Supplemental Exhibit 4(h) to
Indenture dated as of March 1, 1982, Registration Statement
between the Company and The Bank of New No. 33-53906
York, Trustee
4(c) Copy of the Thirty-First Supplemental Exhibit 4(h) to
Indenture dated as of November 1, 1982, Registration Statement
between the Company and The Bank of New No. 33-56162
York, Trustee
4(d) Copy of the Thirty-Second Supplemental Exhibit 4(i) to
Indenture dated as of November 1, 1982, Registration Statement
between the Company and The Bank of New No. 33-56162
York, Trustee
4(e) Copy of the Thirty-Third Supplemental Exhibit 4(e) to Report
Indenture dated as of December 1, 1985, on Form 10-K for the year
between the Company and The Bank of New ended December 31, 1985
York, Trustee (File No. 1-2385)
IV-2
<PAGE>
4(f) Copy of the Thirty-Fourth Supplemental Exhibit 4 to Report
Indenture dated as of April 1, 1986, on Form 10-Q for the quarter
between the Company and The Bank of New ended June 30, 1986
York, Trustee (File No. 1-2385)
4(g) Copy of the Thirty-Fifth Supplemental Exhibit 4(h) to Report
Indenture dated as of December 1, 1986, on Form 10-K for the year
between the Company and The Bank of New ended Decmebr 31, 1986
York, Trustee (File No. 1-9052)
4(h) Copy of the Thirty-Sixth Supplemental Exhibit 4(i) to
Indenture dated as of August 15, 1992, Registration Statement
between the Company and The Bank of New No. 33-53906
York, Trustee
4(i) Copy of the Thirty-Seventh Supplemental Exhibit 4(j) to
Indenture dated as of November 15, Registration Statemnt
1992, between the Company and The Bank No. 33-56162
of New York, Trustee
4(j) Copy of the Thirty-Eighth Supplemental Exhibit 4(k) to
Indenture dated as of November 15, Registration Statement
1992, between the Company and The Bank No. 33-56162
of New York, Trustee
4(k) Copy of the Thirty-Ninth Supplemental Exhibit 4(k) to
Indenture dated as of January 15, 1993, Registration Statemnet
between the Company and The Bank of New No. 33-57928
York, Trustee
4(l) Copy of the Fortieth Supplemental Exhibit 4(m) to Report
Indenture dated as of February 15, on Form 10-K for the year
1993, between the Company and The Bank ended December 31, 1992
of New York, Trustee (File No. 1-2385)
10(a) Description of Management Incentive Exhibit 10(d) to Report
Compensation Program for Certain on Form 10-K for the year
Executive Officers ended December 31, 1986
(File No. 1-9052)
10(b) Copy of Severance Pay Agreement with Exhibit 10(g) to Report
Certain Executive Officers on Form 10-K for the year
ended December 31, 1987
(File No. 1-2385)
IV-3
<PAGE>
10(c) Copy of Supplemental Executive Exhibit 10(f) to Report
Retirement Plan amended August 6, 1991 on Form 10-K for the year
ended December 31, 1991
(File No. 1-2385)
10(d) Amended description of Directors' Exhibit 10(d) to Report
Deferred Stock Compensation Plan on Form 10-K for the year
effective January 1, 1993 ended December 31, 1993
(File No. 1-2385)
10(e) Amended description of Deferred Exhibit 10(e) to Report
Compensation Plan for Non-Employee on Form 10-K for the year
Directors effective January 1, 1993 ended December 31, 1993
(File No. 1-2385)
10(f) Copy of Management Stock Incentive Exhibit 10(f) to Report
Plan amended January 1, 1993 on Form 10-K for the year
ended December 31, 1993
(File No. 1-2385)
18 Copy of preferability letter relating Exhibit 18 to Report on
to change in accounting for unbilled Form 10-K for the year
revenues from Price Waterhouse LLP ended December 31, 1988
(File No. 1-2385)
The following exhibits are filed herewith:
Page No.
--------
21 Copy of List of Subsidiaries of the Company
(b) Reports on Form 8-K
-------------------
None.
IV-4
<PAGE>
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.
THE DAYTON POWER AND LIGHT COMPANY
Registrant
March 30, 1998 /s/ Allen M. Hill
-------------------------------------
Allen M. Hill
President and Chief Executive Officer
Pursuant to the requirements of the Securities 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.
/s/Paul R. Anderson Controller (principal March 30, 1998
- --------------------- accounting officer)
(P. R. Anderson)
Director
- ---------------------
(T. J. Danis)
Director
- ---------------------
(J. F. Dicke, II)
/s/Peter H. Forster Director and Chairman March 30, 1998
- ---------------------
(P. H. Forster)
/s/Ernie Green Director March 30, 1998
- ---------------------
(E. Green)
/s/Jane G. Haley Director March 30, 1998
- ---------------------
(J. G. Haley)
IV-5
<PAGE>
/s/Allen M. Hill Director, President and March 30, 1998
- --------------------- Chief Executive Officer
(A. M. Hill)
Director
- ---------------------
(W A. Hillenbrand)
/s/David R. Holmes Director March 30, 1998
- ---------------------
(D. R. Holmes)
/s/Thomas M. Jenkins Group Vice President and March 30, 1998
- --------------------- Treasurer (principal
(Thomas M. Jenkins) financial officer)
Director
- ---------------------
(B. R. Roberts)
IV-6
<PAGE>
Schedule II
THE DAYTON POWER AND LIGHT COMPANY
VALUATION AND QUALIFYING ACCOUNTS
For the years ended December 31, 1997, 1996 and 1995
- ------------------------------------------------------------------------------
COLUMN A COLUMN B COLUMN C COLUMN D COLUMN E
- ------------------------------------------------------------------------------
Additions
-----------------
Balance at Charged Balance
Beginning to Deductions at End
Description of Period Income Other (1) of Period
- ------------------------------------------------------------------------------
---------------------thousands-----------------------
1997:
Deducted from accounts
receivable--
Provisions for
uncollectible accounts $5,083 $5,515 $ - $5,941 $4,657
1996:
Deducted from accounts
receivable--
Provisions for
uncollectible accounts $6,481 $4,056 $ - $5,454 $5,083
1995:
Deducted from accounts
receivable--
Provision for
uncollectible accounts $7,801 $1,096 $ - $2,416 $6,481
(1) Amounts written off, net of recoveries of accounts previously written off.
IV-7
Exhibit 21
SUBSIDIARIES OF THE DAYTON POWER AND LIGHT COMPANY
The Dayton Power and Light Company had the following wholly
owned subsidiaries on March 30, 1998:
Name State of Incorporation
- ---- ----------------------
MacGregor Park, Inc. Ohio
Miami Valley Equipment, Inc. Ohio
<TABLE> <S> <C>
<ARTICLE> UT
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-END> DEC-31-1997
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 2232000
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0
22900
<LONG-TERM-DEBT-NET> 886000
<SHORT-TERM-NOTES> 11300
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<LONG-TERM-DEBT-CURRENT-PORT> 400
0
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<OTHER-OPERATING-EXPENSES> 910700
<TOTAL-OPERATING-EXPENSES> 1010300
<OPERATING-INCOME-LOSS> 244100
<OTHER-INCOME-NET> 13900
<INCOME-BEFORE-INTEREST-EXPEN> 258000
<TOTAL-INTEREST-EXPENSE> 86000
<NET-INCOME> 172000
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<EARNINGS-AVAILABLE-FOR-COMM> 171100
<COMMON-STOCK-DIVIDENDS> 118500
<TOTAL-INTEREST-ON-BONDS> 85200
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