S-4

As filed with the Securities and Exchange Commission on November 8, 2019

Registration No. 333-______

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM S-4

REGISTRATION STATEMENT

UNDER

THE SECURITIES ACT OF 1933

The Dayton Power and Light Company

(Exact Name of Registrant as Specified in Its Charter)

Ohio	4931	31-0258470
(State or Other Jurisdiction of Incorporation or Organization)	(Primary Standard Industrial Classification Code Number)	(I.R.S. Employer Identification Number)
	1065 Woodman Drive Dayton, OH 45432 (937) 259-7215
(Address, Including Zip Code, and Telephone Number, Including Area Code, of Registrant’s Principal Executive Offices)

	Judi L. Sobecki, Esq. General Counsel The Dayton Power and Light Company 1065 Woodman Drive Dayton, OH 45432 (937) 259-7215
(Name, Address, Including Zip Code, and Telephone Number, Including Area Code, of Agent For Service)

	Copies to:
Richard D. Truesdell, Jr., Esq. Davis Polk & Wardwell LLP 450 Lexington Avenue New York, New York 10017 (212) 450-4000

Approximate date of commencement of proposed sale to the public: As soon as practicable after the effective date of this Registration Statement.

If the securities being registered on this form are being offered in connection with the formation of a holding company and there is compliance with General Instruction G, check the following box. o

If this form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

If this form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

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Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer o    Accelerated filer o

Non-accelerated filer x    Smaller reporting company o

Emerging growth company o

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 7(a)(2)(B) of the Securities Act. o

CALCULATION OF REGISTRATION FEE
Title Of Each Class Of Securities To Be Registered	Amount To Be Registered	Proposed Maximum Offering Price Per Unit(1)	Proposed Maximum Aggregate Offering Price(1)	Amount Of Registration Fee
First Mortgage Bonds, 3.95% Series due 2049	$425,000,000	100%	$425,000,000	$55,165

(1)Estimated solely for the purpose of computing the amount of the registration fee pursuant to Rule 457 under the Securities Act of 1933.

The Registrant hereby amends this Registration Statement on such date or dates as may be necessary to delay its effective date until the registrant shall file a further amendment which specifically states that this Registration Statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933, as amended or until the Registration Statement shall become effective on such date as the Commission, acting pursuant to said Section 8(a), may determine.

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SUBJECT TO COMPLETION, DATED NOVEMBER 8, 2019

PROSPECTUS

The Dayton Power and Light Company

Offer to Exchange

First Mortgage Bonds, 3.95% Series due 2049

for

New First Mortgage Bonds, 3.95% Series due 2049

We are offering to exchange up to $425,000,000 of our new registered First Mortgage Bonds, 3.95% Series due 2049 (the “new bonds”) for up to $425,000,000 of our existing unregistered First Mortgage Bonds, 3.95% Series due 2049 (the “old bonds”). The terms of the new bonds are identical in all material respects to the terms of the old bonds, except that the new bonds have been registered under the Securities Act of 1933, as amended (the “Securities Act”), and the transfer restrictions and registration rights relating to the old bonds do not apply to the new bonds. The new bonds will represent the same debt as the old bonds and we will issue the new bonds under the same indenture.

To exchange your old bonds for new bonds:

• you are required to make the representations described on page 3 to us; and

• you should read the section called “The Exchange Offer” starting on page 52 for further information on how to exchange your old bonds for new bonds.

The exchange offer will expire at 5:00 P.M. New York City time on unless it is extended.

________________

See “Risk Factors” beginning on page 5 of this prospectus for a discussion of risk factors that should be considered by you prior to tendering your old bonds in the exchange offer.

________________

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of the securities to be issued in the exchange offer or passed upon the adequacy or accuracy of this prospectus. Any representation to the contrary is a criminal offense.

, 2019

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TABLE OF CONTENTS

	Page No.
Glossary of Terms	I-5
Summary	1
Risk Factors	5
Cautionary Note Regarding Forward-Looking Statements	16
Use of Proceeds	17
Capitalization	17
Selected Financial and Other Data	18
Management's Discussion and Analysis of Results of Operations and Financial Condition	18
Business	30
Description of the Bonds	36
The Exchange Offer	44
U.S. Federal Income Tax Consequences	50
Plan of Distribution	50
Validity of Securities	50
Experts	51
Where You Can Find More Information	52
Index to Financial Statements	F-1

We have not authorized anyone to provide you with any information other than that contained in this prospectus or to which we have referred you. We take no responsibility for, and can provide no assurance as to the reliability of, any other information that others may give you. You should assume that the information appearing in this prospectus is accurate only as of the date on the front cover of this prospectus. Our business, financial condition, results of operations and prospects may have changed since that date.

This prospectus is based on information provided by us and by other sources that we believe are reliable. We cannot assure you that this information is accurate or complete. This prospectus summarizes certain documents and other information and we refer you to them for a more complete understanding of what we discuss in this prospectus. In making an investment decision, you must rely on your own examination of our company and the terms of the offering and the bonds, including the merits and risks involved.

We are not making any representation to any purchaser of the bonds regarding the legality of an investment in the bonds by such purchaser under any legal investment or similar laws or regulations. You should not consider any information in this prospectus to be legal, business or tax advice. You should consult your own attorney, business advisor and tax advisor for legal, business and tax advice regarding an investment in the bonds.

Neither the Securities and Exchange Commission (“SEC”) nor any state securities commission has approved or disapproved of these securities or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.

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GLOSSARY OF TERMS

The following select terms, abbreviations or acronyms are used in this prospectus:

Term	Definition
2017 ESP	DP&L's ESP, approved October 20, 2017, effective November 1, 2017
AEP Generation	AEP Generation Resources Inc., a subsidiary of American Electric Power Company, Inc. (“AEP”). Columbus Southern Power Company merged into the Ohio Power Company, another subsidiary of AEP, effective December 31, 2011. The Ohio Power generating assets (including jointly-owned units) were transferred into AEP Generation.
AES	The AES Corporation, a global power company, the ultimate parent company of DPL
AES Ohio Generation	AES Ohio Generation, LLC, a wholly-owned subsidiary of DPL that owns and operates a generation facility from which it makes wholesale sales
AFUDC	Allowance for Funds Used During Construction
AMI	Advanced Metering Infrastructure
AOCI	Accumulated Other Comprehensive Income
ARO	Asset Retirement Obligation
ASU	Accounting Standards Update
CAA	U.S. Clean Air Act
Capacity Market	The purpose of the capacity market is to enable PJM to obtain sufficient resources to reliably meet the needs of electric customers within the PJM footprint. PJM procures capacity, through a multi-auction structure, on behalf of the load serving entities to satisfy the load obligations. There are four auctions held for each Delivery Year (running from June 1 through May 31). The Base Residual Auction is held three years in advance of the Delivery Year and there is one Incremental Auction held in each of the subsequent three years. AES Ohio Generation's capacity is in the “rest of” RTO area of PJM.
CCR	Coal Combustion Residuals, which consists of bottom ash, fly ash, and air pollution
Conesville	AES Ohio Generation's interest in Unit 4 at the Conesville EGU which is operated by AEP
CPP	The Clean Power Plan, the USEPA's final carbon dioxide emission rules for existing power plants under Clean Air Act Section 111(d)
CRES	Competitive Retail Electric Service
CSAPR	Cross-State Air Pollution Rule
CWA	U.S. Clean Water Act
Dark spread	A common metric used to estimate returns over fuel costs of coal-fired EGUs
DOE	U.S. Department of Energy
DMP	Distribution Modernization Plan - on December 21, 2018, DP&L filed a comprehensive grid modernization plan pursuant to the PUCO Order in the ESP
DMR	Distribution modernization rider - designed to allow DP&L to modernize and/or maintain its transmission and distribution infrastructure.
DPL	DPL Inc.
DP&L	The Dayton Power and Light Company, the principal subsidiary of DPL and a public utility which sells, transmits and distributes electricity to residential, commercial, industrial and governmental customers in a 6,000 square mile area of West Central Ohio. DP&L is wholly-owned by DPL
DRO	Distribution Rate Order, the order issued by the PUCO on September 26, 2018 establishing new base distribution rates for DP&L, which became effective October 1, 2018
Dths	Decatherms, unit of heat energy equal to 10 therms. One therm is equal to 100,000 British Thermal Units
Duke Energy	Affiliates of Duke Energy with which DP&L co-owns transmission lines in Ohio (Duke Energy Ohio, Inc.)
Dynegy	Dynegy, Inc., the parent of various subsidiaries that, along with AEP Generation and AES Ohio Generation, co-owns coal-fired EGUs in Ohio
EBIT	Earnings before interest and taxes
EBITDA	Earnings before interest, taxes, depreciation and amortization
EGU	Electric Generating Unit
ELG	Steam Electric Power Effluent Limitations Guidelines
ERAC	Environmental Review Appeals Commission - a commission appointed by the Governor of Ohio to resolve appeals related various Ohio agencies including Ohio EPA, Ohio Department of Agriculture and others
ERISA	The Employee Retirement Income Security Act of 1974
ESP	The Electric Security Plan is a cost-based plan that a utility may file with the PUCO to establish SSO rates pursuant to Ohio law
FASB	Financial Accounting Standards Board
FASC	FASB Accounting Standards Codification
FERC	Federal Energy Regulatory Commission
First and Refunding Mortgage	DP&L’s First and Refunding Mortgage, dated October 1, 1935, as amended, with The Bank of New York Mellon as Trustee
FTR	Financial Transmission Rights
GAAP	Generally Accepted Accounting Principles in the United States of America
Generation Separation	The transfer on October 1, 2017, to AES Ohio Generation of the DP&L-owned generating facilities and related liabilities, excluding those of the Beckjord Facility and Hutchings EGU, pursuant to an asset contribution agreement with a subsidiary that was then merged into AES Ohio Generation
GHG	Greenhouse gas

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GLOSSARY OF TERMS (cont.)
Term	Definition
kV	Kilovolts, 1,000 volts
kWh	Kilowatt hour
LIBOR	London Inter-Bank Offering Rate
Master Trust	DP&L established a Master Trust to hold assets that could be used for the benefit of employees participating in employee benefit plans
MATS	Mercury and Air Toxics Standards
Merger	The merger of DPL and Dolphin Sub, Inc., a wholly-owned subsidiary of AES. On November 28, 2011, DPL became a wholly-owned subsidiary of AES.
Miami Valley Lighting	Miami Valley Lighting, LLC is a wholly-owned subsidiary of DPL established in 1985 to provide street and outdoor lighting services to customers in the Dayton region. Miami Valley Lighting serves businesses, communities and neighborhoods in West Central Ohio with over 70,000 lighting solutions for more than 190 businesses and 180 local governments.
MRO	Market Rate Option, a market-based plan that a utility may file with PUCO to establish SSO rates pursuant to Ohio law
MTM	Mark to Market
MVIC	Miami Valley Insurance Company, a wholly-owned insurance subsidiary of DPL that provides insurance services to DPL and its subsidiaries
MW	Megawatt, a unit of power equal to one million watts
MWh	Megawatt hour
NAAQS	National Ambient Air Quality Standards
NAV	Net asset value
NERC	North American Electric Reliability Corporation
Non-bypassable	Charges that are assessed to all customers regardless of whom the customer selects as their retail electric generation supplier
NOV	Notice of Violation
NOX	Nitrogen Oxide
NPDES	National Pollutant Discharge Elimination System
NSR	New Source Review: a preconstruction permitting program regulating new or significantly modified sources of air pollution
OCI	Other Comprehensive Income
Ohio EPA	Ohio Environmental Protection Agency
OTC	Over the counter
OVEC	Ohio Valley Electric Corporation, an electric generating company in which DP&L has a 4.9% interest
Peaker assets	The generation and related assets for the 586.0 MW Tait combustion turbine and diesel generation facility, the 236.0 MW Montpelier combustion turbine generation facility, the 101.5 MW Yankee combustion turbine generation and solar facility, the 25.0 MW Hutchings combustion turbine generation facility, the 12.0 MW Monument diesel generation facility, and the 12.0 MW Sidney diesel generation facility
PJM	PJM Interconnection, LLC, an RTO
PRP	Potentially Responsible Party
PUCO	Public Utilities Commission of Ohio
RTO	Regional Transmission Organization
SB 221	Ohio Senate Bill 221 is an Ohio electric energy bill that requires all Ohio distribution utilities to file either an ESP or MRO. The law also contains, among other things, annual targets relating to advanced energy portfolio standards, renewable energy, demand reduction and energy efficiency standards.
SEC	Securities and Exchange Commission
SEET	Significantly Excessive Earnings Test
Service Company	AES US Services, LLC, the shared services affiliate providing accounting, finance, and other support services to AES’ U.S. SBU businesses
SIP	A State Implementation Plan is a plan for complying with the federal CAA, administered by the USEPA. The SIP consists of narrative, rules, technical documentation and agreements that an individual state will use to clean up polluted areas.
SO2	Sulfur Dioxide
SSO	Standard Service Offer represents the retail transmission, distribution and generation services offered by a utility through regulated rates, authorized by the PUCO
TCJA	The Tax Cuts and Jobs Act of 2017 signed on December 22, 2017
U.S.	United States of America
USD	U.S. dollar
USEPA	U. S. Environmental Protection Agency
USF	The Universal Service Fund (USF) is a statewide program which provides qualified low-income customers in Ohio with income-based bills and energy efficiency education programs
U.S. SBU	U. S. Strategic Business Unit, AES’ reporting unit covering the businesses in the United States, including DPL

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SUMMARY

This summary highlights information contained elsewhere in this prospectus. This summary may not contain all of the information that may be important to you. You should read this entire prospectus before making a decision to exchange your old bonds for new bonds, including the section entitled “Risk Factors” beginning on page [6] of this prospectus.

Unless otherwise indicated or the context otherwise requires, the terms “DPL,” “we,” “our,” “us,” and “the Company” refer to DPL Inc., including all of its subsidiaries and affiliates, collectively.

Our Company

The Dayton Power and Light Company (“DP&L”) is a public utility incorporated in 1911 under the laws of Ohio. DP&L offers retail standard service offer (“SSO”) electric service to residential, commercial, industrial and governmental customers in a 6,000 square mile area of West Central Ohio and has the exclusive right to provide distribution and transmission services to more than 524,000 customers in that service area. In addition to DP&L’s electric transmission and distribution businesses, DP&L has a 4.9% interest in OVEC, an electric generating company. OVEC has two electric generating stations located in Cheshire, Ohio and Madison, Indiana with a combined generation capacity of 2,109 megawatts (“MW”). DP&L’s share of this generation capacity is 103 MW.

The principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, manufacturing and defense. DP&L’s sales reflect general economic and competitive conditions, seasonal weather patterns of the area and the growth of energy efficiency initiatives, however, DP&L’s distribution revenues have been decoupled from weather and energy efficiency variations beginning January 1, 2019 as a result of the decoupling rider the Public Utilities Commission of Ohio (“PUCO”) approved in the distribution rate order establishing new base distribution rates which became effective October 1, 2018 (the “DRO”).

DP&L strives to achieve stable, long-term growth through efficient operations and strong customer and regulatory relations. More specifically, DP&L’s strategy is to utilize the transmission and distribution assets that transfer electricity at the most efficient cost, and to maintain the highest level of customer service and reliability. DP&L’s total revenue and net income for the nine months ended September 30, 2019 were $570.2 million and $103.7 million, respectively. In addition, as of September 30, 2019, DP&L had total assets of approximately $1.8 billion. DP&L’s business is not dependent on any single customer or group of customers.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs or overcollections of riders.

As of September 30, 2019, DP&L employed 642 people. All of DP&L’s outstanding common stock is owned by DPL. DPL is indirectly owned by AES, which is a global power company with operations in 15 countries. DP&L’s principal executive office is located at 1065 Woodman Drive, Dayton, Ohio, 45432, and DP&L’s telephone number is (937) 224-6000. DP&L’s website address is http://www.dpandl.com. Material contained on DP&L’s website is not part of and is not incorporated by reference in this offering memorandum.

The names “DPL,” “The Dayton Power & Light Company” and various other names contained herein are DPL owned trademarks, service marks or trade names. The name “AES” is an AES owned trademark, service mark or trade name. All other trademarks, trade names or service marks appearing herein are owned by their respective holders.

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The Exchange Offer

Securities Offered	DP&L is offering up to $425,000,000 aggregate principal amount of new First Mortgage Bonds, 3.95% Series due 2049 (the “new bonds”), which will be registered under the Securities Act.
The Exchange Offer	DP&L is offering to issue the new bonds in exchange for a like principal amount of your old bonds. DP&L is offering to issue the new bonds to satisfy its obligations contained in the registration rights agreement entered into when the old bonds were sold in transactions permitted by Rule 144A and Regulation S under the Securities Act and therefore not registered with the SEC. For procedures for tendering, see “The Exchange Offer.”
Tenders, Expiration Date, Withdrawal	The exchange offer will expire at 5:00 P.M. New York City time on , 2019 unless it is extended. If you decide to exchange your old bonds for new bonds, you must acknowledge that you are not engaging in, and do not intend to engage in, a distribution of the new bonds. If you decide to tender your old bonds in the exchange offer, you may withdraw them at any time prior to , 2019. If DP&L decides for any reason not to accept any old bonds for exchange, your old bonds will be returned to you without expense to you promptly after the exchange offer expires. You may only exchange old bonds in denominations of $2,000 and integral multiples of $1,000 in excess thereof.
U.S. Federal Income Tax Consequences	Your exchange of old bonds for new bonds in the exchange offer will not result in any income, gain or loss to you for U.S. federal income tax purposes. See “U.S. Federal Income Tax Consequences of the Exchange Offer.”
Use of Proceeds	DP&L will not receive any proceeds from the issuance of the new bonds in the exchange offer.
Exchange Agent	The Bank of New York Mellon is the exchange agent for the exchange offer.
Failure to Tender Your Old Bonds	If you fail to tender your old bonds in the exchange offer, you will not have any further rights under the registration rights agreement, including any right to require DP&L to register your old bonds or to pay you additional interest or liquidated damages. All untendered old bonds will continue to be subject to the restrictions on transfer set forth in the old bonds and in the indenture. In general, the old bonds may not be offered or sold, unless registered under the Securities Act, except pursuant to an exemption from, or in a transaction not subject to, the Securities Act and applicable state securities laws. DP&L does not currently anticipate that it will register such untendered old bonds under the Securities Act and, following this exchange offer, will be under no obligation to do so.

You will be able to resell the new bonds without registering them with the SEC if you meet the requirements described below.

• Based on interpretations by the SEC’s staff in no-action letters issued to third parties, we believe that new bonds issued in exchange for the old bonds in the exchange offer may be offered for resale, resold or otherwise transferred by you without registering the new bonds under the Securities Act or delivering a prospectus, unless you are a broker-dealer receiving securities for your own account, so long as:

2

• you are not one of DP&L’s “affiliates,” which is defined in Rule 405 of the Securities Act;

• you acquire the new bonds in the ordinary course of your business;

• you do not have any arrangement or understanding with any person to participate in the distribution of the new bonds; and

• you are not engaged in, and do not intend to engage in, a distribution of the new bonds.

If you are an affiliate of DP&L, or you are engaged in, intend to engage in or have any arrangement or understanding with respect to, the distribution of new bonds acquired in the exchange offer, you (1) should not rely on our interpretations of the position of the SEC’s staff and (2) must comply with the registration and prospectus delivery requirements of the Securities Act in connection with any resale transaction.

If you are a broker-dealer and receive new bonds for your own account in the exchange offer and/or in exchange for old bonds that were acquired for your own account as a result of market-making or other trading activities:

• you must represent that you do not have any arrangement or understanding with DP&L or any of its affiliates to distribute the new bonds;

• you must acknowledge that you will deliver a prospectus in connection with any resale of the new bonds you receive from DP&L in the exchange offer; and

• you may use this prospectus, as it may be amended or supplemented from time to time, in connection with the resale of new bonds received in exchange for old bonds acquired by you as a result of market-making or other trading activities.

For a period of 90 days after the expiration of the exchange offer, we will make this prospectus available to any broker-dealer for use in connection with any resale described above.

Summary Description of the Bonds

The terms of the new bonds and the old bonds are identical in all material respects, except that the new bonds have been registered under the Securities Act, and the transfer restrictions and registration rights relating to the old bonds do not apply to the new bonds. The new bonds will represent the same debt as the old bonds and will be governed by the same indenture under which the old bonds were issued.

Issuer	The Dayton Power and Light Company
Bonds Offered	$425.0 million aggregate principal amount of First Mortgage Bonds, 3.95% Series due 2049
Maturity	June 15, 2049
Interest Payment Dates	The new bonds will bear interest at an annual rate equal to 3.95%. Interest on the bonds will be paid on each June 15 and December 15.
Record Dates	The regular record date for each interest payment date for the bonds will be the June 1 or December 1 prior to such interest payment date.
Denominations	Minimum denominations of $2,000 and integral multiples of $1,000 in excess thereof.
Security	The new bonds will be secured by DP&L’s assets that are currently mortgaged pursuant to the existing Mortgage. See “Description of the Bonds-Priority and Security.”
Ranking	The new bonds will be DP&L’s senior obligations and will rank equally in right of payment with DP&L’s other existing or future First Mortgage Bonds issued under the Mortgage. As of September 30, 2019, the carrying value of DP&L’s indebtedness was $574.2 million, with approximately $565.0 million of outstanding long-term indebtedness in the form of First Mortgage Bonds.

3

Optional Redemption	Prior to December 15, 2048 (the date that is six months prior to the maturity date), DP&L may redeem the new bonds at its option, at any time in whole or from time to time in part, on at least 20 days’ prior written notice mailed to the registered holders of the new bonds, at a redemption price, together with accrued and unpaid interest to the date of redemption, equal to the greater of: 100% of their principal amount; or the sum of the present values of the principal amount of the new bonds to be redeemed and the remaining scheduled payments of interest on the new bonds from the redemption date to December 15, 2048 (the date that is six months prior to the maturity date), discounted from their respective scheduled payment dates to the redemption date semiannually, assuming a 360-day year consisting of twelve 30-day months, at a discount rate equal to the Treasury Yield plus25 basis points. On or after December 15, 2048 (the date that is months prior to the maturity date), DP&L may redeem the new bonds at its option, at any time in whole or from time to time in part, on at least 20 days’ prior written notice mailed to the registered holders of the new bonds, at a redemption price equal to 100% of the principal amount of the new bonds being redeemed, together with accrued and unpaid interest to the date of redemption. See “Description of the Bonds-Optional Redemption.”
Dividend Restrictions	The Mortgage does not restrict DP&L’s ability to pay dividends on DP&L’s common stock.
Book-Entry Form	The new bonds will be issued in book-entry form represented by one or more global certificates to be deposited with or on behalf of The Depository Trust Company, or DTC, or its nominee. Transfers of the new bonds will be effected only through the facilities of DTC. Beneficial interests in the global certificates may not be exchanged for certificated bonds except in limited circumstances. See “Description of the Bonds-Book-Entry, Delivery and Form.”
Trustee	The Bank of New York Mellon.
Governing Law	The indenture that governs the bonds offered hereby and the bonds are governed by, and will be construed in accordance with, the laws of the State of New York.
Risk Factors	You should carefully consider all of the information contained in this prospectus before deciding to tender your old bonds in the exchange offer. In particular, we urge you to carefully consider the information set forth under “Risk Factors” herein for a discussion of risks and uncertainties relating to us, our business and the new bonds offered hereby.

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RISK FACTORS

If any of the following risks occur, our business, results of operations or financial condition could be materially adversely affected. You should also read the section captioned “Cautionary Note Regarding Forward-Looking Statements” for a discussion of what types of statements are forward-looking as well as the significance of such statements in the context of this prospectus.

Risks Related to the Exchange Offer

If you choose not to exchange your old bonds in the exchange offer, the transfer restrictions currently applicable to your old bonds will remain in force and the market price of your old bonds could decline.

If you do not exchange your old bonds for new bonds in the exchange offer, then you will continue to be subject to the transfer restrictions on the old bonds as set forth in the offering memorandum distributed in connection with the private offering of the old bonds. In general, the old bonds may not be offered or sold unless they are registered or exempt from registration under the Securities Act and applicable state securities laws. Except as required by the registration rights agreement entered into in connection with the private offering of the old bonds, we do not intend to register resales of the old bonds under the Securities Act. The tender of old bonds under the exchange offer will reduce the principal amount of the old bonds outstanding, which may have an adverse effect upon, and increase the volatility of, the market price of the old bonds due to reduction in liquidity.

You must follow the exchange offer procedures carefully in order to receive the new bonds.

If you do not follow the procedures described in this prospectus, you will not receive any new bonds. If you want to tender your old bonds in exchange for new bonds, you will need to contact a DTC participant to complete the book-entry transfer procedures described under “The Exchange Offer,” prior to the expiration date, and you should allow sufficient time to ensure timely completion of these procedures to ensure delivery. No one is under any obligation to give you notification of defects or irregularities with respect to tenders of old bonds for exchange. For additional information, see the section captioned “The Exchange Offer” in this prospectus.

There are state securities law restrictions on the resale of the new bonds.

In order to comply with the securities laws of certain jurisdictions, the new bonds may not be offered or resold by any holder, unless they have been registered or qualified for sale in such jurisdictions or an exemption from registration or qualification is available and the requirements of such exemption have been satisfied. We currently do not intend to register or qualify the resale of the new bonds in any such jurisdictions. However, generally an exemption is available for sales to registered broker-dealers and certain institutional buyers. Other exemptions under applicable state securities laws also may be available.

Risks Related to the Bonds

The collateral securing the new bonds is illiquid.

All of DP&L’s First Mortgage Bonds, including the new bonds, are secured by the lien of the First Mortgage which constitutes a valid, direct first mortgage lien upon DP&L’s interest in substantially all the property now owned by DP&L, subject to certain exceptions. By its nature, some or all of the collateral may be illiquid and may have no readily ascertainable market value. The liquidity and value of the collateral could be impaired in the future as a result of changing economic conditions, competition, environmental conditions and other factors, including the availability of suitable buyers. Further, any foreclosure proceedings with respect to the collateral are likely to be subject to regulatory approval and no assurance can be given that such approval will be given for any particular purchaser of the collateral. The right of the trustee under the First Mortgage to realize on assets subject to the lien of the First Mortgage upon an event of default under the First Mortgage is likely to be significantly impaired or delayed by applicable bankruptcy law if a bankruptcy case were to be commenced by or against DP&L before the trustee repossessed and disposed of the pledged assets. In the event of a foreclosure, liquidation, bankruptcy or similar proceeding, no assurance can be given that the proceeds from any sale or liquidation of the collateral subject to the lien of the First Mortgage will be sufficient to pay obligations under the First Mortgage Bonds, including the new bonds, in full or at all.

5

Credit rating downgrades could adversely affect the trading price of the new bonds.

The trading price for the new bonds may be affected by DP&L’s credit rating, and DP&L’s credit rating may be affected by the credit rating of DPL and/or AES. Credit ratings are continually revised. There is no assurance that any particular credit ratings will be issued or remain in effect for any given period of time or that such ratings will not be downgraded, suspended or withdrawn entirely by the rating agencies, if, in each rating agency’s judgment, circumstances so warrant. Holders of the new bonds will have no recourse against DP&L in the event of a change in or suspension or withdrawal of such ratings. Any downgrade in DP&L’s credit rating or the credit rating of DPL and/or AES could adversely affect the trading price of the new bonds or the trading markets for the new bonds to the extent trading markets for the new bonds develop.

DPL beneficially owns all of the issued and outstanding equity of DP&L, and may take actions that conflict with your interests.

DPL beneficially owns all of the issued and outstanding equity interests of DP&L. As a result of this equity ownership, DPL has the power to direct votes and the election of DP&L’s Board of Directors, as well as transactions involving a potential change of control of DP&L. The interests of DPL could conflict with your interests as a holder of the new bonds. For example, if DP&L encounters financial difficulties or is unable to pay its debts as they mature, the interests of DPL as the beneficial owner of all of the equity of DP&L might conflict with your interests as a holder of the new bonds. DPL may also have an interest in pursuing acquisitions, divestitures, financings or other transactions that would enhance the value of their equity position in DP&L. Corporate opportunities may arise in the area of potential competitive business activities that may be attractive to DP&L as well as to DPL or its affiliates, including through potential acquisitions by DPL or its affiliates of competing businesses. Any competition could intensify if an affiliate or subsidiary of DPL were to enter into or acquire a business similar to DP&L’s business. Further, DPL has no obligation to provide DP&L, directly or indirectly, with any equity or debt financing.

The collateral securing the new bonds might not be sufficient to satisfy all the obligations secured by the collateral.

DP&L’s obligations under the new bonds are secured by the Mortgage. The Mortgage is also for the benefit of all holders of other series of DP&L’s First Mortgage Bonds. See “Description of the Bonds-Priority and Security.” As of September 30, 2019, DP&L has approximately $565.0 million aggregate principal amount of First Mortgage Bonds outstanding. The value of the Mortgage in the event of a liquidation will depend upon market and economic conditions, the availability of buyers and similar factors. No independent appraisals of any of the mortgaged property have been prepared by DP&L or on its behalf in connection with this offering. Since no appraisals have been performed in connection with this offering, DP&L cannot assure you that the proceeds of any sale of the mortgaged assets following an acceleration of maturity of the new bonds would be sufficient to satisfy amounts due on the new bonds and the other debt secured by the mortgaged assets.

DP&L may choose to redeem the new bonds prior to maturity.

Prior to December 15, 2048 (the date that is six months prior to the maturity date), DP&L may redeem the new bonds at its option, at any time in whole or from time to time in part, on at least 20 days’ prior written notice mailed to the registered holders of the new bonds, at a redemption price, together with accrued and unpaid interest to the date of redemption, equal to the greater of: (1) 100% of the principal amount of the new bonds being redeemed; or (2) the sum of the present values of the principal amount of the new bonds to be redeemed and the remaining scheduled payments of interest on the new bonds from the redemption date to December 15, 2048 (the date that is six months prior to the maturity date), discounted from their respective scheduled payment dates to the redemption date semiannually, assuming a 360-day year consisting of twelve 30-day months, at a discount rate equal to the Treasury Yield plus 25 basis points. On or after    December 15, 2048 (the date that is six months prior to the maturity date), DP&L may redeem the new bonds at its option, at any time in whole or from time to time in part, on at least 20 days’ prior written notice mailed to the registered holders of the new bonds, at a redemption price equal to 100% of the principal amount of the new bonds being redeemed, together with accrued and unpaid interest to the date of redemption. If prevailing interest rates are lower at the time of redemption, holders of the new bonds may not be able to reinvest the redemption proceeds in a comparable security at an interest rate as high as the interest rate on the new bonds being redeemed. DP&L’s redemption right may also adversely affect holders’ ability to sell their new bonds. See “Description of the Bonds-Optional Redemption.”

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Risks Related to the Business

We may not always be able to recover our costs to deliver electricity to our retail customers. The costs we can recover and the return on capital we are permitted to earn for certain aspects of our business are regulated and governed by the laws of Ohio and the rules, policies and procedures of the PUCO.

In Ohio, retail generation rates are not subject to cost-based regulation, while the transmission and distribution businesses are still regulated. Even though rate regulation is premised on full recovery of prudently incurred costs and a reasonable rate of return on invested capital, there can be no assurance that the PUCO will agree that all of our costs have been prudently incurred or are recoverable. On May 1, 2008, SB 221, an Ohio electric energy bill, was adopted that requires all Ohio distribution utilities to file either an Electric Security Plan (“ESP”) or Market Rate Option, and established a significantly excessive earnings test for Ohio public utilities that measures a utility’s earnings to determine whether there have been significantly excessive earnings during a given calendar year. There can be no assurance that the regulatory process in which rates are determined will always result in rates that will produce a full or timely recovery of our costs or permitted rates of return. Accordingly, the revenue DP&L receives may or may not match our expenses at any given time.

Changes in or reinterpretations of, or the unexpected application of, the laws, rules, policies and procedures that set or govern electric rates, permitted rates of return, rate structures, operation of a competitive bid structure to supply retail generation service to SSO customers, reliability initiatives, capital expenditures and investments and the recovery of these and other costs on a full or timely basis through rates, power market prices, and the frequency and timing of rate increases could have a material adverse effect on our results of operations, financial condition and cash flows.

Our increased costs due to renewable energy and energy efficiency requirements may not be fully recoverable in the future.

Ohio law contains annual targets for energy efficiency which began in 2009 and require increasing energy reductions each year compared to a baseline energy usage, up to 22.3% by 2027. Peak demand reduction targets began in 2009 with increases in required percentages each year, up to 7.75% by 2020. The renewable energy standards have increased our costs and are expected to continue to increase (and could materially increase) these costs. DP&L is entitled to recover costs associated with its renewable energy compliance costs, as well as its energy efficiency and demand response programs. If in the future we are unable to timely or fully recover these costs, it could have a material adverse effect on our results of operations, financial condition and cash flows. In addition, if we were found not to be in compliance with these standards, monetary penalties could apply. These penalties are not permitted to be recovered from customers and significant penalties could have a material adverse effect on our results of operations, financial condition and cash flows. The demand reduction and energy efficiency standards by design result in reduced energy and demand that could have a material adverse effect on our results of operations, financial condition and cash flows.

We may be negatively affected by a lack of growth or a decline in the number of customers.

Customer growth is affected by a number of factors outside our control, such as population changes, job and income growth, housing starts, new business formation and the overall level of economic activity. A lack of growth, or a decline, in the number of customers in our service territory could have a material adverse effect on our results of operations, financial condition and cash flows and may cause us to fail to fully realize anticipated benefits from investments and expenditures.

We are subject to numerous environmental laws, rules and regulations that require capital expenditures, increase our cost of operations, and may expose us to environmental liabilities.

We are subject to various federal, state, regional and local environmental protection and health and safety laws and regulations governing, among other things, the remediation of retired generation and other facilities, storage, handling, use, disposal and transportation of coal combustion residuals (“CCR”) and other materials, some of which may be defined as hazardous materials, the emission and discharge of hazardous and other materials into the environment; and the health and safety of our employees. Such laws, rules and regulations tend to become stricter over time, and we could also become subject to additional environmental laws, rules and regulations and other requirements in the future. Environmental laws, rules and regulations also require us to comply with inspections and obtain and comply with a wide variety of environmental licenses, permits, inspections and other governmental authorizations. These laws, rules and regulations often require a lengthy and complex process of obtaining and

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renewing licenses, permits and other governmental authorizations from federal, state and local agencies. If we are not able to timely comply with inspections and obtain, maintain or comply with all environmental laws, rules and regulations, and all licenses, permits and other government authorizations required to operate our business, then our operations could be prevented, delayed or subject to additional costs. A violation of environmental laws, rules, regulations, licenses, permits or other requirements can result in substantial fines, penalties, other sanctions, permit revocation, facility shutdowns, the imposition of stricter environmental standards and controls or other injunctive measures affecting operating assets. In addition, any actual or alleged violation of these laws, rules or regulations, or other requirements may require us to expend significant resources to defend against any such actual or alleged violations. Under certain environmental laws, we could also be held strictly, jointly and severally responsible for costs relating to contamination at our past or present facilities and at third-party waste disposal sites. We could also be held liable for human exposure to hazardous substances or for other environmental damage.

In particular, we are subject to potentially significant remediation expenses, enforcement initiatives, private-party lawsuits and reputational risk associated with CCR. CCR, which consists of bottom ash, fly ash and air pollution control wastes generated at our current and former coal-fired generation plant sites, is currently handled and/or has been handled in the past in the following ways: placement in onsite CCR ponds; disposal and beneficial use in onsite and offsite permitted, engineered landfills; use in various beneficial use applications, including encapsulated uses and structural fill; and use in permitted offsite mine reclamation. CCR currently remains onsite at several of our facilities, including in CCR ponds. The final CCR rule of the U.S. Environmental Protection Agency (“USEPA”), which became effective in October 2015 and is currently subject to litigation and undergoing revisions by the USEPA, regulates CCR as nonhazardous solid waste and establishes national minimum criteria for existing and new CCR landfills, impoundments and ponds, including location restrictions, design and operating criteria, groundwater monitoring, corrective action and closure requirements and post-closure care. On December 16, 2016, President Obama signed the Water Infrastructure Improvements for the Nation (“WIIN”) Act into law, which includes provisions to implement the CCR rule through a state permitting program, or if the state chooses not to participate, a possible federal permit program. The primary enforcement mechanisms for the CCR rule could be actions commenced by the USEPA, states and private lawsuits. Compliance with the CCR rule, amendments to the federal CCR rule, or other federal, state, or foreign rules or programs addressing CCR may require us to incur substantial costs. In addition, CCR, particularly with respect to its beneficial use and regulation as nonhazardous solid waste, has been the subject of interest from environmental non-governmental organizations and the media. Any of the foregoing could have a material adverse effect on our results of operations, financial condition and cash flows.

From time to time we are subject to enforcement and litigation actions for claims of noncompliance with environmental laws, rules and regulations or other environmental requirements. We cannot assure that we will be successful in defending against any claim of noncompliance. Any actual or alleged violation of these laws, rules and regulations and other requirements may require us to expend significant resources to defend against any such actual or alleged violations and expose us to unexpected costs. Our costs and liabilities relating to environmental matters could have a material adverse effect on our results of operations, financial condition and cash flows.

The use of non-derivative and derivative instruments in the normal course of business could result in losses that could negatively impact our results of operations, financial position and cash flows.

From time to time, we use non-derivative and derivative instruments, such as swaps, options, futures and forwards, to manage financial risks. These trades are affected by a range of factors, including fluctuations in interest rates and optimization opportunities. We have attempted to manage our risk exposure by establishing and enforcing risk limits and risk management policies. Despite our efforts, however, these risk limits and risk management policies may not work as planned and fluctuating prices and other events could adversely affect our results of operations, financial condition and cash flows. In the absence of actively quoted market prices and pricing information from external sources, the valuation of these instruments can involve management’s judgment or the use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of some of these contracts. We could also recognize financial losses as a result of volatility in the market values of these contracts, a counterparty failing to perform or the underlying transactions which the instruments are intended to hedge failing to materialize, which could result in a material adverse effect on our results of operations, financial condition and cash flows.

The Dodd-Frank Act contains significant requirements related to derivatives that, among other things, could reduce the cost effectiveness of entering into derivative transactions.

In July 2010, The Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”) was signed into law. The Dodd-Frank Act contains significant requirements relating to derivatives, including, among

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others, a requirement that certain transactions be cleared on exchanges that would necessitate the posting of cash collateral for these transactions. We are considered an end-user under the Dodd-Frank Act and therefore are exempt from most of the collateral and margining requirements. We are required to report our bilateral derivative contracts, unless our counterparty is a major swap participant or has elected to report on our behalf. Even though we qualify for an exception from these requirements, our counterparties that do not qualify for the exception may pass along any increased costs incurred by them through higher prices and reductions in unsecured credit limits or be unable to enter into certain transactions with us. The occurrence of any of these events could have a material adverse effect on our results of operations, financial condition and cash flows.

Our business is sensitive to weather and seasonal variations.

Weather conditions significantly affect the demand for electric power, and accordingly, our business is affected by variations in general weather conditions and unusually severe weather. As a result of these factors, our operating revenues and associated operating expenses are not generated evenly by month during the year. We forecast electric sales on the basis of normal weather, which represents a long-term historical average. In addition, severe or unusual weather, such as hurricanes and ice or snow storms, may cause outages and property damage that may require us to incur additional costs that may not be insured or recoverable from customers. While DP&L is permitted to seek recovery of storm damage costs, if DP&L is unable to fully recover such costs in a timely manner, it could have a material adverse effect on our results of operations, financial condition and cash flows.

Our membership in a regional transmission organization presents risks that could have a material adverse effect on our results of operations, financial condition and cash flows.

On October 1, 2004, in compliance with Ohio law, DP&L turned over control of its transmission functions and fully integrated into PJM, an RTO.

The rules governing the various regional power markets may also change from time to time which could affect our costs and revenues and have a material adverse effect on our results of operations, financial condition and cash flows. We may be required to expand our transmission system according to decisions made by PJM rather than our internal planning process. Various proposals and proceedings before the Federal Energy Regulatory Commission (the “FERC”) may cause transmission rates to change from time to time. In addition, PJM has developed and continues to refine rules associated with the allocation and methodology of assigning costs associated with improved transmission reliability, reduced transmission congestion and firm transmission rights that may have a financial effect on us. We also incur fees and costs to participate in PJM.

SB 221 includes a provision that allows electric utilities to seek and obtain recovery of RTO-related charges. Therefore, non-market-based costs are being recovered from all retail customers through the transmission rider. If in the future, however, we are unable to recover all of these costs in a timely manner this could have a material adverse effect on our results of operations, financial condition and cash flows.

As a member of PJM, DP&L is also subject to certain additional risks including those associated with the allocation of losses caused by unreimbursed defaults of other participants in PJM markets among PJM members and those associated with complaint cases filed against PJM that may seek refunds of revenues previously earned by PJM members including DP&L. These amounts could be significant and have a material adverse effect on our results of operations, financial condition and cash flows.

Costs associated with new transmission projects could have a material adverse effect on our results of operations, financial condition and cash flows.

Annually, PJM performs a review of the capital additions required to provide reliable electric transmission services throughout its territory. PJM traditionally allocated the costs of constructing these facilities to those entities that benefited directly from the additions. Over the last several years, however, some of the costs of constructing new large transmission facilities have been “socialized” across PJM without a direct relationship between the costs assigned to and benefits received by particular PJM members. To date, the additional costs charged to DP&L for new large transmission approved projects have not been material. Over time, as more new transmission projects are constructed and if the allocation method is not changed, the annual costs could become material. DP&L is recovering the Ohio retail jurisdictional share of these allocated costs from its retail customers through the Transmission Cost Recovery Rider. To the extent that any costs in the future are material and we are unable to recover them from our customers, such costs could have a material adverse effect on our results of operations, financial condition and cash flows.

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If we were found not to be in compliance with the mandatory reliability standards, we could be subject to sanctions, including substantial monetary penalties.

As an owner of a bulk power transmission system, DP&L is subject to mandatory reliability standards promulgated by the North American Electric Reliability Corporation (the “NERC’) and enforced by the FERC. The standards are based on the functions that need to be performed to ensure the bulk power system operates reliably and is guided by reliability and market interface principles. In addition, DP&L is subject to Ohio reliability standards and targets. Compliance with reliability standards may subject us to higher operating costs or increased capital expenditures. Although we expect to recover costs and expenditures from customers through regulated rates, there can be no assurance that the PUCO will approve full recovery in a timely manner. If we were found not to be in compliance with the mandatory reliability standards, we could be subject to sanctions, including substantial monetary penalties, which could have a material adverse effect on our results of operations, financial condition and cash flows.

We rely on access to the financial markets. General economic conditions and disruptions in the financial markets could adversely affect our ability to raise capital on favorable terms, or at all, and cause increases in our interest expense.

From time to time we rely on access to the capital and credit markets as a source of liquidity for capital requirements not satisfied by operating cash flows. These capital and credit markets experience volatility and disruption from time to time and the ability of corporations to raise capital can be negatively affected. Disruptions in the capital and credit markets make it harder and more expensive to raise capital. It is possible that our ability to raise capital on favorable terms, or at all, could be adversely affected by future market conditions, and we may be unable to access adequate funding to refinance our debt as it becomes due or finance capital expenditures. The extent of any impact will depend on several factors, including our operating cash flows, financial condition and prospects, the overall supply and demand in the credit markets, our credit ratings, credit capacity, the cost of financing, the financial condition, performance and prospects of other companies in our industry or with similar financial circumstances and other general economic and business conditions. It may also depend on the performance of credit counterparties and financial institutions with which we do business. Access to funds under our existing financing arrangements is also dependent on the ability of our counterparties to meet their financing commitments. Our inability to obtain financing on reasonable terms, or at all, with creditworthy counterparties could adversely affect our results of operations, financial condition and cash flows. If our available funding is limited or we are forced to fund our operations at a higher cost, these conditions may require us to curtail our business activities and increase our cost of funding, both of which could reduce our profitability. See Note 7 of the Notes to our Financial Statements.

Our transmission and distribution system is subject to operational, reliability and capacity risks.

The ongoing reliable performance of our transmission and distribution system is subject to risks due to, among other things, weather damage, intentional or unintentional damage, equipment or process failure, catastrophic events, such as fires and/or explosions, facility outages, labor disputes, accidents or injuries, operator error or inoperability of key infrastructure internal or external to us and events occurring on third party systems that interconnect to and affect our system. The failure of our transmission and distribution system to fully operate and deliver the energy demanded by customers could have a material adverse effect on our results of operations, financial condition and cash flows, and if such failures occur frequently and/or for extended periods of time, could result in adverse regulatory action. In addition, the advent and quick adoption of new products and services that require increased levels of electrical energy cannot be predicted and could result in insufficient transmission and distribution system capacity. Also, as a result of the above risks and other potential risks and hazards associated with transmission and distribution operations, we may from time to time become exposed to significant liabilities for which we may not have adequate insurance coverage. We maintain an amount of insurance protection that we believe is adequate, but there can be no assurance that our insurance will be sufficient or effective under all circumstances and against all hazards or liabilities to which we may be subject. Further, any increased costs or adverse changes in the insurance markets may cause delays or inability in maintaining insurance coverage on terms similar to those presently available to us or at all. A successful claim for which we are not fully insured could have a material adverse effect on our results of operations, financial condition and cash flows.

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Current and future conditions in the economy may adversely affect our customers, suppliers and other counterparties, which may adversely affect our results of operations, financial condition and cash flows.

Our business, results of operations, financial condition and cash flows have been and will continue to be affected by general economic conditions. Slowing economic growth, credit market conditions, fluctuating consumer and business confidence, fluctuating commodity prices, and other challenges currently affecting the general economy, have caused and may continue to cause some of our customers to experience deterioration of their businesses, cash flow shortages, and difficulty obtaining financing. As a result, existing customers may reduce their electricity consumption and may not be able to fulfill their payment obligations to us in a normal, timely fashion. In addition, some existing commercial and industrial customers may discontinue their operations. Sustained downturns, recessions or a sluggish economy generally affect the markets in which we operate and negatively influence our energy operations. A contracting, slow or sluggish economy could reduce the demand for energy in areas in which we are doing business. For example, during economic downturns, our commercial and industrial customers may see a decrease in demand for their products, which in turn may lead to a decrease in the amount of energy they require. Furthermore, projects which may result in potential new customers may be delayed until economic conditions improve. Some of our suppliers, customers, other counterparties and others with whom we transact business may also experience financial difficulties, which may impact their ability to fulfill their obligations to us or result in their declaring bankruptcy or similar insolvency-type proceedings. For example, our counterparties on forward purchase contracts and financial institutions involved in our credit facility may become unable to fulfill their contractual obligations. We may not be able to enter into replacement agreements on terms as favorable as our existing agreements. Reduced demand for our electric services, failure by our customers to timely remit full payment owed to us and supply delays or unavailability could have a material adverse effect on our results of operations, financial condition and cash flows. In particular, the projected economic growth and total employment in DP&L’s service territory are important to the realization of our forecasts for annual energy sales.

The level of our indebtedness, and the security provided for this indebtedness, could adversely affect our financial flexibility, and a material change in market interest rates could adversely affect our results of operations, financial condition and cash flows.

As of September 30, 2019, the carrying value of DP&L’s debt was $574.2 million. Of DP&L’s indebtedness, there was $582.6 million of first mortgage bonds, tax-exempt first mortgage bonds and a term loan outstanding as of September 30, 2019, which are each secured by the pledge of substantially all of the assets of DP&L under the terms of DP&L’s First & Refunding Mortgage. This level of indebtedness and related security could have important consequences, including:

• increasing our vulnerability to general adverse economic and industry conditions;

• requiring us to dedicate a substantial portion of our cash flow from operations to make payments on our indebtedness, thereby reducing the availability of our cash flow to fund other corporate purposes;

• limiting our flexibility in planning for, or reacting to, changes in our business and the industry in which we operate; and

• limiting, along with the financial and other restrictive covenants in our indebtedness, our ability to borrow additional funds, as needed.

If DP&L issues additional debt in the future, we may be subject to the terms of such debt agreements and be required to obtain regulatory approvals. To the extent we increase our leverage, the risks described above would also increase. Further, actual cash requirements in the future may be greater than expected. Accordingly, our cash flows from operations may not be sufficient to repay all of the outstanding debt as it becomes due and, in that event, we may not be able to borrow money, sell assets or otherwise raise funds on acceptable terms, or at all, to refinance our debt as it becomes due. For a further discussion of our outstanding debt obligations, see Note 7 of the Notes to our Financial Statements.

DP&L has variable rate debt that bears interest based on a prevailing rate that is reset based on a market index that can be affected by market demand, supply, market interest rates and other market conditions. We also maintain both cash on deposit and investments in cash equivalents from time to time that could be impacted by interest rate fluctuations. As such, any event which impacts market interest rates could have a material effect on our results of operations, financial condition and cash flows. In addition, rating agencies issue ratings on our credit and our debt that affect our borrowing costs under our financial arrangements and affect our potential pool of investors and funding sources. Credit ratings also govern the collateral provisions of certain of our contracts. If the rating agencies

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were to downgrade our credit ratings further, our borrowing costs would likely further increase, our potential pool of investors and funding resources could be reduced, and we could be required to post additional collateral under select contracts. These events would likely reduce our liquidity and profitability and could have a material adverse effect on our results of operations, financial condition and cash flows.

Economic conditions relating to the asset performance and interest rates of our pension and postemployment benefit plans could materially and adversely impact our results of operations, financial condition and cash flows.

Pension costs are based upon a number of actuarial assumptions, including an expected long-term rate of return on pension plan assets, level of employer contributions, the expected life span of pension plan beneficiaries and the discount rate used to determine the present value of future pension obligations. Any of these assumptions could prove to be wrong, resulting in a shortfall of our pension and postemployment benefit plan assets compared to obligations under our pension and postemployment benefit plans. Further, the performance of the capital markets affects the values of the assets that are held in trust to satisfy future obligations under our pension and postemployment benefit plans. These assets are subject to market fluctuations and will yield uncertain returns, which may fall below our projected return rates. A decline in the market value of the pension and postemployment benefit plan assets will increase the funding requirements under our pension and postemployment benefit plans if the actual asset returns do not recover these declines in value in the foreseeable future. Future pension funding requirements, and the timing of funding payments, may also be subject to changes in legislation. We are responsible for funding any shortfall of our pension and postemployment benefit plans’ assets compared to obligations under the pension and postemployment benefit plans, and a significant increase in our pension liabilities could materially and adversely impact our results of operations, financial condition, and cash flows. We are subject to the Pension Protection Act of 2006, which requires underfunded pension plans to improve their funding ratios within prescribed intervals based on the level of their underfunding. As a result, our required contributions to these plans, at times, have increased and may increase in the future. In addition, our pension and postemployment benefit plan liabilities are sensitive to changes in interest rates. When interest rates decrease, the discounted liabilities increase benefit expense and funding requirements. Further, changes in demographics, including increased numbers of retirements or changes in life expectancy assumptions, may also increase the funding requirements for the obligations related to the pension and other postemployment benefit plans. Declines in market values and increased funding requirements could have a material adverse effect on our results of operations, financial condition and cash flows.

Counterparties providing materials or services may fail to perform their obligations, which could harm our results of operations, financial condition and cash flows.

We enter into transactions with and rely on many counterparties in connection with our business, including for purchased power, for our capital improvements and additions and to provide professional services, such as actuarial calculations, payroll processing and various consulting services. If any of these counterparties fails to perform its obligations to us or becomes unavailable, our business plans may be materially disrupted, we may be forced to discontinue certain operations if a cost-effective alternative is not readily available or we may be forced to enter into alternative arrangements at then-current market prices that may exceed our contractual prices and cause delays. Although our agreements are designed to mitigate the consequences of a potential default by the counterparty, our actual exposure may be greater than relief provided by these mitigation provisions. Any of the foregoing could result in regulatory actions, cost overruns, delays or other losses, any of which (or a combination of which) could have a material adverse effect on our results of operations, financial condition and cash flows.

Further, from time to time our construction program may call for extensive expenditures for capital improvements and additions, including the installation of upgrades, improvements to transmission and distribution facilities, as well as other initiatives. As a result, we may engage contractors and enter into agreements to acquire necessary materials and/or obtain required construction related services. In addition, some contracts may provide for us to assume the risk of price escalation and availability of certain metals and key components. This could force us to enter into alternative arrangements at then-current market prices that may exceed our contractual prices and cause construction delays. It could also subject us to enforcement action by regulatory authorities to the extent that such a contractor failure resulted in a failure by DP&L to comply with requirements or expectations, particularly with regard to the cost of the project. If these events were to occur, we might incur losses or delays in completing construction.

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Accidental improprieties and undetected errors in our internal controls and information reporting could result in the disallowance of cost recovery, noncompliant disclosure or incorrect payment processing.

Our internal controls, accounting policies and practices and internal information systems are designed to enable us to capture and process transactions and information in a timely and accurate manner in compliance with GAAP in the United States of America, laws and regulations, taxation requirements and federal securities laws and regulations in order to, among other things, disclose and report financial and other information in connection with the recovery of our costs and with our reporting requirements under federal securities, tax and other laws and regulations and to properly process payments. We have also implemented corporate governance, internal control and accounting policies and procedures in connection with the Sarbanes-Oxley Act of 2002. Our internal controls and policies have been and continue to be closely monitored by management and our board of directors. While we believe these controls, policies, practices and systems are adequate to verify data integrity, unanticipated and unauthorized actions of employees, temporary lapses in internal controls due to shortfalls in oversight or resource constraints could lead to improprieties and undetected errors that could result in the disallowance of cost recovery, noncompliant disclosure and reporting or incorrect payment processing. The consequences of these events could have a material adverse effect on our results of operations, financial condition and cash flows.

New accounting standards or changes to existing accounting standards could materially affect how we report our results of operations, financial condition and cash flows.

Our financial statements are prepared in accordance with accounting principles generally accepted in the United States of America. The SEC, Financial Accounting Standards Board or other authoritative bodies or governmental entities may issue new pronouncements or new interpretations of existing accounting standards that may require us to change our accounting policies. These changes are beyond our control, can be difficult to predict and could materially affect how we report our results of operations, financial condition and cash flows. We could be required to apply a new or revised standard retroactively, which could adversely affect our financial condition. In addition, in preparing our financial statements, management is required to make estimates and assumptions. Actual results could differ significantly from those estimates.

We are subject to extensive laws and local, state and federal regulation, as well as litigation and other proceedings that could affect our operations and costs.

As an electric utility, DP&L is subject to extensive regulation at both the federal and state level. For example, at the federal level, DP&L is regulated by the FERC and the NERC and, at the state level, by the PUCO. The regulatory power of the PUCO over us is both comprehensive and typical of the traditional form of regulation generally imposed by state public utility commissions. We face the risk of unexpected or adverse regulatory action. Regulatory discretion is reasonably broad in Ohio. DP&L is subject to regulation by the PUCO as to our services and facilities, the valuation of property, the construction, purchase, or lease of electric facilities, the classification of accounts, rates of depreciation, the increase or decrease in retail rates and charges, the issuance of securities and incurrence of debt, the acquisition and sale of some public utility properties or securities and certain other matters. As a result of the Energy Policy Act of 2005 and subsequent legislation affecting the electric utility industry, we have been required to comply with rules and regulations in areas including mandatory reliability standards, cybersecurity, transmission expansion and energy efficiency. Complying with the regulatory environment to which we are subject requires us to expend a significant amount of funds and resources. The failure to comply with this regulatory environment could subject us to substantial financial costs and penalties and changes, either forced or voluntary, in the way we operate our business that could have a material adverse effect on our results of operations, financial condition and cash flows.

We may be subject to material litigation, regulatory proceedings, administrative proceedings, audits, settlements, investigations and claims from time to time which may require us to expend significant funds to address. There can be no assurance that the outcome of these matters will not have a material adverse effect on our business, results of operations, financial condition and cash flows. Asbestos and other regulated substances are, and may continue to be, present at our facilities, and we have been named as a defendant in asbestos litigation. The continued presence of asbestos and other regulated substances at these facilities could result in additional litigation being brought against us, which could have a material adverse effect on our results of operations, financial condition and cash flows.

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Tax legislation initiatives or challenges to our tax positions could adversely affect our operations and financial condition.

We are subject to the tax laws and regulations of the U.S. federal, state and local governments. From time to time, legislative measures may be enacted that could adversely affect our overall tax positions regarding income or other taxes. There can be no assurance that our effective tax rate or tax payments will not be adversely affected by these legislative measures.

For example, the United States federal government recently enacted tax reform that, among other things, reduces U.S. federal corporate income tax rates, imposes limits on tax deductions for interest expense and changes the rules related to capital expenditure cost recovery. There are a number of uncertainties and ambiguities as to the interpretation and application of many of the provisions of the newly enacted tax reform measure. Given the unpredictability of these possible changes and their potential interdependency, it remains difficult to assess the overall effect such tax changes will have on our earnings and cash flow, and the extent to which such changes could adversely impact our results of operations. As the impacts of the new law are determined, and as yet-to-be-released regulations and other guidance interpreting the new law are issued and finalized, our financial results could be materially impacted.

In addition, U.S. federal, state and local tax laws and regulations are extremely complex and subject to varying interpretations. There can be no assurance that our tax positions will be sustained if challenged by relevant tax authorities and if not sustained, there could be a material adverse effect on our results of operations, financial condition and cash flows.

If we are unable to maintain a qualified and properly motivated workforce, it could have a material adverse effect on our results of operations, financial condition and cash flows.

One of the challenges we face is to retain a skilled, efficient and cost-effective workforce while recruiting new talent to replace losses in knowledge and skills due to resignations, terminations or retirements. This undertaking could require us to make additional financial commitments and incur increased costs. If we are unable to successfully attract and retain an appropriately qualified workforce, it could have a material adverse effect on our results of operations, financial condition and cash flows. In addition, we have employee compensation plans that reward the performance of our employees. We seek to ensure that our compensation plans encourage acceptable levels for risk and high performance through pay mix, performance metrics and timing. We may not be able to successfully train new personnel as current workers with significant knowledge and expertise retire. We also may be unable to staff our business with qualified personnel in the event of significant absenteeism related to a pandemic illness. Excessive risk-taking by our employees to achieve performance targets, though mitigated by policies and procedures, could result in events that have a material adverse effect on our results of operations, financial condition and cash flows.

We are subject to collective bargaining agreements that could adversely affect our business, results of operations, financial condition and cash flows.

We are subject to collective bargaining agreements with employees who are members of a union. Over half of our employees are represented by a collective bargaining agreement that expires on October 31, 2020. While we believe that we maintain a satisfactory relationship with our employees, it is possible that labor disruptions affecting some or all of our operations could occur during the period of the collective bargaining agreement or at the expiration of the collective bargaining agreement before a new agreement is negotiated. Work stoppages by, or poor relations or ineffective negotiations with, our employees or other workforce issues could have a material adverse effect on our results of operations, financial condition and cash flows.

Potential security breaches (including cybersecurity breaches) and terrorism risks could adversely affect our businesses.

We operate in a highly regulated industry that requires the continued operation of sophisticated systems and network infrastructure at our generation stations, fuel storage facilities and transmission and distribution facilities. We also use various financial, accounting and other systems in our businesses. These systems and facilities are vulnerable to unauthorized access due to hacking, viruses, other cybersecurity attacks and other causes. In particular, given the importance of energy and the electric grid, there is the possibility that our systems and facilities could be targets of terrorism or acts of war. We have implemented measures to help prevent unauthorized access to our systems and facilities, including network and system monitoring, identification and deployment of secure

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technologies, and certain other measures to comply with mandatory regulatory reliability standards. Pursuant to NERC requirements, we have a robust cybersecurity plan in place and are subject to regular audits by an independent auditor approved by the NERC. We routinely test our systems and facilities against these regulatory requirements in order to measure compliance, assess potential security risks, and identify areas for improvement. In addition, we provide cybersecurity training for our employees and perform exercises designed to raise employee awareness of cyber risks on a regular basis. To date, cyber-attacks on our business and operations have not had a material impact on our operations or financial results. Despite these efforts, if our systems or facilities were to be breached or disabled, we may be unable to recover them in a timely manner to fulfill critical business functions, including the supply of electric services to our customers, and we could experience decreases in revenues and increases in costs that could have a material adverse effect on our results of operations, financial condition and cash flows.

In the course of our business, we also store and use customer, employee, and other personal information and other confidential and sensitive information, including personally identifiable information and personal financial information. If our or our third-party vendors’ systems were to be breached or disabled, sensitive and confidential information and other data could be compromised, which could result in negative publicity, remediation costs and potential litigation, damages, consent orders, injunctions, fines and other relief.

To help mitigate these risks, we maintain insurance coverage against some, but not all, potential losses, including coverage for illegal acts against us. However, insurance may not be adequate to protect us against all costs and liabilities associated with these risks.

Our ownership by AES subjects us to potential risks that are beyond our control.

All of our common stock of is owned by DPL, which is a wholly-owned indirect subsidiary of AES. Due to our relationships with DPL and AES, any adverse developments and announcements concerning them may impair our ability to access the capital markets and to otherwise conduct business. In particular, downgrades in DPL or AES’s credit ratings could likely result in our credit ratings of being downgraded. Our common stock of is pledged to secure certain indebtedness of DPL.

Impairment of long-lived assets would negatively affect our results of operations and net worth.

Long-lived assets are amortized or depreciated over their estimated useful lives. Long-lived assets are evaluated for impairment only when impairment indicators are present. The recoverability assessment of long-lived assets requires making estimates and assumptions to determine fair value, as described above.

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This prospectus includes certain “forward-looking statements” that involve many risks and uncertainties. Forward-looking statements express an expectation or belief and contain a projection, plan or assumption with regard to, among other things, our future revenues, income, expenses or capital structure. Such statements of future events or performance are not guarantees of future performance and involve estimates, assumptions and uncertainties. The words “could,” “may,” “predict,” “anticipate,” “would,” “believe,” “estimate,” “expect,” “forecast,” “project,” “objective,” “intend,” “continue,” “should,” “plan,” and similar expressions, or the negatives thereof, are intended to identify forward-looking statements unless the context requires otherwise. These forward-looking statements are based on management’s present expectations and beliefs about future events. As with any projection or forecast, these statements are inherently susceptible to uncertainty and changes in circumstances. We are under no obligation to, and expressly disclaim any obligation to, update or alter the forward-looking statements whether as a result of such changes, new information, subsequent events or otherwise. If we do update one or more forward-looking statements, no inference should be made that we will make additional updates with respect to those or other forward-looking statements.

Important factors that could cause actual results to differ materially from those reflected in such forward-looking statements and that should be considered in evaluating our outlook include, but are not limited to, the following:

• growth in our service territory and changes in demand and demographic patterns;

• weather-related damage to our electrical system;

• performance of our suppliers;

• transmission and distribution system reliability and capacity;

• regulatory actions and outcomes, including, but not limited to, the review and approval of our rates and charges by the PUCO;

• federal and state legislation and regulations;

• changes in our credit ratings or the credit ratings of AES;

• fluctuations in the value of pension plan assets, fluctuations in pension plan expenses and our ability to fund defined benefit pension plans;

• changes in financial or regulatory accounting policies;

• environmental matters, including costs of compliance with, and liabilities related to, current and future environmental laws and requirements;

• interest rates and the use of interest rate hedges, inflation rates and other costs of capital;

• the availability of capital;

• level of creditworthiness of counterparties to contracts and transactions;

• labor strikes or other workforce factors, including the ability to attract and retain key personnel;

• facility or equipment maintenance, repairs and capital expenditures;

• significant delays or unanticipated cost increases associated with construction projects;

• the availability and cost of funds to finance working capital and capital needs, particularly during periods when the time lag between incurring costs and recovery is long and the costs are material;

• local economic conditions;

• costs and effects of legal and administrative proceedings, audits, settlements, investigations and claims and the ultimate disposition of litigation;

• industry restructuring, deregulation and competition;

• issues related to our participation in PJM, including the cost associated with membership, allocation of costs, costs associated with transmission expansion, the recovery of costs incurred and the risk of default of other PJM participants;

• changes in tax laws and the effects of our tax strategies;

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• product development, technology changes and changes in prices of products and technologies;

• cyberattacks and information security breaches;

• the use of derivative contracts;

• catastrophic events such as fires, explosions, terrorist acts, acts of war, pandemic events, or natural disasters such as floods, earthquakes, tornadoes, severe winds, ice or snowstorms, droughts or other similar occurrences; and

• the risks and other factors discussed elsewhere in this prospectus.

All such factors are difficult to predict, contain uncertainties that may materially affect actual results, and many are beyond our control. See “Risk Factors” for a more detailed discussion of the foregoing and certain other factors that could cause actual results to differ materially from those reflected in such forward-looking statements and that should be considered in evaluating our outlook.

USE OF PROCEEDS

We will not receive any cash proceeds from the issuance of the new bonds. The new bonds will be exchanged for old bonds as described in this prospectus upon our receipt of old bonds. We will cancel all of the old bonds surrendered in exchange for the new bonds.

CAPITALIZATION

The following table sets forth a summary of DP&L’s capitalization as of September 30, 2019:

This table should be read in conjunction with “Management’s Discussion and Analysis of Results of Operations and Financial Condition” and the financial statements and related notes included herein.

	As of September 30, 2019
	(in millions)
Short-term and current portion of long-term debt	$	199.6
Long-term debt:
3.95% first mortgage bonds due 2049	425.0
Tax-exempt first mortgage bonds - rates from 2.97% - 3.07% (a) due 2020	140.0
4.20% U.S. Government note due 2061	17.6
Unamortized deferred financing costs	(5.7		)
Unamortized debt discounts and premiums, net	(2.7		)
Total long-term debt	574.2
Common shareholder's equity:
1,500 shares authorized; 1 share issued and outstanding at September 30, 2019	0.4
Other paid-in capital	621.9
Accumulated other comprehensive loss	(34.2		)
Accumulated deficit	(128.3		)
Total common shareholder's equity	459.8
Total capitalization	$	1,233.6

(a) Range of interest rates for the nine months ended September 30, 2019.

(b) Note payable to related party.

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SELECTED FINANCIAL AND OTHER DATA

The table below presents our selected historical financial and other data for the periods presented, which should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our financial statements and related notes included herein.

The selected historical statement of operations data and balance sheet data for each of the years ended December 31, 2018, 2017 and 2016 are derived from our audited financial statements included herein. The selected historical statement of operations data and balance sheet data for each of the nine months ended September 30, 2019 and 2018 are derived from our unaudited condensed financial statements included herein. The unaudited condensed financial statements have been prepared on the same basis as the audited financial statements and, in the opinion of management, include all adjustments, consisting only of normal recurring adjustments, necessary to present fairly the data for the period. Our historical results for any prior period are not necessarily indicative of results to be expected for any future period.

DP&L
	Years ended December 31,								Nine months ended September 30,
$ in millions except as indicated	2018		2017			2016			2019		2018
Statements of Operations Data
Revenues	$	738.7	$	720.0		$	808.0		$	570.2	$	563.5
Operating income	$	135.1	$	122.1		$	169.0		$	128.6	$	96.9
Income from continuing operations	$	104.4	$	88.5		$	143.6		$	108.8	$	73.9
Loss from discontinued operations, net of tax	$	—	$	(40.4	)	$	(870.3	)	$	—	$	—
Net income / (loss)	$	86.7	$	17.0		$	(772.7	)	$	103.7	$	61.9
Capital expenditures	$	93.1	$	101.7		$	128.3		$	121.1	$	65.0
Other operating data
Total electric sales (millions of kWh)	15,194		14,401			15,008			11,152		11,551
Balance Sheet Data (end of period):
Total assets	$	1,819.6	$	1,695.9		$	2,035.1		$	1,779.4	$	1,678.4
Long-term debt (a)	$	581.5	$	642.0		$	731.5		$	434.6	$	582.1
Total common shareholder's equity	$	445.3	$	330.7		$	362.3		$	459.8	$	431.0

(a)    Excluded from this line are the current maturities of long-term debt.

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

RESULTS OF OPERATIONS AND FINANCIAL CONDITION

The following discussion and analysis should be read in conjunction with the financial statements and notes thereto included elsewhere in this prospectus. The following discussion contains forward-looking statements. Our actual results may differ materially from the results suggested by these forward-looking statements. Please see “Cautionary Note Regarding Forward Looking Statements” and “Risk Factors” in this prospectus.

Throughout this discussion and analysis, the terms “we”, “us”, “our” and “ours” are used to refer to both DPL and DP&L, respectively and altogether, unless the context indicates otherwise. Discussions or areas of this section that apply only to DPL or DP&L will clearly be noted.

Business Overview

DP&L is a public utility incorporated in 1911 under the laws of Ohio. DP&L offers retail SSO electric service to residential, commercial, industrial and governmental customers in a 6,000 square mile area of West Central Ohio and has the exclusive right to provide distribution and transmission services to more than 524,000 customers in that service area. In addition to DP&L’s electric transmission and distribution businesses, DP&L has a 4.9% interest in OVEC, an electric generating company. OVEC has two electric generating stations located in Cheshire, Ohio and Madison, Indiana with a combined generation capacity of 2,109 MW. DP&L’s share of this generation capacity is 103 MW.

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The principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, manufacturing and defense. DP&L’s sales reflect general economic and competitive conditions, seasonal weather patterns of the area and the growth of energy efficiency initiatives, however, DP&L’s distribution revenues have been decoupled from weather and energy efficiency variations beginning January 1, 2019 as a result of the decoupling rider the PUCO approved in the DRO.

DP&L strives to achieve stable, long-term growth through efficient operations and strong customer and regulatory relations. More specifically, DP&L’s strategy is to utilize the transmission and distribution assets that transfer electricity at the most efficient cost, and to maintain the highest level of customer service and reliability. DP&L’s total revenue and net income for the nine months ended September 30, 2019 were $570.2 million and $103.7 million, respectively. In addition, as of September 30, 2019, DP&L had total assets of approximately $1.8 billion. DP&L’s business is not dependent on any single customer or group of customers.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs or overcollections of riders.

Additional information relating to our risks is contained in “Risk Factors” elsewhere in this prospectus.

The following discussion should be read in conjunction with the accompanying financial statements and related notes included elsewhere in this prospectus.

Financial Overview

The results of operations for DP&L are discussed in more detail in the following pages.

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RESULTS OF OPERATIONS HIGHLIGHTS – DP&L

	Three months ended						Nine months ended
	September 30,						September 30,
$ in millions	2019			2018			2019			2018
Revenues:
Retail	$	174.3		$	181.0		$	518.7		$	500.7
Wholesale	4.4			4.9			12.8			24.6
RTO ancillary	11.0			10.8			32.8			32.4
Capacity revenues	1.1			2.0			5.0			5.8
Miscellaneous revenues	0.3			—			0.9			—
Total revenues	191.1			198.7			570.2			563.5
Operating costs and expenses
Net fuel cost	0.6			0.1			2.0			1.7
Purchased power:
Purchased power	60.4			67.7			175.7			186.7
RTO charges	5.5			15.3			17.6			46.8
RTO capacity charges	—			—			—			2.2
Net purchased power cost	65.9			83.0			193.3			235.7
Operation and maintenance	42.2			33.8			135.2			105.9
Depreciation and amortization	17.4			19.1			52.9			56.5
Taxes other than income taxes	20.8			19.0			58.2			54.3
Loss / (gain) on asset disposal	(0.1		)	—			—			0.1
Loss on disposal of business	—			—			—			12.4
Total operating costs and expenses	146.8			155.0			441.6			466.6
Operating income	44.3			43.7			128.6			96.9
Other income / (expense), net:
Interest expense	(6.1		)	(5.8		)	(19.9		)	(20.5		)
Loss on early extinguishment of debt	—			—			—			(0.6		)
Other income / (expense)	(0.5		)	(0.4		)	0.1			(1.9		)
Total other expense, net	(6.6		)	(6.2		)	(19.8		)	(23.0		)
Income before income tax (a)	$	37.7		$	37.5		$	108.8		$	73.9

(a) For purposes of discussing operating results, we present and discuss Income before income tax. This format is useful to investors because it allows analysis and comparability of operating trends and includes the same information used by management to make decisions regarding our financial performance.

DP&L – Revenues

Retail customers, especially residential and commercial customers, consume more electricity during warmer and colder weather than they do during mild temperatures. Therefore, our retail sales volume is impacted by the number of heating and cooling degree-days occurring during a year. Cooling degree-days typically have a more significant impact than heating degree-days since some residential customers do not use electricity to heat their homes. Because of the impact of the decoupling rider (effective January 1, 2019) weather has a minimal impact on our net operating results.

We sell our share of the generation from OVEC into the wholesale market which covers a multi-state area and settles on an hourly basis throughout the year. Factors impacting our wholesale sales volume each hour of the year include wholesale market prices; retail demand throughout the entire wholesale market area; and availability of OVEC generating plants to sell into the wholesale market.

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DP&L's electric sales and billed customers were as follows:

ELECTRIC SALES AND CUSTOMERS (a)
	Three months ended		Nine months ended
	September 30,		September 30,
	2019	2018	2019	2018
Retail electric sales (b)	3,858	3,858	10,731	10,943
Wholesale electric sales (c)	151	156	421	608
Total electric sales	4,009	4,014	11,152	11,551
Billed electric customers (end of period)			523,915	523,535

(a) Electric sales are presented in millions of kWh.

(b) DP&L retail electric sales represent the total transmission and distribution retail sales for the periods presented. SSO sales were 1,037 kWh and 2,972 kWh for the three and nine months ended September 30, 2019, respectively, and 1,056 kWh and 2,995 kWh for the three and nine months ended September 30, 2018, respectively.

(c) Included within DP&L wholesale electric sales are DP&L's 4.9% share of the generation output of OVEC.

During the three months ended September 30, 2019, revenue decreased $7.6 million to $191.1 million compared to $198.7 million in the same period of the prior year, and, during the nine months ended September 30, 2019, revenue increased $6.7 million to $570.2 million compared to $563.5 million in the same period of the prior year. These changes were primarily the result of changes in the components of revenue shown below:

	Three months ended			Nine months ended
	September 30,			September 30,
$ in millions	2019 vs. 2018			2019 vs. 2018
Retail
Rate
Increase in energy efficiency and USF revenue rate riders	$	9.7		$	30.1
Increase in base distribution rates due to the DRO	6.3			21.0
Increase due to the DIR, which was effective with the DRO	5.6			16.7
Decrease in the TCRR due to lower transmission costs and the impact of DP&L passing back the benefits of the PJM Transmission Enhancement Settlement to customers	(12.3		)	(27.3		)
Decrease due to energy efficiency lost revenues recorded in the prior year	(5.0		)	(16.7		)
Other	(2.5		)	9.5
Net change in retail rate	1.8			33.3
Volume
Decrease in volume is primarily due to demand in the prior year. The decoupling rider approved in the DRO became effective January 1, 2019 and is designed to eliminate the impacts of weather and demand on DP&L's residential and commercial customers resulting in less of a demand impact in the current year.	(8.2		)	(15.6		)
Other miscellaneous	(0.3		)	0.3
Total retail change	(6.7		)	18.0
Wholesale
Decrease in volumes due to no longer serving the load of certain other parties through their competitive bid process and lower wholesale prices	(0.5		)	(11.8		)
RTO ancillary and capacity revenues
RTO ancillary and capacity revenues	(0.7		)	(0.4		)
Other
Miscellaneous revenues	0.3			0.9
Net change in revenues	$	(7.6	)	$	6.7

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DP&L – Net Purchased Power

During the three months ended September 30, 2019, net purchased power decreased $17.1 million to $65.9 million compared to $83.0 million in the same period of the prior year, and, during the nine months ended September 30, 2019, net purchased power decreased $42.4 million to $193.3 million compared to $235.7 million in the same period of the prior year. These changes were primarily the result of changes in the cost of purchased power shown below.

	Three months ended			Nine months ended
	September 30,			September 30,
$ in millions	2019 vs. 2018			2019 vs. 2018
Net purchased power
Purchased power
Rate
Increase / (decrease) due to pricing in the competitive bid process	$	(1.1	)	$	2.0
Volume
Lower purchases in the nine months ended September 30, 2019 as DP&L stopped purchasing power to serve the load of certain other parties through their competitive bid process after May of 2018	(6.2		)	(13.0		)
Total purchased power change	(7.3		)	(11.0		)
RTO charges
Decrease due to lower transmission and congestion charges, including a decrease due to benefits of the PJM Transmission Enhancement Settlement. RTO charges are incurred by DP&L as a member of PJM and primarily include transmission charges within our network, which are incurred and charged to customers in the transmission rider	(9.8		)	(29.2		)
RTO capacity charges
Decrease due to capacity costs at OVEC	—			(2.2		)
Net change in purchased power	$	(17.1	)	$	(42.4	)

DP&L – Operation and Maintenance

During the three and nine months ended September 30, 2019, Operation and Maintenance expense increased $8.4 million and $29.3 million, respectively, compared to the same periods in the prior year. The main drivers of these changes are as follows:

	Three months ended			Nine months ended
	September 30,			September 30,
$ in millions	2019 vs. 2018			2019 vs. 2018
Increase in alternative energy and energy efficiency programs (a)	$	7.4		$	20.0
Increase in uncollectible expenses for the low-income payment program, which is funded by the USF revenue rate rider (a)	3.1			9.3
Increase in costs charged from the Service Company for services provided	2.9			5.3
Decrease due to prior year write-off of previously deferred rate case costs	—			(5.3		)
Decrease in amortization of previously deferred regulatory costs, including rate case costs, certain transmission costs, and various costs collected under the regulatory compliance rider (a)	(2.0		)	(1.7		)
Other, net	(3.0		)	1.7
Net change in operation and maintenance expense	$	8.4		$	29.3

(a)    There is a corresponding offset in Revenues associated with these programs.

DP&L – Depreciation and Amortization

During the three and nine months ended September 30, 2019, Depreciation and amortization decreased $1.7 million and $3.6 million, respectively, compared to the same periods in the prior year. The decrease was primarily due to lower software amortization in 2019.

DP&L – Taxes Other Than Income Taxes

During the three and nine months ended September 30, 2019, Taxes other than income taxes increased $1.8 million and $3.9 million, respectively, compared to the same periods in the prior year. The increase for the nine months ended September 30, 2019 was primarily the result of a favorable adjustment made in 2018 for 2017 Ohio property taxes to reflect actual payments.

DP&L – Loss on Disposal of Business

During the nine months ended September 30, 2018, DP&L recorded a loss on disposal of business of $12.4 million due to the loss on the transfer of business interests in the Beckjord facility.

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DP&L – Income Tax Expense / (Benefit)

Income tax expense of $6.3 million during the three months ended September 30, 2018 changed to a benefit of $7.2 million during the three months ended September 30, 2019 primarily due to the impact of the September 26, 2019 PUCO order, which finalized the amount of excess deferred tax balances allocable to DP&L’s utility customers.

During the nine months ended September 30, 2019, Income tax expense decreased $6.9 million, compared to the same period in the prior year primarily due to the impact of the September 26, 2019 PUCO order, which finalized the amount of excess deferred tax balances allocable to DP&L’s utility customers, partially offset by higher pre-tax income in the current year as compared to the prior year.

KEY TRENDS AND UNCERTAINTIES

Following the issuance of the DRO in September 2018 and the resulting changes to the decoupling rider, we expect that our financial results will be less driven by retail demand and weather but will be impacted by customer growth within our service territory. In addition, DP&L's financial results are likely to be driven by other factors including, but not limited to:

• regulatory outcomes;

• the passage of new legislation, implementation of regulations or other changes in regulation; and

• timely recovery of transmission and distribution expenditures.

Regulatory Environment

DP&L’s facilities and operations are subject to a wide range of regulations and laws by federal, state and local authorities. As well as imposing continuing compliance obligations, these laws and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. In the normal course of business, we have investigatory and remedial activities underway at these facilities and operations in an effort to comply, or to determine compliance, with such regulations. We record liabilities for losses that are probable and can be reasonably estimated. In addition to matters discussed or updated herein, our 2018 Form 10-K and Forms 10-Q previously filed with the SEC during 2019 describe other regulatory matters which have not materially changed since those filings.

Ohio Regulatory Proceedings

DMR

On October 20, 2017, the PUCO approved DP&L’s 2017 ESP.  On January 7, 2019, the Ohio Consumers' Counsel appealed to the Supreme Court of Ohio the 2017 ESP with respect to the bypassability of the Reconciliation Rider and the exclusion of the DMR from the SEET. That proceeding has been stayed pending an appeal in a related case involving another utility.

Pursuant to the 2017 ESP, on January 22, 2019, DP&L filed a request with the PUCO for a two-year extension of its DMR through October 2022, in the proposed amount of $199.0 million for each of the two additional years. The extension request was set at a level expected to reduce debt obligations at both DP&L and DPL and to position DP&L to make capital expenditures to maintain and modernize its electric grid. DP&L’s DMP investments are contingent upon the PUCO approving the two-year extension of its DMR.

A rehearing process in DP&L's 2017 ESP case, including the DMR, remains pending. On August 1, 2019, DP&L filed a supplemental brief with the PUCO focused on the applicability of a recent court decision involving another Ohio utility’s DMR which is similar to, but not identical to, DP&L’s DMR.

Ohio House Bill 6

On July 23, 2019, the Governor of Ohio signed Ohio House Bill 6, which, among other things, does the following:

• beginning January 1, 2020, replaces DP&L’s non-bypassable Reconciliation Rider, permitting DP&L to defer, recover or credit the net proceeds from selling energy and capacity received as part of DP&L’s interest in OVEC and its OVEC-related costs through 2023, with a non-bypassable recovery mechanism for recovery of prudently incurred OVEC costs through 2030;

• eliminates the annual energy efficiency targets for Ohio utilities after 2020; and

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• allows Ohio utilities to construct customer-sited renewable generation for mercantile customers or groups of mercantile customers, the costs of which may only be recovered from those customers.

Regulatory impact of tax reform

On September 26, 2019 the PUCO approved a unanimous stipulation agreeing to return a total of $65.1 million, $83.2 million when including taxes associated with the refunds, to distribution customers.

See Note 3 – Regulatory Matters of Notes to DP&L's Condensed Financial Statements for further information regarding regulatory matters.

United States Tax Law Reform

Considering the significant changes to the U.S. tax system enacted in 2017, the U.S. Treasury Department and Internal Revenue Service have issued numerous regulations. While certain regulations are now final, there are many regulations that are proposed and still others anticipated to be issued in proposed form. The final version of any regulations may vary from the proposed form. When final, these regulations may materially impact our effective tax rate. Certain of the proposed regulations, when final, may have retroactive effect to January 1, 2018 or January 1, 2019.

Environmental Matters

In addition to imposing continuing compliance obligations, these laws and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. In the normal course of business, we have investigatory and remedial activities underway at our facilities to comply, or to determine compliance, with such regulations. We record liabilities for loss contingencies related to environmental matters when a loss is probable of occurring and can be reasonably estimated in accordance with the provisions of GAAP. Accordingly, we have immaterial accruals for loss contingencies for environmental matters. We also have several environmental matters for which we have not accrued loss contingencies because the risk of loss is not probable, or a loss cannot be reasonably estimated. We evaluate the potential liability related to environmental matters quarterly and may revise our estimates. Such revisions in the estimates of the potential liabilities could have a material adverse effect on our results of operations, financial condition and cash flows. We refer to the discussion in “Item 1. Business - Environmental Matters” in our 2018 Form 10-K for a discussion of certain recent developments in environmental laws and regulations.

We have several pending environmental matters. Some of these matters could have a material adverse effect on our results of operations, financial condition and cash flows.

Clean Water Act Regulation of Water Discharge

On January 7, 2013, the Ohio EPA issued a final NPDES permit to the Stuart Station which included a compliance schedule for performing a study to justify an alternate thermal limitation or take undefined measures to meet certain temperature limits. On February 1, 2013, DP&L appealed various aspects of the final permit to the ERAC. On August 8, 2019, the ERAC dismissed the appeal in response to a Joint Motion to Dismiss.

Notice of Potential Liability for Third Party Disposal Site

On October 16, 2019, DP&L received a special notice that USEPA considers DP&L, along with other parties, to be a PRP for the clean-up of hazardous substances at a third-party landfill known as the Tremont City Barrel Site, located near Dayton, Ohio. While DP&L is currently unable to predict the outcome of this matter, if DP&L were required to contribute to the clean-up of the site, it could have a material adverse effect on our business, financial condition or results of operations.

Regulation of Waste Disposal

The USEPA's final CCR rule became effective in October 2015. Generally, the rule regulates CCR as nonhazardous solid waste and establishes national minimum criteria for existing and new CCR landfills and existing and new CCR ash ponds, including location restrictions, design and operating criteria, groundwater monitoring, corrective action and closure requirements and post-closure care. On December 16, 2016, President Obama signed into law the Water Infrastructure Improvements for the Nation Act ("WIIN Act"), which includes provisions to implement the CCR rule through a state permitting program, or if the state chooses not to participate, a possible federal permit program. The USEPA has indicated that they will implement a phased approach to amending the CCR rule. In July 2018, the USEPA published final CCR rule amendments (Phase One, Part One) in the Federal Register. In August 2018, the D.C. Circuit Court issued a decision in certain CCR litigation matters, which may result in additional revisions to the

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CCR rule. In October 2018, some environmental groups filed a petition for review challenging the USEPA's final CCR rule amendments (Phase One, Part One) which have since been remanded without vacatur to the USEPA. On August 14, 2019, the USEPA published amendments to the CCR rule relating to the CCR rule’s criteria for determining beneficial use and the regulation of CCR piles, among other revisions. On November 4, 2019, the USEPA signed additional amendments to the CCR Rule titled “A Holistic Approach To Closure Part A: Deadline To Initiate Closure.” The October 2015 CCR rule, current or proposed amendments to the October 2015 CCR rule, the results of groundwater monitoring data or the outcome of CCR-related litigation could have a material impact on our business, financial condition and results of operations.

CAPITAL RESOURCES AND LIQUIDITY

DP&L had unrestricted cash and cash equivalents of $14.4 million at September 30, 2019. At that date, DP&L had no short-term investments. DP&L had aggregate principal amounts of long-term debt outstanding of $582.6 million.

Approximately $139.6 million of DP&L's long-term debt matures within twelve months of the balance sheet date. From time to time, we may elect to repurchase our outstanding debt through cash purchases, privately negotiated transactions or otherwise when management believes such repurchases are favorable to make. The amounts involved in any such repurchases may be material.

We depend on timely and continued access to capital markets to manage our liquidity needs. The inability to raise capital on favorable terms, to refinance existing indebtedness or to fund operations and other commitments during times of political or economic uncertainty could have a material adverse effect on our results of operations, financial condition and cash flows. In addition, changes in the timing of tariff increases or delays in regulatory determinations could affect the cash flows and results of operations of our businesses.

CASH FLOWS

Cash Flow Analysis - DP&L

The following table summarizes the cash flows of DP&L:

DP&L	Nine months ended September 30,
$ in millions	2019			2018
Net cash provided by operating activities	$	138.9		$	113.2
Net cash used in investing activities	(124.6		)	(69.0		)
Net cash used in financing activities	(48.5		)	(37.1		)
Net change	(34.2		)	7.1
Balance at beginning of period	66.2			5.6
Cash, cash equivalents, and restricted cash at end of period	$	32.0		$	12.7

DP&L – Change in cash flows from operating activities

	Nine months ended September 30,						$ change
$ in millions	2019			2018			2019 vs. 2018
Net income	$	103.7		$	61.9		$	41.8
Depreciation and amortization	52.9			56.5			(3.6		)
Deferred income taxes	(17.2		)	(7.5		)	(9.7		)
Other adjustments to Net income	—			13.0			(13.0		)
Net income, adjusted for non-cash items	139.4			123.9			15.5
Net change in operating assets and liabilities	(0.5		)	(10.7		)	10.2
Net cash provided by operating activities	$	138.9		$	113.2		$	25.7

The net change in operating assets and liabilities during the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 was driven by the following:

$ in millions	$ Change
Increase from accounts receivable primarily due to higher rates following the DRO	$	22.2
Decrease from accrued taxes primarily due to higher current portion of income tax expense in prior year compared to the current year	(6.9		)
Other	(5.1		)
Net increase in cash from changes in operating assets and liabilities	$	10.2

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DP&L – Cash flows from investing activities

Net cash used in investing activities was $(124.6) million for the nine months ended September 30, 2019 compared to $(69.0) million for the nine months ended September 30, 2018. The investing activity for the nine months ended September 30, 2019 primarily represents capital expenditures of $121.1 million, which increased from the prior year mainly due to significant storm restoration efforts in the third quarter of 2019. The investing activity for the nine months ended September 30, 2018 is primarily capital expenditures of $65.0 million and a payment on the disposal of Beckjord of $14.5 million. This was partially offset by proceeds of $10.6 million related to the June transmission swap with Duke and AEP.

DP&L – Cash flows from financing activities

Net cash used in financing activities was $(48.5) million for the nine months ended September 30, 2019 compared to $(37.1) million from financing activities for the nine months ended September 30, 2018. The financing activity for the nine months ended September 30, 2019 is primarily due to returns of capital paid to parent of $90.0 million, debt repayments, including early payment premium, of $436.1 million, and payments of deferred financing costs of $4.6 million. This was partially offset by debt issuances, net of discount, of $422.3 million. The financing activity for the nine months ended September 30, 2018 is primarily related to $63.3 million of debt repayments and returns of capital paid to parent of $43.8 million. This was partially offset by an $80.0 million capital contribution from DPL.

LIQUIDITY

We expect our existing sources of liquidity to remain sufficient to meet our anticipated operating needs. Our business is capital intensive, requiring significant resources to fund operating expenses, construction expenditures, scheduled debt maturities, debt carrying costs and, dividend payments to DPL. In 2019 and subsequent years, we expect to satisfy these requirements with a combination of cash from operations and funds from debt financing as internal liquidity needs and market conditions warrant. We also expect that the borrowing capacity under bank credit facilities will continue to be available to us to manage working capital requirements during these periods.

At September 30, 2019, DP&L has access to the following revolving credit facilities:

$ in millions	Type	Maturity	Commitment		Amounts available as of September 30, 2019
DP&L	Revolving	June 2024	$	175.0	$	113.9

DP&L has an unsecured revolving credit agreement with a syndicated bank group with a borrowing limit of $175.0 million and a $75.0 million letter of credit sublimit, as well as a feature that provides DP&L the ability to increase the size of the facility by an additional $100.0 million. This facility expires in June 2024. At September 30, 2019, there was one letter of credit in the amount of $1.1 million outstanding under this facility, and $60.0 million in borrowings, with the remaining $113.9 million available to DP&L. Fees associated with this letter of credit facility were not material during the nine months ended September 30, 2019 or 2018.

Capital Requirements

Planned construction additions for 2019 relate primarily to new investments in and upgrades to DP&L’s transmission and distribution system. Capital projects are subject to continuing review and are revised considering changes in financial and economic conditions, load forecasts, legislative and regulatory developments and changing environmental requirements, among other factors.

DP&L is projecting to spend an estimated $649.0 million in capital projects for the period 2019 through 2021. These amounts include expected spending under DP&L's Distribution Modernization Plan filed with the PUCO in December 2018. On January 22, 2019, DP&L filed a request with the PUCO for a two-year extension of its DMR through October 2022, in the proposed amount of $199.0 million for each of the two additional years. The request was made pursuant to the PUCO’s October 20, 2017 ESP order, which approved the DMR and had the option for DP&L to file for a two-year extension. The extension request was set at a level expected to reduce debt obligations at both DP&L and DPL and to position DP&L to make capital expenditures to maintain and modernize its electric grid. To that end, DP&L’s DMP investments are contingent upon the PUCO approving the two-year extension of its DMR.

DP&L is subject to the mandatory reliability standards of NERC and Reliability First Corporation (RFC), one of the eight NERC regions, of which DP&L is a member. DP&L anticipates spending approximately $221.0 million within

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the next five years to reinforce its 138-kV system to comply with NERC standards. Our ability to complete capital projects and the reliability of future service will be affected by our financial condition, the availability of internal funds and the reasonable cost of external funds. We expect to finance our construction additions with a combination of cash on hand, short-term financing, long-term debt and cash flows from operations.

Long-term debt covenants

For information regarding our long-term debt covenants, see Note 6 – Long-term Debt of Notes to DP&L's Condensed Financial Statements.

Debt and Credit Ratings

The following table presents, as of the filing of this report, the debt ratings and outlook for DP&L, along with the effective or affirmed date of each rating.

	DP&L	Outlook	Effective or Affirmed
Fitch Ratings	A- (a)	Stable	October 2018
Moody's Investors Service, Inc.	A3 (a)	Stable	June 2019
Standard & Poor's Financial Services LLC	BBB+ (a)	Negative	October 2019

(a)    Rating relates to DP&L’s Senior secured debt.

The following table presents, as of the filing of this report, the credit ratings (issuer/corporate rating) and outlook for DP&L, along with the effective or affirmed date of each rating.

	DP&L	Outlook	Effective or Affirmed
Fitch Ratings	BBB	Stable	October 2018
Moody's Investors Service, Inc.	Baa2	Stable	June 2019
Standard & Poor's Financial Services LLC	BBB-	Negative	October 2019

If the rating agencies were to reduce our debt or credit ratings, our borrowing costs may increase, our potential pool of investors and funding resources may be reduced, and we may be required to post additional collateral under selected contracts. These events could have an adverse effect on our results of operations, financial condition and cash flows. In addition, any such reduction in our debt or credit ratings may adversely affect the trading price of our outstanding debt securities.

Off-Balance Sheet Arrangements

For information on guarantees, commercial commitments, and contractual obligations, see Note 10 – Contractual Obligations, Commercial Commitments and Contingencies of Notes to DP&L's Condensed Financial Statements.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

DP&L’s Financial Statements are prepared in accordance with GAAP. In connection with the preparation of these financial statements, our management is required to make assumptions, estimates and judgments that affect the reported amounts of assets, liabilities, revenues, expenses and the related disclosure of contingent liabilities. These assumptions, estimates and judgments are based on our historical experience and assumptions that we believe to be reasonable at the time. However, because future events and their effects cannot be determined with certainty, the determination of estimates requires the exercise of judgment. Our critical accounting estimates are those which require assumptions to be made about matters that are highly uncertain. Our significant accounting policies are described in Note 1 - Overview and Summary of Significant Accounting Policies of Notes to DP&L's Financial Statements.

Different estimates could have a material effect on our financial results. Judgments and uncertainties affecting the application of these policies and estimates may result in materially different amounts being reported under different conditions or circumstances. Historically, however, recorded estimates have not differed materially from actual results. Significant items subject to such judgments include: the carrying value of property, plant and equipment; unbilled revenues; the valuation of allowances for deferred income taxes; regulatory assets and liabilities; reserves recorded for income tax exposures; litigation; contingencies; the valuation of AROs; and assets and liabilities related to employee benefits.

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Revenue Recognition (including Unbilled Revenue)

Revenue is primarily earned from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Revenue is recorded net of any taxes assessed on and collected from customers, which are remitted to the governmental authorities.

Income Taxes

We are subject to federal and state income taxes. Our income tax provision requires significant judgment and is based on calculations and assumptions that are subject to examination by the U.S. Internal Revenue Service and other tax authorities. We regularly assess the potential outcome of tax examinations when determining the adequacy of our income tax provisions by considering the technical merits of the filing position, case law, and results of previous tax examinations. Accounting guidance for uncertainty in income taxes prescribes a more-likely-than-not recognition threshold and measurement requirements for financial statement reporting of our income tax positions. Tax reserves have been established which we believe to be adequate in relation to the potential for additional assessments. Once established, reserves are adjusted only when there is more information available or when an event occurs necessitating a change to the reserves. While we believe that the amount of the tax reserves is reasonable, it is possible that the ultimate outcome of current or future examinations may be materially different than the reserve amounts.

Deferred tax assets and liabilities are recognized for future tax consequences attributable to differences between the financial statement carrying amounts of the existing assets and liabilities, and their respective income tax bases. We establish a valuation allowance when it is more likely than not that all or a portion of a deferred tax asset will not be realized.

Regulatory Assets and Liabilities

Application of the provisions of GAAP relating to regulatory accounting requires us to reflect the effect of rate regulation in DP&L’s Financial Statements. For regulated businesses subject to federal or state cost-of-service rate regulation, regulatory practices that assign costs to accounting periods may differ from accounting methods generally applied by non-regulated companies. When it is probable that regulators will permit the recovery of current costs through future rates charged to customers, we defer these costs as Regulatory assets that otherwise would be expensed by non-regulated companies. Likewise, we recognize Regulatory liabilities when it is probable that regulators will require customer refunds through future rates and when revenue is collected from customers for expenses that are not yet incurred. Regulatory assets are amortized into expense and Regulatory liabilities are amortized into income over the recovery period authorized by the regulator.

We evaluate our Regulatory assets to determine whether or not they are probable of recovery through future rates and make various assumptions in our analyses. The expectations of future recovery are generally based on orders issued by regulatory commissions or historical experience, as well as discussions with applicable regulatory authorities. If recovery of a regulatory asset is determined to be less than probable, it will be expensed in the period the assessment is made. We currently believe the recovery of our Regulatory assets is probable. See Note 3 - Regulatory Matters of Note 3 - Regulatory Matters of Notes to DP&L's Financial Statements.

AROs

In accordance with the provisions of GAAP relating to the accounting for AROs, legal obligations associated with the retirement of long-lived assets are required to be recognized at their fair value at the time those obligations are incurred. Upon initial recognition of a legal liability, costs are capitalized as part of the related long-lived asset and allocated to expense over the useful life of the asset. These GAAP provisions also require that components of previously recorded depreciation related to the cost of removal of assets upon future retirement, whether legal AROs or not, must be removed from a company’s accumulated depreciation reserve and be reclassified as a regulatory liability. We make assumptions, estimates and judgments that affect the reported amounts of assets, liabilities and expenses as they relate to AROs. These assumptions and estimates are based on historical experience and assumptions that we believe to be reasonable at the time. See Note 4 - Property, Plant and Equipment of Notes to DP&L's Financial Statements for more information.

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Impairments

In accordance with the provisions of GAAP relating to the accounting for impairments, long-lived assets are reviewed for impairment whenever events or circumstances indicate that the carrying amount may not be recoverable. When required, impairment losses on assets to be held and used are recognized based on the fair value of the asset group. Impairment losses on assets held-for-sale are recognized based on the fair value of the disposal group. We determine the fair value of these assets based upon estimates of future cash flows, market value of similar assets, if available, or independent appraisals, if required. In analyzing the fair value and recoverability using future cash flows, we make projections based on a number of assumptions and estimates of growth rates, future economic conditions, assignment of discount rates and estimates of terminal values. An impairment loss is recognized if the carrying amount of the long-lived asset is not recoverable from its undiscounted cash flows. The measurement of impairment loss is the difference between the carrying amount and fair value of the asset.

Pension and Postretirement Benefits

We account for and disclose pension and postemployment benefits in accordance with the provisions of GAAP relating to the accounting for pension and other postemployment plans. These GAAP provisions require the use of assumptions, such as the discount rate for liabilities and long-term rate of return on assets, in determining the obligations, annual cost, and funding requirements of the plans. See Note 9 - Benefit Plans of Notes to DP&L's Financial Statements for more information.

Contingent and Other Obligations

During the conduct of our business, we are subject to a number of federal and state laws and regulations, as well as other factors and conditions that potentially subject us to environmental, litigation, insurance and other risks. We periodically evaluate our exposure to such risks and record estimated liabilities for those matters where a loss is considered probable and reasonably estimable in accordance with GAAP. In recording such estimated liabilities, we may make assumptions, estimates and judgments that affect the reported amounts of assets, liabilities and expenses as they relate to contingent and other obligations. These assumptions and estimates are based on historical experience and assumptions and may be subject to change. We believe such estimates and assumptions are reasonable.

Recently Issued Accounting Pronouncements

A discussion of recently issued accounting pronouncements is in Note 1 - Overview and Summary of Significant Accounting Policies of Notes to DP&L's Condensed Financial Statements and such discussion is incorporated by reference in this Management's Discussion and Analysis of Financial Condition and Results of Operations and made a part hereof.

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BUSINESS

DP&L is a public utility incorporated in 1911 under the laws of Ohio. DP&L offers retail SSO electric service to residential, commercial, industrial and governmental customers in a 6,000 square mile area of West Central Ohio and has the exclusive right to provide distribution and transmission services to more than 524,000 customers in that service area. In addition to DP&L’s electric transmission and distribution businesses, DP&L has a 4.9% interest in OVEC, an electric generating company. OVEC has two electric generating stations located in Cheshire, Ohio and Madison, Indiana with a combined generation capacity of 2,109 MW. DP&L’s share of this generation capacity is 103 MW.

The principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, manufacturing and defense. DP&L’s sales reflect general economic and competitive conditions, seasonal weather patterns of the area and the growth of energy efficiency initiatives, however, DP&L’s distribution revenues have been decoupled from weather and energy efficiency variations beginning January 1, 2019 as a result of the decoupling rider the PUCO approved in the DRO.

DP&L strives to achieve stable, long-term growth through efficient operations and strong customer and regulatory relations. More specifically, DP&L’s strategy is to utilize the transmission and distribution assets that transfer electricity at the most efficient cost, and to maintain the highest level of customer service and reliability. DP&L’s total revenue and net income for the nine months ended September 30, 2019 were $570.2 million and $103.7 million, respectively. In addition, as of September 30, 2019, DP&L had total assets of approximately $1.8 billion. DP&L’s business is not dependent on any single customer or group of customers.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs or overcollections of riders.

Seasonality

The power delivery business is seasonal and weather patterns have a material effect on energy demand. In the region we serve, demand for electricity is generally greater in the summer months associated with cooling and in the winter months associated with heating compared to other times of the year. DP&L’s sales typically reflect the seasonal weather patterns and the growth of energy efficiency initiatives, however, after the approval of the distribution rate order in 2018, our distribution revenues have been decoupled from weather and energy efficiency variations. Because of the impact of the new decoupling rider (effective January 1, 2019) and because DP&L’s generation has greatly decreased in recent years due to plant sales and closures, we expect that weather and other factors influencing demand will have minimal impact on our net operating results going forward.

Storm activity can also have an adverse effect on our operating performance. Severe storms often damage transmission and distribution equipment, thereby causing power outages, which increase repair costs. Partially mitigating this impact is DP&L’s ability to recover certain repair costs related to severe storms.

Rate Regulation and Government Legislation

DP&L’s delivery service to all retail customers as well as the provisions of its SSO service are regulated by the PUCO. In addition, certain costs are considered to be non-bypassable and are therefore assessed to all of DP&L’s retail customers, under the regulatory authority of the PUCO, regardless of the customer’s retail electric supplier. DP&L’s transmission rates are subject to regulation by the FERC under the Federal Power Act.

Ohio law establishes the process for determining SSO and non-bypassable rates charged by public utilities. Regulation of retail rates encompasses the timing of applications, the effective date of rate changes, the cost basis upon which the rates are set and other service-related matters. Ohio law also established the Office of the Ohio Consumers’ Counsel, which has the authority to represent residential consumers in state and federal judicial and administrative rate proceedings.

Ohio legislation extends the jurisdiction of the PUCO to the records and accounts of certain public utility holding company systems, including DPL. 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 such matters relate to the

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costs associated with the provision of public utility service. Based on existing PUCO and FERC authorization, regulatory assets and liabilities are recorded on both DPL and DP&L’s balance sheets.

Competition and Regulation

Ohio Matters

Ohio Retail Rates

DP&L filed an amended stipulation to its 2017 ESP case on March 13, 2017. The PUCO issued a final decision on October 20, 2017, modifying and adopting the amended stipulation and recommendation. The six-year 2017 ESP establishes DP&L’s framework for providing retail service on a going-forward basis including rate structures, non-bypassable charges and other specific rate recovery true-up rider mechanisms.

On September 26, 2018, the PUCO issued the DRO establishing new base distribution rates for DP&L, which became effective October 1, 2018. The DRO approved, without modification, a stipulation and recommendation previously filed by DP&L, along with various intervening parties and the PUCO staff. The DRO established a revenue requirement of $248.0 million for DP&L’s electric service base distribution rates which reflects an increase to distribution revenues of approximately $29.8 million per year. In addition to the increase in base distribution rates, among other matters, the DRO also provides for a return on equity of 9.999% and a cost of long-term debt of 4.8%. For more information regarding DP&L’s ESP and DRO, see Note 3 of the Notes to DP&L’s financial statements.

In December 2018, DP&L filed a Distribution Modernization Plan (“DMP”) with the PUCO proposing to invest $576.0 million in capital projects over the next 10 years. There are eight principal components of DP&L’s DMP: 1) Smart Meters, 2) Self-Healing Grid, 3) Customer Engagement, 4) Enhancing Sustainability and Embracing Innovation. 5) Telecommunications, 6) Physical and Cyber Security, 7) Governance and Analytics, and 8) Grid Modernization R&D.

These initiatives will also allow DP&L to be ready to leverage and integrate Distributed Energy Resources into its grid, including demonstrations of community solar, energy storage, microgrids, as well as Electric Vehicle charging infrastructure. If approved, DP&L will implement a comprehensive grid modernization project that will deliver benefits to customers, society as a whole and to the Company.

On January 22, 2019, DP&L filed a request with the PUCO for a two-year extension of its distribution modernization rider (“DMR”) through October 2022, in the proposed amount of $199.0 million for each of the two additional years. The request was made pursuant to the PUCO’s October 20, 2017 ESP order, which approved the DMR and granted DP&L the option to file for a two-year extension. The extension request was set at a level expected to reduce both DPL and DP&L’s debt obligations and to position DP&L to make capital expenditures to maintain and modernize its electric grid. To that end, DP&L’s DMP investments are contingent upon the PUCO approving the two-year extension of its DMR.

A rehearing process in DP&L's 2017 ESP case, including the DMR, remains pending. On August 1, 2019, DP&L filed a supplemental brief with the PUCO focused on the applicability of a recent court decision involving another Ohio utility’s DMR which is similar to, but not identical to, DP&L’s DMR.

Ohio law and the PUCO rules contain targets relating to renewable energy, peak demand reduction and energy efficiency standards. If any targets are not met, compliance penalties will apply unless the PUCO makes certain findings that would excuse performance. DP&L is in full compliance with energy efficiency, peak demand reduction and renewable energy targets. DP&L is required to file an energy efficiency portfolio plan to demonstrate how it plans to meet the standards. On June 15, 2017, DP&L filed an energy efficiency portfolio plan for programs in years 2018 through 2020, which was settled and approved by the PUCO on December 20, 2017. DP&L recovers the costs of its compliance with Ohio energy efficiency and renewable energy standards through separate riders which are reviewed and audited by the PUCO.

The rates associated with providing transmission service and wholesale electric sales and ancillary services are subject to FERC jurisdiction. While DP&L has market-based rate authority for wholesale electric sales, DP&L would be required to file an application at FERC under section 205 of the Federal Power Act, 15 U.S.C. section 824d, to change any of its cost-based transmission or ancillary service rates.

As a member of PJM, DP&L receives revenues from the RTO related to its transmission assets and incurs costs associated with its load obligations for retail customers. Ohio law includes a provision that would allow Ohio

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electric utilities to seek and obtain a reconcilable rider to recover RTO-related costs and credits. DP&L continues to recover non-market-based transmission and ancillary costs through its transmission rider.

DP&L is subject to a significantly excessive earnings test (“SEET”) threshold and is required to apply general rules for calculating earnings and comparing them to a comparable group to determine whether there were significantly excessive earnings during a given calendar year. In future years, the SEET could have a material effect on results of operations, financial condition and cash flows. See Note 3 of the Notes to our Financial Statements.

Ohio Competitive Considerations and Proceedings

Since January 2001, DP&L’s electric customers have been permitted to choose their retail electric generation supplier. DP&L continues to have the exclusive right to provide delivery service in its state-certified territory and the obligation to procure and provide electricity to SSO customers that do not choose an alternative supplier. The PUCO maintains jurisdiction over DP&L’s delivery of electricity, SSO and other retail electric services.

As part of Ohio’s electric deregulation law, all of the state’s investor-owned utilities were required to join an RTO. DP&L is a member of the PJM RTO. The role of the RTO is to administer a competitive wholesale market for electricity and ensure reliability of the transmission grid. PJM ensures the reliability of the high-voltage electric power system serving more than 50 million people in all or parts of Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia and the District of Columbia. PJM coordinates and directs the operation of the region’s transmission grid, administers the world’s largest competitive wholesale electricity market and plans regional transmission expansion improvements to maintain grid reliability and relieve congestion.

Ohio House Bill 6

On July 23, 2019, the Governor of Ohio signed Ohio House Bill 6, which, among other things, does the following:

• beginning January 1, 2020, replaces DP&L’s non-bypassable Reconciliation Rider, permitting DP&L to defer, recover or credit the net proceeds from selling energy and capacity received as part of DP&L’s interest in OVEC and its OVEC-related costs through 2023, with a non-bypassable recovery mechanism for recovery of prudently incurred OVEC costs through 2030;

• eliminates the annual energy efficiency targets for Ohio utilities after 2020;

• allows Ohio utilities to construct customer-sited renewable generation for mercantile customers or groups of mercantile customers, the costs of which may only be recovered from those customers.

Environmental Matters

DP&L’s facilities and operations are subject to a wide range of federal, state and local environmental laws, rules and regulations. The environmental issues that may affect us include the following. However, as described further below, as a result of DP&L transferring its generation assets to AES Ohio Generation in 2017, certain of these environmental regulations and laws are now not expected to have a material impact on us with respect to these generation assets.

• The federal Clean Air Act (“CAA”) and state laws and regulations (including state implementation plans) which require compliance, obtaining permits and reporting as to air emissions;

• Litigation with federal and certain state governments and certain special interest groups regarding whether modifications to or maintenance of certain coal-fired generating stations require additional permitting or pollution control technology, or whether emissions from coal-fired generating stations cause or contribute to global climate change;

• Rules and future rules issued by the USEPA, the Ohio Environmental Protection Agency (the “Ohio EPA”) or other authorities that require or will require substantial reductions in SO₂, particulates, mercury, acid gases, NOx, and other air emissions;

• Rules and future rules issued by the USEPA, the Ohio EPA or other authorities that require or will require reporting and reductions of GHGs;

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• Rules and future rules issued by the USEPA, the Ohio EPA or other authorities associated with the federal Clean Water Act (“CWA”), which prohibits the discharge of pollutants into waters of the United States except pursuant to appropriate permits and regulates the design and operation of cooling water intake structures for power plants and other industrial facilities; and

• Solid and hazardous waste laws and regulations, which govern the management and disposal of certain waste.

In addition to imposing continuing compliance obligations, these laws, rules and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. In the normal course of business, we have investigatory and remedial activities underway at our facilities to comply, or to determine compliance, with such laws, rules and regulations. We record liabilities for loss contingencies related to environmental matters when the chance of a loss occurring is probable and can be reasonably estimated in accordance with the provisions of GAAP. Accordingly, we have immaterial accruals for loss contingencies for environmental matters. We also have a number of environmental matters for which we have not accrued loss contingencies because the risk of loss is not probable, or a loss cannot be reasonably estimated. We evaluate the potential liability related to environmental matters quarterly and may revise our estimates. Such revisions in the estimates of the potential liabilities could have a material adverse effect on our results of operations, financial condition or cash flows. See Note 11 of the Notes to our Financial Statements for more information regarding environmental risks, laws and regulations and legal proceedings to which we are and may be subject to in the future.

In response to Executive Orders from the U.S. President, the USEPA is currently evaluating various existing regulations to be considered for repeal, replacement, or modification. We cannot predict at this time the likely outcome of the USEPA’s review of these or other existing regulations or what impact it may have on our business.

We have several pending environmental matters associated with our current and previously owned and operated coal-fired generation units. Some of these matters could have material adverse impacts on our results of operations, financial condition or cash flows.

Environmental Matters Related to Air Quality

As a result of DP&L transferring its generation assets to AES Ohio Generation in 2017, the following environmental matters, regulations and requirements are now not expected to have a material impact on us:

• The CAA and the following regulations:

• The Cross-State Air Pollution Rule and associated updates;

• Mercury and Air Toxic Standards and any associated regulatory or judicial processes;

• National Ambient Air Quality Standards; and

• The Clean Power Plan, the USEPA’s final CO2 emission rules for existing power plants under CAA Section 111(d) or a potential replacement rule, for example, the Affordable Clean Energy Rule.

Notices of Violation Involving Co-Owned Units

In June 2000, the USEPA issued a notice of violation (“NOV”) to the then DP&L-operated Stuart generating station (co-owned by AES Ohio Generation, AEP Generation Resources Inc. (“AEP Generation”) and Dynegy, Inc. for alleged violations of the CAA. The NOV contained allegations consistent with NOVs and complaints that the USEPA had brought against numerous other coal-fired utilities in the Midwest. The NOV indicated the USEPA may: (1) issue an order requiring compliance with the requirements of the Ohio SIP; or (2) bring a civil action seeking injunctive relief and civil penalties of up to $27,500 per day for each violation. To date, neither action has been taken. We cannot predict the outcome of this matter.

On September 9, 2011, DP&L received an NOV from the USEPA with respect to its then co-owned Stuart generating station based on a compliance evaluation inspection conducted by the USEPA and the Ohio EPA in 2009. The notice alleged non-compliance by DP&L with certain provisions of the Resource Conservation and Recovery Act (“RCRA”), the CWA National Pollutant Discharge Elimination System (“NPDES”) permit program and the station’s storm water pollution prevention plan. The notice requested that DP&L respond with the actions it has subsequently taken or plans to take to remedy the USEPA’s findings and ensure that further violations will not occur.

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Based on its review of the findings, although there can be no assurance, we believe that the notice will not result in any material effect on our results of operations, financial condition or cash flows.

In January 2015, DP&L received NOVs from the USEPA alleging violations in opacity at the Stuart and Killen generating stations in 2014. On February 15, 2017, the USEPA issued an NOV alleging violations in opacity at the Stuart generation station in 2016. Operations at both Stuart and Killen have ceased. However, we are currently unable to predict the outcome of these matters.

Notices of Violation Involving Wholly-Owned Stations

On November 18, 2009, the USEPA issued an NOV to DP&L for alleged New Source Review, a preconstruction program regulating new or significantly modified sources of air pollution (“NSR”), violations of the CAA at the Hutchings energy generating unit, which was closed in 2013, relating to capital projects performed in 2001 involving Unit 3 and Unit 6. We do not believe that the two projects described in the NOV were modifications subject to NSR. We cannot predict the outcome of this matter.

Environmental Matters Related to Water Quality, Waste Disposal and Ash Ponds

As a result of DP&L transferring its generation assets to AES Generation in 2017, the following environmental matters, regulations and requirements are now not expected to have a material impact on us with respect to these generation assets (although certain of these requirements related to water quality, waste disposal and CCR are discussed further below):

• water intake regulations, including those finalized by the USEPA on May 19, 2014;

• the appeal of the NPDES permit governing the discharge of water from the Stuart generating station;

• revised technology-based regulations governing water discharges from steam electric generating facilities, finalized by the USEPA on November 3, 2015 and commonly referred to as the Steam Electric Power Effluent Limitations Guidelines rules; and

• CWA rules for Selenium.

Clean Water Act rules for Selenium

On July 13, 2016, the USEPA published the final updated chronic aquatic life criterion for the pollutant selenium in freshwater per section 304(a) of the CWA. The rule will be implemented after state rulemaking occurs, and requirements will be incorporated into NPDES permits with compliance schedules in some cases. It is too early in the rulemaking process to determine the impact, if any, on our operations, financial position or results of operations.

Regulation of Waste Disposal

In 2002, DP&L and other parties received a special notice that the USEPA considered DP&L to be a potentially responsible party (“PRP”) for the clean-up of hazardous substances at a third-party landfill known as the South Dayton Dump (“Landfill”). Several of the parties voluntarily accepted some of the responsibility for contamination at the Landfill and, in May 2010, three of those parties, Hobart Corporation, Kelsey-Hayes Company, and NCR Corporation (“PRP Group”), filed a civil complaint in Ohio federal court (the “District Court”) against DP&L and numerous other defendants, alleging that the defendants contributed to the contamination at the Landfill and were liable for contribution to the PRP Group for costs associated with the investigation and remediation of the site.

While DP&L was able to get the initial case dismissed, the PRP Group subsequently, in 2013, entered into an additional Administrative Settlement Agreement and Order on Consent (“ASAOC”) with the USEPA relating to vapor intrusion and again filed suit against DP&L and other defendants. Trial for that issue was scheduled to be held in 2019, but the District Court recently vacated that trial date and it is unknown when it will be rescheduled. Plaintiffs also attempted to add an additional ASAOC they entered into in 2016 pertaining to the investigation and remediation of all hazardous substances present in the Landfill-potentially including undefined areas outside the original dump footprint-to the vapor intrusion trial proceeding. The District Court allowed the claim to be added to the litigation but ruled that the 2016 ASAOC could not be adjudicated until after completion of the remedial investigation feasibility study, which is expected to be complete years after the vapor intrusion trial. While DP&L is unable to predict the outcome of these matters, if DP&L were required to contribute to the clean-up of the site, it could have a material adverse effect on our business, financial condition or results of operations.

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On October 16, 2019, DP&L received a special notice that USEPA considers DP&L, along with other parties, to be a PRP for the clean-up of hazardous substances at a third-party landfill known as the Tremont City Barrel Site, located near Dayton, Ohio. While DP&L is unable to predict the outcome of this matter, if DP&L were required to contribute to the clean-up of the site, it could have a material adverse effect on our business, financial condition or results of operations.

Regulation of CCR

The USEPA's final CCR rule became effective in October 2015. Generally, the rule regulates CCR as nonhazardous solid waste and establishes national minimum criteria for existing and new CCR landfills and existing and new CCR ash ponds, including location restrictions, design and operating criteria, groundwater monitoring, corrective action and closure requirements and post-closure care. On December 16, 2016, President Obama signed into law the Water Infrastructure Improvements for the Nation Act ("WIIN Act"), which includes provisions to implement the CCR rule through a state permitting program, or if the state chooses not to participate, a possible federal permit program. The USEPA has indicated that they will implement a phased approach to amending the CCR rule.

In July 2018, the USEPA published final CCR rule amendments (Phase One, Part One) in the Federal Register. In August 2018, the D.C. Circuit Court issued a decision in certain CCR litigation matters, which may result in additional revisions to the CCR Rule. In October 2018, some environmental groups filed a petition for review challenging the USEPA's final CCR rule amendments (Phase One, Part One) which have since been remanded without vacatur to the USEPA. On August 14, 2019, the USEPA published amendments to the CCR rule; the amendment published on August 14, 2019 relates to the CCR rule’s criteria for determining beneficial use and the regulation of CCR piles, among other revisions. The CCR rule, current or proposed amendments to the CCR rule, the results of groundwater monitoring data or the outcome of CCR-related litigation could have a material impact on our business, financial condition and results of operations.

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DESCRIPTION OF THE BONDS

In this Description of the Bonds, references to the “Company,” “we,” “us,” and “our” refer to DP&L.

General

The new bonds are to be issued under the First and Refunding Mortgage, dated as of October 1, 1935, between us and The Bank of New York Mellon, as trustee (the “Trustee”), as amended and supplemented by all supplemental indentures prior to the date hereof and as amended and supplemented by a Fifty-Second Supplemental Indenture relating to the new bonds (collectively referred to as the “Mortgage”).

The statements herein concerning the new bonds and the Mortgage are a summary and do not purport to be complete. The statements make use of defined terms and are qualified in their entirety by express reference to the definitions in, and the appropriate sections and articles of, the Mortgage, a copy of which will be made available upon request to the Trustee.

Maturity, Interest and Payment

The new bonds will mature on June 15, 2049, and will bear interest from the date of original issuance thereof at the rate per annum set forth in their title, payable semi-annually on June 15 and December 15 of each year to bondholders of record at the close of business on the June 1 and December 1 immediately preceding the interest payment date, the first interest payment date being December 15, 2019. The amount of interest payable for any period will be computed on the basis of a 360-day year of twelve 30-day months and for any period shorter than a full month, on the basis of the actual number of days elapsed. In the event that any date on which principal or interest is payable on the new bonds is not a business day, the payment of the principal or interest payable on such date will be made on the next succeeding day which is a business day (and without any interest or other payment in respect of any such delay), with the same force and effect as if made on the date the payment was originally payable. The term “business day” means any day, other than a Saturday or Sunday, or which is not a day on which banking institutions or trust companies in The City of New York are generally authorized or required by law, regulation or executive order to remain closed (or which is not a day on which the corporate trust office of the Trustee is closed for business). We have agreed to pay interest on any overdue principal and, if such payment is enforceable under applicable law, on any overdue installment of interest on the new bonds at the rate per annum set forth in its title.

The new bonds will be issued only in minimum denominations of $2,000 and integral multiples of $1,000 in excess thereof. We will make principal, premium, if any, and interest payments on the new bonds, other than certificated new bonds, to Cede & Co. (as nominee of The Depository Trust Company (“DTC”)) so long as Cede & Co. is the registered owner. Disbursement of such payments to DTC’s participants is the responsibility of DTC, and disbursement of such payments to the beneficial owners of the new bonds is the responsibility of DTC participants and indirect participants in DTC, all as described below under “-Book-Entry, Delivery and Form.”

The new bonds will not have the benefit of any sinking fund.

Optional Redemption

Prior to December 15, 2048 (the date that is six months prior to the maturity date), we may redeem the new bonds at our option, at any time in whole or from time to time in part, on at least 20 days’ prior written notice mailed to the registered holders of the new bonds, at a redemption price, together with accrued and unpaid interest to the date of redemption, equal to the greater of:

• 100% of the principal amount of the new bonds being redeemed; or

• the sum of the present values of the principal amount of the new bonds to be redeemed and the remaining scheduled payments of interest on the new bonds from the redemption date to December 15, 2048 (the date that is six months prior to the maturity date), discounted from their respective scheduled payment dates to the redemption date semiannually, assuming a 360-day year consisting of twelve 30-day months, at a discount rate equal to the Treasury Yield plus 25 basis points.

On or after December 15, 2048 (the date that is six months prior to the maturity date), we may redeem the new bonds at our option, at any time in whole or from time to time in part, on at least 20 days’ prior written notice mailed

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to the registered holders of the new bonds, at a redemption price equal to 100% of the principal amount of the new bonds being redeemed, together with accrued and unpaid interest to the date of redemption.

“Treasury Yield” means, with respect to any redemption date, the annual rate equal to the semiannual equivalent yield to maturity (to December 15, 2048) of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue expressed as a percentage of its principal amount equal to the Comparable Treasury Price for such redemption date.

“Comparable Treasury Issue” means the United States treasury security selected by an independent investment banker as having a maturity comparable to the remaining term (to December 15, 2048) of the new bonds to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term (to December 15, 2048) of the new bonds.

“Comparable Treasury Price” means, with respect to any date of redemption:

• the average of the bid and asked prices for the Comparable Treasury Issue, expressed in each case as a percentage of its principal amount, on the third business day preceding the redemption date, as set forth in the daily statistical release published by the Federal Reserve Bank of New York and designated “Composite 3:30 p.m. Quotations for U.S. Government Securities,” or

• if this release is not published or does not contain such prices on the business day in question, the Reference Treasury Dealer Quotation for the redemption date.

“Quotation Agent” means the Reference Treasury Dealer.

“Reference Treasury Dealer Quotation” means, with respect to the Reference Treasury Dealer and redemption date, the average, as determined by the Quotation Agent, of the bid and asked prices for the Comparable Treasury Issue expressed in each case as a percentage of its principal amount and quoted in writing to us by the Reference Treasury Dealer at 5:00 p.m. on the third business day preceding the redemption date.

“Reference Treasury Dealer” means a primary United States government securities dealer in New York City (a “Primary Treasury Dealer”) appointed by BofA Securities, Inc. or J.P. Morgan Securities LLC and their successors or any other Primary Treasury Dealer appointed by us.

Notice of redemption will be mailed by first class mail or electronically transmitted through the facilities of DTC at least 20 days before the redemption date to each holder of the new bonds to be redeemed at its registered address.

If fewer than all the new bonds are to be redeemed, selection of new bonds for redemption will be made by the trustee in the manner specified in the mortgage.

Unless we default in payment of the redemption price, from and after the date of redemption, the new bonds or portions thereof called for redemption will cease to bear interest, and the holders of the new bonds will have no right in respect of the new bonds except the right to receive the redemption price.

Notwithstanding the foregoing, upon the notice and in the manner and with the effect provided in the mortgage, the new bonds shall be redeemable by us prior to the maturity of the new bonds out of monies deposited with the trustee representing the proceeds of mortgaged and pledged property taken by the exercise of the power of eminent domain or otherwise as provided in the mortgage, at the principal amount of the new bonds to be redeemed and accrued interest to the date of redemption.

Priority and Security

The new bonds will rank equally and ratably with all other First Mortgage Bonds at any time outstanding under the Mortgage. As of September 30, 2019, we had approximately $565.0 million aggregate principal amount of First Mortgage Bonds outstanding.

All outstanding First Mortgage Bonds will be secured, equally and ratably, by the lien of the Mortgage on substantially all properties owned by us (other than property excepted from such lien and such property as may be released from such lien in accordance with the terms of the Mortgage), and improvements, extensions and additions to, and renewals and replacements of, such properties.

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The lien under the Mortgage is subject to certain exclusions, including liens for taxes assessed but not then due or payable, vendor’s liens, liens of purchase money mortgages, liens for paving, conservancy or other assessments, any mortgage or other lien on any property hereafter acquired by us which may exist on the date of such acquisition, prior liens and excepted encumbrances. “Excepted encumbrances” include the following:

• any liens, neither assumed by us nor on which we customarily pay interest charges, existing upon real estate or rights in or relating to real estate we acquired for substation, transmission line, distribution line or right of way purposes;

• rights reserved to or vested in any municipality or public authority by the terms of any franchise, grant, license, permit or by any provision of law to purchase or recapture or to designate a purchaser of any of our property;

• rights reserved to or vested in others to take or receive any part of the power developed or generated by any of our property;

• easements or reservation in any of our property created at or before the time we acquired that property for the purpose of roads, pipe lines, transmission lines and other like purposes;

• rights reserved to or vested in any municipality or public authority to use or control or regulate any of our properties; or

• any obligations or duties affecting our property to any municipality or public authority with respect to any franchise, grant, license or permit.

The Mortgage provides that we will maintain the mortgaged property in working order and condition and equipped with suitable equipment and appliances; that we will make regular charges to expense for the establishment of reasonably adequate reserves for depreciation and will make all needed and proper repairs, retirements, renewals and replacements of the mortgaged property; that we will not charge to our property, plant and equipment accounts any expenditures that are properly chargeable to maintenance or repairs or to any other permitted expense account; and that we may promptly retire property that has permanently ceased to be used or useful in our business.

Release of Property

When not in default, we may obtain the release of any of the mortgaged and pledged property, including, without limiting the generality of the foregoing, any one or more of our heating, gas or water properties substantially as an entirety (provided, however, that our electric property shall not in any event be released substantially as an entirety (other than the assets and operations which formed part of our generation business that were transferred by us in connection with the separation of our generation business from our transmission and distribution assets in 2017 in compliance with an order of the PUCO) and, further, that prior lien bonds deposited with the Trustee shall not be released except as provided by the Mortgage) upon deposit with the Trustee of cash equivalent to the amount (if any) by which the value of the property to be released exceeds certain credits, including the cost or fair value, whichever is less, to us of any Property Additions acquired or constructed prior to or concurrently with such release that have not been used as a basis to issue additional First Mortgage Bonds. Money received by the Trustee upon any release may be withdrawn against Property Additions or against the deposit of bonds or prior lien bonds, or at our request, may be applied to purchase First Mortgage Bonds or to redeem First Mortgage Bonds that are redeemable by their terms at that time.

“Property Additions” means property acquired or constructed after September 30, 1945, to be used in the electric, natural gas, steam or water business.

“Funded Property” includes Property Additions used to satisfy requirements of bond issuances and obligations or bond retirements.

Issuance of Additional First Mortgage Bonds

The Mortgage permits us to issue an unlimited amount of First Mortgage Bonds from time to time in one or more series. All First Mortgage Bonds of one series need not be issued at the same time, and a series may be reopened for issuances of additional First Mortgage Bonds of such series. This means that we may from time to time, without the consent of the existing holders of the new bonds, create and issue additional First Mortgage Bonds having the same terms and conditions as the new bonds in all respects, except for issue date, issue price and, if applicable, the initial interest payment on the new bonds. Additional First Mortgage Bonds issued in this

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manner will be consolidated with, and will form a single series with, the previously outstanding First Mortgage Bonds of such series, including, if applicable, the new bonds.

Additional First Mortgage Bonds, including additional First Mortgage Bonds of an existing series, may be issued:

• upon the basis of Property Additions which are not then Funded Property in a principal amount which, together with any prior lien bonds outstanding on such Property Additions, will not exceed 60% of the cost or fair value to us of such Property Additions, whichever is less;

• against deposits or retirement of prior lien bonds deducted in determining the amount of First Mortgage Bonds issuable upon the basis of Property Additions;

• upon payment, retirement, redemption, cancellation or surrender to the Trustee for cancellation (except when canceled pursuant to certain provisions of the Mortgage as amended) of other First Mortgage Bonds issued under the Mortgage or upon deposit with the Trustee of the money necessary for their purchase or payment, in principal amount equivalent to the First Mortgage Bonds paid, retired, redeemed, canceled or surrendered or for which money has been so deposited; or

• upon deposit with the Trustee of cash equal to the principal amount of the First Mortgage Bonds to be issued; such cash may be withdrawn in lieu of First Mortgage Bonds, which we may be entitled to have authenticated and delivered to us.

The issuance of additional First Mortgage Bonds (other than bonds issued on the basis of prior bond retirements, as described above) is also limited by a net earnings test, under which no First Mortgage Bonds may be issued upon the basis of Property Additions or under certain other circumstances unless our adjusted net earnings for 12 consecutive calendar months in the 18 calendar months preceding the application for the issue of such First Mortgage Bonds shall be at least two times annual interest charges on all First Mortgage Bonds outstanding (except any for the payment of which the First Mortgage Bonds applied for are to be issued), on the additional First Mortgage Bonds and on the principal amount of all other indebtedness (except indebtedness for the payment of which the First Mortgage Bonds applied for are to be issued and indebtedness for the purchase, payment or redemption of which moneys in the necessary amount shall have been deposited with or be held by the Trustee or the trustee or other holder of a lien prior to the lien of the Mortgage upon property subject to the lien of the Mortgage with irrevocable direction so to apply the same; provided that, in the case of redemption, the notice required therefor shall have been given or have been provided for to the satisfaction of the Trustee), outstanding in the hands of the public and secured by a lien prior to the lien of the Mortgage upon property subject to the lien of the Mortgage, if said indebtedness has been assumed by us or if we customarily pay the interest upon the principal thereof.

As of September 30, 2019, approximately $319.4 million of First Mortgage Bonds was permitted to be issued as a result of prior bond retirements. The new bonds will be issued upon the basis of prior bond retirements.

Modification of Mortgage

Our rights and obligations and those of the holders of the First Mortgage Bonds may be modified upon the written consent of the holders of at least a majority of the First Mortgage Bonds then outstanding, but no such modification shall extend the maturity of or reduce the rate of interest on or otherwise modify the terms of payment of principal of or interest on First Mortgage Bonds or permit the creation of any lien ranking prior to or equal with the lien of the Mortgage on any of the mortgaged property. If any proposed modification shall affect the rights of holders of the First Mortgage Bonds of one or more, but not all, series, then only holders of First Mortgage Bonds of the series to be affected shall be required to consent to or shall have authority to approve such modification. Any waiver of a completed default shall be deemed to affect the First Mortgage Bonds of all series, and, subject to the foregoing, any modification of the provisions of any sinking fund established in respect of a particular series shall be deemed to affect only the First Mortgage Bonds of that series. The determination of the Trustee as to what series of First Mortgage Bonds are affected by any modification shall be conclusive.

Events of Default

Among the events which constitute a “completed default” by us under the Mortgage are the following: (a) default in the payment of the principal of any First Mortgage Bond; (b) default for 90 days in the payment of interest on any First Mortgage Bond; (c) default for 90 days in the payment of amounts required for any sinking fund established in respect of a particular series; (d) certain events in bankruptcy, insolvency or reorganization; and (e)

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default, for 90 days after notice to us from the Trustee, in the performance of any other covenant, agreement or condition contained in the Mortgage. Upon the occurrence of any such completed default, the Trustee or the holders of not less than 25% in principal amount of the First Mortgage Bonds of all series outstanding under the Mortgage may declare the principal of, and any accrued interest on, all such First Mortgage Bonds immediately due and payable, subject to the right of the holders of a majority in principal amount of all such First Mortgage Bonds to annul such declaration if before any sale of the mortgaged property the default is cured. We are not required to furnish periodically to the Trustee evidence as to the absence of default or as to compliance with the terms of the Mortgage, but such evidence is required in connection with the issuance of any additional First Mortgage Bond under the Mortgage and in certain other circumstances. In addition, we are required by law to furnish annually to the Trustee a certificate as to compliance with all conditions and covenants under the Mortgage.

No bondholder may institute any action, suit or proceeding for any remedy under the Mortgage unless it shall have previously given to the Trustee written notice of a default by us and, in addition, (i) the holders of not less than 25% in principal amounts of the First Mortgage Bonds outstanding under the Mortgage shall have made a written request to the Trustee to exercise its powers under the Mortgage or to institute such action, suit or proceeding in its own name, (ii) such holders shall have offered to the Trustee security and indemnity satisfactory to it against the costs, expenses and liabilities to be incurred thereby and (iii) the Trustee shall have refused to exercise such powers or to institute such action in its own name or shall have failed to do so for an unreasonable time. Bondholders, however, have an absolute and unconditional right, without such notice to the Trustee, to enforce the payment of the principal of and the interest on their First Mortgage Bonds at and after the maturity thereof.

No personal liability of directors, officers, employees, managers and stockholders

No personal liability whatever shall attach to, or be incurred by, any incorporator or any past, present or future subscriber to capital stock, stockholder, officer or director of the Company or of any predecessor or successor corporation, or any of them, because of the incurring of the indebtedness authorized by the Mortgage, or under or by reason of any of the obligations, covenants or agreements contained in the Mortgage or in any indenture supplemental thereto or in any of the First Mortgage Bonds, or implied therefrom. Each holder of First Mortgage Bonds by accepting a First Mortgage Bond waives and releases all such liability. The waiver and release are part of the consideration for issuance of the First Mortgage Bonds. The waiver may not be effective to waive liabilities under the federal securities laws.

Satisfaction and Discharge of the Mortgage

Upon our making due provision for the payment of all First Mortgage Bonds and paying all other sums due under the Mortgage, the Mortgage shall cease to be of further effect and may be satisfied and discharged of record.

Merger, Consolidation and Sale

Subject to the conditions listed in the next paragraph, we may consolidate with or merge into any corporation having corporate authority to carry on any of the businesses of generating, manufacturing, transmitting, distributing or supplying (i) electricity or gas for light, heat, power or other purposes, (ii) steam or hot water for power or heat or other purposes or (iii) water for domestic or public use and consumption. The Mortgage also allows conveyance or transfer of all of the mortgaged and pledged property substantially as an entirety to any corporation that is lawfully entitled to acquire and operate such property.

The consolidation, merger, conveyance or transfer of all of the mortgaged and pledged property substantially as an entirety must satisfy the following conditions: (i) it must be upon such terms as to preserve and in no respect impair the lien or security of the Mortgage, or any rights or powers of the Trustee or the holders of First Mortgage Bonds; and (ii) the person formed by such consolidation, or into which we shall have been merged, or acquiring all the mortgaged and pledged property substantially as an entirety must expressly assume in writing the due and punctual payment of the principal and interest of all First Mortgage Bonds and the due and punctual performance and observance of all covenants and conditions of the Mortgage.

After such consolidation, merger, conveyance or transfer, the lien of the Mortgage will generally not cover the property of the successor corporation, other than the property that it acquires from us with certain exceptions.

Dividend Covenant

The Mortgage does not restrict our ability to pay dividends on our common stock.

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Defeasance

Any new bonds, or any portion of the principal amount thereof, will be deemed to have been paid for all purposes of the Mortgage, and the entirety of our indebtedness in respect thereof will be deemed to have been satisfied and discharged, if there has been irrevocably deposited with the Trustee or any paying agent (other than us) for such purpose, in trust:

• money (including funded cash not otherwise applied pursuant to the Mortgage, to the extent permitted by the Mortgage) in an amount which will be sufficient; or

• in the case of a deposit made prior to the date on which principal is due, eligible obligations (as described below), which do not contain provisions permitting the redemption or other prepayment thereof at the option of the issuer thereof, the principal of and the interest on which when due, without any regard to reinvestment thereof, will provide monies which, together with the money, if any, deposited with or held by the trustee or such paying agent pursuant to the first bullet point, will be sufficient; or

• a combination of options in the preceding bullet points,

which in each case, will be sufficient, without reinvestment, in the opinion of a nationally recognized investment bank, appraisal firm or firm of independent public accountants expressed in a written certification delivered to the Trustee, to pay when due the principal of and premium, if any, and interest, if any, due and to become due on such new bonds or portions thereof. For this purpose, eligible obligations include direct obligations of, or obligations unconditionally guaranteed by, the United States of America, entitled to the benefit of the full faith and credit thereof, and certificates, depository receipts or other instruments, which may be issued by the Trustee that evidence a direct ownership interest in such obligations or in any specific interest or principal payments due in respect thereof.

Notwithstanding the foregoing, no new bond shall be deemed to have been paid as aforesaid unless we shall have delivered to the Trustee either:

• an opinion of counsel in the United States who is reasonably acceptable to the Trustee confirming that (i) we have received from, or there has been published by, the Internal Revenue Service a ruling or (ii) since the date of the Mortgage, there has been a change in the applicable federal income tax law, in either case to the effect that, and based thereon such opinion of counsel shall confirm that, the holders of the outstanding new bonds will not recognize income, gain or loss for federal income tax purposes as a result of such defeasance and will be subject to federal income tax on the same amounts, in the same manner and at the same times as would have been the case if such defeasance had not occurred; or

• an instrument wherein we, notwithstanding the satisfaction and discharge of our indebtedness in respect of new bonds, shall assume the obligation (which shall be absolute and unconditional) to irrevocably deposit with the Trustee such additional sums of money, if any, or additional eligible obligations, if any, or any combination thereof, at such time or times, as shall be necessary, together with the money and/or eligible obligations theretofore so deposited, to pay when due the principal of and premium, if any, and interest due and to become due on such new bonds or portions thereof; provided, however, that such instrument may state that our obligation to make additional deposits as aforesaid shall be subject to the delivery to us by a holder of a Bond of a notice asserting the deficiency accompanied by an opinion of an independent public accountant of nationally recognized standing showing the calculation thereof; and

• an opinion of tax counsel in the United States who is reasonably acceptable to the Trustee to the effect that the holders of the outstanding new bonds will not recognize income, gain or loss for federal income tax purposes as a result of such defeasance and will be subject to federal income tax on the same amounts, in the same manner and at the same times as would have been the case if such defeasance had not occurred.

Regarding the Trustee

The Trustee under the Mortgage is The Bank of New York Mellon. We, DPL, AES and their other subsidiaries also maintain various banking, lending, trust and other relationships with The Bank of New York Mellon and its affiliates.

The Mortgage provides that our obligations to compensate the Trustee and reimburse the Trustee for expenses (including any indemnity obligations) will be secured by a lien generally prior to that of the First Mortgage Bonds on the Mortgage trust estate and the proceeds thereof.

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Book-Entry, Delivery and Form

The new bonds will be issued in the form of fully registered securities in global form (the “global securities”). The global securities will be deposited with, or on behalf of, DTC, or the depositary, and registered in the name of the depositary or its nominee.

Upon issuance of the global securities, the depositary or its nominee will credit, on its book entry registration and transfer system, the number of new bonds exchanged to the account of institutions that have accounts with the depositary or its nominee participants (the “DTC participants”), including indirectly to the accounts of institutions that have accounts with the Euroclear Bank SA/NV (“Euroclear”), as operator of the Euroclear System and Clearstream Banking, S.A. (“Clearstream”), or their respective nominee participants (the “Euroclear and Clearstream participants” and, collectively with the DTC participants, the “participants”). The accounts to be credited shall be designated by the Exchange Agent. Ownership of beneficial interests in the global securities will be limited to participants or persons that may hold interests through participants. Ownership of beneficial interests in such global securities will be shown on, and the transfer of that ownership will be effected only through, records maintained by the depositary or its nominee (with respect to the participants’ interests) for such global securities, or by participants or persons that hold interests through participants (with respect to beneficial interests of persons other than participants). The laws of some jurisdictions may require that certain purchasers of securities take physical delivery of such securities in definitive form. Such limits and laws may impair the ability to transfer or pledge beneficial interests in the global securities. Investors may hold their interests in a Regulation S global security directly through Clearstream or Euroclear, if they are participants in those systems, or indirectly through organizations that are participants in those systems. Clearstream and Euroclear will hold interests in the Regulation S global securities on behalf of their participants through the depositary.

So long as the depositary, or its nominee, is the registered holder of any global securities, the depositary or such nominee, as the case may be, will be considered the sole legal owner of such securities for all purposes under the Mortgage and the new bonds. Except as set forth below, owners of beneficial interests in global securities will not be entitled to have such global securities registered in their names, will not receive or be entitled to receive physical delivery in exchange therefor and will not be considered to be the owners or holders of such global securities for any purpose under the new bonds or the Mortgage. We understand that under existing industry practice, in the event an owner of a beneficial interest in a global security desires to take any action that the depositary, as the holder of such global security, is entitled to take, the depositary would authorize the participants to take such action, and that the participants would authorize beneficial owners owning through such participants to take such action or would otherwise act upon the instructions of beneficial owners owning through them.

Any payment of principal, premium, if any, or interest due on the new bonds on any interest payment date, redemption date, or at maturity will be made available by us to the Trustee by such date. As soon as possible thereafter, the Trustee will make such payments to the depositary or its nominee, as the case may be, as the registered owner of the global securities representing such new bonds in accordance with existing arrangements between the Trustee and the depositary.

We expect that the depositary or its nominee, upon receipt of any payment of principal, premium or interest in respect of the global securities, will credit immediately the accounts of the related participants with payments in amounts proportionate to their respective beneficial interests in the principal amount of such global security as shown on the records of the depositary. We also expect that payments by participants to owners of beneficial interests in the global securities held through such participants will be governed by standing instructions and customary practices, as is now the case with securities held for the accounts of customers in bearer form or registered in “street name” and will be the responsibility of such participants.

Transfers between participants in the depositary will be effected in the ordinary way in accordance with the depositary’s rules and will be settled in same-day funds. Transfers between Euroclear and Clearstream participants will be effected in the ordinary way in accordance with their respective rules and operating procedures.

None of us, the Trustee, or any paying agent for the global securities will have any responsibility or liability for any aspect of the records relating to or payments made on account of beneficial ownership interests in any of the global securities or for maintaining, supervising or reviewing any records relating to such beneficial ownership interests or for other aspects of the relationship between the depositary and its participants or the relationship between such participants and the owners of beneficial interests in the global securities owning through such participants.

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Unless and until exchanged in whole or in part for securities in definitive form in accordance with the terms of the new bonds, the global securities may not be transferred except as a whole by the depositary to a nominee of the depositary or by a nominee of the depositary to the depositary or another nominee of the depositary or by the depositary of any such nominee to a successor of the depositary or a nominee of each successor.

Settlement for the new bonds will be made by the initial purchasers in immediately available funds. So long as the depositary continues to make its settlement system available to us, all payments of principal of, premium, if any, and interest on the global securities will be made by us in immediately available funds.

Although the depositary has agreed to the foregoing procedures in order to facilitate transfers of interests in the global securities among participants of the depositary, it is under no obligation to perform or continue to perform such procedures, and such procedures may be discontinued at any time. Neither the Trustee nor we will have any responsibility for the performance by the depositary or its participants or indirect participants of their respective obligations under the rules and procedures governing their operations. We and the Trustee may conclusively rely on, and shall be protected in relying on, instructions from the depositary for all purposes.

The global securities shall be exchangeable for corresponding certificated new bonds registered in the name of persons other than the depositary or its nominee only if (a) the depositary (i) notifies us that it is unwilling or unable to continue as depositary for any of the global securities or (ii) at any time ceases to be a clearing agency registered under the Exchange Act, (b) there shall have occurred and be continuing an event of default under the Mortgage with respect to the related series of new bonds or (c) we execute and deliver to the Trustee, an order that the global securities shall be so exchangeable. Any certificated new bonds will be issued only in fully registered form and shall be issued without coupons in minimum denominations of $2,000 and in integral multiples of $1,000 in excess thereof. Any certificated new bonds so issued will be registered in such names as the depositary shall request.

Principal, premium, if any, and interest on all certificated new bonds in registered form will be payable at the office or agency of the Trustee in The City of New York, except that, at our option, payment of any interest (except interest due at maturity) may be made by check mailed to the address of the person entitled thereto as such address shall appear in the security register or by wire transfer to an account maintained by the person entitled thereto as specified in the security register.

The depositary has advised us as follows: The depositary is a limited-purpose trust company organized under the laws of the State of New York, a member of the Federal Reserve System, a “clearing corporation” within the meaning of the New York Uniform Commercial Code and “a clearing agency” registered under the Exchange Act. The depositary was created to hold securities of institutions that have accounts with the depositary and to facilitate the clearance and settlement of securities transactions among its participants in such securities through electronic book-entry changes in accounts of participants, thereby eliminating the need for physical movement of securities certificates. The depositary’s participants include securities brokers and dealers (which may include the initial purchasers), banks, trust companies, clearing corporations and certain other organizations some of whom (or their representatives) own DTC. Access to the depositary’s book-entry system is also available to others such as banks, brokers, dealers and trust companies that clear through or maintain a custodial relationship with a participant, whether directly or indirectly.

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THE EXCHANGE OFFER

General

We hereby offer to exchange a like principal amount of new bonds for any or all outstanding old bonds on the terms and subject to the conditions set forth in this prospectus. We often refer to this offer as the “exchange offer.” You may tender some or all of your outstanding old bonds pursuant to this exchange offer. As of the date of this prospectus, $425,000,000 aggregate principal amount of the old bonds are outstanding. Our obligation to accept old bonds for exchange pursuant to the exchange offer is subject to certain conditions set forth hereunder.

Purpose and Effect of the Exchange Offer

In connection with the offering of the old bonds, which was consummated on June 6, 2019, we entered into a registration rights agreement with the initial purchasers of the old bonds, under which we agreed:

(1)    to use our reasonable best efforts to cause to be filed a registration statement with respect to an offer to exchange the old bonds for a new issue of securities, with terms substantially the same as of the old bonds but registered under the Securities Act;

(2)    to use our reasonable best efforts to cause the registration statement to be declared effective by the SEC and remain effective until the closing of the exchange offer; and

(3)    to use our reasonable best efforts to consummate the exchange offer and issue the new bonds within 390 days after the closing of the old bonds offering.

The registration rights agreement provides that, if (a) we do not consummate the exchange offer registration on or prior to the date that is 390 days following the issuance of the old bonds (the “exchange offer closing deadline”) or (b) we have not caused to become effective a shelf registration statement by the 90th day after such obligation arises (the “shelf effectiveness deadline”) (which in no event, however, shall be earlier than the exchange offer closing deadline), the interest rate for the bonds will increase by a rate of 0.25% per annum from the exchange offer closing deadline or the shelf effectiveness deadline, as applicable, during the first 90 day period, and shall further increase by 0.25% per annum beginning on the 91st day following either of the foregoing, until the exchange offer is completed, in the case of an exchange offer, or the shelf registration statement is declared effective. The additional interest rate for the old bonds will not at any time exceed 0.50% per annum notwithstanding our failure to meet more than one of these requirements.

The exchange offer is not being made to, nor will we accept tenders for exchange from, holders of old bonds in any jurisdiction in which the exchange offer or acceptance of the exchange offer would violate the securities or blue sky laws of that jurisdiction. Furthermore, each holder of old bonds that wishes to exchange their old bonds for new bonds in this exchange offer will be required to make certain representations as set forth herein.

Terms of the Exchange Offer; Period for Tendering Old Bonds

This prospectus contains the terms and conditions of the exchange offer. Upon the terms and subject to the conditions included in this prospectus, we will accept for exchange old bonds which are properly tendered on or prior to the expiration date, unless you have previously withdrawn them.

• When you tender to us old bonds as provided below, our acceptance of the old bonds will constitute a binding agreement between you and us upon the terms and subject to the conditions in this prospectus.

• For each $2,000 principal amount of old bonds (and $1,000 principal amount of old bonds in excess thereof) surrendered to us in the exchange offer, we will give you $2,000 principal amount of new bonds (and $1,000 principal amount of new bonds in excess thereof). Outstanding bonds may only be tendered in denominations of $2,000 and integral multiples of $1,000 in excess thereof.

• We will keep the exchange offer open for not less than 20 business days, or longer if required by applicable law, after the date that we first mail notice of the exchange offer to the holders of the old bonds. We are sending this prospectus on or about the date of this prospectus to all of the registered holders of old bonds at their addresses listed in the trustee’s security register with respect to the old bonds.

• The exchange offer expires at 5:00 P.M., New York City time, on ; provided, however, that we, in our sole discretion, may extend the period of time for which the exchange offer is open. The term

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“expiration date” means or, if extended by us, the latest time and date to which the exchange offer is extended.

• As of the date of this prospectus, $425,000,000 aggregate principal amount of the old bonds were outstanding. The exchange offer is not conditioned upon any minimum principal amount of old bonds being tendered.

• Our obligation to accept old bonds for exchange in the exchange offer is subject to the conditions that we describe in the section called “Conditions to the Exchange Offer” below.

• We expressly reserve the right, at any time, to extend the period of time during which the exchange offer is open, and thereby delay acceptance of any old bonds, by giving oral or written notice of an extension to the exchange agent and notice of that extension to the holders as described below. During any extension, all old bonds previously tendered will remain subject to the exchange offer unless withdrawal rights are exercised. Any old bonds not accepted for exchange for any reason will be returned without expense to the tendering holder promptly following the expiration or termination of the exchange offer.

• We expressly reserve the right to amend or terminate the exchange offer, and not to accept for exchange any old bonds that we have not yet accepted for exchange, if any of the conditions of the exchange offer specified below under “Conditions to the Exchange Offer” are not satisfied. In the event of a material change in the exchange offer, including the waiver of a material condition, we will extend the offer period if necessary so that at least five business days remain in the exchange offer following notice of the material change.

• We will give oral or written notice of any extension, amendment, termination or non-acceptance described above to holders of the old bonds promptly. If we extend the expiration date, we will give notice by means of a press release or other public announcement no later than 9:00 a.m., New York City time, on the business day after the previously scheduled expiration date. Without limiting the manner in which we may choose to make any public announcement and subject to applicable law, we will have no obligation to publish, advertise or otherwise communicate any public announcement other than by issuing a release to Dow Jones and Company News Agency and/or other similar news service.

• Holders of old bonds do not have any appraisal or dissenters’ rights in connection with the exchange offer.

• Old bonds which are not tendered for exchange or are tendered but not accepted in connection with the exchange offer will remain outstanding and be entitled to the benefits of the indenture, but will not be entitled to any further registration rights under the registration rights agreement.

• We intend to conduct the exchange offer in accordance with the applicable requirements of the Exchange Act and the rules and regulations of the SEC thereunder.

Important rules concerning the exchange offer

You should note that:

• All questions as to the validity, form, eligibility, time of receipt and acceptance of old bonds tendered for exchange will be determined by us in our sole discretion, which determination shall be final and binding.

• We reserve the absolute right to reject any and all tenders of any particular old bonds not properly tendered or to not accept any particular old bonds which acceptance might, in our judgment or the judgment of our counsel, be unlawful.

• We also reserve the absolute right to waive any defects or irregularities or conditions of the exchange offer as to any particular old bonds either before or after the expiration date, including the right to waive the ineligibility of any holder who seeks to tender old bonds in the exchange offer. Unless we agree to waive any defect or irregularity in connection with the tender of old bonds for exchange, you must cure any defect or irregularity within any reasonable period of time as we shall determine.

• Our interpretation of the terms and conditions of the exchange offer as to any particular old bonds either before or after the expiration date shall be final and binding on all parties.

• Neither DP&L, the exchange agent nor any other person shall be under any duty to give notification of any defect or irregularity with respect to any tender of old bonds for exchange, nor shall any of them incur any liability for failure to give any notification.

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Procedures for Tendering Old Bonds

What to submit and how

If you, as the registered holder of an old bonds, wish to tender your old bonds for exchange in the exchange offer, you must contact a DTC participant to complete the book-entry transfer procedures described below on or prior to the expiration date.

In addition,

(1)    a timely confirmation of a book-entry transfer of old bonds, if such procedure is available, into the exchange agent’s account at DTC using the procedure for book-entry transfer described below, must be received by the exchange agent prior to the expiration date, or

(2)    you must comply with the guaranteed delivery procedures described below.

The method of delivery of notices of guaranteed delivery is at your election and risk. In all cases, sufficient time should be allowed to assure timely delivery.

How to sign your documents

Signatures on a notice of withdrawal must be guaranteed unless the old bonds being surrendered for exchange are tendered for the account of an eligible institution.

If signatures on a notice of withdrawal are required to be guaranteed, the guarantees must be by any of the following eligible institutions:

• a firm which is a member of a registered national securities exchange or a member of the Financial Industry Regulatory Authority, Inc. or

• a commercial bank or trust company having an office or correspondent in the United States.

Acceptance of Old Bonds for Exchange; Delivery of New Bonds

Once all of the conditions to the exchange offer are satisfied or waived, we will accept, promptly after the expiration date, all old bonds properly tendered and will issue the new bonds promptly after the expiration of the exchange offer. See “Conditions to the Exchange Offer” below. For purposes of the exchange offer, our giving of oral or written notice of our acceptance to the exchange agent will be considered our acceptance of the exchange offer.

In all cases, we will issue new bonds in exchange for old bonds that are accepted for exchange only after timely receipt by the exchange agent of a timely book-entry confirmation of transfer of old bonds into the exchange agent’s account at DTC using the book-entry transfer procedures described below.

If we do not accept any tendered old bonds for any reason included in the terms and conditions of the exchange offer, non-exchanged old bonds will be credited to an account maintained with DTC promptly following the expiration or termination of the exchange offer.

Book-Entry Transfer

The exchange agent will make a request to establish an account with respect to the old bonds at DTC for purposes of the exchange offer promptly after the date of this prospectus. Any financial institution that is a participant in DTC’s systems may make book-entry delivery of old bonds by causing DTC to transfer old bonds into the exchange agent’s account in accordance with DTC’s Automated Tender Offer Program procedures for transfer. However, the exchange for the old bonds so tendered will only be made after timely confirmation of book-entry transfer of old bonds into the exchange agent’s account, and timely receipt by the exchange agent of an agent’s message, transmitted by DTC and received by the exchange agent and forming a part of a book-entry confirmation. The agent’s message must state that DTC has received an express acknowledgment from the participant tendering old bonds that are the subject of that book-entry confirmation that the participant has received and agrees to be bound by the terms of the prospectus, and that we may enforce the agreement against that participant.

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Although delivery of old bonds may be effected through book-entry transfer into the exchange agent’s account at DTC, an agent’s message, properly completed and duly executed, with any required signature guarantees, must in any case be delivered to and received by the exchange agent at its address listed under “¯Exchange Agent” on or prior to the expiration date.

If your old bonds are held through DTC, you must complete a form called “instructions to registered holder and/or book-entry participant,” which will instruct the DTC participant through whom you hold your securities of your intention to tender your old bonds or not tender your old bonds. Please note that delivery of documents to DTC in accordance with its procedures does not constitute delivery to the exchange agent and we will not be able to accept your tender of bonds until the exchange agent receives an agent’s message and a book-entry confirmation from DTC with respect to your bonds. A copy of that form is available from the exchange agent.

Guaranteed Delivery Procedures

If you are a registered holder of old bonds and you want to tender your old bonds but your old bonds are not immediately available, or time will not permit an agent’s message or your old bonds to reach the exchange agent before the expiration date, or the procedure for book-entry transfer cannot be completed on a timely basis, a tender may be effected if:

• the tender is made through an eligible institution,

• prior to the expiration date, the exchange agent receives, by facsimile transmission, mail or hand delivery, from that eligible institution a properly completed and duly executed notice of guaranteed delivery, substantially in the form provided by us, stating:

• the name and address of the holder of old bonds;

• the amount of old bonds tendered;

• the tender is being made by delivering that notice; and

• guaranteeing that within three New York Stock Exchange trading days after the date of execution of the notice of guaranteed delivery, a book-entry confirmation will be deposited by that eligible institution with the exchange agent, and

• a book-entry confirmation is received by the exchange agent within three New York Stock Exchange trading days after the date of execution of the Notice of Guaranteed Delivery.

Withdrawal Rights

You can withdraw your tender of old bonds at any time on or prior to the expiration date.

For a withdrawal to be effective, a written notice of withdrawal must be received by the exchange agent at one of the addresses listed below under “Exchange Agent.” Any notice of withdrawal must specify:

• the name of the person having tendered the old bonds to be withdrawn

• the old bonds to be withdrawn

• the principal amount of the old bonds to be withdrawn; and

• any notice of withdrawal must specify the name and number of the account at DTC to be credited with the withdrawn old bonds and otherwise comply with the procedures of that facility.

Please note that all questions as to the validity, form, eligibility and time of receipt of notices of withdrawal will be determined by us, and our determination shall be final and binding on all parties. Any old bonds so withdrawn will be considered not to have been validly tendered for exchange for purposes of the exchange offer. If you have properly withdrawn old bonds and wish to re-tender them, you may do so by following one of the procedures described under “Procedures for Tendering Old Bonds” above at any time on or prior to the expiration date.

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Conditions to the Exchange Offer

Notwithstanding any other provisions of the exchange offer, we will not be required to accept for exchange, or to issue new bonds in exchange for, any old bonds and may terminate or amend the exchange offer, if at any time before the expiration of the exchange offer:

• that acceptance or issuance would violate applicable law or any interpretation of the staff of the SEC; or

• any holder of the old bonds exchanged in the exchange offer has not represented that all new bonds to be received by it shall be acquired in the ordinary course of its business and that at the time of the consummation of the exchange offer it shall have no arrangement or understanding with any person to participate in the distribution (within the meaning of the Securities Act) of the new bonds and shall have made such other representations as may be reasonably necessary under applicable SEC rules, regulations or interpretations to render the use of Form S-4 or other appropriate form under the Securities Act available.

The conditions described above are for our sole benefit and may be asserted by us regardless of the circumstances giving rise to that condition. Our failure at any time to exercise the foregoing rights shall not be considered a waiver by us of that right. Our rights described in the prior paragraph are ongoing rights which we may assert at any time and from time to time prior to the expiration of the exchange offer.

In addition, we will not accept for exchange any old bonds tendered, and no new bonds will be issued in exchange for any old bonds, if at that time any stop order shall be threatened or in effect with respect to the exchange offer to which this prospectus relates or the qualification of the indenture under the Trust Indenture Act.

Exchange Agent

The Bank of New York Mellon has been appointed as the exchange agent for the exchange offer. Questions and requests for assistance, requests for additional copies of this prospectus and requests for notices of guaranteed delivery should be directed to the exchange agent, addressed as follows:

Deliver To:

By Registered, Regular or Certified Mail or Overnight Delivery:

The Bank of New York Mellon

111 Sanders Creek Parkway

East Syracuse, NY 13057

Attn: Corporate Trust Reorg - Eric Herr

Facsimile Transmissions:

732-667-9408

To Confirm by Email:

ct_reorg_unit_inquiries@bnymellon.com

To Confirm by Telephone or for Information:

315-414-3362

Delivery to an address other than as listed above or transmission of instructions via facsimile other than as listed above does not constitute a valid delivery.

Fees and Expenses

The principal solicitation is being made by mail; however, additional solicitation may be made by telegraph, telephone or in person by our officers, regular employees and affiliates. We will not pay any additional compensation to any of our officers and employees who engage in soliciting tenders. We will not make any payment to brokers, dealers, or others soliciting acceptances of the exchange offer. However, we will pay the exchange agent reasonable and customary fees for its services and will reimburse it for its reasonable out-of-pocket expenses in connection with the exchange offer.

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The estimated cash expenses to be incurred in connection with the exchange offer, including legal, accounting, SEC filing, printing and exchange agent expenses, will be paid by us and are estimated in the aggregate to be $270,000.

Accounting Treatment

We will record the new bonds in our accounting records at the same carrying value as the old bonds, which is the aggregate principal amount as reflected in our accounting records on the date of exchange. Accordingly, we will not recognize any gain or loss for accounting purposes upon the consummation of this exchange offer. We will capitalize the expenses of this exchange offer and amortize them over the life of the bonds.

Transfer Taxes

Holders who tender their old bonds for exchange will not be obligated to pay any transfer taxes in connection therewith, except that holders who instruct us to register new bonds in the name of, or request that old bonds not tendered or not accepted in the exchange offer be returned to, a person other than the registered tendering holder will be responsible for the payment of any applicable transfer tax thereon.

Resale of the New Bonds

Under existing interpretations of the staff of the SEC contained in several no-action letters to third parties, the new bonds would in general be freely transferable after the exchange offer without further registration under the Securities Act. The relevant no-action letters include the Exxon Capital Holdings Corporation letter, which was made available by the SEC on May 13, 1988, and the Morgan Stanley & Co. Incorporated letter, made available on June 5, 1991.

However, any purchaser of old bonds who is an “affiliate” of DP&L or who intends to participate in the exchange offer for the purpose of distributing the new bonds

(1)    will not be able to rely on the interpretation of the staff of the SEC,

(2)    will not be able to tender its old bonds in the exchange offer and

(3)    must comply with the registration and prospectus delivery requirements of the Securities Act in connection with any sale or transfer of the securities unless that sale or transfer is made using an exemption from those requirements.

In addition, in connection with any resales of new bonds, any broker-dealer participating in the exchange offer who acquired securities for its own account as a result of market-making or other trading activities must deliver a prospectus meeting the requirements of the Securities Act. The SEC has taken the position in the Shearman & Sterling no-action letter, which it made available on July 2, 1993, that participating broker-dealers may fulfill their prospectus delivery requirements with respect to the new bonds, other than a resale of an unsold allotment from the original sale of the old bonds, with the prospectus contained in the exchange offer registration statement. Under the registration rights agreement, we are required to allow participating broker-dealers and other persons, if any, subject to similar prospectus delivery requirements to use this prospectus as it may be amended or supplemented from time to time, in connection with the resale of new bonds.

Failure to Exchange

Holders of old bonds who do not exchange their old bonds for new bonds under the exchange offer will remain subject to the restrictions on transfer of such old bonds as set forth in the legend printed on the bonds as a consequence of the issuance of the old bonds pursuant to the exemptions from, or in transactions not subject to, the registration requirements of the Securities Act and applicable state securities laws, and otherwise set forth in the confidential offering memorandum distributed in connection with the private offering of the old bonds.

Other

Participating in the exchange offer is voluntary, and you should carefully consider whether to accept. You are strongly urged to consult your financial, legal and tax advisors in making your own decision on what action to take.

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U.S. FEDERAL INCOME TAX CONSEQUENCES

The exchange of old bonds for new bonds in the exchange offer will not be a taxable event for holders. When a holder exchanges an old bond for a new bond in the exchange offer, the holder will have the same adjusted tax basis and holding period in the new bond as in the old bond immediately before the exchange.

Persons considering the exchange of old bonds for new bonds should consult their own tax advisers concerning the U.S. federal income tax consequences in light of their particular situations as well as any tax consequences arising under the laws of any other taxing jurisdiction.

PLAN OF DISTRIBUTION

Each broker-dealer that receives new bonds for its own account in the exchange offer must acknowledge that it will deliver a prospectus in connection with any resale of new bonds. This prospectus, as it may be amended or supplemented from time to time, may be used by a broker-dealer in connection with resales of new bonds received in exchange for old bonds where old bonds were acquired as a result of market-making activities or other trading activities. We have agreed that, for a period of 90 days after the expiration date, we will make this prospectus, as amended or supplemented, available to any broker-dealer for use in connection with any resale of new bonds received by it in exchange for old bonds.

We will not receive any proceeds from any sale of new bonds by broker-dealers.

New bonds received by broker-dealers for their own account in the exchange offer may be sold from time to time in one or more transactions:

• in the over-the-counter market;

• in negotiated transactions;

• through the writing of options on the new bonds; or

• a combination of those methods of resale,

at market prices prevailing at the time of resale, at prices related to prevailing market prices or negotiated prices.

Any resale may be made:

• directly to purchasers; or

• to or through brokers or dealers who may receive compensation in the form of commissions or concessions from any broker-dealer or the purchasers of any new bonds.

Any broker-dealer that resells new bonds that were received by it for its own account in the exchange offer and any broker or dealer that participates in a distribution of those new bonds may be considered to be an “underwriter” within the meaning of the Securities Act. Any profit on any resale of those new bonds and any commission or concessions received by any of those persons may be considered to be underwriting compensation under the Securities Act.

We have agreed to pay all expenses incident to the exchange offer, other than commissions or concessions of any brokers or dealers and will indemnify the holders of the securities, including any broker-dealers, against some liabilities, including liabilities under the Securities Act.

VALIDITY OF SECURITIES

Davis Polk & Wardwell LLP will opine for us on whether the new bonds are valid and binding obligations of The Dayton Power and Light Company and will rely on the opinion of Brian Hylander, Assistant General Counsel of The Dayton Power and Light Company with respect to certain matters under the laws of the State of Ohio.

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EXPERTS

The financial statements of The Dayton Power and Light Company at December 31, 2018 and 2017, and for each of the three years in the period ended December 31, 2018, and the related notes and schedule appearing in this registration statement have been audited by Ernst & Young LLP, independent registered public accounting firm, as set forth in their report thereon appearing elsewhere herein, and are included in reliance upon such report given on the authority of such firm as experts in accounting and auditing.

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WHERE YOU CAN FIND MORE INFORMATION

We have filed with the SEC, Washington, D.C. 20549, a registration statement on Form S-4 under the Securities Act with respect to our offering of the new bonds. This prospectus does not contain all of the information set forth in the registration statement and the exhibits and schedules thereto. For further information with respect to the company and the new bonds, reference is made to the registration statement and the exhibits and any schedules filed therewith. Statements contained in this prospectus as to the contents of any contract or other document referred to are not necessarily complete and in each instance, if such contract or document is filed as an exhibit, reference is made to the copy of such contract or other document filed as an exhibit to the registration statement, each statement being qualified in all respects by such reference. A copy of the registration statement, including exhibits and schedules thereto, is available to the public on the SEC’s website at https://www.sec.gov.

If for any reason we are not required to comply with the reporting requirements of the Securities Exchange Act of 1934, as amended, or we do not otherwise report on an annual or quarterly basis on forms provided for such annual and quarterly reporting pursuant to rules and regulations promulgated by the SEC, we are still required under the indenture to deliver (which may be accomplished through posting on the internet) to the trustee and to holders of the bonds, without any cost to any holder: (1) within 90 days after the end of each fiscal year, audited financial statements and (2) within 45 days after the end of each of the first three fiscal quarters of each fiscal year, quarterly unaudited financial statements. We are also required under the indenture to provide without charge upon the written request of (1) a holder of any bonds or (2) a prospective holder of any of the bonds who is a “qualified institutional buyer” within the meaning of Rule 144A and is designated by an existing holder of any of the bonds with the information with respect to the Company required to be delivered under Rule 144A(d)(f) under the Securities Act to enable resales of the bonds to be made pursuant to Rule 144A.

Any such requests should be directed to us at: The Dayton Power and Light Company, 1065 Woodman Drive, Dayton, Ohio 45432, Phone: (937) 259-7215, Attention: Treasurer.

We also maintain an Internet site at https://www.dpandl.com. Our website and the information contained therein or connected thereto shall not be deemed to be a part of this prospectus or the registration statement of which it forms a part.

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INDEX TO FINANCIAL STATEMENTS

The Dayton Power & Light Company Annual Financial Statements
December 31, 2018, 2017 and 2016
Report of Independent Registered Public Accounting Firm	F-2
Statements of Operations	F-3
Statements of Comprehensive Income / (Loss)	F-4
Balance Sheets	F-5
Statements of Cash Flows	F-6
Statements of Shareholder’s Equity	F-7
Notes to Financial Statements	F-8
Schedule II – Valuation and Qualifying Accounts	F-41
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.
The Dayton Power & Light Company Condensed Financial Statements
September 30, 2019
Condensed Statements of Operations	F-42
Condensed Statements of Comprehensive Income	F-43
Condensed Balance Sheets	F-44
Condensed Statements of Cash Flows	F-45
Condensed Statements of Shareholder's Equity	F-46
Notes to Condensed Financial Statements	F-47

F-1

Report of Independent Registered Public Accounting Firm

Report of Independent Registered Public Accounting Firm

To the Shareholder and Board of Directors of The Dayton Power & Light Company

Opinion on the Financial Statements

We have audited the accompanying balance sheets of The Dayton Power & Light Company (the Company) as of December 31, 2018 and 2017, the related statements of operations, comprehensive income/(loss), cash flows and shareholder’s equity for each of the three years in the period ended December 31, 2018, and the related notes and schedule (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2018 and 2017, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2018 in conformity with U.S. generally accepted accounting principles.

Basis for Opinion

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ Ernst & Young LLP

We have served as the Company’s auditor since 2012.

Indianapolis, Indiana

February 26, 2019

F-2

THE DAYTON POWER AND LIGHT COMPANY
Statements of Operations
	Years ended December 31,
$ in millions	2018			2017			2016
Revenues	$	738.7		$	720.0		$	808.0
Cost of revenues:
Net fuel costs	2.4			0.5			5.3
Net purchased power cost	301.3			289.8			316.7
Total cost of revenues	303.7			290.3			322.0
Gross margin	435.0			429.7			486.0
Operating expenses:
Operation and maintenance	139.7			156.5			178.4
Depreciation and amortization	74.5			75.3			71.0
General taxes	73.1			76.3			68.0
Loss / (gain) on asset disposal	0.2			(0.5		)	(0.4		)
Loss on disposal of business (Note 15)	12.4			—			—
Total operating expenses	299.9			307.6			317.0
Operating income	135.1			122.1			169.0
Other income / (expense), net
Interest expense	(27.3		)	(30.5		)	(24.7		)
Charge for early redemption of debt	(0.6		)	(1.1		)	(0.5		)
Other income / (expense)	(2.8		)	(2.0		)	(0.2		)
Total other expense, net	(30.7		)	(33.6		)	(25.4		)
Income from continuing operations before income tax	104.4			88.5			143.6
Income tax expense from continuing operations	17.7			31.1			46.0
Net income from continuing operations	86.7			57.4			97.6
Discontinued operations (Note 14)
Loss from discontinued operations before income tax	—			(56.3		)	(1,338.7		)
Income tax benefit from discontinued operations	—			(15.9		)	(468.4		)
Net loss from discontinued operations	—			(40.4		)	(870.3		)
Net income / (loss)	86.7			17.0			(772.7		)
Dividends on preferred stock	—			—			0.7
Income / (loss) attributable to common stock	$	86.7		$	17.0		$	(773.4	)

See Notes to Financial Statements.

F-3

THE DAYTON POWER AND LIGHT COMPANY
Statements of Comprehensive Income / (Loss)
	Years ended December 31,
$ in millions	2018			2017			2016
Net income / (loss)	$	86.7		$	17.0		$	(772.7	)
Equity securities activity:
Change in fair value of equity securities, net of income tax expense of $0.0, ($0.2) and ($0.1) for each respective period	—			0.5			0.2
Reclassification to earnings, net of income tax benefit of $0.0, $0.0 and $0.0 for each respective period	—			(0.1		)	—
Net change in fair value of equity securities	—			0.4			0.2
Derivative activity:
Change in derivative fair value, net of income tax benefit / (expense) of $0.1, ($7.2) and ($8.7) for each respective period	(0.1		)	12.4			16.1
Reclassification to earnings, net of income tax benefit of $0.4, $0.2 and $0.2 for each respective period	(0.7		)	(0.7		)	(0.8		)
Reclassification of earnings related to discontinued operations, net of income tax benefit of $0.0, $3.0 and $16.2 for each respective period	—			(5.5		)	(29.2		)
Net change in fair value of derivatives	(0.8		)	6.2			(13.9		)
Pension and postretirement activity:
Prior service cost for the period, net of income tax benefit of $0.6, $1.0 and $0.0 for each respective period	(2.2		)	(1.9		)	(0.1		)
Net gain / (loss) for the period, net of income tax benefit / (expense) of ($0.4), $0.4 and $1.1 for each respective period	1.7			(0.8		)	(5.9		)
Reclassification to earnings, net of income tax expense of ($1.0), ($2.3) and ($1.8) for each respective period	3.3			4.5			5.9
Net change in unfunded pension and postretirement obligations	2.8			1.8			(0.1		)
Other comprehensive income / (loss)	2.0			8.4			(13.8		)
Net comprehensive income / (loss)	$	88.7		$	25.4		$	(786.5	)

See Notes to Financial Statements.

F-4

THE DAYTON POWER AND LIGHT COMPANY
Balance Sheets
$ in millions	December 31, 2018			December 31, 2017
ASSETS
Current assets:
Cash and cash equivalents	$	45.0		$	5.2
Restricted cash	21.2			0.4
Accounts receivable, net (Note 2)	90.4			70.8
Inventories (Note 2)	7.7			7.3
Taxes applicable to subsequent years	72.4			71.1
Regulatory assets, current (Note 3)	41.1			23.9
Taxes receivable	19.6			6.5
Other prepayments and current assets	13.3			14.6
Total current assets	310.7			199.8
Property, plant and equipment:
Property, plant and equipment	2,274.4			2,247.2
Less: Accumulated depreciation and amortization	(988.0		)	(987.3		)
	1,286.4			1,259.9
Construction work in process	31.7			41.5
Total net property, plant and equipment	1,318.1			1,301.4
Other non-current assets:
Regulatory assets, non-current (Note 3)	152.6			163.2
Intangible assets, net of amortization	17.2			18.8
Other deferred assets	21.0			12.7
Total other non-current assets	190.8			194.7
Total Assets	$	1,819.6		$	1,695.9
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Current portion - long-term debt (Note 7)	$	4.6		$	4.6
Short-term debt	—			10.0
Accounts payable	55.8			46.6
Accrued taxes	75.7			76.6
Accrued interest	0.4			0.8
Customer security deposits	21.3			21.8
Regulatory liabilities, current (Note 3)	34.9			14.8
Other current liabilities	17.5			12.9
Total current liabilities	210.2			188.1
Non-current liabilities:
Long-term debt (Note 7)	581.5			642.0
Deferred taxes (Note 8)	131.7			131.0
Taxes payable	77.1			75.8
Regulatory liabilities, non-current (Note 3)	278.3			221.2
Pension, retiree and other benefits (Note 9)	83.2			91.1
Asset retirement obligations	4.7			8.0
Other deferred credits	7.6			8.0
Total non-current liabilities	1,164.1			1,177.1
Commitments and contingencies (Note 11)
Common shareholder's equity:
Common stock, par value of $0.01 per share	0.4			0.4
50,000,000 shares authorized, 41,172,173 shares issued and outstanding
Other paid-in capital	711.8			685.8
Accumulated other comprehensive loss	(35.3		)	(36.2		)
Accumulated deficit	(231.6		)	(319.3		)
Total common shareholder's equity	445.3			330.7
Total Liabilities and Shareholder's Equity	$	1,819.6		$	1,695.9

See Notes to Financial Statements.

F-5

THE DAYTON POWER AND LIGHT COMPANY
Statements of Cash Flows
	Years ended December 31,
$ in millions	2018			2017			2016
Cash flows from operating activities:
Net income / (loss)	$	86.7		$	17.0		$	(772.7	)
Adjustments to reconcile Net income / (loss) to Net cash from operating activities
Depreciation and amortization	74.5			87.2			120.3
Amortization of deferred financing costs	3.1			1.1			2.9
Unrealized loss (gain) on derivatives	—			(1.0		)	(4.2		)
Deferred income taxes	16.3			8.1			(477.5		)
Charge for early redemption of debt	0.6			1.1			0.5
Fixed-asset impairment	—			66.3			1,353.5
Loss on disposal of business	12.4			—			—
Loss / (Gain) on asset disposal	0.2			15.7			(0.1		)
Changes in certain assets and liabilities:
Accounts receivable	13.5			14.6			(8.3		)
Inventories	(0.3		)	10.3			32.2
Prepaid taxes	—			—			2.7
Taxes applicable to subsequent years	(1.3		)	6.4			—
Deferred regulatory costs, net	(9.2		)	(23.7		)	4.1
Accounts payable	3.8			(48.7		)	14.6
Accrued taxes payable / receivable	(12.7		)	(17.5		)	(10.5		)
Accrued interest payable	(0.4		)	(1.3		)	(2.0		)
Pension, retiree and other benefits	(2.4		)	4.8			3.0
Other	11.0			(5.0		)	(21.3		)
Net cash provided by operating activities	195.8			135.4			237.2
Cash flows from investing activities:
Capital expenditures	(93.1		)	(101.7		)	(128.3		)
Payments on disposal of business	(14.5		)	—			—
Proceeds from sale of property	10.6			—			0.2
Insurance proceeds	0.4			12.5			6.1
Other investing activities, net	(0.3		)	(0.3		)	0.4
Net cash used in investing activities	(96.9		)	(89.5		)	(121.6		)
Cash flows from financing activities
Dividends and returns of capital paid to parent	(43.8		)	(39.0		)	(70.0		)
Dividends paid on preferred stock	—			—			(0.7		)
Retirement of long-term debt	(64.5		)	(104.5		)	(445.3		)
Capital contribution from parent	80.0			70.0			—
Issuance of long-term debt	—			—			442.8
Deferred financing costs	—			—			(8.5		)
Redemption on preferred stock	—			—			(23.5		)
Borrowings from revolving credit facilities	30.0			40.0			—
Repayment of borrowings from revolving credit facilities	(40.0		)	(30.0		)	—
Borrowings from related party	—			30.0			10.0
Repayment of borrowings from related party	—			(35.0		)	(40.0		)
Other financing activities, net	—			(0.4		)	—
Net cash used in financing activities	(38.3		)	(68.9		)	(135.2		)
Increase in cash and restricted cash of discontinued operations and held-for-sale businesses	—			27.0			15.8
Cash, cash equivalents, and restricted cash:							.
Net increase / (decrease) in cash, cash equivalents and restricted cash	60.6			4.0			(3.8		)
Balance at beginning of year	5.6			1.6			5.4
Cash, cash equivalents, and restricted cash at end of year	$	66.2		$	5.6		$	1.6
Supplemental cash flow information:
Interest paid, net of amounts capitalized	$	22.9		$	28.4		$	21.4
Income taxes paid, net	$	13.1		$	28.1		$	0.3
Non-cash financing and investing activities:
Accruals for capital expenditures	$	10.8		$	19.7		$	14.8
Equity contribution to settle liability	$	—		$	—		$	7.5
Distribution of generation assets to subsidiary of parent	$	(10.0	)	$	(86.2	)	$	—

See Notes to Financial Statements.

F-6

THE DAYTON POWER AND LIGHT COMPANY
Statements of Shareholder's Equity
	Common Stock (a)
$ in millions	Outstanding Shares	Amount		Other Paid-in Capital			Accumulated Other Comprehensive Income / (Loss)			Retained Earnings / Accumulated Deficit			Total
Year ended December 31, 2016
Beginning balance	41,172,173	$	0.4	$	803.7		$	(28.7	)	$	437.3		$	1,212.7
Net comprehensive loss							(13.8		)	(772.7		)	(786.5		)
Common stock dividends and returns of capital										(70.0		)	(70.0		)
Preferred stock dividends										(0.7		)	(0.7		)
Other				7.0						(0.2		)	6.8
Ending balance	41,172,173	0.4		810.7			(42.5		)	(406.3		)	362.3
Year ended December 31, 2017
Net comprehensive income							8.4			17.0			25.4
Common stock dividends and returns of capital				(39.0		)							(39.0		)
Transfer of generation assets to subsidiary of parent				(86.2		)	(2.1		)				(88.3		)
Capital contribution from parent				70.0									70.0
Other (b)				(69.7		)				70.0			0.3
Ending balance	41,172,173	0.4		685.8			(36.2		)	(319.3		)	330.7
Year ended December 31, 2018
Net comprehensive income							2.0			86.7			88.7
Common stock dividends and returns of capital				(43.8		)							(43.8		)
Transfer of generation assets to subsidiary of parent (c)				(10.0		)							(10.0		)
Capital contribution from parent				80.0									80.0
Other (d)				(0.2		)	(1.1		)	1.0			(0.3		)
Ending balance	41,172,173	$	0.4	$	711.8		$	(35.3	)	$	(231.6	)	$	445.3

(a) $0.01 par value, 50,000,000 shares authorized.

(b) In 2017, we reclassified the presentation of the December 2016 dividend payment of $70.0 million. This was originally recorded as a charge to Accumulated deficit but was reclassified as a charge to Other paid-in capital as it represented a return of capital.

(c) In 2018, DP&L transferred additional deferred taxes to AES Ohio Generation under the provisions of SAB 118 through an equity transaction with DPL. See Note 8 – Income Taxes for additional information.

(d) ASU 2016-01 “Recognition and Measurement of Financial Assets and Financial Liabilities” was effective as of January 1, 2018. This ASU requires the change in the fair value of equity instruments to be recorded in income rather than in OCI. Equity Instruments were defined to include all mutual funds, regardless of the underlying investments.

See Notes to Financial Statements.

F-7

The Dayton Power and Light Company

Notes to Financial Statements

For the years ended December 31, 2018, 2017 and 2016

Note 1 – Overview and Summary of Significant Accounting Policies

Description of Business

DP&L is a public utility incorporated in 1911 under the laws of Ohio. Beginning in 2001, Ohio law gave consumers the right to choose the electric generation supplier from whom they purchase retail generation service, however transmission and distribution services are still regulated. DP&L has the exclusive right to provide such service to its approximately 525,000 customers located in West Central Ohio. DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a 6,000 square mile area of West Central Ohio. Since January 2016, DP&L has been sourcing all of the generation for its SSO customers through a competitive bid process. Through September 30, 2017, DP&L owned undivided interests in multiple coal-fired power stations and multiple peaking electric generating facilities as well as numerous transmission facilities. On October 1, 2017, the DP&L-owned generating facilities, excluding the Beckjord Facility and Hutchings EGU, were transferred to AES Ohio Generation, an affiliate of DP&L and wholly-owned subsidiary of DPL, through an asset contribution agreement to a subsidiary that was merged into AES Ohio Generation. Also, Stuart Station Unit 1 was retired on October 1, 2017. Principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, manufacturing and defense. DP&L's sales reflect the general economic conditions, seasonal weather patterns of the area and the market price of electricity. Through the date of Generation Separation, DP&L sold energy and capacity into the wholesale market. As a result of Generation Separation, DP&L now only has one reportable segment, Transmission and Distribution. In addition to DP&L's electric transmission and distribution businesses, the Transmission and Distribution segment includes revenues and costs associated with DP&L's investment in OVEC and the historical results of DP&L’s Beckjord and Hutchings Coal generating facilities, which were either closed or sold in prior periods.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs or overcollections of riders.

DP&L employed 647 people at January 31, 2019. Approximately 58% of all employees are under a collective bargaining agreement.

Financial Statement Presentation

DP&L does not have any subsidiaries.

Through June 2018, DP&L had undivided ownership interests in numerous transmission facilities. These undivided interests in jointly-owned facilities were accounted for on a pro rata basis in the Financial Statements. In June 2018, DP&L closed on a transmission asset transaction with Duke and AEP, where ownership stakes in certain previously co-owned transmission assets were exchanged to eliminate co-ownership. Each previously co-owned transmission asset became wholly-owned by one of DP&L, Duke or AEP after the transaction. See Note 4 – Property, Plant and Equipment for more information.

We have evaluated subsequent events through the date this report is issued.

Certain amounts from prior periods have been reclassified to conform to the current period presentation.

The preparation of financial statements in conformity with GAAP requires us to make estimates and judgments that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the revenues and expenses of the periods reported. Actual results could differ from these estimates. Significant items subject to such estimates and judgments include: the carrying value of Property, plant and equipment; unbilled revenues; the valuation of derivative instruments; the valuation of insurance and claims liabilities; the valuation of allowances for receivables and deferred income taxes; regulatory assets and liabilities; reserves recorded for income tax exposures; litigation; contingencies; the valuation of AROs; and assets and liabilities related to employee benefits.

F-8

Revenue Recognition

Revenues are recognized from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Energy sales to customers are based on the reading of their meters that occurs on a systematic basis throughout the month. We recognize the revenues on our Statements of Operations using an accrual method for retail and other energy sales that have not yet been billed, but where electricity has been consumed. This is termed “unbilled revenues” and is a widely recognized and accepted practice for utilities. At the end of each month, unbilled revenues are determined by the estimation of unbilled energy provided to customers since the date of the last meter reading, estimated line losses, the assignment of unbilled energy provided to customer classes and the average rate per customer class.

The power sales and purchases within DP&L’s service territory are reported on a net hourly basis as revenues or purchased power on our Statements of Operations. We record expenses when purchased electricity is received and when expenses are incurred. For additional information, see Note 13 – Revenue.

Allowance for Uncollectible Accounts

We establish provisions for uncollectible accounts by using both historical average loss percentages to project future losses and by establishing specific provisions for known credit issues. Amounts are written off when reasonable collections efforts have been exhausted.

Property, Plant and Equipment

We record our ownership share of our undivided interest in jointly-owned transmission and distribution property as an asset in property, plant and equipment. New property, plant and equipment additions are stated at cost. For regulated transmission and distribution property, cost includes direct labor and material, allocable overhead expenses and an allowance for funds used during construction (AFUDC). AFUDC represents the cost of borrowed funds and equity used to finance regulated construction projects. For non-regulated property, cost also includes capitalized interest. Capitalization of AFUDC and interest ceases at either project completion or at the date specified by regulators AFUDC and capitalized interest was $0.5 million, $1.5 million and $2.0 million for the years ended December 31, 2018, 2017 and 2016, respectively.

For substantially all depreciable property, when a unit of property is retired, the original cost of that property less any salvage value is charged to Accumulated depreciation and amortization, consistent with composite depreciation practices.

Property is evaluated for impairment when events or changes in circumstances indicate that its carrying amount may not be recoverable.

Repairs and Maintenance

Costs associated with maintenance activities are recognized at the time the work is performed. These costs, which include labor, materials and supplies, and outside services required to maintain equipment and facilities, are capitalized or expensed based on defined units of property.

Depreciation

Depreciation expense is calculated using the straight-line method, which allocates the cost of property over its estimated useful life. For DP&L’s transmission and distribution assets, straight-line depreciation is applied monthly on an average composite basis using group rates. For DP&L’s transmission and distribution assets, straight-line depreciation is applied on an average annual composite basis using group rates that approximated 3.0% in 2018, 3.4% in 2017 and 4.6% in 2016. Depreciation expense was $68.2 million, $69.6 million and $64.3 million for the years ended December 31, 2018, 2017 and 2016, respectively.

Regulatory Accounting

As a regulated utility, DP&L applies the provisions of FASC 980 “Regulated Operations”, which gives recognition to the ratemaking and accounting practices of the PUCO and the FERC. Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in customer rates. Regulatory assets can also represent performance incentives permitted by the regulator. Regulatory assets have been included as allowable costs for ratemaking purposes, as authorized by the PUCO or established regulatory practices. Regulatory liabilities generally represent obligations to make refunds or future rate reductions to

F-9

customers for previous over collections or the deferral of revenues collected for costs that DP&L expects to incur in the future.

The deferral of costs (as regulatory assets) is appropriate only when the future recovery of such costs is probable. In assessing probability, we consider such factors as specific orders from the PUCO or FERC, regulatory precedent and the current regulatory environment. To the extent recovery of costs is no longer deemed probable, related regulatory assets would be required to be expensed in current period earnings. Our regulatory assets and liabilities have been created pursuant to a specific order of the PUCO or FERC or established regulatory practices, such as other utilities under the jurisdiction of the PUCO or FERC being granted recovery of similar costs. It is probable, but not certain, that these regulatory assets will be recoverable, subject to PUCO or FERC approval. Regulatory assets and liabilities are classified as current or non-current based on the term in which recovery is expected See Note 3 – Regulatory Matters for more information.

Inventories

Inventories are carried at average cost and include materials and supplies used for utility operations.

Intangibles

Intangibles include software, emission allowances and renewable energy credits. Emission allowances are carried on a first-in, first-out (FIFO) basis for purchased emission allowances. Net gains or losses on the sale of excess emission allowances, representing the difference between the sales proceeds and the cost of emission allowances, are recorded as a component of our fuel costs and are reflected in Operating income when realized. Emission allowances are amortized as they are used in our operations on a FIFO basis. Renewable energy credits are carried on a weighted average cost basis and amortized as they are used or retired.

Software is amortized over seven years. Amortization expense was $6.3 million, $5.7 million and $6.7 million for the years ended December 31, 2018, 2017 and 2016, respectively. The estimated amortization expense of this internal-use software over the next five years is $11.1 million ($3.5 million in 2019, $2.4 million in 2020, $2.2 million in 2021, $1.8 million in 2022 and $1.2 million in 2023).

Income Taxes

Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of the existing assets and liabilities, and their respective income tax bases. We establish an allowance when it is more likely than not that all or a portion of a deferred tax asset will not be realized. Our tax positions are evaluated under a more likely than not recognition threshold and measurement analysis before they are recognized for financial statement reporting. Uncertain tax positions have been classified as noncurrent income tax liabilities unless expected to be paid within one year. Our policy for interest and penalties is to recognize interest and penalties as a component of the provision for income taxes in the Statement of Operations.

Income taxes payable, which are includable in allowable costs for ratemaking purposes in future years, are recorded as regulatory assets or liability with a corresponding deferred tax liability or asset. Investment tax credits that reduced federal income taxes in the years they arose have been deferred and are being amortized to income over the useful lives of the properties in accordance with regulatory treatment See Note 3 – Regulatory Matters for additional information.

DP&L files U.S. federal income tax returns as part of the consolidated U.S. income tax return filed by AES. The consolidated tax liability is allocated to each subsidiary based on the separate return method which is specified in our tax allocation agreement and which provides a consistent, systematic and rational approach See Note 8 – Income Taxes for additional information.

Financial Instruments

Our Master Trust investments in debt and equity financial instruments of publicly traded entities are classified as equity investments. These equity securities are carried at fair value and unrealized gains and losses on these securities are recorded in Other income. As these financial instruments are held to be used for the benefit of employees participating in employee benefit plans and are not used for general operating purposes, they are classified as non-current in Other deferred assets on the Balance Sheets.

F-10

Held-for-sale Businesses

A business classified as held-for-sale is reflected on the balance sheet at the lower of its carrying amount or estimated fair value less cost to sell. A loss is recognized if the carrying amount of the business exceeds its estimated fair value less cost to sell. This loss is limited to the carrying value of long-lived assets until the completion of the sale, at which point, any additional loss is recognized. If the fair value of the business subsequently exceeds the carrying amount while the business is still held-for-sale, any impairment expense previously recognized will be reversed up to the lower of the previously recognized expense or the subsequent excess.

Assets and liabilities related to a business classified as held-for-sale are segregated in the current balance sheet in the period in which the business is classified as held-for-sale. Assets and liabilities of held-for-sale businesses are classified as current when they are expected to be disposed of within twelve months. Transactions between the business held-for-sale and businesses that are expected to continue to exist after the disposal are not eliminated to appropriately reflect the continuing operations and balances held-for-sale. See Note 14 – Generation Separation for further information.

Discontinued Operations

Discontinued operations reporting occurs only when the disposal of a business or a group of assets represents a strategic shift that has (or will have) a major effect on our operations and financial results. We report financial results for discontinued operations separately from continuing operations to distinguish the financial impact of disposal transactions from ongoing operations. Prior period amounts in the statement of operations and balance sheet are retrospectively revised to reflect the businesses determined to be discontinued operations. The cash flows of businesses that are determined to be discontinued operations are included within the relevant categories within operating, investing and financing activities on the face of the Statements of Cash Flows.

Transactions between the businesses determined to be discontinued operations and businesses that are expected to continue to exist after the disposal are not eliminated to appropriately reflect the continuing operations and balances held-for-sale. The results of discontinued operations include any gain or loss recognized on closing or adjustment of the carrying amount to fair value. See Note 14 – Generation Separation for further information.

Generation Separation

With the transfer of DP&L's generation assets to an affiliate (see Note 14 – Generation Separation), DP&L's generation business is presented as a discontinued operation and the operating activities have been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016 and in the notes to the financial statements.

Accounting for Taxes Collected from Customers and Remitted to Governmental Authorities

DP&L collects certain excise taxes levied by state or local governments from its customers. DP&L’s excise taxes and certain other taxes are accounted for on a net basis and recorded as a reduction in revenues in the accompanying Statements of Operations. The amounts for the years ended December 31, 2018, 2017 and 2016 were $51.7 million, $49.4 million and $50.9 million, respectively.

Cash and Cash Equivalents

Cash and cash equivalents are stated at cost, which approximates fair value. All highly liquid short-term investments with original maturities of three months or less are considered cash equivalents.

Restricted Cash

Restricted cash includes cash which is restricted as to withdrawal or usage. The nature of the restrictions includes restrictions imposed by agreements related to deposits held as collateral and cash collected under the DMR which is restricted to pay debt obligations at DPL and DP&L and position DP&L to modernize and/or maintain its transmission and distribution infrastructure.

The following table provides a summary of cash, cash equivalents, and restricted cash amounts reported on the Balance Sheet that reconcile to the total of such amounts as shown on the Statements of Cash Flows:

$ in millions	December 31, 2018		December 31, 2017
Cash and cash equivalents	$	45.0	$	5.2
Restricted cash	21.2		0.4
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	66.2	$	5.6

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Financial Derivatives

All derivatives are recognized as either assets or liabilities in the balance sheets and are measured at fair value. Changes in the fair value are recorded in earnings unless the derivative is designated as a cash flow hedge of a forecasted transaction.

We use interest rate hedges to manage the interest rate risk of our variable rate debt. We use cash flow hedge accounting when the hedge or a portion of the hedge is deemed to be highly effective, which results in changes in fair value being recorded within accumulated other comprehensive income, a component of shareholder’s equity. We have elected not to offset net derivative positions in the financial statements. Accordingly, we do not offset such derivative positions against the fair value of amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral under master netting agreements. See Note 6 – Derivative Instruments and Hedging Activities for additional information.

Insurance and Claims Costs

In addition to insurance obtained from third-party providers, MVIC, a wholly-owned captive subsidiary of DPL, provides insurance coverage solely to us and other DPL subsidiaries for workers’ compensation, general liability, and property damage on an ongoing basis. DP&L is responsible for claims costs below certain coverage thresholds of MVIC and third-party insurers for the insurance coverage noted above. DP&L has estimated liabilities for medical, life, disability, and other reserves for claims costs below certain coverage thresholds of third-party providers of approximately $4.3 million and $4.4 million at December 31, 2018 and 2017, respectively, within Other current liabilities and Other deferred credits on the balance sheets. The estimated liabilities for workers’ compensation, medical, life and disability costs at DP&L are actuarially determined using certain assumptions. There is uncertainty associated with these loss estimates, and actual results may differ from the estimates. Modification of these loss estimates based on experience and changed circumstances is reflected in the period in which the estimate is re-evaluated.

Pension and Postretirement Benefits

We recognize in our Balance Sheets an asset or liability reflecting the funded status of pension and other postretirement plans with current-year changes from actuarial gains or losses related to our regulated operations, that would otherwise be recognized in AOCI, recorded as a regulatory asset as this can be recovered through future rates. Such changes that are not related to our regulated operations are recognized in AOCI. All plan assets are recorded at fair value. We follow the measurement date provisions of the accounting guidance, which require a year-end measurement date of plan assets and obligations for all defined benefit plans.

We account for and disclose pension and postretirement benefits in accordance with the provisions of GAAP relating to the accounting for pension and other postretirement plans. These GAAP provisions require the use of assumptions, such as the discount rate for liabilities and long-term rate of return on assets, in determining the obligations, annual cost and funding requirements of the plans. Consistent with the requirements of FASC 715, we apply a disaggregated discount rate approach for determining service cost and interest cost for our defined benefit pension plans and postretirement plans.

See Note 9 – Benefit Plans for more information.

Related Party Transactions

In the normal course of business, DP&L enters into transactions with other subsidiaries of DPL or AES. See Note 12 – Related Party Transactions for additional information on Related Party Transactions.

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New accounting pronouncements adopted in 2018

The following table provides a brief description of recently adopted accounting pronouncements that had an impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or did not have a material impact on our financial statements.

Accounting Standard	Description	Date of Adoption	Effect on the financial statements upon adoption
New Accounting Standards Adopted
2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract	This standard aligns the accounting for implementation costs incurred for a cloud computing arrangement that is a service with the requirement for capitalizing implementation costs associated with developing or obtaining internal-use software. Transition method: retrospective or prospective.	October 1, 2018	We elected to early-adopt this standard on a prospective basis, effective for fiscal year 2018. The adoption of this standard did not have a material impact on our financial statements.
2018-14, Compensation— Retirement Benefits — Defined Benefit Plans — General (Subtopic 715-20): Disclosure Framework	This standard modifies the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. Transition method: retrospective.	Early adoption elected, January 1, 2018	Impact limited to changes in financial statement disclosures.
2017-07, Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost	This standard changes the presentation of non-service costs associated with defined benefit plans and updates the guidance so that only the service cost component will be eligible for capitalization. Transition method: retrospective for presentation of non-service cost and prospective for the change in capitalization.	January 1, 2018	For the years ended December 31, 2017 and 2016 we reclassified non-service pension costs from Operating expenses to Other expense of ($1.5) million and ($0.9) million, respectively.
2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force)	This standard requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Transition method: retrospective.	January 1, 2018	For the years ended December 31, 2017 and 2016, we reclassified from "Net cash used in investing activities" to "Net increase / (decrease) in cash, cash equivalents and restricted cash" $26.6 million and ($11.9) million, respectively.
2016-01, Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities	The standard significantly revises an entity’s accounting related to (1) classification and measurement of investments in equity securities and (2) the presentation of certain fair value changes for financial liabilities measured at fair value. It also amends certain disclosures of financial instruments. Transition method: modified retrospective. Prospective for equity investments without readily determinable fair value.	January 1, 2018	We adopted this standard January 1, 2018. At that date, we transferred $1.7 million ($1.1 million net of tax) of unrealized gains from AOCI to Retained Earnings.
2014-09, 2015-14, 2016-08, 2016-10, 2016-12, 2016-20, 2017-10, 2017-13, Revenue from Contracts with Customers (Topic 606)	See discussion of the ASU below.	January 1, 2018	See impact upon adoption of the standard below.

Adoption of FASC Topic 606, "Revenue from Contracts with Customers"

On January 1, 2018, we adopted ASU 2014-09, "Revenue from Contracts with Customers", and its subsequent corresponding updates ("FASC 606"). The core principle of this standard is that an entity shall recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. We applied the modified retrospective method of adoption to those contracts which were not completed as of January 1, 2018. Results for reporting periods beginning January 1, 2018 are presented under FASC 606, while prior period amounts were not adjusted and continue to be reported in accordance with our historic accounting under the previous revenue recognition standard. For contracts that were modified before January 1, 2018, we have not retrospectively restated the contracts for modifications. We instead reflected the aggregate effect of all modifications when identifying the satisfied and unsatisfied performance obligations, determining the transaction price and allocating the transaction price. We do not expect the adoption of the new revenue standard to have a material impact to our net income on an ongoing basis.

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There was no cumulative effect to our January 1, 2018 Balance Sheet resulting from the adoption of FASC 606.

New accounting pronouncements issued but not yet effective - The following table provides a brief description of recent accounting pronouncements that could have a material impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or are expected to have no material impact on our financial statements.

Accounting Standard	Description	Date of Adoption	Effect on the financial statements upon adoption
New Accounting Standards Issued but Not Yet Effective
2018-02, Income Statement - Reporting Comprehensive Income (Topic 220), Reclassification of Certain Tax Effects from AOCI	This amendment allows a reclassification of the stranded tax effects resulting from the implementation of the Tax Cuts and Jobs Act from AOCI to retained earnings. Because this amendment only relates to the reclassification of the income tax effects of the Tax Cuts and Jobs Act, the underlying guidance that requires that the effect of a change in tax laws or rates be included in income from continuing operations is not affected.	January 1, 2019. Early adoption is permitted.	We do not expect any impact on our financial statements upon adoption of the standard on January 1, 2019.
2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities	The standard updates the hedge accounting model to expand the ability to hedge nonfinancial and financial risk components, reduce complexity, and ease certain documentation and assessment requirements. When facts and circumstances are the same as at the previous quantitative test, a subsequent quantitative effectiveness test is not required. The standard also eliminates the requirement to separately measure and report hedge ineffectiveness. For cash flow hedges, this means that the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item in the period in which it settles. Transition method: modified retrospective with the cumulative effect adjustment recorded to the opening balance of retained earnings as of the initial application date. Prospective for presentation and disclosures.	January 1, 2019. Early adoption is permitted.	We are currently evaluating the impact of adopting the standard on our financial statements.
2018-19, 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	The standard updates the impairment model for financial assets measured at amortized cost. For trade and other receivables, held-to-maturity debt securities, loans and other instruments, entities will be required to use a new forward-looking "expected loss" model that generally will result in the earlier recognition of allowance for losses. For available-for-sale debt securities with unrealized losses, entities will measure credit losses as it is done today, except that the losses will be recognized as an allowance rather than a reduction in the amortized cost of the securities. Transition method: various.	January 1, 2020. Early adoption is permitted only as of January 1, 2019.	We are currently evaluating the impact of adopting the standard on our financial statements.
2016-02, 2018-01, 2018-10, 2018-11, 2018-20 Leases (Topic 842)	See discussion of the ASU below.	January 1, 2019. Early adoption is permitted.	We will adopt the standard on January 1, 2019; see below for the evaluation of the impact of its adoption on our financial statements.

Adoption of FASC Topic 842, "Leases"

ASU 2016-02 and its subsequent corresponding updates require lessees to recognize assets and liabilities for most leases but recognize expenses in a manner similar to today’s accounting. For lessors, the guidance modifies the lease classification criteria and the accounting for sales-type and direct financing leases. The guidance also eliminates today’s real estate-specific provisions.

The standard must be adopted using a modified retrospective approach. The FASB has provided an optional transition method, which we have elected, that allows entities to continue to apply the guidance in FASC 840 Leases to the comparative periods presented in the year of adoption. Under this transition method, we will apply the transition provisions starting on January 1, 2019.

We have elected to apply a package of practical expedients that allow lessees and lessors not to reassess: (1) whether any expired or existing contracts are or contain leases, (2) lease classification for any expired or existing leases, and (3) whether initial direct costs for any expired or existing leases qualify for capitalization under FASC 842. These three practical expedients must be elected as a package and must be consistently applied to all leases. We have also elected to apply an optional transition practical expedient for land easements that allows an entity to

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continue applying its current accounting policy for all land easements that exist before the standard’s effective date that were not previously accounted for under FASC 840.

We established a task force focused on the identification of contracts that would be under the scope of the new standard and on the assessment and measurement of the right-of-use assets and related liabilities. Additionally, the implementation team has been working on the configuration of a lease accounting tool that will support the implementation and the subsequent accounting. The implementation team has also evaluated changes to our business processes, systems and controls to support recognition and disclosure under the new standard.

Under FASC 842, it is expected that fewer contracts will contain a lease. However, due to the elimination of the real estate-specific guidance and changes to certain lessor classification criteria, more leases will qualify as sales-type leases and direct financing leases. Under these two models, a lessor will derecognize the asset and will recognize a lease receivable. According to FASC 842, the lease receivable includes the fair value of the plant after the contract period but does not include any variable payments such as margin on the sale of energy. Therefore, the lease receivable could be significantly different than the carrying amount of the underlying asset at lease commencement. In such circumstances, the difference between the initially recognized lease receivable and the carrying amount of the underlying asset is recognized as a gain/loss at lease commencement.

The adoption of FASC 842 did not have a material impact on our financial statements.

Note 2 – Supplemental Financial Information

	December 31,
$ in millions	2018			2017
Accounts receivable, net
Customer receivables	$	53.3		$	44.2
Unbilled revenue	16.8			18.0
Amounts due from partners in jointly-owned stations	—			5.0
Due from PJM transmission enhancement settlement (a)	16.5			—
Due from affiliates	2.3			0.6
Other	2.4			4.1
Provisions for uncollectible accounts	(0.9		)	(1.1		)
Total accounts receivable, net	$	90.4		$	70.8
Inventories, at average cost
Materials and supplies	$	7.1		$	6.9
Other	0.6			0.4
Total inventories, at average cost	$	7.7		$	7.3

(a) - See Note 3 – Regulatory Matters for more information.

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Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the years ended December 31, 2018, 2017 and 2016 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) Components	Affected line item in the Statements of Operations	Years ended December 31,
$ in millions		2018			2017			2016
Gains and losses on equity securities activity (Note 5):
	Other deductions	$	—		$	(0.1	)	$	—
	Income tax expense	—			—			—
	Net of income taxes	—			(0.1		)	—
Gains and losses on cash flow hedges (Note 6):
	Interest expense	(1.1		)	(0.9		)	(1.0		)
	Income tax benefit	0.4			0.2			0.2
	Net of income taxes	(0.7		)	(0.7		)	(0.8		)
	Loss from discontinued operations	—			(8.5		)	(45.4		)
	Income tax benefit from discontinued operations	—			3.0			16.2
	Net of income taxes	—			(5.5		)	(29.2		)
Amortization of defined benefit pension items (Note 9):
	Other income	4.3			6.8			7.7
	Income tax expense	(1.0		)	(2.3		)	(1.8		)
	Net of income taxes	3.3			4.5			5.9
Total reclassifications for the period, net of income taxes		$	2.6		$	(1.8	)	$	(24.1	)

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the years ended December 31, 2018 and 2017 are as follows:

$ in millions	Gains / (losses) on equity securities			Gains / (losses) on cash flow hedges			Change in unfunded pension obligation			Total
Balance at December 31, 2016	$	0.7		$	(2.7	)	$	(40.5	)	$	(42.5	)
Other comprehensive income / (loss) before reclassifications	0.5			12.4			(2.7		)	10.2
Amounts reclassified from accumulated other comprehensive income / (loss)	(0.1		)	(6.2		)	4.5			(1.8		)
Net current period other comprehensive income	0.4			6.2			1.8			8.4
Transfer of generation assets to subsidiary of parent	—			(2.1		)	—			(2.1		)
Balance at December 31, 2017	1.1			1.4			(38.7		)	(36.2		)
Other comprehensive loss before reclassifications	—			(0.1		)	(0.5		)	(0.6		)
Amounts reclassified from accumulated other comprehensive income / (loss) to earnings	—			(0.7		)	3.3			2.6
Net current period other comprehensive income / (loss)	—			(0.8		)	2.8			2.0
Amounts reclassified from accumulated other comprehensive income to accumulated deficit (a)	(1.1		)	—			—			(1.1		)
Balance at December 31, 2018	$	—		$	0.6		$	(35.9	)	$	(35.3	)

(a) ASU 2016-01 “Recognition and Measurement of Financial Assets and Financial Liabilities” was effective as of January 1, 2018. This ASU requires the change in the fair value of equity instruments to be recorded in income rather than in OCI. Equity Instruments were defined to include all mutual funds, regardless of the underlying investments.

Note 3 – Regulatory Matters

Distribution Rate Order

On September 26, 2018 the PUCO issued the DRO establishing new base distribution rates for DP&L, which became effective October 1, 2018. The DRO approved, without modification, a stipulation and recommendation previously filed by DP&L, along with various intervening parties and the PUCO staff. The DRO established a

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revenue requirement of $248.0 million for DP&L's electric service base distribution rates which reflects an increase to distribution revenues of approximately $29.8 million per year. In addition to the increase in base distribution rates, and among other matters, the DRO provides for a return on equity of 9.999% and a cost of long-term debt of 4.8% and for the following items:

DIR – The DRO authorized DP&L to begin charging a Distribution Investment Rider ("DIR") set initially at $12.2 million annually, effective October 1, 2018. The DIR revenue requirement shall be updated quarterly and will increase as DP&L makes qualified investments in its distribution network, subject to annual revenue limits which increase each year; the revenue limit for 2019 is $22.0 million. The DIR will expire in November 2022 unless DP&L files a base distribution rate case on or before October 31, 2022, in which case the DIR will expire in November 2023.

Decoupling Rider – The DRO eliminated provisions in the existing decoupling rider which allowed DP&L to recover lost revenues resulting from the implementation of energy efficiency programs and replaced it with a revenue requirement that attempts to eliminate the impacts of weather and demand on DP&L’s revenues from residential and commercial distribution customers beginning January 1, 2019. As a result, in years with very mild weather and/or decreased demand, DP&L will be able to accrue a regulatory asset for recovery through the rider to normalize the revenues. Conversely, in periods of extreme temperatures or high demand for electricity, DP&L may record a liability for future reimbursement to customers. The rider also includes a one-time $3.7 million revenue requirement based on the increase in the number of DP&L’s residential and commercial customers from the rate case test year until September 30, 2018. Such amount was accrued and included in revenues in the third quarter of 2018 and will be collected by DP&L in 2019.

TCJA – The DRO partially resolved the TCJA impacts. The new distribution rates include the impacts of the decrease in current federal income taxes beginning October 1, 2018. The DRO did not designate how much DP&L may owe for any overcollection of taxes from January 1, 2018 through September 30, 2018, nor did it resolve any decrease in future rates related to amortization of excess accumulated deferred income taxes (“ADIT”). The DRO did, however, stipulate that DP&L must refund its customers an amount no less than $4.0 million per year for the first five years of the amortization period unless all balances owed are fully returned within the first five years. For more on the impacts of the TCJA, see below.

Vegetation Management Costs – The DRO authorizes DP&L to defer as a regulatory asset, with no carrying costs, annual expenses for vegetation management performed by third-party vendors. For calendar year 2018 annual expenses which are incremental to the baseline of $10.7 million can be deferred up to a $4.6 million cap. For calendar years 2019 and thereafter, annual expenses in excess of $15.7 million can be deferred up to a $4.6 million annual cap. Annual spending of less than the vegetation management baseline amounts will result in a reduction to the regulatory asset or creation of a regulatory liability. For 2018, DP&L accrued a regulatory asset for the maximum amount of $4.6 million based upon such provisions and spending above the baseline.

In December 2018, DP&L filed a Distribution Modernization Plan (“DMP”) with the PUCO proposing to invest $576.0 million in capital projects over the next 10 years. There are eight principal components of DP&L’s DMP: 1) Smart Meters, 2) Self-Healing Grid, 3) Customer Engagement, 4) Enhancing Sustainability and Embracing Innovation. 5) Telecommunications, 6) Physical and Cyber Security, 7) Governance and Analytics, and 8) Grid Modernization R&D.

ESP Order

On March 13, 2017, DP&L filed an amended stipulation to its 2017 ESP, which was subject to approval by the PUCO. A final decision was issued by the PUCO on October 20, 2017, modifying and adopting the amended stipulation and recommendation. The six-year 2017 ESP establishes DP&L's framework for providing retail service on a going-forward basis including rate structures, non-bypassable charges and other specific rate recovery true-up mechanisms which include, but are not limited to, the following:

• Bypassable standard offer energy rates for DP&L’s customers based on competitive bid auctions;

• The establishment of a three year non-bypassable Distribution Modernization Rider (DMR) designed to collect $105.0 million in revenue per year to pay debt obligations at DPL and DP&L and position DP&L to modernize and/or maintain its transmission and distribution infrastructure with an option for DP&L to file for an extension of the rider for an additional two years in an amount subject to approval by the PUCO.

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Consistent with that settlement and the PUCO order, on January 22, 2019, DP&L filed a request to extend the DMR for the additional two years at an annual revenue amount of $199.0 million. That request is pending PUCO review;

• The establishment of a non-bypassable Distribution Investment Rider to recover incremental distribution capital investments, the amount of which was established in the DP&L DRO;

• A non-bypassable Reconciliation Rider permitting DP&L to defer, recover or credit the net proceeds from selling energy and capacity received as part of DP&L’s investment in OVEC and DP&L's OVEC related costs;

• Implementation by DP&L of a Smart Grid Rider, Economic Development Rider, Economic Development Fund, Regulatory Compliance Rider and certain other new, or changes to existing, rates, riders and competitive retail market enhancements, with tariffs consistent with the order. These riders became effective November 1, 2017;

• A commitment to commence a sale process to sell our ownership interests in the Miami Fort, Zimmer and Conesville coal-fired generation plants, with all sales proceeds used to pay debt of DPL and DP&L;

• Restrictions on DPL making dividend or tax sharing payments and an obligation to convert then existing tax payments owed by DPL to AES into equity investments in DPL. See ; Note 8 – Income Taxes and Note 10 – Equity for more information on the tax sharing payment restrictions; and

• Various other riders and competitive retail market enhancements.

On October 19, 2018 IGS, a retail electricity supplier, filed a Notice of Withdrawal from the amended settlement, citing a material modification by the PUCO's October 2017 order. To address the withdrawal, the PUCO established a new procedural schedule, including a hearing currently scheduled to begin April 1, 2019. Additionally, on January 7, 2019, the Ohio Consumers' Counsel appealed the 2017 ESP Order to the Supreme Court of Ohio. That appeal is pending.

DP&L is subject to a SEET threshold and is required to apply general rules for calculating earnings and comparing them to a comparable group to determine whether there were significantly excessive earnings during a given calendar year. The 2017 ESP maintains DP&L’s return on equity SEET threshold at 12% and provides that DMR amounts are excluded from the SEET calculation. On October 22, 2018, a stipulation was reached agreeing that DP&L did not exceed the SEET threshold for 2016 or 2017. That stipulation is pending PUCO approval. In future years, the SEET could have a material effect on results of operations, financial condition and cash flows.

Impact of Tax Reform

On January 10, 2018 the PUCO initiated a proceeding to consider the impacts of the TCJA to determine the appropriate course of action to pass benefits resulting from the legislation on to ratepayers. The PUCO also directed Ohio utilities to record deferred liabilities for the estimated reduction in federal income tax resulting from the TCJA beginning January 1, 2018. Under the terms of the ESP, DPL will not make tax sharing payments. Under the terms of the stipulation in the distribution rate case mentioned above, DP&L agreed to file an application at the PUCO by March 1, 2019 to refund eligible excess accumulated deferred income taxes (ADIT) and any related regulatory liability over a ten-year period. Excess ADIT related to depreciation life and method differences will be returned to customers in accordance with federal tax law and related regulations. DP&L’s rates were set using the new tax rate as a result of the distribution rate case.

FERC Proceedings

On May 8, 2018, DP&L filed to adjust its FERC jurisdictional transmission rates to reflect the effects of the decrease in federal income tax rates on the current portion of income tax expense as part of the TCJA, resulting in a decrease of approximately $2.4 million annually. The revised rates are in effect and all DP&L over and undercollections dating back to the March 21st effective date were settled in December 2018.

On November 15, 2018 FERC issued a Notice of Proposed Rulemaking to address amortization of excess accumulated deferred income taxes resulting from the TCJA and their impact on transmission rates. Such notice requires all public utility transmission providers with stated transmission rates under an Open Access Transmission Tariff (OATT) to determine the amount of excess deferred income taxes caused by the TCJA. DP&L is unable to predict the outcome of this notice or the impact it may have on our Financial Statements

PJM Transmission Enhancement Settlement

On May 31, 2018, the FERC issued an Order on Contested Settlement regarding the cost allocation method for existing and new transmission facilities contained in the PJM Interconnection’s OATT. The FERC order approved the settlement which reduces DP&L’s transmission costs through PJM beginning in August 2018, including credits

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to reimburse DP&L for amounts overcharged in prior years. DP&L estimates the prior overcharge by PJM to be $41.6 million, of which approximately $14.3 million has been repaid to DP&L through December 31, 2018 and $16.5 million is classified as current in "Accounts receivable, net" and $10.8 million is classified as non-current in "Other deferred assets" on the accompanying Balance Sheet. All of the transmission charges and credits impacted by this FERC order are items that are included for full recovery in DP&L’s nonbypassable TCRR. Accordingly, DP&L has also established offsetting regulatory liabilities. While this development will have a temporary cash flow benefit to DP&L, there is no impact to operating income or net income as all credits will be passed to DP&L’s customers through the TCRR, which began in November 2018.

Regulatory Assets and Liabilities

In accordance with FASC 980, we have recognized total regulatory assets of $193.7 million and $187.1 million at December 31, 2018 and 2017, respectively, and total regulatory liabilities of $313.2 million and $236.0 million at December 31, 2018 and 2017, respectively. Regulatory assets and liabilities are classified as current or non-current based on the term in which recovery is expected. See Note 1 – Overview and Summary of Significant Accounting Policies for accounting policies regarding Regulatory Assets and Liabilities.

The following table presents DP&L’s Regulatory assets and liabilities:

	Type of Recovery	Amortization Through	December 31,
$ in millions			2018		2017
Regulatory assets, current:
Undercollections to be collected through rate riders	A/B	2019	$	40.5	$	23.9
Rate case expenses being recovered in base rates	B	2019	0.6		—
Total regulatory assets, current			41.1		23.9
Regulatory assets, non-current:
Pension benefits	B	Ongoing	87.5		92.4
Unrecovered OVEC charges	C	Undetermined	28.7		27.8
Fuel costs	B	2020	3.3		9.3
Regulatory compliance costs	B	2020	6.1		9.2
Smart grid and AMI costs	B	Undetermined	8.5		7.3
Unamortized loss on reacquired debt	B	Various	6.0		7.0
Deferred storm costs	A	Undetermined	4.7		2.1
Deferred vegetation management and other	A/B	Undetermined	7.8		8.1
Total regulatory assets, non-current			152.6		163.2
Total regulatory assets			$	193.7	$	187.1
Regulatory liabilities, current:
Overcollection of costs to be refunded through rate riders	A/B	2018	$	34.9	$	14.8
Total regulatory liabilities, current			34.9		14.8
Regulatory liabilities, non-current:
Estimated costs of removal - regulated property		Not Applicable	139.1		132.8
Deferred income taxes payable through rates		Various	116.3		83.4
PJM transmission enhancement settlement	A	2025	16.9		—
Postretirement benefits	B	Ongoing	6.0		5.0
Total regulatory liabilities, non-current			278.3		221.2
Total regulatory liabilities			$	313.2	$	236.0

A – Recovery of incurred costs plus rate of return.

B – Recovery of incurred costs without a rate of return.

C – Recovery not yet determined, but recovery is probable of occurring in future rate proceedings.

Current regulatory assets and liabilities primarily represent costs that are being recovered per specific rate order; recovery for the remaining costs is probable, but not certain. DP&L is earning a net return on $5.5 million of this net deferral. These items include undercollection of: (i) Distribution Modernization Rider revenues, (ii) decoupling rider (see above), (iii) uncollectible rider and (iv) energy efficiency rider. It also includes the current portion of the following deferred costs which are described in greater detail below: unbilled fuel, regulatory compliance rider costs and deferred storm costs. As current liabilities, this includes overcollection of: (i) competitive bidding energy and auction costs, (ii) energy efficiency program costs, (iii) alternative energy rider, (iv) economic development rider, (v) certain transmission related costs including current portion of PJM transmission enhancement settlement (see above) and (vi) reconciliation rider.

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Pension benefits represent the qualifying FASC 715 “Compensation - Retirement Benefits” costs of our regulated operations that for ratemaking purposes are deferred for future recovery. We recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of OCI, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. This regulatory asset represents the regulated portion that would otherwise be charged as a loss to OCI. As per PUCO and FERC precedents, these costs are probable of future rate recovery.

Unrecovered OVEC charges includes the portion of charges from OVEC that were not recoverable through DP&L’s fuel rider from October 2014 through October 2017. DP&L expects to recover these costs through a future rate proceeding. Beginning on November 1, 2017, such costs are being recovered through DP&L’s Reconciliation Rider which was authorized as part of the 2017 ESP.

Fuel costs represent unrecovered fuel costs related to DP&L’s fuel rider from 2010 through 2015 resulting from a declining SSO customer base. DP&L was granted recovery of these costs without a return through the SSO as approved in the 2017 ESP. These costs are being recovered over the three-year period that began November 1, 2017.

Regulatory compliance rider represents the long-term portion of the regulatory compliance rider which was established by the 2017 ESP to recover the following costs: (i) Consumer Education Campaign, (ii) Retail Settlement System, (iii) Generation Separation, (iv) Bill Format Redesign, (v) Green Pricing Tariff and (vi) Supplier Consolidated Billing. All of these costs except for Generation Separation earn a return. These costs are being recovered over a three-year period.

Rate case costs represents costs associated with preparing a distribution rate case. DP&L was granted recovery of these costs which do not earn a return, as part of the DRO.

Smart Grid and AMI costs represent costs incurred as a result of studying and developing distribution system upgrades and implementation of AMI. On October 19, 2010, DP&L elected to withdraw its case pertaining to the Smart Grid and AMI programs. The PUCO accepted the withdrawal in an order issued on January 5, 2011. The PUCO also indicated that it expects DP&L to continue to monitor other utilities’ Smart Grid and AMI programs and to explore the potential benefits of investing in Smart Grid and AMI programs and that DP&L will, when appropriate, file new Smart Grid and/or AMI business cases in the future. DP&L requested recovery of these costs as part of the December 2018 DMP filing with the PUCO described earlier.

Unamortized loss on reacquired debt represents losses on long-term debt reacquired or redeemed in prior periods that have been deferred. These deferred losses are being amortized over the lives of the original issues in accordance with the rules of the FERC and the PUCO.

Deferred storm costs represent the long-term portion of deferred costs for major storms which occurred during 2017 and 2018. The 2017 ESP granted DP&L approval to establish a rider by which to seek recovery of these types of costs with a return. DP&L plans to file petitions seeking recovery of each calendar year of storm costs in the following calendar year. Recovery of these costs is probable by 2020, but not certain.

Estimated costs of removal - regulated property reflect an estimate of amounts collected in customer rates for costs that are expected to be incurred in the future to remove existing transmission and distribution property from service when the property is retired.

Deferred income taxes payable through rates represent deferred income tax liabilities recognized from the normalization of flow-through items as the result of taxes previously charged to customers. A deferred income tax asset or liability is created from a difference in income recognition between tax laws and accounting methods. As a regulated utility, DP&L includes in ratemaking the impacts of current income taxes and changes in deferred income tax liabilities or assets. On December 22, 2017, the TCJA was signed, which includes a provision to, among other things, reduce the federal corporate income tax rate to 21%, beginning January 1, 2018. As required by GAAP, on December 31, 2017, DP&L remeasured its deferred income tax assets and liabilities using the new expected tax rate. DP&L believes that the portion of the reduction in the net deferred tax liability which is related to deferred taxes considered in ratemaking will be used in future ratemaking to reduce jurisdictional retail rates. Accordingly, this liability reflects the estimated deferred taxes DP&L expects to return to customers in future periods.

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Postretirement benefits represent the qualifying FASC 715 “Compensation – Retirement Benefits” gains related to our regulated operations that, for ratemaking purposes, are probable of being reflected in future rates. We recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of OCI, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. This regulatory liability represents the regulated portion that would otherwise be reflected as a gain to OCI.

Note 4 – Property, Plant and Equipment

The following is a summary of DP&L’s Property, plant and equipment with corresponding composite depreciation rates at December 31, 2018 and 2017:

	December 31, 2018			December 31, 2017
$ in millions			Composite Rate			Composite Rate (a)
Regulated:
Transmission	$	386.7	2.4%	$	414.6	2.4%
Distribution	1,796.4		3.2%	1,735.9		3.4%
General	30.9		3.6%	31.2		3.1%
Non-depreciable	60.4		N/A	64.6		N/A
Total regulated	2,274.4			2,246.3
Unregulated:
Other	—		N/A	0.2		2.7%
Non-depreciable	—		N/A	0.7		N/A
Total unregulated	—			0.9
Total property, plant and equipment in service	$	2,274.4	3.0%	$	2,247.2	3.4%

In June 2018, DP&L closed on a transmission asset transaction with Duke and AEP, where ownership stakes in certain previously co-owned transmission assets were exchanged to eliminate co-ownership. Each previously co-owned transmission asset became wholly-owned by one of DP&L, Duke or AEP after the transaction. This transaction also resulted in cash proceeds to DP&L of $10.6 million.

AROs

We recognize AROs in accordance with GAAP which requires legal obligations associated with the retirement of long-lived assets to be recognized at their fair value at the time those obligations are incurred. Upon initial recognition of a legal liability, costs are capitalized as part of the related long-lived asset and depreciated over the useful life of the related asset. The DP&L AROs are for our retired Hutchings EGU and relate primarily to asbestos removal.

Estimating the amount and timing of future expenditures of this type requires significant judgment. Management routinely updates these estimates as additional information becomes available.

Changes in the Liability for Generation AROs

$ in millions
Balance at December 31, 2016	$	8.2
Calendar 2017
Accretion expense	0.1
Settlements	(0.3		)
Balance at December 31, 2017	8.0
Calendar 2018
Settlements (a)	(3.3		)
Balance at December 31, 2018	$	4.7

(a) Primarily includes settlement related to transfer of Beckjord Facility. See Note 15 – Dispositions for additional information.

See Note 5 – Fair Value for further discussion on ARO fair value measurements.

Asset Removal Costs

We continue to record costs of removal for our regulated transmission and distribution assets through our depreciation rates and recover those amounts in rates charged to our customers. There are no known legal AROs associated with these assets. We have recorded $139.1 million and $132.8 million in estimated costs of removal at

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December 31, 2018 and 2017, respectively, as regulatory liabilities for our transmission and distribution property. These amounts represent the excess of the cumulative removal costs recorded through depreciation rates versus the cumulative removal costs actually incurred. See Note 3 – Regulatory Matters for additional information.

Changes in the Liability for Transmission and Distribution Asset Removal Costs

$ in millions
Balance at December 31, 2016	$	126.5
Calendar 2017
Additions	12.0
Settlements	(5.7		)
Balance at December 31, 2017	132.8
Calendar 2018
Additions	14.3
Settlements	(8.0		)
Balance at December 31, 2018	$	139.1

Note 5 – Fair Value

The fair values of our financial instruments are based on published sources for pricing when possible. We rely on valuation models only when no other method is available to us. The fair value of our financial instruments represents estimates of possible value that may or may not be realized in the future.

The table below presents the fair value and cost of our non-derivative instruments at December 31, 2018 and 2017. See also Note 6 – Derivative Instruments and Hedging Activities for the fair values of our derivative instruments.

	December 31, 2018				December 31, 2017
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.4	$	0.4	$	0.3	$	0.3
Equity securities	2.4		3.5		2.5		4.2
Debt securities	4.1		4.0		4.3		4.3
Hedge funds	0.1		0.1		0.1		0.2
Tangible assets	0.1		0.1		0.1		0.1
Total assets	$	7.1	$	8.1	$	7.3	$	9.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	586.1	$	593.8	$	646.6	$	658.4

Fair Value Hierarchy

Fair value is defined as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. The fair value hierarchy requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. These inputs are then categorized as:

• Level 1 (quoted prices in active markets for identical assets or liabilities);

• Level 2 (observable inputs such as quoted prices for similar assets or liabilities or quoted prices in markets that are not active); or

• Level 3 (unobservable inputs reflecting management’s own assumptions about the inputs used in pricing the asset or liability).

Valuations of assets and liabilities reflect the value of the instrument including the values associated with counterparty risk. We include our own credit risk and our counterparty’s credit risk in our calculation of fair value using global average default rates based on an annual study conducted by a large rating agency.

We did not have any transfers of the fair values of our financial instruments among Level 1, Level 2 or Level 3 of the fair value hierarchy during the years ended December 31, 2018 and 2017.

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Debt

The fair value of debt is based on current public market prices for disclosure purposes only. Unrealized gains or losses are not recognized in the financial statements as debt is presented at the carrying value, net of unamortized premium or discount, in the financial statements. The debt amounts include the current portion payable in the next twelve months and have maturities that range from 2020 to 2061.

Master Trust Assets

DP&L established a Master Trust to hold assets that could be used for the benefit of employees participating in employee benefit plans and these assets are not used for general operating purposes. ASU 2016-01 “Recognition and Measurement of Financial Assets and Financial Liabilities” was effective as of January 1, 2018. This ASU requires the change in the fair value of equity instruments to be recorded in income rather than in OCI. Equity Instruments were defined to include all mutual funds, regardless of the underlying investments. Therefore, as of January 1, 2018, AOCI of $1.7 million ($1.1 million net of tax) was reversed to Accumulated Deficit and all future changes to fair value on the Master Trust Assets will be included in income in the period that the changes occur. These changes to fair value were not material for the year ended December 31, 2018. These assets are primarily comprised of open-ended mutual funds, which are valued using the net asset value per unit. These investments are recorded at fair value within Other deferred assets on the balance sheets and classified as available for sale.

During the year ended December 31, 2018, $0.5 million ($0.4 million after tax) of various investments were sold to facilitate the distribution of benefits.

The fair value of assets and liabilities at December 31, 2018 and 2017 and the respective category within the fair value hierarchy for DP&L was determined as follows:

$ in millions	Fair Value at December 31, 2018 (a)								Fair Value at December 31, 2017 (a)
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Master trust assets
Money market funds	$	0.4	$	—	$	—	$	0.4	$	0.3	$	—	$	—	$	0.3
Equity securities	—		3.5		—		3.5		—		4.2		—		4.2
Debt securities	—		4.0		—		4.0		—		4.3		—		4.3
Hedge funds	—		0.1		—		0.1		—		0.2		—		0.2
Tangible assets	—		0.1		—		0.1		—		0.1		—		0.1
Total Master trust assets	0.4		7.7		—		8.1		0.3		8.8		—		9.1
Derivative assets
Interest rate hedges	—		1.5		—		1.5		—		1.5		—		1.5
Total derivative assets	—		1.5		—		1.5		—		1.5		—		1.5
Total assets	$	0.4	$	9.2	$	—	$	9.6	$	0.3	$	10.3	$	—	$	10.6
Liabilities
Long-term debt	$	—	$	576.1	$	17.7	$	593.8	$	—	$	640.6	$	17.8	658.4
Total liabilities	$	—	$	576.1	$	17.7	$	593.8	$	—	$	640.6	$	17.8	$	658.4

(a) Includes credit valuation adjustment

Our financial instruments are valued using the market approach in the following categories:

Level 1 inputs are used for money market accounts that are considered cash equivalents. The fair value is determined by reference to quoted market prices and other relevant information generated by market transactions.

• Level 2 inputs are used to value derivatives such as interest rate hedge contracts which are valued using a benchmark interest rate. Other Level 2 assets include open-ended mutual funds in the Master Trust, which are valued using the end of day NAV per unit.

• Level 3 inputs such as certain debt balances are considered a Level 3 input because the notes are not publicly traded. Our long-term debt is fair valued for disclosure purposes only.

All of the inputs to the fair value of our derivative instruments are from quoted market prices.

F-23

Our long-term debt is fair valued for disclosure purposes only and most of the fair values are determined using quoted market prices in inactive markets. These fair value inputs are considered Level 2 in the fair value hierarchy. As the Wright-Patterson Air Force Base note is not publicly traded, fair value is assumed to equal carrying value. These fair value inputs are considered Level 3 in the fair value hierarchy as there are no observable inputs. Additional Level 3 disclosures are not presented since our long-term debt is not recorded at fair value.

Non-recurring Fair Value Measurements

We use the cost approach to determine the fair value of our AROs, which are estimated by discounting expected cash outflows to their present value at the initial recording of the liability. Cash outflows are based on the approximate future disposal cost as determined by market information, historical information or other management estimates. These inputs to the fair value of the AROs would be considered Level 3 inputs under the fair value hierarchy. The balance of AROs was $4.7 million and $8.0 million at December 31, 2018 and 2017, respectively.

Note 6 – Derivative Instruments and Hedging Activities

In the normal course of business, DP&L enters into various financial instruments, including derivative financial instruments. We use derivatives principally to manage the interest rate risk associated with our long-term debt. The derivatives that we use to economically hedge these risks are governed by our risk management policies for forward and futures contracts. Our net positions are continually assessed within our structured hedging programs to determine whether new or offsetting transactions are required. We monitor and value derivative positions monthly as part of our risk management processes. We use published sources for pricing, when possible, to mark positions to market. All of our derivative instruments are used for risk management purposes and are designated as cash flow hedges if they qualify under FASC 815 for accounting purposes.

DP&L's interest rate swaps are designated as a cash flow hedge. At December 31, 2018 and 2017, the principal balance of the interest rate hedges was $140.0 million and $200.0 million, respectively.

Cash Flow Hedges

As part of our risk management processes, we identify the relationships between hedging instruments and hedged items, as well as the risk management objective and strategy for undertaking various hedge transactions. The fair values of cash flow hedges determined by current public market prices will continue to fluctuate with changes in market prices up to contract expiration. The effective portion of the hedging transaction is recognized in AOCI and transferred to earnings using specific identification of each contract when the forecasted hedged transaction takes place or when the forecasted hedged transaction is probable of not occurring. The ineffective portion of the cash flow hedge is recognized in earnings in the current period. All risk components were considered to determine the hedge effectiveness of the cash flow hedges. With the adoption of ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities effective January 1, 2019, we will no longer be required to calculate effectiveness and thus the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item in the period in which it settles.

We have two interest rate swaps to hedge the variable interest on our $140.0 million variable interest rate tax-exempt First Mortgage Bonds. The interest rate swaps have a combined notional amount of $140.0 million and will settle monthly based on a one-month LIBOR. As of December 31, 2017, the interest rate swaps had a combined notional amount of $200.0 million. On March 29, 2018, we settled $60.0 million of these interest rate swaps due to the partial repayment of the underlying debt and a gain of $0.8 million was recorded as a reduction to interest expense. Since the swap was partially settled, the remaining swaps were de-designated and then re-designated with a new hypothetical derivative. The AOCI associated with the remaining swaps will be amortized out of AOCI into interest expense over the remaining life of the underlying debt.

We use the income approach to value the swaps, which consists of forecasting future cash flows based on contractual notional amounts and applicable and available market data as of the valuation date. The most common market data inputs used in the income approach include volatilities, spot and forward benchmark interest rates (LIBOR). Forward rates with the same tenor as the derivative instrument being valued are generally obtained from published sources, with these forward rates being assessed quarterly at a portfolio-level for reasonableness versus comparable published rates. We reclassify gains and losses on the swaps out of AOCI and into earnings in those periods in which hedged interest payments occur.

F-24

The following tables provide information on gains or losses recognized in AOCI for the cash flow hedges for the periods indicated:

	Years ended December 31,
	2018			2017						2016
$ in millions (net of tax)	Interest Rate Hedges			Power			Interest Rate Hedges			Power			Interest Rate Hedges
Beginning accumulated derivative gain / (loss) in AOCI	$	1.4		$	(4.3	)	$	1.6		$	9.2		$	2.0
Net gains / (losses) associated with current period hedging transactions	(0.1		)	11.9			0.5			15.7			0.4
Net gains / (losses) reclassified to earnings:
Interest expense	(0.7		)	—			(0.7		)	—			(0.8		)
Loss from discontinued operations	—			(5.5		)	—			(29.2		)	—
Transfer of generation assets to subsidiary of parent	—			(2.1		)	—			—			—
Ending accumulated derivative gain / (loss) in AOCI	$	0.6		$	—		$	1.4		$	(4.3	)	$	1.6
Portion expected to be reclassified to earnings in the next twelve months	$	0.7
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	20

Net gains or losses associated with the ineffective portion of the hedging transactions were immaterial in the periods presented.

DP&L has elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivative agreements. The fair value derivative position of DP&L's interest rate swaps are as follows:

			December 31,
	Hedging Designation	Balance sheet classification	2018		2017
Interest rate hedges in a Current asset position	Cash Flow Hedge	Other prepayments and current assets
Gross Fair Value as presented in the Balance Sheets			$	0.9	$	—
Interest rate hedges in a non-current asset position	Cash Flow Hedge	Other deferred assets
Gross Fair Value as presented in the Balance Sheets			$	0.6	$	1.5

Note 7 – Long-term debt

Long-term debt is as follows:

Long-term debt
$ in millions	Interest Rate	Maturity	December 31, 2018			December 31, 2017
Term loan - rates from: 3.57% - 4.82% (a) and 4.00% - 4.60% (b)		2022	$	436.1		$	440.6
Tax-exempt First Mortgage Bonds - rates from: 2.49% - 2.93% (a) and 1.29% - 1.42% (b)		2020	140.0			200.0
U.S. Government note	4.2%	2061	17.7			17.8
Unamortized deferred financing costs			(6.3		)	(9.8		)
Unamortized debt discount			(1.4		)	(2.0		)
Total long-term debt			586.1			646.6
Less: current portion			(4.6		)	(4.6		)
Long-term debt, net of current portion			$	581.5		$	642.0

(a) Range of interest rates for the year ended December 31, 2018.

(b) Range of interest rates for the year ended December 31, 2017.

F-25

At December 31, 2018, maturities of long-term debt are summarized as follows:

Due during the years ending December 31,
$ in millions
2019	$	4.6
2020	144.7
2021	4.7
2022	422.8
2023	0.2
Thereafter	16.8
	593.8
Unamortized discounts and premiums, net	(1.4		)
Deferred financing costs, net	(6.3		)
Total long-term debt	$	586.1

Significant Transactions

On January 3, 2018, DP&L and its lenders amended DP&L's Term Loan B credit agreement. The amendment (a) modified the definition of "applicable rate", from 2.25% per annum to 1.00% per annum - in the case of the Base Rate, and from 3.25% per annum to 2.00% per annum - in the case of the Eurodollar Rate, and (b) included a "call protection" provision which stated that in the event the loan was repriced or any portion of the loans were prepaid, repaid, refinanced, substituted, or replaced on or prior July 3, 2018, such prepayment, acceleration, repayment, refinancing, substitution or replacement would be made at 101% of the principal amount so prepaid, repaid, refinanced, substituted or replaced. After July 3, 2018 any such transaction would occur at 100% of the principal amount of the then outstanding loans. There were no such transactions prior to July 3, 2018.

On March 30, 2018, DP&L commenced a redemption of $60.0 million of outstanding tax exempt First Mortgage Bonds due 2020 at par value (plus accrued and unpaid interest). These bonds were redeemed at par plus accrued interest on April 30, 2018 with cash on hand.

Debt Covenants and Restrictions

DP&L’s unsecured revolving credit agreement and Bond Purchase and Covenants Agreement (financing document entered into in connection with the sale of $200.0 million of variable rate tax-exempt First Mortgage Bonds, dated as of August 1, 2015) have two financial covenants. The first measures Total Debt to Total Capitalization and is calculated, at the end of each fiscal quarter, by dividing total debt at the end of the quarter by total capitalization at the end of the quarter. DP&L’s Total Debt to Total Capitalization ratio shall not be greater than 0.65 to 1.00; except that, the ratio shall be suspended if DP&L’s long-term indebtedness is less than or equal to $750.0 million. Additionally, the ratio shall be suspended any time after separation during which DP&L maintains a rating of BBB- (or in the case of Moody’s Investors Service, Inc. Baa3) or higher with a stable outlook from at least one of Fitch Investors Service Inc., Standard & Poor’s Ratings Services or Moody’s Investors Service, Inc. As of December 31, 2018, DP&L's ratings meet those requirements and this ratio is suspended for the quarter ended December 31, 2018.

The second financial covenant measures EBITDA to Interest Expense. The Total Consolidated EBITDA to Consolidated Interest Charges ratio is calculated, at the end of each fiscal quarter, by dividing consolidated EBITDA for the four prior fiscal quarters by the consolidated interest charges for the same period. The ratio, per the agreement, is to be not less than 2.50 to 1.00. This covenant was met with a ratio of 8.09 to 1.00 as of December 31, 2018.

DP&L does not have any meaningful restrictions in its debt financing documents prohibiting dividends to its parent, DPL.

As of December 31, 2018, DP&L was in compliance with all debt covenants, including the financial covenants described above.

Substantially all property, plant & equipment of DP&L is subject to the lien of the mortgage securing DP&L’s First and Refunding Mortgage. All generation assets were released from the lien of DP&L's first and refunding mortgage in connection with the completion of Generation Separation on October 1, 2017.

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Note 8 – Income Taxes

DP&L’s components of income tax expense on continuing operations were as follows:

	Years ended December 31,
$ in millions	2018			2017			2016
Computation of tax expense
Federal income tax expense (a)	$	22.2		$	31.0		$	50.1
Increases (decreases) in tax resulting from:
State income taxes, net of federal effect	0.6			0.4			0.4
Depreciation of flow-through differences	(4.3		)	1.2			3.0
Investment tax credit amortized	(0.3		)	(0.3		)	(0.4		)
Accrual (settlement) for open tax years	—			(0.5		)	3.4
Other, net (b)	(0.5		)	(0.7		)	(10.5		)
Total tax expense	$	17.7		$	31.1		$	46.0
Components of tax expense
Federal - current	$	1.4		$	13.5		$	37.7
State and Local - current	—			0.2			0.5
Total current	1.4			13.7			38.2
Federal - deferred	15.5			17.0			7.7
State and local - deferred	0.8			0.4			0.1
Total deferred	16.3			17.4			7.8
Total tax expense	$	17.7		$	31.1		$	46.0

(a) The statutory tax rate of 21% in 2018 and 35% in 2017 and 2016 was applied to pre-tax earnings.

(b) Includes expense / (benefit) of $(0.7) million and $(0.4) million in the years ended December 31, 2017 and 2016, respectively, of income tax related to adjustments from prior years.

Effective and Statutory Rate Reconciliation

The following table summarizes a reconciliation of the U.S. statutory federal income tax rate to DP&L's effective tax rate, as a percentage of income from continuing operations before taxes for the years ended December 31, 2018, 2017 and 2016:

	Years ended December 31,
	2018		2017		2016
Statutory Federal tax rate	21.0	%	35.0	%	35.0	%
State taxes, net of Federal tax benefit	0.6	%	0.4	%	0.3	%
AFUDC - Equity	(0.1	)%	1.4	%	2.1	%
Amortization of investment tax credits	(0.3	)%	(0.4	)%	(0.3	)%
Depreciation of flow-through differences	(4.0	)%	—	%	—	%
Other - net	(0.2	)%	(1.3	)%	(5.1	)%
Effective tax rate	17.0	%	35.1	%	32.0	%

Deferred Income Taxes

Deferred income taxes reflect the net tax effects of (a) temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes and (b) operating loss carryforwards. These items are stated at the enacted tax rates that are expected to be in effect when taxes are actually paid or recovered. Investment tax credits related to utility property have been deferred and are being amortized over the estimated useful lives of the related property.

Components of Deferred Tax Assets and Liabilities
	December 31,
$ in millions	2018			2017
Net non-current assets / (liabilities)
Depreciation / property basis	$	(130.6	)	$	(126.5	)
Income taxes recoverable	25.0			11.0
Regulatory assets	(16.2		)	(23.9		)
Investment tax credit	0.5			0.4
Compensation and employee benefits	0.3			17.6
Other	(10.7		)	(9.6		)
Net non-current liabilities	$	(131.7	)	$	(131.0	)

F-27

U.S. Tax Reform

On December 22, 2017, the U.S. enacted the TCJA. The TCJA significantly changes U.S. corporate income tax law.

In 2017, we recognized the income tax effects of the TCJA in accordance with Staff Accounting Bulletin No. 118 (“SAB 118”) which provides SEC guidance on the application of FASC 740, Income Taxes, in the reporting period in which the TCJA was signed into law. Accordingly, our 2017 financial statements reflected the income tax effects of U.S. tax reform for which the accounting was complete and provisional amounts for those impacts for which the accounting under FASC 740 was incomplete, but a reasonable estimate could be determined.

We completed our calculation of the impact of the TCJA in our income tax provision for the year ended December 31, 2018 in accordance with our understanding of the TCJA and guidance available as of the date of this filing. As a result of this remeasurement, certain deferred tax assets and liabilities related to regulated utility property of $17.0 million and $135.2 million at December 31, 2018 and 2017 were recorded as regulatory liabilities and were non-cash adjustments. These amounts result from the remeasurement of certain deferred tax assets and liabilities as the rates changed from 35% to 21%. Additionally, consistent with the provisions of SAB 118, in 2018 we finalized the remeasurement of deferred tax asset balances transferred to AES Ohio Generation as part of Generation Separation which resulted in an additional $10.0 million return of capital to DPL in 2018.

The following table presents the tax expense / (benefit) related to pensions, postemployment benefits, cash flow hedges and financial instruments that were credited to Accumulated other comprehensive loss.

	Years ended December 31,
$ in millions	2018			2017		2016
Tax expense / (benefit)	$	(0.3	)	$	4.0	$	(7.0	)

Uncertain Tax Positions

We apply the provisions of GAAP relating to the accounting for uncertainty in income taxes. A reconciliation of the beginning and ending amount of unrecognized tax benefits for DP&L is as follows:

$ in millions
Balance at December 31, 2016	$	4.9
Calendar 2017
Tax positions taken during prior period	—
Lapse of Statute of Limitations	(0.1		)
Balance at December 31, 2017	4.8
Calendar 2018
Tax positions taken during prior period	—
Lapse of Statute of Limitations	—
Balance at December 31, 2018	$	4.8

Of the December 31, 2018 balance of unrecognized tax benefits, $4.8 million is due to uncertainty in the timing of deductibility.

We recognize interest and penalties related to unrecognized tax benefits in Income tax expense. The amounts accrued and tax expense / (benefit) recorded were not material for each period presented.

Following is a summary of the tax years open to examination by major tax jurisdiction:

U.S. Federal – 2011 and forward

State and Local – 2011 and forward

None of the unrecognized tax benefits are expected to significantly increase or decrease within the next twelve months other than those subject to expiring statute of limitations.

Note 9 – Benefit Plans

Defined Contribution Plans

DP&L sponsors two defined contribution plans. One is for non-union employees (the management plan) and one is for collective bargaining employees (the union plan). Both plans are qualified under Section 401 of the Internal Revenue Code.

Certain non-union and union employees become eligible to participate in their respective plan upon date of hire.

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Participants may elect to contribute up to 85% of eligible compensation to their plan. Non-union participant contributions are matched 100% on the first 1% of eligible compensation and 50% on the next 5% of eligible compensation and they are fully vested in their employer contributions after two years of service. Union participant contributions are matched 150% but are capped at $2,400 for 2018 and they are fully vested in their employer contributions after three years of service. All participants are fully vested in their own contributions.

We contributed $3.7 million, $3.1 million and $5.1 million for the years ended December 31, 2018, 2017 and 2016, respectively. DP&L matching contributions are paid quarterly, in arrears. Therefore, the contributions by year include the fourth quarter matching contribution that is paid in the following year. DP&L also contributes an annual bonus to the accounts of its union participants. This payment is typically made in January of the following year.

Defined Benefit Plans

DP&L sponsors a traditional defined benefit pension plan for most of the employees of DPL and its subsidiaries. For collective bargaining employees, the defined benefits are based on a specific dollar amount per year of service. For all other employees (management employees), the traditional defined benefit pension plan is based primarily on compensation and years of service. As of December 31, 2010, this traditional pension plan formula was closed to new management employees. A participant is 100% vested in all amounts credited to his or her account upon the completion of five-years vesting, as defined in The Dayton Power and Light Company Retirement Income Plan, or the participant’s death or disability. If a participant’s employment is terminated, other than by death or disability, prior to such participant becoming 100% vested in his or her account, the account shall be forfeited as of the date of termination. Employees that transferred from DP&L to the Service Company maintain their previous eligibility to participate in the DP&L pension plan. In addition, employees that transferred from DP&L to AES Ohio Generation due to Generation Separation maintain their previous eligibility to participate in the DP&L pension plan.

Almost all management employees beginning employment on or after January 1, 2011 participate in a cash balance pension plan formula. Similar to the traditional pension plan for management employees, the cash balance benefits are based on compensation and years of service. A participant shall become 100% vested in all amounts credited to his or her account upon the completion of three vesting years, as defined in The Dayton Power and Light Company Retirement Income Plan, or the participant’s death or disability. If a participant’s employment is terminated, other than by death or disability, prior to such participant becoming 100% vested in his or her account, the account shall be forfeited as of the date of termination. Vested benefits in the cash balance plan are fully portable upon termination of employment.

In addition, we have a Supplemental Executive Retirement Plan (SERP) for certain retired key executives. The SERP has an immaterial unfunded liability related to agreements for retirement benefits of certain terminated and retired key executives. We also include our net liability to our partners in our co-owned generating plants related to our share of their pension liabilities within Pension, retiree and other benefits on our Balance Sheets.

We recognize an asset for a plan’s overfunded status and a liability for a plan’s underfunded status and recognize, as a component of OCI, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. For the transmission and distribution areas of our electric business, these amounts are recorded as regulatory assets and liabilities which represent the regulated portion that would otherwise be charged or credited to AOCI. We have historically recorded these costs on the accrual basis and this is how these costs have been historically recovered through customer rates. This factor, combined with the historical precedents from the PUCO and FERC, make these costs probable of future rate recovery.

Postretirement Benefits

Qualified employees who retired prior to 1987 and their dependents are eligible for health care and life insurance benefits until their death, while qualified employees who retired after 1987 are eligible for life insurance benefits and partially subsidized health care. The partially subsidized health care is at the election of the employee, who pays the majority of the cost, and is available only from their retirement until they are covered by Medicare. We have funded a portion of the union-eligible benefits using a Voluntary Employee Beneficiary Association Trust. These postretirement health care benefits and the related unfunded obligation of $9.2 million and $12.7 million at December 31, 2018 and 2017, respectively, were not material to the financial statements in the periods covered by this report.

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The following tables set forth the changes in our pension plan's obligations and assets recorded on the Balance Sheets at December 31, 2018 and 2017. The amounts presented in the following tables for pension obligations include the collective bargaining plan formula, traditional management plan formula and cash balance plan formula and the SERP in the aggregate and have not been adjusted for $1.8 million and $1.1 million of costs billed to the Service Company for the years ended December 31, 2018 and 2017 or $3.3 million and $0.7 million of costs billed to AES Ohio Generation for the years ended December 31, 2018 and 2017.

$ in millions	Years ended December 31,
Change in benefit obligation	2018			2017
Benefit obligation at January 1	$	436.9		$	419.6
Service cost	6.1			5.7
Interest cost	13.8			14.2
Plan amendments	5.1			—
Plan curtailment	—			3.0
Actuarial (gain) / loss	(34.6		)	28.1
Benefits paid	(40.8		)	(33.7		)
Benefit obligation at December 31	386.5			436.9
Change in plan assets
Fair value of plan assets at January 1	357.5			341.0
Actual return on plan assets	(11.7		)	44.8
Employer contributions	7.9			5.4
Benefits paid	(40.8		)	(33.7		)
Fair value of plan assets at December 31	312.9			357.5
Unfunded status of plan	$	(73.6	)	$	(79.4	)
	December 31,
Amounts recognized in the Balance sheets	2018			2017
Current liabilities	$	(0.4	)	$	(0.4	)
Non-current liabilities	(73.2		)	(79.0		)
Net liability at end of year	$	(73.6	)	$	(79.4	)
Amounts recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax
Components:
Prior service cost	$	10.4		$	6.7
Net actuarial loss	137.2			148.3
Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax	$	147.6		$	155.0
Recorded as:
Regulatory asset	$	87.3		$	92.2
Accumulated other comprehensive income	60.3			62.8
Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax	$	147.6		$	155.0

The accumulated benefit obligation for our defined benefit pension plans was $378.7 million and $428.3 million at December 31, 2018 and 2017, respectively.

The net periodic benefit cost of the pension plans was:

	Years ended December 31,
$ in millions	2018			2017			2016
Service cost	$	6.1		$	5.7		$	5.7
Interest cost	13.8			14.2			14.7
Expected return on assets	(21.2		)	(22.8		)	(22.8		)
Plan curtailment (a)	—			5.6			5.7
Amortization of unrecognized:
Actuarial loss	9.4			8.7			7.2
Prior service cost	1.4			1.5			3.0
Net periodic benefit cost	$	9.5		$	12.9		$	13.5
Rates relevant to each year's expense calculations
Discount rate	3.66		%	4.28		%	4.49		%
Expected return on plan assets	6.25		%	6.50		%	6.50		%

(a)    As a result of the decision to retire certain coal-fired plants, we recognized a plan curtailment of $5.6 million and $5.7 million in 2017 and 2016, respectively.

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Other Changes in Plan Assets and Benefit Obligation Recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities

	Years ended December 31,
$ in millions	2018			2017			2016
Net actuarial loss	$	3.4		$	9.1		$	20.9
Plan curtailment (a)	—			(5.6		)	(5.7		)
Reversal of amortization item:
Net actuarial loss	(9.4		)	(8.7		)	(7.2		)
Prior service cost	(1.4		)	(1.5		)	(3.0		)
Total recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities	$	(7.4	)	$	(6.7	)	$	5.0
Total recognized in net periodic benefit cost and Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities	$	2.1		$	6.2		$	18.5

(a)    As a result of the decision to retire certain coal-fired plants, we recognized a plan curtailment of $5.6 million and $5.7 million in 2017 and 2016, respectively.

Significant Gains and Losses Related to Changes in the Benefit Obligation

The actuarial gain of $34.6 million decreased the benefit obligation for the year ended December 31, 2018 and an actuarial loss of $28.1 million increased the benefit obligation for the year ended December 31, 2017. The actuarial gain in 2018 was primarily due to an increase in the discount rate, while the actuarial loss in 2017 was primarily due to a decrease in the discount rate.

Assumptions

Our expected return on plan asset assumptions, used to determine benefit obligations, are based on historical long-term rates of return on investments, which use the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current market factors, such as inflation and interest rates, as well as asset diversification and portfolio rebalancing, are evaluated when long-term capital market assumptions are determined. Peer data and historical returns are reviewed to verify reasonableness and appropriateness.

At December 31, 2018, we are maintaining our long-term rate of return assumption of 6.25% for pension plan assets. The rate of return represents our long-term assumptions based on our long-term portfolio mix. Also, at December 31, 2018, we have increased our assumed discount rate to 4.35% from 3.66% for pension expense to reflect current duration-based yield curve discount rates. A one percent increase in the rate of return assumption for pension would result in a decrease in 2019 pension expense of approximately $3.2 million. A one percent decrease in the rate of return assumption for pension would result in an increase in 2019 pension expense of approximately $3.2 million. A 25-basis point increase in the discount rate for pension would result in a decrease of approximately $0.1 million to 2019 pension expense. A 25-basis point decrease in the discount rate for pension would result in an increase of approximately $0.4 million to 2019 pension expense.

In determining the discount rate to use for valuing liabilities, we used a market yield curve on high-quality fixed income investments as of December 31, 2018. We project the expected benefit payments under the plan based on participant data and based on certain assumptions concerning mortality, retirement rates, termination rates, etc. The expected benefit payments for each year are then discounted back to the measurement date using the appropriate spot rate for each half-year from the yield curve, thereby obtaining a present value of all expected future benefit payments using the yield curve. Finally, an equivalent single discount rate is determined which produces a present value equal to the present value determined using the full yield curve.

In future periods, differences in the actual return on pension plan assets and assumed return, or changes in the discount rate, will affect the timing of contributions, if any, to the plans.

The weighted average assumptions used to determine benefit obligations at December 31, 2018, 2017 and 2016 were:

Benefit Obligation Assumptions	Pension
	2018	2017	2016
Discount rate for obligations	4.35%	3.66%	4.28%
Rate of compensation increases	3.94%	3.94%	3.94%

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Pension Plan Assets

Plan assets are invested using a total return investment approach whereby a mix of equity securities, debt securities and other investments are used to preserve asset values, diversify risk and achieve our target investment return benchmark. Investment strategies and asset allocations are based on careful consideration of plan liabilities, the plan's funded status and our financial condition. Investment performance and asset allocation are measured and monitored on an ongoing basis.

Plan assets are managed in a balanced portfolio comprised of two major components: an equity portion and a fixed income portion. The expected role of plan equity investments is to maximize the long-term real growth of plan assets, while the role of fixed income investments is to generate current income, provide for more stable periodic returns and provide some protection against a prolonged decline in the market value of plan equity investments.

Long-term strategic asset allocation guidelines, as well as short-term tactical asset allocation guidelines, are determined by a Risk/Advisory Committee and approved by a Fiduciary Committee. These allocations consider the plan’s long-term objectives. The long-term target allocations for plan assets are 24% – 52% for equity securities and 47% – 65% for fixed income securities. Equity securities include U.S. and international equity, while fixed income securities include long-duration and high-yield bond funds and emerging market debt funds.

Tactically, the committees, on a short-term basis, will make asset allocations that are outside the long-term allocation guidelines. The short-term allocation positions are likely to not exceed one-year in duration. In addition to the equity and fixed income investments, the short-term allocation may also include a relatively small allocation to alternative investments. The plan currently has a small target allocation in a core property fund.

Most of our plan assets are measured using quoted, observable prices which are considered Level One inputs in the Fair Value Hierarchy. The Core Property Collective Fund is measured using Level Two inputs that are quoted prices for identical assets in markets that are less active.

The following table summarizes our target pension plan allocation for 2018:

	Long-Term Mid-Point Target Allocation	Percentage of plan assets as of December 31,
Asset category		2018	2017
Equity Securities	38%	33%	35%
Debt Securities	56%	58%	55%
Cash and Cash Equivalents	—%	1%	—%
Real Estate	6%	8%	10%

The fair values of our pension plan assets at December 31, 2018 by asset category are as follows:

Fair Value Measurements for Pension Plan Assets at December 31, 2018
$ in millions	Market Value at December 31, 2018		Quoted prices in active markets for identical assets		Significant observable inputs		Significant unobservable inputs
Asset category			(Level 1)		(Level 2)		(Level 3)
Mutual funds:
U.S. equities (a)	$	79.3	$	79.3	$	—	$	—
International equities (a)	25.9		25.9		—		—
Fixed income (b)	143.7		143.7		—		—
Fixed income securities:
U.S. Treasury securities	37.5		37.5		—		—
Cash and cash equivalents:
Money market funds (c)	2.4		2.4		—		—
Other investments:
Core property collective fund (d)	24.1		—		24.1		—
Total pension plan assets	$	312.9	$	288.8	$	24.1	$	—

(a) This category includes investments in equity securities of large, small and medium sized U.S. companies and equity securities of foreign companies including those in developing countries. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(b) This category includes investments in investment-grade fixed-income instruments, U.S. dollar-denominated debt securities of emerging market issuers and high yield fixed-income securities that are rated below investment grade. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

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(c) This category is comprised of investments in U.S. treasury obligations that seek to preserve principal and maintain liquidity while providing current income. The funds are valued at the assets’ amortized cost to maintain a stable per share net asset value.

(d) This category represents a property fund that invests in commercial real estate. The fair value of the fund is valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

The fair values of our pension plan assets at December 31, 2017 by asset category are as follows:

Fair Value Measurements for Pension Plan Assets at December 31, 2017
$ in millions	Market Value at December 31, 2017		Quoted prices in active markets for identical assets		Significant observable inputs		Significant unobservable inputs
Asset category			(Level 1)		(Level 2)		(Level 3)
Mutual funds:
U.S. equities (a)	$	78.2	$	78.2	$	—	$	—
International equities (a)	46.3		46.3		—		—
Fixed income (b)	163.3		163.3		—		—
Fixed income securities:
U.S. Treasury securities	33.5		33.5		—		—
Other investments: (c)
Core property collective fund	36.2		—		36.2		—
Total pension plan assets	$	357.5	$	321.3	$	36.2	$	—

(a) This category includes investments in equity securities of large, small and medium sized U.S. companies and equity securities of foreign companies including those in developing countries. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(b) This category includes investments in investment-grade fixed-income instruments, U.S. dollar-denominated debt securities of emerging market issuers and high yield fixed-income securities that are rated below investment grade. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(c) This category represents a property fund that invests in commercial real estate. The fair value of the fund is valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

Pension Funding

We generally fund pension plan benefits as accrued in accordance with the minimum funding requirements of the Employee Retirement Income Security Act of 1974 (ERISA) and, in addition, make voluntary contributions from time to time. We contributed $7.5 million to the pension plan in the year ended December 31, 2018 and $5.0 million to the pension plan in each of the years ended December 31, 2017 and 2016.

We expect to make contributions of $0.4 million to our SERP in 2019 to cover benefit payments. We also expect to make contributions of $7.5 million to our pension plan during 2019.

Funding for the qualified Defined Benefit Pension Plan is based upon actuarially determined contributions that consider the amount deductible for income tax purposes and the minimum contribution required under ERISA, as amended by the Pension Protection Act of 2006, as well as targeted funding levels necessary to meet certain thresholds.

From an ERISA funding perspective, DP&L’s funded target liability percentage was estimated to be 101%. In addition, DP&L must also contribute the normal service cost earned by active participants during the plan year. The funding of normal cost is expected to be approximately $5.4 million in 2019, which includes $1.9 million for plan expenses. Each year thereafter, if the plan’s underfunding increases to more than the present value of the remaining annual installments, the excess is separately amortized over seven years. DP&L’s funding policy for the pension plans is to contribute annually no less than the minimum required by applicable law, and no more than the maximum amount that can be deducted for federal income tax purposes.

Benefit payments, which reflect future service, are expected to be paid as follows:

Estimated future benefit payments
$ in millions due within the following years:	Pension
2019	$	26.7
2020	$	26.5
2021	$	26.3
2022	$	26.0
2023	$	25.9
2024 - 2028	$	125.1

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Note 10 – Equity

Redeemable Preferred Stock

On October 13, 2016 (the "Redemption Date"), DP&L redeemed all of its issued and outstanding preferred stock, consisting of the following series: Preferred Stock, 3.75% Series A, Cumulative (the “Series A Stock”); Preferred Stock, 3.75% Series B, Cumulative (the “Series B Stock”); and Preferred Stock, 3.90% Series C, Cumulative (the “Series C Stock” and, together with the Series A Stock and the Series B Stock, the “Preferred Stock”). On the Redemption Date, the Preferred Stock of each series was redeemed at the following prices as specified in DP&L’s Amended and Restated Articles of Incorporation, plus, in each case an amount equal to all accrued dividends payable with respect to such Preferred Stock to the Redemption Date: a price of $102.50 per share for the Series A Stock, a price of $103.00 per share for the Series B Stock, and a price of $101.00 per share for the Series C Stock. Dividends on the Preferred Stock ceased to accrue on the Redemption Date. Upon redemption, the Preferred Stock was no longer outstanding, and all rights of the holders thereof as shareholders of DP&L, except the right to payment of the redemption price, ceased to exist. The difference between the carrying value of the Redeemable Preferred Stock and the redemption amount was charged to Other paid-in capital.

Common Stock

DP&L has 50,000,000 authorized common shares, of which 41,172,173 are outstanding at December 31, 2018. All common shares are held by DP&L’s parent, DPL.

Equity Settlement of Related Party Payable

In 2016, DP&L settled a $7.5 million payable to DPL relating to income taxes. This payable balance was settled through equity and DPL's investment in DP&L was increased by $7.5 million as consideration for extinguishing the payable.

Capital Contribution and Returns of Capital

In 2018, DP&L received an $80.0 million capital contribution from its parent, DPL. In addition, DP&L made returns of capital payments of $43.8 million to DPL. In addition, DP&L recorded $10.0 million in 2018 as a return of capital to transfer additional deferred tax amounts under Generation Separation. See Note 8 – Income Taxes and Note 14 – Generation Separation for more information.

In 2017, DP&L received a $70.0 million capital contribution from its parent, DPL. In addition, DP&L made returns of capital payments of $39.0 million to DPL. In connection with Generation Separation, DP&L recorded $86.2 million as a return of capital. See Note 14 – Generation Separation for more information.

In 2016, DP&L made a dividend payment of $70.0 million to DPL.

Note 11 – Contractual Obligations, Commercial Commitments and Contingencies

DP&L – Equity Ownership Interest

DP&L has a 4.9% equity ownership interest in OVEC which is recorded using the cost method of accounting under GAAP. At December 31, 2018, DP&L could be responsible for the repayment of 4.9%, or $68.1 million, of a $1,389.6 million debt obligation comprised of both fixed and variable rate securities with maturities between 2019 and 2040. OVEC could also seek additional contributions from us to avoid a default in the event that other OVEC members defaulted on their respective OVEC obligations. One of the other OVEC members, with a 4.85% interest in OVEC, filed for bankruptcy protection and the bankruptcy court approved that member's rejection of the OVEC arrangement and its related obligations on July 31, 2018. We do not expect these events to have a material impact on our financial condition, results of operations or cash flows.

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Contractual Obligations and Commercial Commitments

We enter into various contractual obligations and other commercial commitments that may affect the liquidity of our operations. At December 31, 2018, these include:

	Payments due in:
$ in millions	Total		Less than 1 year		2 - 3 years		4 - 5 years		More than 5 years
Electricity purchase commitments	$	209.4	$	139.5	$	69.9	$	—	$	—
Purchase orders and other contractual obligations	$	39.8	$	11.3	$	14.7	$	13.8	$	—

Electricity purchase commitments:

DP&L enters into long-term contracts for the purchase of electricity. In general, these contracts are subject to variable quantities or prices and are terminable only in limited circumstances.

Purchase orders and other contractual obligations:

At December 31, 2018, DP&L had various other contractual obligations including non-cancelable contracts to purchase goods and services with various terms and expiration dates. Due to uncertainty regarding the timing and payment of future obligations to the Service Company, and DP&L's ability to terminate such obligations upon 90 days' notice, we have excluded such amounts in the contractual obligations table above

Contingencies

In the normal course of business, we are subject to various lawsuits, actions, proceedings, claims and other matters asserted under laws and regulations. We believe the amounts provided in our Financial Statements, as prescribed by GAAP, are adequate in light of the probable and estimable contingencies. However, there can be no assurances that the actual amounts required to satisfy alleged liabilities from various legal proceedings, claims, tax examinations, and other matters, including the matters discussed below, and to comply with applicable laws and regulations, will not exceed the amounts reflected in our Financial Statements. As such, costs, if any, that may be incurred in excess of those amounts provided as of December 31, 2018, cannot be reasonably determined.

Environmental Matters

DP&L's facilities and operations are subject to a wide range of federal, state and local environmental laws, rules and regulations. The environmental issues that may affect us include the following. However, as described further below, as a result of DPL’s retirement of its Stuart and Killen generating stations, the sale of its ownership interest in the Miami Fort and Zimmer generating stations, the planned 2020 retirement of Conesville and our exiting of our generation business, certain of these environmental regulations and laws are now not expected to have a material impact on DPL with respect to these generating stations.

• The federal CAA and state laws and regulations (including SIPs) which require compliance, obtaining permits and reporting as to air emissions;

• Rules and future rules issued by the USEPA, the Ohio EPA or other authorities that require or will require reporting and reductions of GHGs;

• Rules and future rules issued by the USEPA, the Ohio EPA or other authorities associated with the federal Clean Water Act, which prohibits the discharge of pollutants into waters of the United States except pursuant to appropriate permits; and

• Solid and hazardous waste laws and regulations, which govern the management and disposal of certain waste.

In addition to imposing continuing compliance obligations, these laws, rules and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. In the normal course of business, we have investigatory and remedial activities underway at our facilities to comply, or to determine compliance, with such laws, rules and regulations. We record liabilities for loss contingencies related to environmental matters when a loss is probable of occurring and can be reasonably estimated in accordance with the provisions of GAAP. Accordingly, we have immaterial accruals for loss contingencies for environmental matters. We also have a number of environmental matters for which we have not accrued loss contingencies because the risk of loss is not probable, or a loss cannot be reasonably estimated. We evaluate the potential liability related to environmental matters quarterly and may revise our estimates. Such revisions in the estimates of the potential liabilities could have a material adverse effect on our results of operations, financial condition or cash flows.

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We have several pending environmental matters associated with our current and previously owned and operated coal-fired generation units. Some of these matters could have material adverse impacts on our results of operations, financial condition or cash flows.

Note 12 – Related Party Transactions

Service Company

The Service Company allocates the costs for services provided based on cost drivers designed to result in fair and equitable allocations. This includes ensuring that the regulated utilities served, including DP&L, are not subsidizing costs incurred for the benefit of other businesses.

Benefit Plans

DPL participates in an agreement with Health and Welfare Benefit Plans LLC, an affiliate of AES, to participate in a group benefits program, including but not limited to, health, dental, vision and life benefits. Health and Welfare Benefit Plans LLC administers the financial aspects of the group insurance program, receives all premium payments from the participating affiliates, and makes all vendor payments.

Long-term Compensation Plan

During 2018, 2017 and 2016, many of DP&L’s non-union employees received benefits under the AES Long-term Compensation Plan, a deferred compensation program. This type of plan is a common employee retention tool used in our industry. Benefits under this plan are granted in the form of performance units payable in cash and AES restricted stock units. Restricted stock units vest ratably over a three-year period. The performance units payable in cash vest at the end of the three-year performance period and are subject to certain AES performance criteria. Total deferred compensation expense recorded during 2018, 2017 and 2016 was $0.3 million, $0.4 million and $0.5 million, respectively, and was included in “Other Operating Expenses” on DP&L’s Statements of Operations. The value of these benefits is being recognized over the 36-month vesting period and a portion is recorded as miscellaneous deferred credits with the remainder recorded as “Paid in capital” on DP&L’s Balance Sheets in accordance with FASC 718 “Compensation - Stock Compensation.”

The following table provides a summary of our related party transactions:

	Years ended December 31,
$ in millions	2018			2017			2016
DP&L Cost of revenues:
Fuel and power purchased from AES Ohio Generation	$	—		$	5.4		$	8.7
DP&L Operation & Maintenance Expenses:
Premiums charged for insurance services provided by MVIC (a)	$	2.7		$	3.1		$	3.4
Transactions with the Service Company:
Charges for services provided	$	25.7		$	39.0		$	38.7
Charges to the Service Company	$	4.9		$	4.2		$	4.5
Transactions with other AES affiliates:
Charges for health, welfare and benefit plans	$	8.7		$	14.3		$	9.4
Charges to affiliates for non-power goods or services (b)	$	7.1		$	3.7		$	5.7
Consulting services	$	2.0		$	—		$	—
Balances with related parties:	At December 31, 2018			At December 31, 2017
Net payable to the Service Company	$	(4.8	)	$	(3.9	)
Net receivable from / (payable) to other AES affiliates	$	(0.5	)	$	4.8

(a) MVIC, a wholly-owned captive insurance subsidiary of DPL, provides insurance coverage to DP&L and other DPL subsidiaries for workers’ compensation, general liability, property damages and directors’ and officers’ liability. These amounts represent insurance premiums charged by MVIC to DP&L.

(b) In the normal course of business DP&L incurred and recorded expenses on behalf of DPL affiliates. Such expenses included but were not limited to employee-related expenses, accounting, information technology, payroll, legal and other administration expenses. DP&L subsequently charged these expenses to the affiliates at DP&L’s cost and credited the expense in which they were initially recorded.

Income Taxes

AES files federal and state income tax returns which consolidate DPL and its subsidiaries, including DP&L. Under a tax sharing agreement with DPL, DP&L is responsible for the income taxes associated with its own taxable income and records the provision for income taxes using a separate return method. Under this agreement, DP&L had a net receivable balance of $19.6 million and $6.5 million at December 31, 2018 and 2017, respectively, which is

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recorded in Taxes receivable on the accompanying Balance Sheets. During 2018, 2017 and 2016, DP&L made net payments of $14.6 million, $28.1 million and $0.0 million respectively, to DPL for its share of income taxes.

Note 13 – Revenue

Revenue is primarily earned from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Revenue is recorded net of any taxes assessed on and collected from customers, which are remitted to the governmental authorities.

Retail Revenues – DP&L energy sales to utility customers are based on the reading of meters at the customer's location that occurs on a systematic basis throughout the month. DP&L sells electricity directly to end-users, such as homes and businesses, and bills customers directly. Performance obligations for retail revenues are satisfied over time as energy is delivered and the same method is used to measure progress, and thus the performance obligation meets the criteria to be considered a series. This includes both the promise to transfer energy and other distribution and/or transmission services.

In exchange for the exclusive right to sell or distribute electricity in our service area, DP&L is subject to rate regulation by federal and state regulators. This regulation sets the framework for the prices (“tariffs”) that DP&L is allowed to charge customers for electricity. Since tariffs are approved by the regulator, the price that DP&L has the right to bill corresponds directly with the value to the customer of DP&L's performance completed in each period. Therefore, revenue under these contracts is recognized using an output method measured by the MWhs delivered each month at the approved tariff.

In cases where a customer chooses to receive generation services from a CRES provider, the price for generation services is negotiated between the customer and the CRES provider, and DP&L only serves as a billing agent if requested by the CRES provider. As such, DP&L recognizes the consolidated billing arrangement with the CRES provider on a net basis, thereby recording no revenue for the generation component. Retail revenue from these customers would only be related to transmission and distribution charges.

Wholesale Revenues – DP&L's share of the power produced at OVEC is sold to PJM and is classified as Wholesale revenues.

In PJM, the promise to sell energy as wholesale revenue is separately identifiable from participation in the capacity market and the two products can be transacted independently of one another. Therefore, wholesale revenues are a separate contract with a single performance obligation. Revenue is recorded based on the quantities (MWh) delivered in each hour during each month at the spot price, making the contract effectively “month-to-month”.

RTO Revenues – Compensation for use of DP&L’s transmission assets and compensation for various ancillary services are classified as RTO revenues. As DP&L owns and operates transmission lines in southwest Ohio within PJM, demand charges collected from network customers by PJM are then allocated to the appropriate transmission owners (i.e. DP&L) and recognized as transmission revenues. Additionally, as an owner of generation and transmission assets within PJM, DPL is compensated for various ancillary services; such as reactive supply, regulation services, scheduling reserves, operating reserves, spinning/synchronized reserves as well as congestion credits that are provided to PJM via these assets.

Transmission revenues have a single performance obligation, as transmission services represent a distinct service. Additionally, as the performance obligation is satisfied over time and the same method is used to measure progress, the performance obligation meets the criteria to be considered a series. The price that DP&L, as the transmission operator, has the right to bill (received as a credit from PJM) corresponds directly with the value to the customer of performance completed in each period, as the price paid is the allocation of the tariff rate (as approved by the regulator) charged to network participants.

RTO Capacity Revenues – Compensation received from PJM for making installed generation capacity available to satisfy system integrity and reliability requirements is classified as RTO capacity revenues. Capacity, which is a stand-ready obligation to deliver energy when called upon by the RTO, is measured using MWs. If plant availability exceeds a contractual target, we may receive a performance bonus payment, or if the plant availability falls below a guaranteed minimum target, we may incur a non-availability penalty. Such bonuses or penalties represent a form of

F-37

variable consideration and are estimated and recognized when it is probable that there will not be a significant reversal and therefore the transaction price is recognized on an output basis based on the MWs.

RTO capacity revenues have a single performance obligation, as capacity is a distinct good. Additionally, as the performance obligation is satisfied over time and the same method is used to measure progress, the performance obligation meets the criteria to be considered a series. The capacity price is set through a competitive auction process established by PJM.

DP&L's revenue from contracts with customers was $706.6 million for the year ended December 31, 2018. The following table presents our revenue from contracts with customers and other revenue by segment for the year ended December 31, 2018:

	Year ended December 31,
$ in millions	2018
Retail Revenue
Retail revenue from contracts with customers	$	625.8
Other retail revenues (a)	32.1
Wholesale Revenue
Wholesale revenue from contracts with customers	29.9
RTO revenue	43.1
RTO capacity revenues	7.8
Total revenues	$	738.7

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606.

The balances of receivables from contracts with customers were $70.1 million and $62.1 million as of December 31, 2018 and January 1, 2018, respectively. Payment terms for all receivables from contracts with customers are typically within 30 days.

We have elected to apply the optional disclosure exemptions under FASC 606. Therefore, we have no disclosures pertaining to revenue expected to be recognized in any future year related to remaining performance obligations, as we exclude contracts with an original length of one year or less, contracts for which we recognize revenue based on the amount we have the right to invoice for services performed, and variable consideration allocated entirely to a wholly unsatisfied performance obligation when the consideration relates specifically to our efforts to satisfy the performance obligation and depicts the amount to which we expect to be entitled for DP&L.

Note 14 – Generation Separation

On October 1, 2017, DP&L completed the transfer of its generating plants, the real property on which the generation plants and generation-related assets are sited, step-up transformers and other transmission plant assets used to interconnect with the electric transmission grid, fuel inventory, equipment inventory and spare parts, working capital, and other miscellaneous generation-related assets and liabilities to AES Ohio Generation. The transfer was completed as a contribution through an asset contribution agreement to a wholly-owned subsidiary of DP&L after which DP&L then distributed all of the outstanding equity in the subsidiary to DPL and then the subsidiary was merged into AES Ohio Generation.

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The following table summarizes the carrying amounts of DP&L's Generation assets that were transferred to AES Ohio Generation on October 1, 2017:

$ in millions	October 1, 2017
ASSETS
Restricted cash	$	2.0
Accounts receivable, net	31.3
Inventories	42.0
Taxes applicable to subsequent years	1.8
Property, plant & equipment, net	87.0
Intangible assets, net	0.7
Other assets	15.5
Total assets	$	180.3
LIABILITIES
Accounts payable	$	12.4
Accrued taxes (b)	(3.9		)
Long-term debt (a)	0.3
Deferred taxes (b)	(91.9		)
Pension, retiree and other benefits	9.6
Unamortized investment tax credit	15.1
Asset retirement obligations	126.3
Other liabilities	24.1
Total liabilities	$	92.0
Total accumulated other comprehensive income	2.1
Net assets transferred to AES Ohio Generation	$	86.2

(a) Long-term debt that transferred to AES Ohio Generation relates to capital leases.

(b) Accrued taxes and deferred taxes transferred to AES Ohio Generation represent the tax asset position netted with liabilities on DP&L prior to Generation Separation.

DP&L's generation business met the criteria to be classified as a discontinued operation, and, accordingly, the historical activity has been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016.

The following table summarizes the revenues, cost of revenues, operating and other expenses and income tax of discontinued operations for the periods indicated:

	Years ended December 31,
$ in millions	2017			2016
Revenues	$	358.4		$	557.9
Cost of revenues	(191.6		)	(341.1		)
Operating and other expenses	(156.8		)	(202.0		)
Fixed-asset impairment	(66.3		)	(1,353.5		)
Loss from discontinued operations	(56.3		)	(1,338.7		)
Income tax benefit from discontinued operations	(15.9		)	(468.4		)
Net loss from discontinued operations	$	(40.4	)	$	(870.3	)

In 2018, DP&L transferred additional deferred taxes to AES Ohio Generation under the provisions of SAB 118 through an equity transaction with DPL in the amount of $10.0 million. See Note 8 – Income Taxes for additional information.

Cash flows related to discontinued operations are included in the Statements of Cash Flows. Cash flows from operating activities for discontinued operations were $21.8 million and $29.9 million for the years ended December 31, 2017 and 2016, respectively. Cash flows from investing activities for discontinued operations were $(3.5) million and $(39.0) million for the years ended December 31, 2017 and 2016, respectively.

The PUCO authorized DP&L to maintain long-term debt of $750 million or 75% of its rate base, whichever is greater, until January 1, 2018, or to file an application to explain why it would not achieve those metrics. Accordingly, $750.0 million of debt and the pro rata interest expense associated with that debt were allocated to continuing operations. All remaining interest expense is included in discontinued operations above. The interest expense included in discontinued operations was $0.2 million and $0.5 million for the years ended December 31, 2017 and 2016, respectively.

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Note 15 – Dispositions

Beckjord Facility – On February 26, 2018, DP&L and its co-owners of the retired Beckjord Facility agreed to transfer their interests in the retired Facility to a third party, including their obligations to remediate the Facility and its site, and the transfer occurred on that same date. As a result, DP&L recognized a loss on the transfer of $12.4 million and made cash expenditures of $14.5 million, inclusive of cash expenditures for the transfer charges. The Beckjord Facility was retired in 2014, and, as such, the income / (loss) from continuing operations before income tax related to the Beckjord Facility was immaterial for the years ended December 31, 2018, 2017 and 2016, excluding the loss on transfer noted above.

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Schedule II

    

THE DAYTON POWER AND LIGHT COMPANY
VALUATION AND QUALIFYING ACCOUNTS
For each of the three years ended December 31, 2018
$ in thousands
Description	Balance at Beginning of Period		Additions		Deductions (a)		Balance at End of Period
Year ended December 31, 2018
Deducted from accounts receivable -
Provision for uncollectible accounts	$	1,053	$	3,411	$	3,574	$	890
Year ended December 31, 2017
Deducted from accounts receivable -
Provision for uncollectible accounts	$	1,159	$	3,141	$	3,247	$	1,053
Year ended December 31, 2016
Deducted from accounts receivable -
Provision for uncollectible accounts	$	835	$	4,113	$	3,789	$	1,159

(a)    Amounts written off, net of recoveries of accounts previously written off

F-41

THE DAYTON POWER AND LIGHT COMPANY
Condensed Statements of Operations
(Unaudited)
	Three months ended						Nine months ended
	September 30,						September 30,
$ in millions	2019			2018			2019			2018
Revenues	$	191.1		$	198.7		$	570.2		$	563.5
Operating costs and expenses
Net fuel cost	0.6			0.1			2.0			1.7
Net purchased power cost	65.9			83.0			193.3			235.7
Operation and maintenance	42.2			33.8			135.2			105.9
Depreciation and amortization	17.4			19.1			52.9			56.5
Taxes other than income taxes	20.8			19.0			58.2			54.3
Loss / (gain) on asset disposal	(0.1		)	—			—			0.1
Loss on disposal of business (Note 12)	—			—			—			12.4
Total operating costs and expenses	146.8			155.0			441.6			466.6
Operating income	44.3			43.7			128.6			96.9
Other income / (expense), net:
Interest expense	(6.1		)	(5.8		)	(19.9		)	(20.5		)
Loss on early extinguishment of debt	—			—			—			(0.6		)
Other income / (expense)	(0.5		)	(0.4		)	0.1			(1.9		)
Total other expense, net	(6.6		)	(6.2		)	(19.8		)	(23.0		)
Income before income tax	37.7			37.5			108.8			73.9
Income tax expense / (benefit)	(7.2		)	6.3			5.1			12.0
Net income	$	44.9		$	31.2		$	103.7		$	61.9

See Notes to Condensed Financial Statements.

F-42

THE DAYTON POWER AND LIGHT COMPANY
Condensed Statements of Comprehensive Income
(Unaudited)
	Three months ended						Nine months ended
	September 30,						September 30,
$ in millions	2019			2018			2019			2018
Net income	$	44.9		$	31.2		$	103.7		$	61.9
Derivative activity:
Change in derivative fair value, net of income tax (expense) / benefit of $0.0, $(0.1), $0.2 and $(0.1) for each respective period	(0.1		)	—			(0.9		)	0.5
Reclassification to earnings, net of income tax expense of $0.0, $0.1, $0.0 and $0.6 for each respective period	—			(0.2		)	(0.1		)	(0.5		)
Total change in fair value of derivatives	(0.1		)	(0.2		)	(1.0		)	—
Pension and postretirement activity:
Reclassification to earnings, net of income tax (benefit) / expense of $0.9, $(0.2), $(0.5) and $(0.7) for each respective period	1.7			0.8			2.1			2.5
Total change in unfunded pension and postretirement obligations	1.7			0.8			2.1			2.5
Other comprehensive income	1.6			0.6			1.1			2.5
Net comprehensive income	$	46.5		$	31.8		$	104.8		$	64.4

See Notes to Condensed Financial Statements.

F-43

THE DAYTON POWER AND LIGHT COMPANY
Condensed Balance Sheets
(Unaudited)
$ in millions	September 30, 2019			December 31, 2018
ASSETS
Current assets:
Cash and cash equivalents	$	14.4		$	45.0
Restricted cash	17.6			21.2
Accounts receivable, net (Note 2)	71.7			90.4
Inventories (Note 2)	9.8			7.7
Taxes applicable to subsequent years	18.1			72.4
Regulatory assets, current	40.2			41.1
Taxes receivable	17.4			19.6
Prepayments and other current assets	8.6			13.3
Total current assets	197.8			310.7
Property, plant & equipment:
Property, plant & equipment	2,306.5			2,274.4
Less: Accumulated depreciation and amortization	(1,010.4		)	(988.0		)
	1,296.1			1,286.4
Construction work in process	93.0			31.7
Total net property, plant & equipment	1,389.1			1,318.1
Other non-current assets:
Regulatory assets, non-current	154.7			152.6
Intangible assets, net of amortization	18.1			17.2
Other non-current assets	19.7			21.0
Total other non-current assets	192.5			190.8
Total assets	$	1,779.4		$	1,819.6
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Short-term and current portion of long-term debt (Note 6)	$	199.6		$	4.6
Accounts payable	51.1			55.8
Accrued taxes	78.5			75.7
Accrued interest	6.5			0.4
Customer deposits	20.3			21.3
Regulatory liabilities, current	36.5			34.9
Accrued and other current liabilities	16.8			17.5
Total current liabilities	409.3			210.2
Non-current liabilities:
Long-term debt (Note 6)	434.6			581.5
Deferred income taxes	132.5			131.7
Taxes payable	4.9			77.1
Regulatory liabilities, non-current	252.3			278.3
Accrued pension and other post-retirement benefits	73.9			83.2
Asset retirement obligations	4.7			4.7
Other non-current liabilities	7.4			7.6
Total non-current liabilities	910.3			1,164.1
Commitments and contingencies (Note 10)
Common shareholder's equity:
Common stock, at par value of $0.01 per share	0.4			0.4
50,000,000 shares authorized, 41,172,173 shares issued and outstanding
Other paid-in capital	621.9			711.8
Accumulated other comprehensive loss	(34.2		)	(35.3		)
Accumulated deficit	(128.3		)	(231.6		)
Total common shareholder's equity	459.8			445.3
Total liabilities and shareholder's equity	$	1,779.4		$	1,819.6

See Notes to Condensed Financial Statements.

F-44

THE DAYTON POWER AND LIGHT COMPANY
Condensed Statements of Cash Flows
(Unaudited)
	Nine months ended September 30,
$ in millions	2019			2018
Cash flows from operating activities:
Net income	$	103.7		$	61.9
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	52.9			56.5
Loss on early extinguishment of debt	—			0.6
Deferred income taxes	(17.2		)	(7.5		)
Loss on disposal of business	—			12.4
Changes in certain assets and liabilities:
Accounts receivable, net	18.9			(3.3		)
Inventories	(2.1		)	(0.2		)
Taxes applicable to subsequent years	54.3			54.0
Deferred regulatory costs, net	2.9			(4.1		)
Accounts payable	(4.8		)	(1.1		)
Accrued taxes payable / receivable	(65.6		)	(58.7		)
Accrued interest	6.0			(0.3		)
Accrued pension and other post-retirement benefits	(9.3		)	(3.1		)
Other	(0.8		)	6.1
Net cash provided by operating activities	138.9			113.2
Cash flows from investing activities:
Capital expenditures	(121.1		)	(65.0		)
Insurance proceeds	—			0.1
Payments on disposal of business	—			(14.5		)
Proceeds from sale of property	—			10.6
Other investing activities, net	(3.5		)	(0.2		)
Net cash used in investing activities	(124.6		)	(69.0		)
Cash flows from financing activities:
Payments of deferred financing costs	(4.6		)	—
Returns of capital paid to parent	(90.0		)	(43.8		)
Capital contributions from parent	—			80.0
Borrowings from revolving credit facilities	60.0			30.0
Repayment of borrowings from revolving credit facilities	—			(40.0		)
Issuance of long-term debt, net of discount	422.3			—
Retirement of long-term debt, including early payment premium	(436.1		)	(63.3		)
Other financing activities, net	(0.1		)	—
Net cash used in financing activities	(48.5		)	(37.1		)
Cash, cash equivalents, and restricted cash:
Net change	(34.2		)	7.1
Balance at beginning of period	66.2			5.6
Cash, cash equivalents, and restricted cash at end of period	$	32.0		$	12.7
Supplemental cash flow information:
Interest paid, net of amounts capitalized	$	10.8		$	17.0
Income taxes paid, net	$	19.0		$	8.3
Non-cash financing and investing activities:
Accruals for capital expenditures	$	2.0		$	7.2

See Notes to Condensed Financial Statements.

F-45

THE DAYTON POWER AND LIGHT COMPANY

Condensed Statements of Shareholder's Equity

(Unaudited)

	Common Stock (a)
$ in millions	Outstanding Shares	Amount		Other Paid-in Capital			Accumulated Other Comprehensive Loss			Accumulated Deficit			Total
Balance, January 1, 2018	41,172,173	$	0.4	$	685.8		$	(36.2	)	$	(319.3	)	$	330.7
Net comprehensive income							1.1			15.7			16.8
Return of capital				(23.8		)							(23.8		)
Capital contributions from parent				80.0									80.0
Other (b)				(0.3		)	(1.1		)	1.0			(0.4		)
Balance, March 31, 2018	41,172,173	0.4		741.7			(36.2		)	(302.6		)	403.3
Net comprehensive income							0.8			15.0			15.8
Balance, June 30, 2018	41,172,173	0.4		741.7			(35.4		)	(287.6		)	419.1
Net comprehensive income / (loss)							0.6			31.2			31.8
Return of capital				(20.0		)							(20.0		)
Other				0.1									0.1
Balance, September 30, 2018	41,172,173	$	0.4	$	721.8		$	(34.8	)	$	(256.4	)	$	431.0

(a) $0.01 par value, 50,000,000 shares authorized.

(b) ASU 2016-01 “Recognition and Measurement of Financial Assets and Financial Liabilities” was effective as of January 1, 2018. This ASU requires the change in the fair value of equity instruments to be recorded in income rather than in Other Comprehensive Income. Equity Instruments were defined to include all mutual funds, regardless of the underlying investments. Therefore, as of January 1, 2018, AOCI of $1.7 million ($1.1 million net of tax) was reversed to Accumulated deficit.

	Common Stock (a)
$ in millions	Outstanding Shares	Amount		Other Paid-in Capital			Accumulated Other Comprehensive Loss			Accumulated Deficit			Total
Balance, January 1, 2019	41,172,173	$	0.4	$	711.8		$	(35.3	)	$	(231.6	)	$	445.3
Net comprehensive income							0.4			29.0			29.4
Other										(0.3		)	(0.3		)
Balance, March 31, 2019	41,172,173	0.4		711.8			(34.9		)	(202.9		)	474.4
Net comprehensive income							(0.9		)	29.8			28.9
Return of capital				(70.0		)							(70.0		)
Balance, June 30, 2019	41,172,173	0.4		641.8			(35.8		)	(173.1		)	433.3
Net comprehensive income / (loss)							1.6			44.9			46.5
Return of capital				(20.0		)							(20.0		)
Other				0.1						(0.1		)	—
Balance, September 30, 2019	41,172,173	$	0.4	$	621.9		$	(34.2	)	$	(128.3	)	$	459.8

(a) $0.01 par value, 50,000,000 shares authorized.

See Notes to Condensed Financial Statements.

F-46

The Dayton Power and Light Company

Notes to Condensed Financial Statements (Unaudited)

Note 1 – Overview and Summary of Significant Accounting Policies

Description of Business

DP&L is a public utility incorporated in 1911 under the laws of Ohio. Beginning in 2001, Ohio law gave Ohio consumers the right to choose the electric generation supplier from whom they purchase retail generation service; however, retail transmission and distribution services are still regulated. DP&L has the exclusive right to provide such transmission and distribution services to approximately 524,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a 6,000-square mile area of West Central Ohio. As a result of Generation Separation, DP&L now only has one reportable segment, the Utility segment. In addition to DP&L's electric transmission and distribution businesses, the Utility segment includes revenues and costs associated with DP&L's investment in OVEC and the historical results of DP&L’s Beckjord and Hutchings Coal generating facilities, which have either been closed or sold. Principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, health care, data management, manufacturing and defense. Following the issuance of the DRO in September 2018 and the resulting changes to the decoupling rider effective January 1, 2019, DP&L's distribution sales are primarily impacted by customer growth within our service territory. DP&L sells its proportional share of energy and capacity from its investment in OVEC into the wholesale market. DP&L is a subsidiary of DPL. The terms “we,” “us,” “our” and “ours” are used to refer to DP&L.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs.

DP&L employed 642 people as of September 30, 2019. Approximately 58% of DP&L employees are under a collective bargaining agreement, which expires October 31, 2020.

Financial Statement Presentation

DP&L does not have any subsidiaries.

We have evaluated subsequent events through the date this report is issued.

Certain immaterial amounts from prior periods have been reclassified to conform to the current period presentation.

These financial statements have been prepared in accordance with GAAP for interim financial statements, the instructions of Form 10-Q and Regulation S-X. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with GAAP have been omitted from this interim report. Therefore, our interim financial statements in this report should be read along with the annual financial statements included in our Form 10-K for the fiscal year ended December 31, 2018.

In the opinion of our management, the Condensed Financial Statements presented in this report contain all adjustments necessary to fairly state our financial position as of September 30, 2019; our results of operations for the three and nine months ended September 30, 2019 and 2018, our cash flows for the nine months ended September 30, 2019 and 2018 and the changes in our equity for the three and nine months ended September 30, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three and nine months ended September 30, 2019 may not be indicative of our results that will be realized for the full year ending December 31, 2019.

The preparation of financial statements in conformity with GAAP requires us to make estimates and judgments that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the revenues and expenses of the periods reported. Actual results could differ from these estimates. Significant items subject to such estimates and judgments include: recognition of revenue including unbilled revenues, the carrying value of property, plant and equipment; the valuation of derivative instruments; the valuation of insurance and claims liabilities; the valuation of allowances for receivables and deferred income taxes; regulatory assets and

F-47

liabilities; liabilities recorded for income tax exposures; litigation; contingencies; the valuation of AROs; and assets and liabilities related to employee benefits.

Cash, Cash Equivalents, and Restricted Cash

The following table provides a summary of cash, cash equivalents, and restricted cash amounts reported on the Condensed Balance Sheet that reconcile to the total of such amounts as shown on the Condensed Statements of Cash Flows:

$ in millions	September 30, 2019		December 31, 2018
Cash and cash equivalents	$	14.4	$	45.0
Restricted cash	17.6		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	32.0	$	66.2

Accounting for Taxes Collected from Customers and Remitted to Governmental Authorities

DP&L collects certain excise taxes levied by state or local governments from its customers. These taxes are accounted for on a net basis and not included in revenue. The amounts of such taxes collected for the three months ended September 30, 2019 and 2018 were $13.0 million and $13.8 million, respectively. The amounts of such taxes collected for the nine months ended September 30, 2019 and 2018 were $37.3 million and $39.2 million, respectively.

New accounting pronouncements adopted in 2019 – The following table provides a brief description of recently adopted accounting pronouncements that had an impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or did not have a material impact on our financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
2018-02, Income Statement — Reporting Comprehensive Income (Topic 220), Reclassification of Certain Tax Effects from AOCI	This amendment allows a reclassification of the stranded tax effects resulting from the implementation of the Tax Cuts and Jobs Act from AOCI to retained earnings at the election of the filer. Because this amendment only relates to the reclassification of the income tax effects of the Tax Cuts and Jobs Act, the underlying guidance that requires that the effect of a change in tax laws or rates be included in income from continuing operations is not affected.	January 1, 2019	We have not elected to reclassify any amounts to retained earnings. Our accounting policy for releasing the income tax effects from AOCI occurs on a portfolio basis.
2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities	The standard updates the hedge accounting model to expand the ability to hedge nonfinancial and financial risk components, reduce complexity, and ease certain documentation and assessment requirements. When facts and circumstances are the same as at the previous quantitative test, a subsequent quantitative effectiveness test is not required. The standard also eliminates the requirement to separately measure and report hedge ineffectiveness. For cash flow hedges, this means that the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item. Transition method: modified retrospective with the cumulative effect adjustment recorded to the opening balance of retained earnings as of the initial application date. Prospective for presentation and disclosures.	January 1, 2019	The adoption of this standard had no material impact on our condensed financial statements.
2016-02, 2018-01, 2018-10, 2018-11 Leases (Topic 842)	See "Adoption of FASC Topic 842, Leases" below.	January 1, 2019	See impact upon adoption of the standard below.

Adoption of FASC Topic 842, "Leases"

On January 1, 2019, we adopted ASU 2016-02 Leases and its subsequent corresponding updates (“FASC 842”). Under this standard, lessees are required to recognize assets and liabilities for most leases and recognize expenses in a manner similar to the current accounting method. For lessors, the guidance modifies the lease classification criteria and the accounting for sales-type and direct financing leases. The guidance eliminates current real estate-specific provisions.

Under FASC 842, it is expected that fewer contracts will contain a lease. However, due to the elimination of the real estate-specific guidance and changes to certain lessor classification criteria, more leases will qualify as sales-type leases and direct financing leases. Under these two models, a lessor will derecognize the asset and will recognize a net investment in a lease. According to FASC 842, the net investment in the lease includes the fair value of the

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plant after the contract period but does not include variable payments such as margin on the sale of energy. Therefore, the net investment in the lease could be significantly different than the carrying amount of the underlying asset at lease commencement. In such circumstances, the difference between the initially recognized net investment in the lease and the carrying amount of the underlying asset is recognized as a gain/loss at lease commencement.

During the course of adopting FASC 842, we applied various practical expedients including:

• The package of practical expedients (applied to all leases) that allowed lessees and lessors not to reassess:

a. whether any expired or existing contracts are or contain leases,

b. lease classification for any expired or existing leases, and

c. whether initial direct costs for any expired or existing leases qualify for capitalization under FASC 842.

• The transition practical expedient related to land easements, allowing us to carry forward our accounting treatment for land easements on existing agreements, and

• The transition practical expedient for lessees that allowed businesses to not separate lease and non-lease components. We applied the practical expedient to all classes of underlying assets when valuing right-of-use assets and lease liabilities. Contracts where we are the lessor were separated between the lease and non-lease components.

We applied the modified retrospective method of adoption and elected to continue to apply the guidance in FASC 840 Leases to the comparative periods presented in the year of adoption. Under this transition method, we applied the transition provisions starting at the date of adoption.

The adoption of FASC 842 did not have a material impact on our Condensed Financial Statements.

New Accounting Pronouncements Issued But Not Yet Effective – The following table provides a brief description of recent accounting pronouncements that could have a material impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or are expected to have no material impact on our financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
2016-13, 2019-04, 2019-05, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	See discussion of the ASU below.	January 1, 2020	We will adopt the standard on January 1, 2020; see below for the evaluation of the impact of the adoption on the condensed financial statements.

ASU 2016-13 and its subsequent corresponding updates will update the impairment model for financial assets measured at amortized cost. For trade and other receivables, held-to-maturity debt securities, loans and other instruments, entities will be required to use a new forward-looking "expected loss" model that generally will result in the earlier recognition of allowance for losses. For available-for-sale debt securities with unrealized losses, entities will measure credit losses as it is done today, except that the losses will be recognized as an allowance rather than a reduction in the amortized cost of the securities. There are various transition methods available upon adoption.

We are currently evaluating the impact of adopting the standard on our condensed financial statements; however, it is expected that the new current expected credit loss model will primarily impact the calculation of expected credit losses on $72.1 million in gross trade accounts receivable.

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Note 2 – Supplemental Financial Information

Accounts receivable and Inventories are as follows at September 30, 2019 and December 31, 2018:

	September 30,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	50.0		$	53.3
Unbilled revenue	15.2			16.8
Amounts due from affiliates	3.2			2.3
Due from PJM transmission enhancement settlement	2.4			16.5
Other	1.3			2.4
Provision for uncollectible accounts	(0.4		)	(0.9		)
Total accounts receivable, net	$	71.7		$	90.4
Inventories, at average cost:
Materials and supplies	$	9.8		$	7.1
Other	—			0.6
Total inventories, at average cost	$	9.8		$	7.7

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three and nine months ended September 30, 2019 and 2018 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) components	Affected line item in the Condensed Statements of Operations	Three months ended					Nine months ended
		September 30,					September 30,
$ in millions		2019		2018			2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	—	$	(0.3	)	$	(0.1	)	$	(1.1	)
	Income tax expense	—		0.1			—			0.6
	Net of income taxes	—		(0.2		)	(0.1		)	(0.5		)
Amortization of defined benefit pension items (Note 8):
	Other expense	0.8		1.0			2.6			3.2
	Income tax expense / (benefit)	0.9		(0.2		)	(0.5		)	(0.7		)
	Net of income taxes	1.7		0.8			2.1			2.5
Total reclassifications for the period, net of income taxes		$	1.7	$	0.6		$	2.0		$	2.0

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the nine months ended September 30, 2019 are as follows:

$ in millions	Gains / (losses) on cash flow hedges			Change in unfunded pension and postretirement benefit obligation			Total
Balance at January 1, 2019	$	0.6		$	(35.9	)	$	(35.3	)
Other comprehensive loss before reclassifications	(0.9		)	—			(0.9		)
Amounts reclassified from AOCI to earnings	(0.1		)	2.1			2.0
Net current period other comprehensive income / (loss)	(1.0		)	2.1			1.1
Balance at September 30, 2019	$	(0.4	)	$	(33.8	)	$	(34.2	)

Note 3 – Regulatory Matters

DMR

On October 20, 2017, the PUCO approved DP&L’s 2017 ESP.  On January 7, 2019, the Ohio Consumers' Counsel appealed to the Supreme Court of Ohio the 2017 ESP with respect to the bypassability of the Reconciliation Rider and the exclusion of the DMR from the SEET. That proceeding has been stayed pending an appeal in a related case involving another utility.

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Pursuant to the 2017 ESP, on January 22, 2019, DP&L filed a request with the PUCO for a two-year extension of its DMR through October 2022, in the proposed amount of $199.0 million for each of the two additional years. The extension request was set at a level expected to reduce debt obligations at both DP&L and DPL and to position DP&L to make capital expenditures to maintain and modernize its electric grid. DP&L’s DMP investments are contingent upon the PUCO approving the two-year extension of its DMR.

A rehearing process in DP&L's 2017 ESP case, including the DMR, remains pending. On August 1, 2019, DP&L filed a supplemental brief with the PUCO focused on the applicability of a recent court decision involving another Ohio utility’s DMR which is similar to, but not identical to, DP&L’s DMR.

Ohio House Bill 6

On July 23, 2019, the Governor of Ohio signed Ohio House Bill 6, which, among other things, does the following:

• beginning January 1, 2020, replaces DP&L’s non-bypassable Reconciliation Rider, permitting DP&L to defer, recover or credit the net proceeds from selling energy and capacity received as part of DP&L’s interest in OVEC and its OVEC-related costs through 2023, with a non-bypassable recovery mechanism for recovery of prudently incurred OVEC costs through 2030;

• eliminates the annual energy efficiency targets for Ohio utilities after 2020; and

• allows Ohio utilities to construct customer-sited renewable generation for mercantile customers or groups of mercantile customers, the costs of which may only be recovered from those customers.

Regulatory impact of tax reform

On January 10, 2018, the PUCO initiated a proceeding to consider the impacts of the TCJA to determine the appropriate course of action to pass benefits resulting from the legislation on to ratepayers. The PUCO also directed Ohio utilities to record deferred liabilities for the estimated reduction in federal income tax resulting from the TCJA beginning January 1, 2018. Beginning October 1, 2018, the new distribution rates approved in the DRO include the impacts of the decrease in current federal income taxes as a result of the TCJA. Under the terms of the stipulation approved in the DRO, DP&L agreed to file an application at the PUCO to refund eligible excess accumulated deferred income taxes and any related regulatory liability over a ten-year period. DP&L made such a filing on March 1, 2019. DP&L negotiated a unanimous stipulation with the parties in the proceeding, agreeing to return a total of $65.1 million, $83.2 million when including taxes associated with the refunds. This stipulation was approved by the PUCO on September 26, 2019. See Note 7 – Income Taxes for additional information. In connection with this stipulation, we reduced our long-term regulatory liability related to deferred income taxes by $23.4 million.

Note 4 – Fair Value

The fair value of current financial assets and liabilities, debt service reserves and other deposits approximate their reported carrying amounts. The estimated fair values of our assets and liabilities have been determined using available market information. By virtue of these amounts being estimates and based on hypothetical transactions to sell assets or transfer liabilities, the use of different market assumptions and/or estimation methodologies may have a material effect on the estimated fair value amounts. For further information on our valuation techniques and policies, see Note 5—Fair Value in Item 8.—Financial Statements and Supplementary Data of our Form 10-K.

The following table presents the fair value, carrying value and cost of our non-derivative instruments at September 30, 2019 and December 31, 2018. Further information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	September 30, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.2	$	0.2	$	0.4	$	0.4
Equity securities	2.3		3.9		2.4		3.5
Debt securities	4.1		4.1		4.1		4.0
Hedge funds	0.1		0.1		0.1		0.1
Tangible assets	0.1		0.1		0.1		0.1
Total assets	$	6.8	$	8.4	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	574.2	$	631.0	$	586.1	$	593.8

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These financial instruments are not subject to master netting agreements or collateral requirements and as such are presented in the Condensed Balance Sheet at their gross fair value, except for Long-term debt, which is presented at amortized carrying value.

We did not have any transfers of the fair values of our financial instruments between Level 1, Level 2 or Level 3 of the fair value hierarchy during the nine months ended September 30, 2019 or 2018.

Master Trust Assets

DP&L established a Master Trust to hold assets that could be used for the benefit of employees participating in employee benefit plans and these assets are not used for general operating purposes. On January 1, 2018, AOCI of $1.7 million ($1.1 million net of tax) was reversed to Accumulated Deficit and all future changes to fair value on the Master Trust Assets will be included in income in the period that the changes occur. Changes to fair value were not material for the nine months ended September 30, 2019 or 2018. These assets are primarily comprised of open-ended mutual funds, which are valued using the net asset value per unit. These investments are recorded at fair value within Other deferred assets on the Condensed Balance Sheets and classified as available for sale.

Long-term debt

The fair value of debt is based on current public market prices for disclosure purposes only. Unrealized gains or losses are not recognized in the financial statements as long-term debt is presented at carrying value, net of unamortized premium or discount and unamortized deferred financing costs in the financial statements. The long-term debt amounts include the current portion payable in the next twelve months and have maturities that range from 2020 to 2061.

The fair value of assets and liabilities at September 30, 2019 and December 31, 2018 and the respective category within the fair value hierarchy for DP&L is as follows:

$ in millions	Fair value at September 30, 2019 (a)								Fair value at December 31, 2018 (a)
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Master Trust assets
Money market funds	$	0.2	$	—	$	—	$	0.2	$	0.4	$	—	$	—	$	0.4
Equity securities	—		3.9		—		3.9		—		3.5		—		3.5
Debt securities	—		4.1		—		4.1		—		4.0		—		4.0
Hedge funds	—		0.1		—		0.1		—		0.1		—		0.1
Tangible assets	—		0.1		—		0.1		—		0.1		—		0.1
Total Master Trust assets	0.2		8.2		—		8.4		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		0.2		—		0.2		—		1.5		—		1.5
Total derivative assets	—		0.2		—		0.2		—		1.5		—		1.5
Total assets	$	0.2	$	8.4	$	—	$	8.6	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	613.4	$	17.6	631.0		$	—	$	576.1	$	17.7	$	593.8
Total liabilities	$	—	$	613.4	$	17.6	$	631.0	$	—	$	576.1	$	17.7	$	593.8

(a) Includes credit valuation adjustment

Our financial instruments are valued using the market approach in the following categories:

• Level 1 inputs are used for money market accounts that are considered cash equivalents. The fair value is determined by reference to quoted market prices and other relevant information generated by market transactions.

• Level 2 inputs are used to value derivatives such as interest rate hedge contracts which are valued using a benchmark interest rate. Other Level 2 assets include open-ended mutual funds in the Master Trust, which are valued using the end of day NAV per unit.

• Level 3 inputs such as certain debt balances are considered a Level 3 input because the notes are not publicly traded. Our long-term debt is fair valued for disclosure purposes only.

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All of the inputs to the fair value of our derivative instruments are from quoted market prices.

Our long-term debt is fair valued for disclosure purposes only and most of the fair values are determined using quoted market prices in inactive markets. These fair value inputs are considered Level 2 in the fair value hierarchy. As the Wright-Patterson Air Force Base note is not publicly traded, fair value is assumed to equal carrying value. These fair value inputs are considered Level 3 in the fair value hierarchy as there are no observable inputs. Additional Level 3 disclosures are not presented since our long-term debt is not recorded at fair value.

Note 5 – Derivative Instruments and Hedging Activities

In the normal course of business, DP&L enters into interest rate hedges to manage the interest rate risk of our variable rate debt. All of our derivative instruments are used for risk management purposes and are designated as cash flow hedges if they qualify under FASC 815 for accounting purposes. In prior periods, we have used commodity derivatives principally to manage the risk of changes in market prices for commodities.

Cash Flow Hedges

As part of our risk management processes, we identify the relationships between hedging instruments and hedged items, as well as the risk management objective and strategy for undertaking various hedge transactions. The fair values of cash flow hedges determined by current public market prices will continue to fluctuate with changes in market prices up to contract expiration. With the adoption of ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities effective January 1, 2019, we will no longer be required to calculate effectiveness and thus the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item in the period in which it settles.

As of September 30, 2019, we have two interest rate swaps to hedge the variable interest on our $140.0 million variable interest rate tax-exempt First Mortgage Bonds. The interest rate swaps have a combined notional amount of $140.0 million and settle monthly based on a one-month LIBOR. On March 29, 2018, we settled $60.0 million of these interest rate swaps due to the partial repayment of the underlying debt and a gain of $0.8 million was recorded as a reduction to interest expense. Since the swap was partially settled, the remaining swaps were de-designated and then re-designated with a new hypothetical derivative. The AOCI associated with the remaining swaps will be amortized out of AOCI into interest expense over the remaining life of the underlying debt.

The following tables provide information concerning gains or losses recognized in AOCI for the cash flow hedges for the three and nine months ended September 30, 2019 and 2018:

	Three months ended
	September 30, 2019			September 30, 2018
	Interest			Interest
$ in millions (net of tax)	Rate Hedge			Rate Hedge
Beginning accumulated derivative gains / (losses) in AOCI	$	(0.3	)	$	1.6
Net losses associated with current period hedging transactions	(0.1		)	—
Net gains reclassified to earnings
Interest expense	—			(0.2		)
Ending accumulated derivative gains / (losses) in AOCI	$	(0.4	)	$	1.4
	Nine months ended
	September 30, 2019			September 30, 2018
	Interest			Interest
$ in millions (net of tax)	Rate Hedge			Rate Hedge
Beginning accumulated derivative gains in AOCI	$	0.6		$	1.4
Net gains / (losses) associated with current period hedging transactions	(0.9		)	0.5
Net gains reclassified to earnings
Interest expense	(0.1		)	(0.5		)
Ending accumulated derivative gains / (losses) in AOCI	$	(0.4	)	$	1.4
Portion expected to be reclassified to earnings in the next twelve months	$	(0.2	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	11

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Net gains or losses associated with the ineffective portion of the hedging transactions were immaterial in the prior year period presented.

Financial Statement Effect

DP&L has elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivative agreements. The fair value derivative position of DP&L's interest rate swaps are as follows:

Fair Values of Derivative Instruments
at September 30, 2019
				Gross Amounts Not Offset in the Condensed Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Prepayments and other current assets)
Interest rate swap	Designated	$	0.2	$	—	$	—	$	0.2
Total assets		$	0.2	$	—	$	—	$	0.2

(a)    Includes credit valuation adjustment.

Fair Values of Derivative Instruments
at December 31, 2018
				Gross Amounts Not Offset in the Condensed Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Prepayments and other current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other non-current assets)
Interest rate swaps	Designated	0.6		—		—		0.6
Total assets		$	1.5	$	—	$	—	$	1.5

(a)    Includes credit valuation adjustment.

Any prior year ineffectiveness on the interest rate hedges and the monthly settlement of the interest rate hedges is recorded in interest expense within the Condensed Statements of Operations.

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Note 6 – Long-term Debt

The following table summarizes DP&L's long-term debt.

	Interest		September 30,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	—		$	436.1
First Mortgage Bonds	3.95%	2049	425.0			—
Tax-exempt First Mortgage Bonds - rates from 2.97% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.20%	2061	17.6			17.7
Unamortized deferred financing costs			(5.7		)	(6.3		)
Unamortized debt discounts and premiums, net			(2.7		)	(1.4		)
Total long-term debt			574.2			586.1
Less: current portion			(139.6		)	(4.6		)
Long-term debt, net of current portion			$	434.6		$	581.5

(a) Range of interest rates for the nine months ended September 30, 2019.

(b) Range of interest rates for the year ended December 31, 2018.

Deferred financing costs are amortized over the remaining life of the debt using the effective interest method. Premiums or discounts on long-term debt are amortized over the remaining life of the debt using the effective interest method.

Line of credit

At September 30, 2019 and December 31, 2018, DP&L had outstanding borrowings on its line of credit of $60.0 million and $0.0 million, respectively.

Significant transactions

On June 19, 2019, DP&L amended and restated its unsecured revolving credit facility. The revolving credit facility has a $175.0 million borrowing limit, with a $75.0 million letter of credit sublimit, a feature that provides DP&L the ability to increase the size of the facility by an additional $100.0 million, a maturity date of June 2024, and a provision that provides DP&L the option to request up to two one-year extensions of the maturity date.

On June 6, 2019, DP&L closed on a $425.0 million issuance of First Mortgage Bonds due 2049. These new bonds carry an interest rate of 3.95%. The proceeds of this issuance were used to repay in full the outstanding principal of $435.0 million of DP&L's variable rate Term Loan B credit agreement.

On March 30, 2018, DP&L commenced a redemption of $60.0 million of outstanding tax exempt First Mortgage Bonds due 2020 at par value (plus accrued and unpaid interest). These bonds were redeemed at par plus accrued interest on April 30, 2018 with cash on hand.

Long-term debt covenants and restrictions

DP&L’s Bond Purchase and Covenants Agreement (financing document entered into in connection with the sale of $200.0 million of variable rate tax-exempt First Mortgage Bonds, dated as of August 1, 2015) has two financial covenants. The first measures Total Debt to Total Capitalization and is calculated, at the end of each fiscal quarter, by dividing total debt at the end of the quarter by total capitalization at the end of the quarter. DP&L’s Total Debt to Total Capitalization ratio shall not be greater than 0.65 to 1.00. Except that, after Generation Separation and the twelve-month period following (October 1, 2017 to September 30, 2018) the ratio shall be a) increased to 0.75 to 1.00 or b) suspended if DP&L’s long-term indebtedness is less than or equal to $750.0 million. Additionally, this covenant shall be suspended any time after separation during which DP&L maintains a rating of BBB- (or in the case of Moody’s Investors Service, Inc. Baa3) or higher with a stable outlook from at least one of Fitch Investors Service Inc., Standard & Poor’s Ratings Services or Moody’s Investors Service, Inc. The Total Debt to Capitalization covenant is calculated as the sum of DP&L’s current and long-term portion of debt, divided by the total of DP&L’s net worth and total debt. As of September 30, 2019, DP&L's ratings meet those requirements and this covenant is suspended for the quarter ended September 30, 2019.

The second financial covenant measures EBITDA to Interest Expense. The Total EBITDA to Interest Charges ratio is calculated, at the end of each fiscal quarter, by dividing EBITDA for the four prior fiscal quarters by the interest charges for the same period. The ratio, per the agreement, is to be not less than 2.50 to 1.00. This financial covenant was met with a ratio of 9.36 to 1.00 as of September 30, 2019.

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DP&L's unsecured revolving credit facility has one financial covenant. The covenant measures Total Debt to Total Capitalization and is calculated, at the end of each fiscal quarter, by dividing total debt at the end of the quarter by total capitalization at the end of the quarter. DP&L’s Total Debt to Total Capitalization ratio shall not be greater than 0.67 to 1.00. This financial covenant was met with a ratio of 0.58 to 1.00 as of September 30, 2019.

As of September 30, 2019, DP&L was in compliance with all debt covenants, including the financial covenants described above.

DP&L does not have any meaningful restrictions in its debt financing documents prohibiting dividends to its parent, DPL.

Substantially all property, plant & equipment of DP&L is subject to the lien of the mortgage securing DP&L’s First and Refunding Mortgage.

Note 7 – Income Taxes

The following table details the effective tax rates for the three and nine months ended September 30, 2019 and 2018.

	Three months ended		Nine months ended
	September 30,		September 30,
	2019	2018	2019	2018
DP&L	(19.1)%	16.8%	4.7%	16.2%

Income tax expense for the nine months ended September 30, 2019 and 2018 was calculated using the estimated annual effective income tax rates for 2019 and 2018 of 4.5% and 17.1%, respectively. Management estimates the annual effective tax rate based on its forecast of annual pre-tax income. To the extent that actual pre-tax results for the year differ from the forecasts applied to the most recent interim period, the estimated rates could be materially different from the actual effective tax rates. DP&L’s effective combined state and federal income tax rate was (19.1)% and 4.7% for the three and nine months ended September 30, 2019, respectively. This is lower than the combined federal and state statutory rate of 21.6% primarily due to the net tax benefit related to the reversal of excess deferred taxes and the impact of the September 26, 2019 PUCO order which finalized the amount of excess deferred tax balances allocable to DP&L’s utility customers.

For the nine months ended September 30, 2019, DP&L’s current period effective tax rate for all operations was not materially different than the estimated annual effective rate.

Note 8 – Benefit Plans

DP&L sponsors a defined benefit pension plan for the majority of its employees.

We generally fund pension plan benefits as accrued in accordance with the minimum funding requirements of ERISA and, in addition, make voluntary contributions from time to time. There were $7.5 million in employer contributions during each of the nine months ended September 30, 2019 and 2018.

The amounts presented in the following tables for pension include the collective bargaining plan formula, the traditional management plan formula, the cash balance plan formula and the SERP, in the aggregate. The pension costs below have not been adjusted for amounts billed to the Service Company for former DP&L employees who are now employed by the Service Company or for amounts billed to AES Ohio Generation for employees employed by AES Ohio Generation that are still participants in the DP&L plan.

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The net periodic benefit cost of the pension benefit plans for the three and nine months ended September 30, 2019 and 2018 was:

	Three months ended						Nine months ended
	September 30,						September 30,
$ in millions	2019			2018			2019			2018
Service cost	$	0.9		$	1.5		$	2.7		$	4.5
Interest cost	3.7			3.4			11.2			10.3
Expected return on plan assets	(5.0		)	(5.3		)	(15.0		)	(15.9		)
Amortization of unrecognized:
Prior service cost	0.4			0.4			1.3			1.1
Actuarial loss	1.8			2.4			5.3			7.1
Net periodic benefit cost	$	1.8		$	2.4		$	5.5		$	7.1

In addition, DP&L provides postretirement health care and life insurance benefits to certain retired employees, their spouses and eligible dependents. We have funded a portion of the union-eligible benefits using a Voluntary Employee Beneficiary Association Trust. These postretirement health care benefits and the related unfunded obligation of $9.0 million at September 30, 2019 and $9.2 million at December 31, 2018 were not material to the financial statements in the periods covered by this report.

Note 9 – Shareholder's Equity

Capital Contribution and Returns of Capital

During the nine months ended September 30, 2019, DP&L made returns of capital payments of $90.0 million to DPL.

During the nine months ended September 30, 2018, DP&L received an $80.0 million capital contribution from its parent, DPL. In addition, DP&L made returns of capital payments of $43.8 million to DPL.

Note 10 – Contractual Obligations, Commercial Commitments and Contingencies

Equity Ownership Interest

DP&L has a 4.9% equity ownership interest in OVEC, which is recorded using the cost method of accounting under GAAP. DP&L, along with several non-affiliated energy companies party to an OVEC arrangement, receive and pay for OVEC capacity and energy and are responsible for OVEC debt obligations and other fixed costs in proportion to their power participation ratios under the arrangement which, for DP&L, is the same as its equity ownership interest. At September 30, 2019, DP&L could be responsible for the repayment of 4.9%, or $67.2 million, of $1,371.3 million OVEC debt obligations if they came due, comprised of both fixed and variable rate securities with maturities from 2022 to 2040. OVEC could also seek additional contributions from DP&L to avoid a default in the event that other OVEC members defaulted on their respective OVEC obligations. One of the other OVEC members, with a 4.85% interest in OVEC, filed for bankruptcy protection and the bankruptcy court approved that member's rejection of the OVEC arrangement and its related obligations on July 31, 2018. We do not expect these events to have a material impact on our financial condition, results of operations or cash flows.

Contingencies

In the normal course of business, we are subject to various lawsuits, actions, proceedings, claims and other matters asserted under various laws and regulations. We believe the amounts provided in our Condensed Financial Statements, as prescribed by GAAP, are adequate considering the probable and estimable contingencies. However, there can be no assurances that the actual amounts required to satisfy alleged liabilities from various legal proceedings, claims, tax examinations and other matters discussed below, and to comply with applicable laws and regulations, will not exceed the amounts reflected in our Condensed Financial Statements. As such, costs, if any, that may be incurred in excess of those amounts provided as of September 30, 2019, cannot be reasonably determined.

Environmental Matters

DP&L’s facilities and operations are subject to a wide range of federal, state and local environmental regulations and laws. The environmental issues that may affect us include:

• The federal CAA and state laws and regulations (including State Implementation Plans) which require compliance, obtaining permits and reporting as to air emissions;

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• Litigation with federal and certain state governments and certain special interest groups;

• Rules and future rules issued by the USEPA, the Ohio EPA or other authorities associated with the federal Clean Water Act, which prohibits the discharge of pollutants into waters of the United States except pursuant to appropriate permits; and

• Solid and hazardous waste laws and regulations, which govern the management and disposal of certain waste.

In addition to imposing continuing compliance obligations, these laws and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. In the normal course of business, we have investigatory and remedial activities underway at our facilities to comply, or to determine compliance, with such regulations. We record liabilities for loss contingencies related to environmental matters when a loss is probable of occurring and can be reasonably estimated in accordance with the provisions of GAAP. Accordingly, we have immaterial accruals for loss contingencies for environmental matters. We also have several environmental matters for which we have not accrued loss contingencies because the risk of loss is not probable, or a loss cannot be reasonably estimated. We evaluate the potential liability related to environmental matters quarterly and may revise our estimates. Such revisions in the estimates of the potential liabilities could have a material adverse effect on our results of operations, financial condition and cash flows.

Note 11 – Revenue

Revenue is primarily earned from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Revenue is recorded net of any taxes assessed on and collected from customers, which are remitted to the governmental authorities. For further discussion of our Retail, Wholesale, RTO ancillary, and Capacity revenues, see Note 13 — Revenue in Item 8.—Financial Statements and Supplementary Data of our Form 10-K.

DP&L's revenue from contracts with customers was $187.0 million and $186.1 million for the three months ended September 30, 2019 and 2018, respectively, and $554.4 million and $532.1 million for the nine months ended September 30, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue for the three and nine months ended September 30, 2019 and 2018:

	Three months ended				Nine months ended
	September 30,				September 30,
$ in millions	2019		2018		2019		2018
Retail revenue
Retail revenue from contracts with customers	$	170.5	$	168.4	$	503.8	$	469.3
Other retail revenue (a)	3.8		12.6		14.9		31.4
Wholesale revenue
Wholesale revenue from contracts with customers	4.4		4.9		12.8		24.6
RTO ancillary revenue	11.0		10.8		32.8		32.4
Capacity revenue	1.1		2.0		5.0		5.8
Miscellaneous revenue	0.3		—		0.9		—
Total revenues	$	191.1	$	198.7	$	570.2	$	563.5

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606.

The balances of receivables from contracts with customers were $65.2 million and $70.1 million as of September 30, 2019 and December 31, 2018, respectively. Payment terms for all receivables from contracts with customers are typically within 30 days.

Note 12 – Dispositions

Beckjord Facility – On February 26, 2018, DP&L and its co-owners of the retired Beckjord Facility agreed to transfer their interests in the retired Facility to a third party, including their obligations to remediate the Facility and its site, and the transfer occurred on that same date. As a result, DP&L recognized a loss on the transfer of $12.4 million and made cash expenditures of $14.5 million, inclusive of cash expenditures for the transfer charges. The Beckjord Facility was retired in 2014, and, as such, the income / (loss) from continuing operations before income tax related to the Beckjord Facility was immaterial for the three and nine months ended September 30, 2018, excluding the loss on transfer noted above.

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The Dayton Power and Light Company

Offer to Exchange

First Mortgage Bonds, 3.95% Series due 2049

for

New First Mortgage Bonds, 3.95% Series due 2049

Until          all dealers that effect transactions in these securities, whether or not participating in this offering, may be required to deliver a prospectus.  This is in addition to the dealers’ obligation to deliver a prospectus when acting as underwriters with respect to their unsold allotments or subscriptions.

PROSPECTUS

       , 2019

PART II

INFORMATION NOT REQUIRED IN PROSPECTUS

Item 20.  Indemnification of Directors and Officers.

Article VII of the Regulations of The Dayton Power and Light Company (the “Company”), dated April 9, 1981 provides for indemnification of directors, officers, employees or agents of the Company, or individuals who serve at the request of the Company in such capacities for other entities, against any and all expenses, judgments, fines and settlements incurred by them in connection with claims and/or litigation arising out of their service. Article VII provides that indemnification shall be available to the full extent permitted by law including, without limitation, Section 1701.13(E) of the Ohio Revised Code. The Code of Regulations further provides that the indemnification rights set forth in Article VII are not exclusive of any rights to which those seeking indemnification may be entitled under the Company’s Amended Articles of Incorporation or Code of Regulations or any agreement, vote of shareholders or disinterested directors, or otherwise. The Company’s Amended Articles of Incorporation and Code of Regulations are exhibits to this registration statement.

Section 1701.13(E) of the Ohio Revised Code provides as follows:

(E) (1) A corporation may indemnify or agree to indemnify any person who was or is a party, or is threatened to be made a party, to any threatened, pending, or completed action, suit, or proceeding, whether civil, criminal, administrative, or investigative, other than an action by or in the right of the corporation, by reason of the fact that the person is or was a director, officer, employee, or agent of the corporation, or is or was serving at the request of the corporation as a director, trustee, officer, employee, member, manager, or agent of another corporation, domestic or foreign, nonprofit or for profit, a limited liability company, or a partnership, joint venture, trust, or other enterprise, against expenses, including attorney’s fees, judgments, fines, and amounts paid in settlement actually and reasonably incurred by the person in connection with such action, suit, or proceeding, if the person acted in good faith and in a manner the person reasonably believed to be in or not opposed to the best interests of the corporation, and, with respect to any criminal action or proceeding, if the person had no reasonable cause to believe the person’s conduct was unlawful. The termination of any action, suit, or proceeding by judgment, order, settlement, or conviction, or upon a plea of nolo contendere or its equivalent, shall not, of itself, create a presumption that the person did not act in good faith and in a manner the person reasonably believed to be in or not opposed to the best interests of the corporation, and, with respect to any criminal action or proceeding, the person had reasonable cause to believe that the person’s conduct was unlawful.

(2) A corporation may indemnify or agree to indemnify any person who was or is a party, or is threatened to be made a party, to any threatened, pending, or completed action or suit by or in the right of the corporation to procure a judgment in its favor, by reason of the fact that the person is or was a director, officer, employee, or agent of the corporation, or is or was serving at the request of the corporation as a director, trustee, officer, employee, member, manager, or agent of another corporation, domestic or foreign, nonprofit or for profit, a limited liability company, or a partnership, joint venture, trust, or other enterprise, against expenses, including attorney’s fees, actually and reasonably incurred by the person in connection with the defense or settlement of such action or suit, if the person acted in good faith and in a manner the person reasonably believed to be in or not opposed to the best interests of the corporation, except that no indemnification shall be made in respect of any of the following:

(a) Any claim, issue, or matter as to which such person is adjudged to be liable for negligence or misconduct in the performance of the person’s duty to the corporation unless, and only to the extent that, the court of common pleas or the court in which such action or suit was brought determines, upon application, that, despite the adjudication of liability, but in view of all the circumstances of the case, such person is fairly and reasonably entitled to indemnity for such expenses as the court of common pleas or such other court shall deem proper;

(b) Any action or suit in which the only liability asserted against a director is pursuant to section 1701.95 of the Revised Code.

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(3) To the extent that a director, trustee, officer, employee, member, manager, or agent has been successful on the merits or otherwise in defense of any action, suit, or proceeding referred to in division (E)(1) or (2) of this section, or in defense of any claim, issue, or matter in the action, suit, or proceeding, the person shall be indemnified against expenses, including attorney’s fees, actually and reasonably incurred by the person in connection with the action, suit, or proceeding.

(4) Any indemnification under division (E)(1) or (2) of this section, unless ordered by a court, shall be made by the corporation only as authorized in the specific case, upon a determination that indemnification of the director, trustee, officer, employee, member, manager, or agent is proper in the circumstances because the person has met the applicable standard of conduct set forth in division (E)(1) or (2) of this section. Such determination shall be made as follows:

(a) By a majority vote of a quorum consisting of directors of the indemnifying corporation who were not and are not parties to or threatened with the action, suit, or proceeding referred to in division (E)(1) or (2) of this section;

(b) If the quorum described in division (E)(4)(a) of this section is not obtainable or if a majority vote of a quorum of disinterested directors so directs, in a written opinion by independent legal counsel other than an attorney, or a firm having associated with it an attorney, who has been retained by or who has performed services for the corporation or any person to be indemnified within the past five years;

(c) By the shareholders;

(d) By the court of common pleas or the court in which the action, suit, or proceeding referred to in division (E)(1) or (2) of this section was brought.

Any determination made by the disinterested directors under division (E)(4)(a) or by independent legal counsel under division (E)(4)(b) of this section shall be promptly communicated to the person who threatened or brought the action or suit by or in the right of the corporation under division (E)(2) of this section, and, within ten days after receipt of that notification, the person shall have the right to petition the court of common pleas or the court in which the action or suit was brought to review the reasonableness of that determination.

(5) (a) Unless at the time of a director’s act or omission that is the subject of an action, suit, or proceeding referred to in division (E)(1) or (2) of this section, the articles or the regulations of a corporation state, by specific reference to this division, that the provisions of this division do not apply to the corporation and unless the only liability asserted against a director in an action, suit, or proceeding referred to in division (E)(1) or (2) of this section is pursuant to section 1701.95 of the Revised Code, expenses, including attorney’s fees, incurred by a director in defending the action, suit, or proceeding shall be paid by the corporation as they are incurred, in advance of the final disposition of the action, suit, or proceeding, upon receipt of an undertaking by or on behalf of the director in which the director agrees to do both of the following:

(i) Repay that amount if it is proved by clear and convincing evidence in a court of competent jurisdiction that the director’s action or failure to act involved an act or omission undertaken with deliberate intent to cause injury to the corporation or undertaken with reckless disregard for the best interests of the corporation;

(ii) Reasonably cooperate with the corporation concerning the action, suit, or proceeding.

(b) Expenses, including attorney’s fees, incurred by a director, trustee, officer, employee, member, manager, or agent in defending any action, suit, or proceeding referred to in division (E)(1) or (2) of this section, may be paid by the corporation as they are incurred, in advance of the final disposition of the action, suit, or proceeding, as authorized by the directors in the specific case, upon receipt of an undertaking by or on behalf of the director, trustee, officer, employee, member, manager, or agent to repay that amount, if it ultimately is determined that the person is not entitled to be indemnified by the corporation.

(6) The indemnification or advancement of expenses authorized by this section shall not be exclusive of, and shall be in addition to, any other rights granted to those seeking indemnification or advancement of expenses under the articles, the regulations, any agreement, a vote of shareholders or disinterested directors, or otherwise, both as to action in their official capacities and as to action in another capacity while holding their offices or positions, and shall continue as to a person who has ceased to be a director, trustee, officer,

II 2

employee, member, manager, or agent and shall inure to the benefit of the heirs, executors, and administrators of that person. A right to indemnification or to advancement of expenses arising under a provision of the articles or the regulations shall not be eliminated or impaired by an amendment to that provision after the occurrence of the act or omission that becomes the subject of the civil, criminal, administrative, or investigative action, suit, or proceeding for which the indemnification or advancement of expenses is sought, unless the provision in effect at the time of that act or omission explicitly authorizes that elimination or impairment after the act or omission has occurred.

(7) A corporation may purchase and maintain insurance or furnish similar protection, including, but not limited to, trust funds, letters of credit, or self-insurance, on behalf of or for any person who is or was a director, officer, employee, or agent of the corporation, or is or was serving at the request of the corporation as a director, trustee, officer, employee, member, manager, or agent of another corporation, domestic or foreign, nonprofit or for profit, a limited liability company, or a partnership, joint venture, trust, or other enterprise, against any liability asserted against the person and incurred by the person in any such capacity, or arising out of the person’s status as such, whether or not the corporation would have the power to indemnify the person against that liability under this section. Insurance may be purchased from or maintained with a person in which the corporation has a financial interest.

(8) The authority of a corporation to indemnify persons pursuant to division (E)(1) or (2) of this section does not limit the payment of expenses as they are incurred, indemnification, insurance, or other protection that may be provided pursuant to divisions (E)(5), (6), and (7) of this section. Divisions (E)(1) and (2) of this section do not create any obligation to repay or return payments made by the corporation pursuant to division (E)(5), (6), or (7).

(9) As used in division (E) of this section, “corporation” includes all constituent entities in a consolidation or merger and the new or surviving corporation, so that any person who is or was a director, officer, employee, trustee, member, manager, or agent of such a constituent entity, or is or was serving at the request of such constituent entity as a director, trustee, officer, employee, member, manager, or agent of another corporation, domestic or foreign, nonprofit or for profit, a limited liability company, or a partnership, joint venture, trust, or other enterprise, shall stand in the same position under this section with respect to the new or surviving corporation as the person would if the person had served the new or surviving corporation in the same capacity.

The Company maintains standard policies of insurance under which coverage is provided to its directors and officers against loss rising from claims made by reason of breach of duty or other wrongful act, and to the Company with respect to payments which may be made by the Company to such officers and directors pursuant to the above indemnification provision or otherwise as a matter of law.

The Registration Rights Agreement filed as Exhibit 4(t) to this Registration Statement provides for indemnification of directors and officers of The Dayton Power and Light Company by the initial purchasers against certain liabilities.

II 3

Item 21. Exhibits

DP&L exhibits are incorporated by reference as described unless otherwise filed as set forth herein.

The exhibits filed as part of DP&L’s Annual Report on Form 10-K, updated through our most recent 10-Q, are:

Exhibit Number	Exhibit	Location
2(b)	Asset Purchase Agreement dated April 21, 2017, by and among Dynegy Zimmer, LLC, Dynegy Miami Fort, LLC, AES Ohio	Exhibit 2.1 to Report on Form 8-K filed April 24, 2017 (File No. 1-2385)
2(c)	Asset Contribution Agreement, dated as of September 28, 2017, by and between The Dayton Power and Light Company and AES Ohio Merger Sub, LLC	Exhibit 2.1 to Report on Form 8-K filed on October 2, 2017 (File No. 1-2385)
2(d)	Agreement and Plan of Merger, dated as of September 28, 2017, by and between AES Ohio Merger Sub, LLC and AES Ohio Generation, LLC	Exhibit 2.2 to Report on Form 8-K filed on October 2, 2017 (File No. 1-2385)
3(c)	Amended Articles of Incorporation of The Dayton Power and Light Company, as of January 4, 1991	Exhibit 3(c) to Report on Form 10-K filed on February 26, 2018 (File No. 1-9052)
3(d)	Regulations of The Dayton Power and Light Company, as of April 9, 1981	Exhibit 3(a) to Report on Form 8-K filed on May 3, 2004 (File No. 1-2385)
4(a)	Composite Indenture dated as of October 1, 1935, between The Dayton Power and Light Company and Irving Trust Company, Trustee with all amendments through the Twenty-Ninth Supplemental Indenture	Exhibit 4.1 to Registration Statement No. 333-183556
4(b)	Forty-First Supplemental Indenture dated as of February 1, 1999, between The Dayton Power and Light Company and The Bank of New York, Trustee	Exhibit 4.4 to Registration Statement No. 333-183556
4(c)	Forty-Second Supplemental Indenture dated as of September 1, 2003, between The Dayton Power and Light Company and The Bank of New York, Trustee	Exhibit 4(r) to Report on Form 10-K for the year ended December 31, 2003 (File No. 1-2385)
4(d)	Forty-Third Supplemental Indenture dated as of August 1, 2005, between The Dayton Power and Light Company and The Bank of New York, Trustee	Exhibit 4.4 to Report on Form 8-K filed August 24, 2005 (File No. 1-2385)
4(h)	Loan Agreement, dated as of September 1, 2006, by and between Ohio Air Quality Development Authority and The Dayton Power and Light Company	Exhibit 4.1 to Report on Form 8-K filed September 19, 2006 (File No. 1-2385)
4(l)	Loan Agreement dated August 1, 2015, between the Ohio Air Quality Development Authority and The Dayton Power and Light Company, relating to the 2015 Series A bonds	Exhibit 4.1 to Report on Form 8-K filed August 6, 2015 (File No. 1-2385)
4(m)	Loan Agreement dated August 1, 2015, between the Ohio Air Quality Development Authority and The Dayton Power and Light Company, relating to the 2015 Series B bonds	Exhibit 4.2 to Report on Form 8-K filed August 6, 2015 (File No. 1-2385)
4(n)	Forty-Eighth Supplemental Indenture dated as of August 1, 2015 between The Bank of New York Mellon, Trustee and The Dayton Power and Light Company	Exhibit 4.3 to Report on Form 8-K filed August 6, 2015 (File No. 1-2385)
4(o)	Forty-Ninth Supplemental Indenture dated as of August 1, 2015 between The Bank of New York Mellon, Trustee and The Dayton Power and Light Company	Exhibit 4.4 to Report on Form 8-K filed August 6, 2015 (File No. 1-2385)
4(p)	Bond Purchase and Covenants Agreement dated as of August 1, 2015, among The Dayton Power and Light Company, SunTrust Bank, as Administrative Agent, and the several lenders from time to time party thereto	Exhibit 4.5 to Report on Form 8-K filed August 6, 2015 (File No. 1-2385)
4(q)	Amendment dated February 21, 2017 to Bond Purchase and Covenants Agreement by and among The Dayton Power and Light Company, SunTrust Bank, as Administrative Agent, and several lenders from time to time party thereto, dated as of August 1, 2015	Exhibit 4.R to Report Filed on Form 10-K for the year ended December 31, 2016 (File No. 1-2385)
4(r)	Fiftieth Supplemental Indenture dated as of August 1, 2016, by and between The Dayton Power and Light Company and The Bank of New York Mellon, Trustee	Exhibit 4.3 to Report on Form 8-K filed August 30, 2016 (File No. 1-2385)
4(s)	Fifty-First Supplemental Indenture between The Bank of New York Mellon, as Trustee, and The Dayton Power and Light Company	Exhibit 4.1 to Report on Form 8-K filed October 2, 2017 (File No. 1-2385)
4(t)	Registration Rights Agreement dated June 6, 2019 between The Dayton Power and Light Company and BofA Securities, Inc. and J.P. Morgan Securities LLC	Exhibit 4.2 to Report on Form 8-K filed June 6, 2019 (File No. 1-2385)
5.1	Opinion of Davis Polk & Wardwell LLP with respect to the new bonds	Filed herewith as Exhibit 5.1
5.2	Opinion of Brian Hylander, Assistant General Counsel of The Dayton Power and Light Company	Filed herewith as Exhibit 5.2

Exhibit Number	Exhibit	Location
10(f)	Credit Agreement dated as of July 31, 2015, among The Dayton Power and Light Company, PNC Bank, National Association, as Administrative Agent, Swing Line Lender and an L/C Issuer, Fifth Third Bank, as Syndication Agent and an L/C Issuer, Bank of America, N.A., as Documentation Agent and an L/C Issuer, and the other lenders party to the Credit Agreement	Exhibit 10.5 to Report on Form 8-K filed August 6, 2015 (File No. 1-2385)
10(g)	Amendment dated as of February 21, 2017 to Credit Agreement by and among The Dayton Power and Light Company, PNC Bank, National Association, as Administrative Agent, Swing Line Lender and an L/C Issuer, Fifth Third Bank, as Syndication Agent and an L/C Issuer, Bank of America, N.A., as Documentation Agent and an L/C Issuer, and the other lenders party to the Credit Agreement, dated as of July 31, 2015	Exhibit 10.F to Report Filed on Form 10-K for the year ended December 31, 2016 (File No. 1-2385)
10(j)	Credit Agreement dated August 24, 2016, among The Dayton Power and Light Company, the lenders from time to time party thereto, JPMorgan Chase Bank, N.A., as administrative agent and collateral agent, Morgan Stanley Senior Funding, Inc., as a lender and BMO Capital Markets Corp., Fifth Third Securities, The Huntington National Bank, PNC Capital Markets LLC, RBC Capital Markets, LLC, Regions Capital Markets, a division of Regions Bank, and SunTrust Robinson Humphrey, Inc., as managing agents	Exhibit 4.1 to Report on Form 8-K filed August 30, 2016 (File No. 1-2385)
10(k)	Amendment to Credit Agreement dated as of January 3, 2018, among The Dayton Power and Light Company, JPMorgan Chase Bank, N.A., as Administrative Agent and certain of the lenders party thereto	Exhibit 4.1 to Report on Form 8-K filed January 5, 2018 (File No. 1-2385)
10(l)	Pledge and Security Agreement dated as of August 24, 2016, between The Dayton Power and Light Company and JPMorgan Chase Bank, N.A., as collateral agent	Exhibit 4.2 to Report on Form 8-K filed August 30, 2016 (File No. 1-2385)
10(m)	Stipulation and Recommendation dated January 30, 2017	Exhibit 10.1 to Report on Form 8-K filed February 3, 2017 (File No. 1-2385)
10(n)	Amended Stipulation and Recommendation dated March 13, 2017	Exhibit 10.1 to Report on Form 8-K filed March 14, 2017 (File No. 1-2385)
10.15	Amended and Restated Credit Agreement, dated as of June 19, 2019, among DPL Inc., each lender from time to time party thereto, U.S. Bank National Association, as Administrative Agent, Collateral Agent, Swing Line Lender and an L/C Issuer, PNC Bank, National Association, as Syndication Agent and an L/C Issuer, and Fifth Third Bank, BMO Harris Bank, N.A., SunTrust Bank and The Huntington National Bank, as Documentation Agents.	Exhibit 10.1 to Report on Form 8-K filed June 21, 2019 (File No. 1-9052)
10.16	Amended and Restated Pledge Agreement, dated as of June 19, 2019, between DPL Inc. and U.S. Bank National Association, as Collateral Agent.	Exhibit 10.2 to Report on Form 8-K filed June 21, 2019 (File No. 1-9052)
10.17	Amended and Restated Credit Agreement, dated as of June 19, 2019, among The Dayton Power and Light Company, each lender from time to time party thereto, PNC Bank, National Association, as Administrative Agent, Swing Line Lender and an L/C Issuer, U.S. Bank National Association, as Syndication Agent and an L/C Issuer, and Fifth Third Bank, BMO Harris Bank, N.A., SunTrust Bank and The Huntington National Bank, as Documentation Agents.	Exhibit 10.3 to Report on Form 8-K filed June 21, 2019 (File No. 1-9052)
23.1	Consent of Davis Polk & Wardwell LLP	Included in Exhibit 5.1
23.2	Consent of Brian Hylander, Assistant General Counsel of The Dayton Power and Light Company	Included in Exhibit 5.2
23.3	Consent of Independent Registered Accounting Firm, Ernst & Young LLP	Filed herewith as Exhibit 23.3
24.1	Powers of Attorney	Included on signature page to registration statement
25.1	Statement of Eligibility of The Bank of New York Mellon, as Trustee, on Form T-1	Filed herewith as Exhibit 25.1
99.1	Form of Notice of Guaranteed Delivery	Filed herewith as Exhibit 99.1
99.2	Form of Letter to Clients	Filed herewith as Exhibit 99.2
99.3	Form of Letter to Brokers	Filed herewith as Exhibit 99.3
99.4	Form of Instructions to Registered Holder and/or Book-Entry Transfer Participant from Owner	Filed herewith as Exhibit 99.4
101.INS	XBRL Instance	Furnished herewith as Exhibit 101.INS
101.SCH	XBRL Taxonomy Extension Schema	Furnished herewith as Exhibit 101.SCH
101.CAL	XBRL Taxonomy Extension Calculation Linkbase	Furnished herewith as Exhibit 101.CAL

Exhibit Number	Exhibit	Location
101.DEF	XBRL Taxonomy Extension Definition Linkbase	Furnished herewith as Exhibit 101.DEF
101.LAB	XBRL Taxonomy Extension Label Linkbase	Furnished herewith as Exhibit 101.LAB
101.PRE	XBRL Taxonomy Extension Presentation Linkbase	Furnished herewith as Exhibit 101.PRE

Item 22. - Undertakings

(a)    The undersigned hereby undertakes:

(1) To file during any period in which offers or sales are being made, a post-effective amendment to this registration statement:

(i) to include any prospectus required by Section 10(a)(3) of the Securities Act of 1933;

(ii) to reflect in the prospectus any facts or events arising after the effective date of the registration statement (or the most recent post-effective amendment thereof) which, individually or in the aggregate, represent a fundamental change in the information set forth in the registration statement. Notwithstanding the foregoing, any increase or decrease in the volume of securities offered (if the total dollar value of securities offered would not exceed that which was registered) and any deviation from the low or high end of the estimated maximum offering range may be reflected in the form of prospectus filed with the Commission pursuant to Rule 424(b) if, in the aggregate, the changes in volume and price represent no more than a 20 percent change in the maximum aggregate offering price set forth in the “Calculation of Registration Fee” table in the effective registration statement; and

(iii) to include any material information with respect to the plan of distribution not previously disclosed in the registration statement or any material change to such information in the registration statement;

(2) That, for the purpose of determining any liability under the Securities Act of 1933, each such post-effective amendment shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.

(3) To remove from registration by means of a post-effective amendment any of the securities being registered which remain unsold at the termination of the offering.

(4) That, for the purpose of determining liability under the Securities Act of 1933 to any purchaser, each prospectus filed pursuant to Rule 424(b) as part of a registration statement relating to an offering, other than registration statements relying on Rule 430B or other than prospectuses filed in reliance on Rule 430A, shall be deemed to be part of and included in the registration statement as of the date it is first used after effectiveness; provided, however, that no statement made in a registration statement or prospectus that is part of the registration statement or made in a document deemed incorporated by reference into the registration statement or prospectus that is part of the registration statement will, as to a purchaser with a time of contract of sale prior to such first use, superseded or modify any statement that was made in the registration statement or prospectus that was part of the registration statement or made in any such document immediately prior to such date of first use.

(5) That, for the purpose of determining liability of the registrant under the Securities Act of 1933 to any purchaser in the initial distribution of the securities: The undersigned registrant undertakes that in a primary offering of securities of the undersigned registrant pursuant to this registration statement, regardless of the underwriting method used to sell the securities to the purchaser, if the securities are offered or sold to such purchaser by means of any of the following communications, the undersigned registrant will be a seller to the purchaser and will be considered to offer or sell such securities to such purchaser: (i) any preliminary prospectus or prospectus of the undersigned registrant relating to the offering required to be filed pursuant to Rule 424; (ii) any free writing prospectus relating to the offering prepared by or on behalf of the undersigned registrant or used or referred to by the undersigned registrant; (iii) the portion of any other free writing prospectus relating to the offering containing material information about the undersigned registrant or its securities provided by or on behalf of the undersigned registrant; and (iv) any other communication that is an offer in the offering made by the undersigned registrant to the purchaser.

(b) Insofar as indemnification for liabilities arising under the Securities Act of 1933 may be permitted to our directors, officers and controlling persons pursuant to the foregoing provisions, or otherwise, we have been advised that in the opinion of the Securities and Exchange Commission such indemnification is against public policy as expressed in the Act and is, therefore, unenforceable.  In the event that a claim for indemnification against such liabilities (other than the payment by us of expenses incurred or paid by one of our directors, officers or controlling persons in the successful defense of any action, suit or proceeding) is asserted by such director, officer or controlling person in connection with the securities being registered, we will, unless in the

opinion of its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Act and will be governed by the final adjudication of such issue.

(c) The undersigned hereby undertakes to respond to requests for information that is incorporated by reference into the prospectus pursuant to Item 4, 10(b), 11 or 13 of this form, within one business day of receipt of such request, and to send the incorporated documents by first class mail or other equally prompt means.  This includes information contained in documents filed subsequent to the effective date of the registration statement through the date of responding to the request.

(d) The undersigned hereby undertakes to supply by means of a post-effective amendment all information concerning a transaction and the company being acquired involved therein, that was not the subject of and included in the registration statement when it became effective.

SIGNATURES

Pursuant to the requirements of the Securities Act of 1933, as amended, The Dayton Power and Light Company has duly caused this registration statement to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Indianapolis, State of Indiana, on November 8, 2019.

	The Dayton Power and Light Company
By:	/s/ Gustavo Garavaglia
	Gustavo Garavaglia
	Vice President and Chief Financial Officer

KNOW ALL MEN BY THESE PRESENTS, that each person whose signature appears below constitutes and appoints Gustavo Garavaglia and Judi L. Sobecki, and each of them, his or her true and lawful attorneys-in-fact and agents, with full power to act separately and full power of substitution and resubstitution, for him or her and in his or her name, place and stead, in any and all capacities, to sign any and all amendments (including post-effective amendments) to this registration statement and all additional registration statements pursuant to Rule 462(b) of the Securities Act of 1933, as amended, and to file the same, with all exhibits thereto, and all other documents in connection therewith, with the Securities and Exchange Commission, granting unto each said attorney-in-fact and agent full power and authority to do and perform each and every act in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or either of them or his or her or their substitute or substitutes may lawfully do or cause to be done by virtue hereof.

Pursuant to the requirements of the Securities Act of 1933, as amended, this registration statement has been signed by the following persons in the capacities and on the dates indicated.

/s/ Kenneth J. Zagzebski	Director and Chairman	November 8, 2019
Kenneth J. Zagzebski
/s/ Barry J. Bentley	Director	November 8, 2019
Barry J. Bentley
/s/ Lisa Krueger	Director	November 8, 2019
Lisa Krueger
/s/ Mark E. Miller	Director	November 8, 2019
Mark E. Miller
/s/ Tish D. Mendoza	Director	November 8, 2019
Tish D. Mendoza
/s/ Thomas A. Raga	Director	November 8, 2019
Thomas A. Raga
/s/ Vincent Parisi	Director, President and Chief Executive Officer	November 8, 2019
Vincent Parisi	(principal executive officer)
/s/ Gustavo Garavaglia	Vice President and Chief Financial Officer	November 8, 2019
Gustavo Garavaglia	(principal financial officer)
/s/ Karin M. Nyhuis	Controller	November 8, 2019
Karin M. Nyhuis	(principal accounting officer)

EX-5.1

		New York Northern California Washington DC São Paulo London	Paris Madrid Tokyo Beijing Hong Kong
Davis Polk & Wardwell LLP450 Lexington AvenueNew York, NY 10017	212 450 4000 tel 212 701 5800 fax

November 8, 2019

The Dayton Power and Light Company1065 Woodman DriveDayton, OH 45432

Ladies and Gentlemen:

We have acted as special counsel to The Dayton Power and Light Company, an Ohio corporation (the “Company”), in connection with the Company’s offer (the “Exchange Offer”) to exchange its First Mortgage Bonds, 3.95% Series due 2049 (the “New Notes”), issued pursuant to the provisions of the First and Refunding Mortgage dated as of October 1, 1935 (the “Base Mortgage and Deed of Trust”) between the Company and The Bank of New York Mellon Trust Company, N.A., as heretofore amended and supplemented, and as further amended and supplemented by a Fifty-Second Supplemental Indenture dated as of June 6, 2019 (the “Supplemental Indenture”) between the Company and The Bank of New York Mellon, as trustee (as so amended and supplemented, the “Mortgage and Deed Trust”), for any and all of its outstanding First Mortgage Bonds, 3.95% Series due 2049 (the “Old Notes”) pursuant to the registration statement on Form S-4 (the “Registration Statement”) filed by the Company with the Securities and Exchange Commission.

We, as your counsel, have examined originals or copies of such documents, corporate records, certificates of public officials and other instruments as we have deemed necessary or advisable for the purpose of rendering this opinion.

In rendering the opinion expressed herein, we have, without independent inquiry or investigation, assumed that (i) all documents submitted to us as originals are authentic and complete, (ii) all documents submitted to us as copies conform to authentic, complete originals, (iii) all signatures on all documents that we reviewed are genuine, (iv) all natural persons executing documents had and have the legal capacity to do so, (v) all statements in certificates of public officials and officers of the Company that we reviewed were and are accurate and (vi) all representations made by the Company as to matters of fact in the documents that we reviewed were and are accurate.

1

The Dayton Power and Light Company                            November 8, 2019

Based upon the foregoing, and subject to the additional assumptions and qualifications set forth below, we are of the opinion that the New Notes, when the New Notes are executed, authenticated and delivered in exchange for the Old Notes in accordance with the terms of the Mortgage and Deed Trust and the Exchange Offer, will constitute valid and binding obligations of the Company enforceable in accordance with their terms, subject to applicable bankruptcy, insolvency and similar laws affecting creditors’ rights generally, concepts of reasonableness and equitable principles of general applicability; provided that we express no opinion as to the (x) enforceability of any waiver of rights under any usury or stay law, (y) effect of fraudulent conveyance, fraudulent transfer or similar provision of applicable law on the conclusions expressed above or (z) validity, legally binding effect or enforceability of any provision that permits holders to collect any portion of stated principal amount upon acceleration of the New Notes to the extent determined to constitute unearned interest.

In connection with the opinions expressed above, we have assumed that (i) the Registration Statement shall have been declared effective and such effectiveness shall not have been suspended; (ii) the Mortgage and Deed Trust and the New Notes are each valid, binding and enforceable agreements of each party thereto (other than as expressly covered above in respect of the Company); and (iii) there shall not have occurred any change in law affecting the validity or enforceability of any of the New Notes.

We note that the Notes and the Mortgage and Deed of Trust are not stated by their terms to be governed by New York law. We express no opinion as to whether they are governed by New York law, and for purposes of our opinions we have assumed that New York law governs.

We are members of the Bar of the State of New York and the foregoing opinion is limited to the laws of the State of New York and the federal laws of the United States. Insofar as the foregoing opinion involves matters governed by the laws of Ohio, we have relied, without independent inquiry or investigation, on the opinion of Brian Hylander, filed with the Registration Statement on the date hereof.

We hereby consent to the filing of this opinion as an exhibit to the Registration Statement and further consent to the reference to our name under the caption “Validity of Securities” in the prospectus, which is a part of the Registration Statement. In giving this consent, we do not admit that we are in the category of persons whose consent is required under Section 7 of the Securities Act of 1933.

Very truly yours,

/s/ Davis Polk & Wardwell LLP

2

EX-5.2

OPINION OF THE DAYTON POWER AND LIGHT COMPANY ASSISTANT GENERAL COUNSEL

November 8, 2019

The Dayton Power and Light Company
1065 Woodman Drive
Dayton, OH 45432

Re: The Dayton Power and Light Company Registration Statement on Form S-4

Ladies and Gentlemen:

I am the Assistant General Counsel of The Dayton Power and Light Company, an Ohio corporation (the “Company”), and am acting as counsel to the Company in connection with the Registration Statement on Form S-4 (the “Registration Statement”) filed by the Company with the Securities and Exchange Commission (the “Commission”) under the Securities Act of 1933, as amended (the “Securities Act”). The Registration Statement relates to the issuance by the Company of up to $425,000,000 aggregate principal amount of its 3.95% First Mortgage Bonds due 2049 (the “New Bonds”). The New Bonds will be offered by the Company in exchange for $425,000,000 aggregate principal amount of its outstanding 3.95% First Mortgage Bonds due 2049, which have not been registered under the Securities Act. The New Bonds will be issued pursuant to the provisions of the First and Refunding Mortgage dated as of October 1, 1935, as amended and supplemented from time to time and as amended and supplemented by a Fifty-Second Supplemental Indenture dated as of June 6, 2019 relating to the New Bonds, between The Bank of New York Mellon Trust Company, N.A. and the Company. All capitalized terms used and not otherwise defined herein shall have the meanings assigned to such terms in the Registration Statement.

 In rendering my opinions expressed below, I have examined such certificates, corporate and public records, instruments and other documents and reviewed such matters of law as I have considered necessary and appropriate. In my examination of the foregoing, I have assumed, without independent investigation, (i) the genuineness of all signatures, (ii) the legal capacity of all natural persons, (iii) the authenticity and completeness of all documents submitted to me as originals, (iv) the conformity to original documents of all documents submitted to me as duplicates or certified or conformed copies, (v) the authenticity and completeness of the originals of such latter documents, and (vi) that each certificate, record, instrument and other document issued by any governmental authority is accurate and complete.

The Dayton Power and Light Company Registration Statement on Form S-4

November 8, 2019

Page 2

Based upon the foregoing, and subject to the assumptions, qualifications and limitations stated herein, I am of the opinion that:

1.    The Company is validly existing as a corporation in good standing under the laws of the State of Ohio and has the corporate power and authority required to carry on its business as it is currently being conducted and to own, lease or operate its properties and to issue the New Bonds.

2.    The Company has duly authorized the issuance of the New Bonds.

My opinion as to the valid existence and good standing of the Company set forth in paragraph 1 above is based solely on my review and examination of the certificate issued by the Ohio Secretary of State regarding the legal existence and corporate good standing of the Company in the State of Ohio.

I am a member of the bar of the State of Ohio and my opinion is limited to the laws of the State of Ohio.

This opinion letter has been prepared for use in connection with the Registration Statement and may not be relied upon for any other purpose. This opinion letter is limited to the matters stated herein and no opinions may be implied or inferred beyond the matters expressly stated herein.

The opinions expressed herein are as of the date hereof, and I assume no obligation to update or supplement such opinions to reflect any facts or circumstances that may hereafter come to my attention or any changes in law that may hereafter occur.

I hereby consent to reliance on this opinion letter and the opinions provided herein by Davis Polk & Wardwell LLP in connection with the legal opinion provided by that law firm that is included as an exhibit to the Registration Statement.

            I hereby consent to the references in the Registration Statement to my name and my position as Assistant General Counsel of the Company under the caption “Validity of Securities”, and to the inclusion of this opinion as an exhibit to the Registration Statement. In giving this consent, I do not thereby admit that I am within the category of persons whose consent is required under Section 7 of the Securities Act, or the rules and regulations of the Commission thereunder.

Very truly yours,

/s/ Brian Hylander

Brian Hylander

Assistant General Counsel

The Dayton Power and Light Company

EX-23.3

Consent of Independent Registered Public Accounting Firm

We consent to the reference to our firm under the caption "Experts" and to the use of our report dated February 26, 2019, in the Registration Statement (Form S-4) of The Dayton Power and Light Company for the registration of $425,000,000 of First Mortgage Bonds, 3.95% Series due 2049.

/s/ Ernst & Young LLP

Indianapolis, Indiana

November 8, 2019

EX-25.1

Exhibit 25.1

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM T-1

STATEMENT OF ELIGIBILITY UNDER THE TRUST

INDENTURE ACT OF 1939 OF A CORPORATION

DESIGNATED TO ACT AS TRUSTEE

CHECK IF AN APPLICATION TO DETERMINE ELIGIBILITY OF A

TRUSTEE PURSUANT TO SECTION 305(b)(2)

_________________

THE BANK OF NEW YORK MELLON

(Exact name of trustee as specified in its charter)

New York (Jurisdiction of incorporation if not a U.S. national bank)	13-5160382 (I.R.S. Employer Identification No.)
240 Greenwich Street New York, New York (Address of principal executive offices)	10286 (Zip code)

Legal Department

The Bank of New York Mellon

240 Greenwich Street

New York, NY 10286

(212) 635-1270

(Name, address and telephone number of agent for service)

The Dayton Power and Light Company

(Exact name of obligor as specified in its charter)

Ohio (State or other jurisdiction of incorporation or organization)	31-0258470 (I.R.S. Employer Identification No.)
1065 Woodman Drive Dayton, Ohio (Address of principal executive offices)	45432 (Zip code)

_________________

First Mortgage Bonds, 3.95% Series due 2049

(Title of the indenture securities)

Item 1. General Information.

Furnish the following information as to the Trustee:

(a) Name and address of each examining or supervising authority to

which it is subject.

Superintendent of Banks of the    One State Street, New York, N.Y. 10004-1417

State of New York and Albany, N.Y. 12203

Federal Reserve Bank of New York    33 Liberty Plaza, New York, N.Y. 10045

Federal Deposit Insurance Corporation    550 17th Street, N.W., Washington, D.C. 20429

New York Clearing House Association    New York, N.Y. 10005

(b) Whether it is authorized to exercise corporate trust powers.

Yes.

Item 2. Affiliations with Obligor.

If the obligor is an affiliate of the trustee, describe each such affiliation.

None.

Item 16. List of Exhibits.

Exhibits identified in parentheses below, on file with the Commission, are incorporated herein by reference as an exhibit hereto, pursuant to Rule 7a-29 under the Trust Indenture Act of 1939 (the "Act") and 17 C.F.R. 229.10(d).

1. -    A copy of the Organization Certificate of The Bank of New York Mellon (formerly The Bank of New York (formerly Irving Trust Company)) as now in effect, which contains the authority to commence business and a grant of powers to exercise corporate trust powers. (Exhibit 1 to Amendment No. 1 to Form T-1 filed with Registration Statement No. 33-6215, Exhibits 1a and 1b to Form T-1 filed with Registration Statement No. 33-21672, Exhibit 1 to Form T-1 filed with Registration Statement No. 33-29637, Exhibit 1 to Form T-1 filed with Registration Statement No. 333-121195 and Exhibit 1 to Form T-1 filed as Exhibit 25.1 to Current Report on Form 8-K of Nevada Power Company, Date of Report (Date of Earliest Event Reported) July 25, 2008 (File No. 000-52378).)

4. -    A copy of the existing By-laws of the Trustee. (Exhibit 4 to Form T-1 with Registration Statement No. 333-155238.)

6. -    The consent of the Trustee required by Section 321(b) of the Act. (Exhibit 6 to Form T-1 filed with Registration Statement No. 333-152856.)

7. -    A copy of the latest report of condition of the Trustee published pursuant to law or to the requirements of its supervising or examining authority.

SIGNATURE

Pursuant to the requirements of the Act, the Trustee, The Bank of New York Mellon, a corporation organized and existing under the laws of the State of New York, has duly caused this statement of eligibility to be signed on its behalf by the undersigned, thereunto duly authorized, all in The City of New York, and State of New York, on the 8th day of November, 2019.

THE BANK OF NEW YORK MELLON

By:    /s/ Francine Kincaid    

Name: Francine Kincaid

    Title: Vice President

Consolidated Report of Condition ofTHE BANK OF NEW YORK MELLONof 240 Greenwich Street, New York, N.Y. 10286
And Foreign and Domestic Subsidiaries,

a member of the Federal Reserve System, at the close of business June 30, 2019, published in accordance with a call made by the Federal Reserve Bank of this District pursuant to the provisions of the Federal Reserve Act.

ASSETS	Dollar amounts in thousands
Cash and balances due from depository institutions:
Noninterest-bearing balances and currency and coin	$	4,814,000
Interest-bearing balances	84,689,000
Securities:
Held-to-maturity securities	34,540,000
Available-for-sale securities	83,638,000
Equity securities with readily determinable fair values not held for trading	41,000
Federal funds sold and securities purchased under agreements to resell:
Federal funds sold in domestic offices	0
Securities purchased under agreements to resell	47,936,000
Loans and lease financing receivables:
Loans and leases held for sale	0
Loans and leases held for investment	23,952,000
LESS: Allowance for loan and lease losses	120,000
Loans and leases held for investment, net of allowance	23,832,000
Trading assets	3,898,000
Premises and fixed assets (including capitalized leases)	2,469,000
Other real estate owned	2,000
Investments in unconsolidated subsidiaries and associated companies	1,772,000
Direct and indirect investments in real estate ventures	0
Intangible assets:	7,052,000
Other assets	15,465,000
Total assets	$	310,148,000

LIABILITIES
Deposits:
In domestic offices	$	140,976,000
Noninterest-bearing	53,754,000
Interest-bearing	87,222,000
In foreign offices, Edge and Agreement subsidiaries, and IBFs	117,370,000
Noninterest-bearing	5,915,000
Interest-bearing	111,455,000
Federal funds purchased and securities sold under agreements to repurchase:
Federal funds purchased in domestic offices	3,311,000
Securities sold under agreements to repurchase	962,000
Trading liabilities	2,366,000
Other borrowed money: (includes mortgage indebtedness and obligations under capitalized leases)	12,531,000
Not applicable
Not applicable
Subordinated notes and debentures	0
Other liabilities	6,626,000
Total liabilities	284,142,000
EQUITY CAPITAL
Perpetual preferred stock and related surplus	0
Common stock	1,135,000
Surplus (exclude all surplus related to preferred stock)	11,080,000
Retained earnings	15,154,000
Accumulated other comprehensive income	(1,363,000		)
Other equity capital components	0
Total bank equity capital	26,006,000
Noncontrolling (minority) interests in consolidated subsidiaries	0
Total equity capital	26,006,000
Total liabilities and equity capital	$	310,148,000

I, Michael Santomassimo, Chief Financial Officer of the above-named bank do hereby declare that this Report of Condition is true and correct to the best of my knowledge and belief.

Michael Santomassimo
Chief Financial Officer

We, the undersigned directors, attest to the correctness of this statement of resources and liabilities. We declare that it has been examined by us, and to the best of our knowledge and belief has been prepared in conformance with the instructions and is true and correct.

Charles W. Scharf
Samuel C. Scott
Joseph J. Echevarria Directors

EX-99.1

NOTICE OF GUARANTEED DELIVERY
For Tender OfFirst Mortgage Bonds, 3.95% Series due 2049

(144A CUSIP: 240019 BT5; Reg S CUSIP: U23926 AB1)

ofThe Dayton Power and Light Company

This Notice of Guaranteed Delivery or one substantially equivalent hereto must be used to accept the Exchange Offer (as defined below) if the procedures for book-entry transfer of First Mortgage Bonds, 3.95% Series due 2049 (the “Old Notes”) cannot be completed on a timely basis. This Notice of Guaranteed Delivery may be delivered by hand or sent by facsimile transmission, overnight courier or mail to The Bank of New York Mellon (the “Exchange Agent”). See “The Exchange Offer—Guaranteed Delivery Procedures” in the Prospectus dated , 2019 (which constitutes the “Exchange Offer”) of The Dayton Power and Light Company, an Ohio Corporation (the “Company”).

The Exchange Agent for the Exchange Offer is:

The Bank of New York Mellon

By Mail, Overnight Courier or by Hand: The Bank of New York Mellon 111 Sanders Creek Parkway East Syracuse, NY 13057 Attn: Corporate Trust Reorg - Eric Herr By Facsimile Transmission(for Eligible Institutions only): The Bank of New York Mellon 732-667-9408 Confirmation by Telephone: 315-414-3362

DELIVERY OF THIS NOTICE OF GUARANTEED DELIVERY TO AN ADDRESS OTHER THAN AS SET FORTH ABOVE OR TRANSMISSION OF THIS NOTICE OF GUARANTEED DELIVERY VIA A FACSIMILE TRANSMISSION TO A NUMBER OTHER THAN AS SET FORTH ABOVE WILL NOT CONSTITUTE A VALID DELIVERY.

THIS NOTICE OF GUARANTEED DELIVERY IS NOT TO BE USED TO GUARANTEE SIGNATURES.

THE FOLLOWING GUARANTEE MUST BE COMPLETED
GUARANTEE OF DELIVERY
(Not to be used for Signature Guarantee)

The undersigned, a firm which is a member of a registered national securities exchange or a member of the Financial Industry Regulatory Authority, Inc. or a commercial bank or trust company having an office or correspondent in the United States, hereby guarantees to deliver to the Exchange Agent, at one of its addresses set forth above, the confirmation of the book-entry transfer of all tendered Old Notes to the Exchange Agent’s account at The Depository Trust Company (“DTC”), pursuant to the procedures for book-entry transfer set forth in the Prospectus together with any other documents required by the Prospectus within three New York Stock Exchange trading days after the date of execution of this Notice of Guaranteed Delivery.

The undersigned acknowledges that it must deliver the Old Notes tendered hereby to the Exchange Agent within the time period set forth above and that failure to do so could result in a financial loss to the undersigned.

Name of Firm:
	(Authorized Signature)
Address:	Title:
	Name:
(Zip Code)		(Please type or print)
Area Code and Telephone Number:	Date:

2

EX-99.2

Offer to ExchangeFirst Mortgage Bonds, 3.95% Series due 2049(Registered under the Securities Act of 1933)
for Any and All Outstanding

First Mortgage Bonds, 3.95% Series due 2049

(144A CUSIP: 240019 BT5; Reg S CUSIP: U23926 AB1)

ofThe Dayton Power and Light Company

To Our Clients:

Enclosed is a Prospectus dated , 2019 (which constitutes the “Exchange Offer”) of The Dayton Power and Light Company, an Ohio corporation (the “Company”), relating to the offer by the Company to exchange its First Mortgage Bonds, 3.95% Series due 2049 (the “New Notes”), pursuant to an offering registered under the Securities Act of 1933, as amended (the “Securities Act”), for a like principal amount of its issued and outstanding First Mortgage Bonds, 3.95% Series due 2049 (the “Old Notes”) upon the terms and subject to the conditions set forth in the Exchange Offer.

Please note that the Exchange Offer will expire at 11:59 P.M., New York City time, on , 2019, unless extended.

The Exchange Offer is not conditioned upon any minimum number of Old Notes being tendered.

We are the holder of record and/or participant in the book-entry transfer facility of Old Notes held by us for your account. A tender of such Old Notes can be made only by us as the record holder and/or participant in the book-entry transfer facility and pursuant to your instructions.

We request instructions as to whether you wish to tender any or all of the Old Notes held by us for your account pursuant to the terms and conditions of the Exchange Offer. We also request that you confirm that we may on your behalf make the representations contained in the Prospectus.

Pursuant to the Prospectus, each holder of Old Notes will represent to the Company that (i) the holder is not an “affiliate” of the Company, (ii) any New Notes to be received by the holder are being acquired in the ordinary course of its business, and (iii) the holder has no arrangement or understanding with any person to participate, and is not engaged and does not intend to engage in a distribution (within the meaning of the Securities Act) of such New Notes. If the tendering holder is a broker-dealer that will receive New Notes for its own account in exchange for Old Notes, we will represent on behalf of such broker-dealer that the Old Notes to be exchanged for the New Notes were acquired by it as a result of market-making activities or other trading activities, and acknowledge on behalf of such broker-dealer that it will deliver a prospectus meeting the requirements of the Securities Act in connection with any resale of such New Notes. By acknowledging that it will deliver and by delivering a prospectus meeting the requirements of the Securities Act in connection with any resale of such New Notes, such broker-dealer is not deemed to admit that it is an “underwriter” within the meaning of the Securities Act.

Very truly yours,

2

EX-99.3

Offer to ExchangeFirst Mortgage Bonds, 3.95% Series due 2049(Registered under the Securities Act of 1933)for Any and All Outstanding

First Mortgage Bonds, 3.95% Series due 2049

(144A CUSIP: 240019 BT5; Reg S CUSIP: U23926 AB1)

ofThe Dayton Power and Light Company

To Registered Holders and The Depository
Trust Company Participants:

Enclosed are the materials listed below relating to the offer by The Dayton Power and Light Company, an Ohio corporation (the “Company”), to exchange its First Mortgage Bonds, 3.95% Series due 2049 (the “New Notes”), pursuant to an offering registered under the Securities Act of 1933, as amended (the “Securities Act”), for a like principal amount of its issued and outstanding First Mortgage Bonds, 3.95% Series due 2049 (the “Old Notes”) upon the terms and subject to the conditions set forth in the Company’s Prospectus dated , 2019 (which constitutes the “Exchange Offer”).

Enclosed herewith are copies of the following documents:

1. Prospectus dated , 2019;

2. Notice of Guaranteed Delivery;

3. Instruction to Registered Holder and/or Book-Entry Transfer Participant from Owner; and

4. Letter which may be sent to your clients for whose account you hold Old Notes in your name or in the name of your nominee, to accompany the instruction form referred to above, for obtaining such client’s instruction with regard to the Exchange Offer.

We urge you to contact your clients promptly. Please note that the Exchange Offer will expire at 11:59 P.M., New York City time, on , 2019, unless extended.

The Exchange Offer is not conditioned upon any minimum number of Old Notes being tendered.

Pursuant to the Prospectus, each holder of Old Notes will represent to the Company that (i) the holder is not an “affiliate” of the Company, (ii) any New Notes to be received by it are being acquired in the ordinary course of its business, and (iii) the holder has no arrangement or understanding with any person to participate, and is not engaged and does not intend to engage, in a distribution (within the meaning of the Securities Act) of such New Notes. If the tendering holder is a broker-dealer that will receive New Notes for its own account in exchange for Old Notes, you will represent on behalf of such broker-dealer that the Old Notes to be exchanged for the New Notes were acquired by it as a result of market-making activities or other trading activities, and acknowledge on behalf of such broker-dealer that it will deliver a prospectus

meeting the requirements of the Securities Act in connection with any resale of such New Notes. By acknowledging that it will deliver and by delivering a prospectus meeting the requirements of the Securities Act in connection with any resale of such New Notes, such broker-dealer is not deemed to admit that it is an “underwriter” within the meaning of the Securities Act.

The enclosed Instruction to Registered Holder and/or Book-Entry Transfer Participant from Owner contains an authorization by the beneficial owners of the Old Notes for you to make the foregoing representations.

The Company will not pay any fee or commission to any broker or dealer or to any other persons (other than the Exchange Agent) in connection with the solicitation of tenders of Old Notes pursuant to the Exchange Offer. The Company will pay or cause to be paid any transfer taxes payable on the transfer of Old Notes to it.

Additional copies of the enclosed materials may be obtained from the undersigned.

Very truly yours,

The Dayton Power and Light Company

NOTHING CONTAINED HEREIN OR IN THE ENCLOSED DOCUMENTS SHALL CONSTITUTE YOU THE AGENT OF THE DAYTON POWER AND LIGHT COMPANY OR THE BANK OF NEW YORK MELLON OR AUTHORIZE YOU TO USE ANY DOCUMENT OR MAKE ANY STATEMENT ON THEIR BEHALF IN CONNECTION WITH THE EXCHANGE OFFER OTHER THAN THE DOCUMENTS ENCLOSED HEREWITH AND THE STATEMENTS CONTAINED THEREIN.

2

EX-99.4

INSTRUCTION TO REGISTERED HOLDER AND/OR
BOOK-ENTRY TRANSFER PARTICIPANT FROM OWNER
OFThe Dayton Power and Light CompanyFirst Mortgage Bonds, 3.95% Series due 2049

(144A CUSIP: 240019 BT5; Reg S CUSIP: U23926 AB1)
(the “Old Notes”)

To Registered Holder and/or Participant of the Book-Entry Transfer Facility:

The undersigned hereby acknowledges receipt of the Prospectus dated , 2019 (the “Prospectus”) of The Dayton Power and Light Company, an Ohio corporation, (the “Company”) that constitutes the Company’s offer (the “Exchange Offer”). Capitalized terms used but not defined herein have the meanings as ascribed to them in the Prospectus.

This will instruct you, the registered holder and/or book-entry transfer facility participant, as to the action to be taken by you relating to the Exchange Offer with respect to the Old Notes held by you for the account of the undersigned.

The aggregate face amount of the Old Notes held by you for the account of the undersigned is (fill in amount):

$___________ of the First Mortgage Bonds, 3.95% Series due 2049

With respect to the Exchange Offer, the undersigned hereby instructs you (check appropriate box):

To TENDER the following Old Notes held by you for the account of the undersigned (insert principal amount of Old Notes to be tendered, if any):

$___________ of the First Mortgage Bonds, 3.95% Series due 2049

NOT to TENDER any Old Notes held by you for the account of the undersigned.

If the undersigned instructs you to tender the Old Notes held by you for the account of the undersigned, it is understood that you are authorized to make, on behalf of the undersigned (and the undersigned, by its signature below, hereby makes to you), the representations and warranties contained in the Prospectus that are to be made with respect to the undersigned as a beneficial owner, including but not limited to the representations that (i) the holder is not an “affiliate” of the Company, (ii) any New Notes to be received by the holder are being acquired in the ordinary course of its business, and (iii) the holder has no arrangement or understanding with any person to participate, and is not engaged and does not intend to engage, in a distribution (within the meaning of the Securities Act) of such New Notes. If the undersigned is a broker-dealer that will receive New Notes for its own account in exchange for Old Notes, it represents that such Old Notes were acquired as a result of market-making activities or other trading activities, and it acknowledges that it will deliver a prospectus meeting the requirements of the Securities Act in connection with any resale of such New Notes. By acknowledging that it will deliver and by delivering a prospectus meeting the requirements of the Securities Act in connection with any resale of such

New Notes, such broker-dealer is not deemed to admit that it is an “underwriter” within the meaning of the Securities Act of 1933, as amended.

2

SIGN HERE

Name of beneficial owner(s):

Signature(s):

Name(s) (please print):

Address:

Telephone Number:

Taxpayer Identification or Social Security Number:

Date:

3

XML

Related Party Transactions (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2016
Related Party Transaction [Line Items]
Deferred Compensation Arrangement with Individual, Compensation Expense	$ 0.3	$ 0.4	$ 0.5
Sales to related party	4.9	4.2	4.5
Charges for Services Provided	25.7	39.0	38.7
Net payable to the Service Company	(4.8)	(3.9)
Premiums paid for Insurance Services provided by MVIC	2.7	3.1	3.4
Due to Affiliate	0.5	(4.8)
AES Ohio Generation [Member]
Related Party Transaction [Line Items]
Charges for Services Provided	0.0	5.4	8.7
Subsidiary of Common Parent [Member]
Related Party Transaction [Line Items]
Net payable to the Service Company				$ (7.5)
Income Taxes Paid, Net [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	14.6	28.1	0.0
Charges for health, welfare and benefit plans [Member] | Subsidiary of Common Parent [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	8.7	14.3	9.4
Consulting Services [Member] | Subsidiary of Common Parent [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	2.0	0.0	0.0
Charges for affiliates for non-power goods or services [Member] | Subsidiary of Common Parent [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	$ 7.1	$ 3.7	$ 5.7

XML

Benefit Plans (Other Changes in Plan Assets and Benefit Obligation Recognized in Accumulated Other Comprehensive Income, Regulatory Assets And Regulatory Liabilities) (Details) - Pension [Member] - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) / loss	$ 3.4	$ 9.1	$ 20.9
Defined Benefit Plan, Accumulated Other Comprehensive Income, Plan Curtailments	0.0	(5.6)	(5.7)
Reversal of amortization item, Net actuarial (gain) / loss	(9.4)	(8.7)	(7.2)
Reversal of amortization item, Prior service cost / (credit)	(1.4)	(1.5)	(3.0)
Total recognized in Accumulated other comprehensive income, Regulatory assets and Regulatory liabilities	(7.4)	(6.7)	5.0
Total recognized in net periodic benefit cost and Accumulated other comprehensive income, Regulatory assets and Regulatory liabilities	2.1	6.2	18.5
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement and Curtailment	$ 0.0	$ (5.6)	$ (5.7)

XML

Benefit Plans (Fair Value Measurements for Pension Plan Assets) (Details) - Pension [Member] - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Total Pension Plan Assets	$ 312.9	$ 357.5	$ 341.0
Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Pension Plan Assets	288.8	321.3
Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Pension Plan Assets	24.1	36.2
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Pension Plan Assets	0.0	0.0
U.S. Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	79.3	78.2
U.S. Equities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	79.3	78.2
U.S. Equities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	0.0	0.0
U.S. Equities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	0.0	0.0
International Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	25.9	46.3
International Equities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	25.9	46.3
International Equities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	0.0	0.0
International Equities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	0.0	0.0
Fixed Income Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	143.7	163.3
Fixed Income Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	143.7	163.3
Fixed Income Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	0.0	0.0
Fixed Income Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Equity Securities	0.0	0.0
US Treasury Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Debt Securities	37.5	33.5
US Treasury Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Debt Securities	37.5	33.5
US Treasury Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Debt Securities	0.0	0.0
US Treasury Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Debt Securities	0.0	0.0
Money Market Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Debt Securities	2.4
Money Market Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Debt Securities	2.4
Money Market Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Debt Securities	0.0
Money Market Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Debt Securities	0.0
Core Property Collective Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Other Investments	24.1	36.2
Core Property Collective Fund [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Other Investments	0.0	0.0
Core Property Collective Fund [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Other Investments	24.1	36.2
Core Property Collective Fund [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Other Investments	$ 0.0	$ 0.0

XML

Generation Separation (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Dec. 31, 2017	Dec. 31, 2016	Oct. 01, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Long Term Indebtedness, Less than or Equal to	$ 750.0	$ 750.0	$ 750.0
Debt Percentage of Rate Base			75.00%
Income / (loss) from discontinued operations before income tax	0.0		$ (56.3)	$ (1,338.7)
Income tax expense from discontinued operations	0.0		(15.9)	(468.4)
Net income / (loss) from discontinued operations	0.0		(40.4)	(870.3)
Transmission and Distribution [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Long-term Debt, Gross					$ 750.0
Generation [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash Provided by (Used in) Operating Activities, Discontinued Operations			21.8	29.9
Cash Provided by (Used in) Investing Activities, Discontinued Operations			(3.5)	(39.0)
Disposal Group, Including Discontinued Operation, Restricted Cash					2.0
Accounts receivable, net					31.3
Disposal Group, Including Discontinued Operation, Inventory					42.0
Disposal Group, Including Discontinued Operations, Taxes Applicable to Subsequent Years					1.8
Property, plant & equipment, net					87.0
Intangible assets, net					0.7
Other assets					15.5
Total assets of the disposal group classified as held for sale in the balance sheets					180.3
Accounts payable					12.4
Disposal Group, Including Discontinued Operation, Accrued Income Tax Payable					(3.9)
Disposal Group, Including Discontinued Operations, Long-Term Debt					0.3
Disposal Group, Including Discontinued Operation, Deferred Tax Liabilities					(91.9)
Disposal Group, Including Discontinued Operation, Pension Plan Benefit Obligation					9.6
Disposal Group, Including Discontinued Operation, Accumulated Deferred Investment Tax Credit					15.1
Asset Retirement Obligation, Held for Sale					126.3
Other liabilities					24.1
Total liabilities of the disposal group classified as held for sale in the balance sheets					92.0
Disposal Group, Including Discontinued Operation, Accumulated Other Comprehensive Income (Loss), Net of Tax					2.1
Disposal Group, Including Discontinued Operation, Net Assets	$ 10.0			0.0	$ 86.2
Revenues			358.4	557.9
Cost of revenues			(191.6)	(341.1)
Disposal Group, Including Discontinued Operation, Operating and Other Expenses			(156.8)	(202.0)
Disposal Group, Including Discontinued Operation, Fixed-Asset Impairment			(66.3)	(1,353.5)
Income / (loss) from discontinued operations before income tax			(56.3)	(1,338.7)
Income tax expense from discontinued operations			(15.9)	(468.4)
Net income / (loss) from discontinued operations			(40.4)	(870.3)
Disposal Group, Including Discontinued Operation, Interest Expense			$ 0.2	$ 0.5

XML

Fair Value Measurements (Fair Value of Assets and Liabilities Measured on Recurring Basis) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Sep. 30, 2019	Dec. 31, 2017
Proceeds from Sale of Debt Securities, Available-for-sale	$ 0.5
AvailableForSaleSecuritiesGross Realized Gains Losses Sale Proceeds Net of Tax	0.4
Fair Value, Inputs, Level 1 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.4	$ 0.2	$ 0.3
Total Derivative Assets	0.0	0.0	0.0
Total Assets	0.4	0.2	0.3
Debt Instrument, Fair Value Disclosure			0.0
Total Liabilities	0.0	0.0	0.0
Fair Value, Inputs, Level 1 [Member] | Subsidiaries [Member] | Interest Rate Contract [Member]
Total Derivative Assets	0.0	0.0	0.0
Fair Value, Inputs, Level 2 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	7.7	8.2	8.8
Total Derivative Assets	1.5	0.2	1.5
Total Assets	9.2	8.4	10.3
Debt Instrument, Fair Value Disclosure			640.6
Total Liabilities	576.1	613.4	640.6
Fair Value, Inputs, Level 2 [Member] | Subsidiaries [Member] | Interest Rate Contract [Member]
Total Derivative Assets	1.5	0.2	1.5
Fair Value, Inputs, Level 3 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Total Derivative Assets	0.0	0.0
Total Assets	0.0	0.0	0.0
Debt Instrument, Fair Value Disclosure			17.8
Total Liabilities	17.7	17.6	17.8
Fair Value, Inputs, Level 3 [Member] | Subsidiaries [Member] | Interest Rate Contract [Member]
Total Derivative Assets	0.0	0.0
Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0	0.0
Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	3.5	3.9	4.2
Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Debt Securities [Member] | Fair Value, Inputs, Level 1 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0	0.0
Debt Securities [Member] | Fair Value, Inputs, Level 2 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	4.0	4.1	4.3
Debt Securities [Member] | Fair Value, Inputs, Level 3 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Money Market Funds [Member] | Fair Value, Inputs, Level 1 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.4	0.2	0.3
Money Market Funds [Member] | Fair Value, Inputs, Level 2 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0	0.0
Money Market Funds [Member] | Fair Value, Inputs, Level 3 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Hedge Funds [Member] | Fair Value, Inputs, Level 1 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0	0.0
Hedge Funds [Member] | Fair Value, Inputs, Level 2 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.1	0.1	0.2
Hedge Funds [Member] | Fair Value, Inputs, Level 3 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Tangible Assets [Member] | Fair Value, Inputs, Level 1 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0	0.0
Tangible Assets [Member] | Fair Value, Inputs, Level 2 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.1	0.1	0.1
Tangible Assets [Member] | Fair Value, Inputs, Level 3 [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Debt [Member] | Fair Value, Inputs, Level 1 [Member] | Subsidiaries [Member]
Debt Instrument, Fair Value Disclosure	0.0	0.0
Debt [Member] | Fair Value, Inputs, Level 2 [Member] | Subsidiaries [Member]
Debt Instrument, Fair Value Disclosure	576.1	613.4
Debt [Member] | Fair Value, Inputs, Level 3 [Member] | Subsidiaries [Member]
Debt Instrument, Fair Value Disclosure	17.7	17.6
Fair Value [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	8.1	8.4	9.1
Total Derivative Assets	1.5	0.2	1.5
Total Assets	9.6	8.6	10.6
Total Liabilities	593.8	631.0	658.4
Fair Value [Member] | Subsidiaries [Member] | Interest Rate Contract [Member]
Total Derivative Assets	1.5	0.2	1.5
Fair Value [Member] | Equity Securities [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	3.5	3.9	4.2
Fair Value [Member] | Debt Securities [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	4.0	4.1	4.3
Fair Value [Member] | Money Market Funds [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.4	0.2	0.3
Fair Value [Member] | Hedge Funds [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.1	0.1	0.2
Fair Value [Member] | Tangible Assets [Member] | Subsidiaries [Member]
Total Master Trust Assets, Fair Value	0.1	0.1	0.1
Fair Value [Member] | Debt [Member] | Subsidiaries [Member]
Debt Instrument, Fair Value Disclosure	593.8	631.0	658.4
Long-term Debt, Fair Value	$ 593.8	$ 631.0	$ 658.4

XML

Property, Plant and Equipment (Changes in the Liability for Generation of AROs) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at January 1	$ 8.0	$ 8.2
Accretion expense		0.1
Settlements	(3.3)	(0.3)
Balance at December 31	$ 4.7	$ 8.0

XML

Derivative Instruments and Hedging Activities (Gains or Losses Recognized in AOCI for the Cash Flow Hedges) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Forward Contract Power [Member]
Derivative Instrument, loss from discontinued operations						$ (5.5)	$ (29.2)
Beginning accumulated derivative gain / (loss) in AOCI				$ 0.0	$ 0.0	(4.3)	9.2
Net gains / (losses) associated with current period hedging transactions						11.9	15.7
Ending accumulated derivative gain / (loss) in AOCI						0.0	(4.3)
Derivative Instrument, transfer of generation assets of subsidiary						(2.1)
Interest Rate Contract [Member]
Beginning accumulated derivative gain / (loss) in AOCI	$ (0.3)	$ 1.6	$ 0.6	1.4	1.4	1.6	2.0
Net gains / (losses) associated with current period hedging transactions	(0.1)	0.0	(0.9)	0.5	(0.1)	0.5	0.4
Ending accumulated derivative gain / (loss) in AOCI	(0.4)	1.4	(0.4)	1.4	0.6	1.4	1.6
Portion expected to be reclassified to earnings in the next twelve months	(0.2)		$ (0.2)		$ 0.7
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)			11 months		20 months
Interest Expense [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	$ 0.0	$ (0.2)	$ (0.1)	$ (0.5)	$ (0.7)	$ (0.7)	$ (0.8)

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Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Schedule of Related Party Transactions

The following table provides a summary of our related party transactions:

	Years ended December 31,
$ in millions	2018			2017			2016
DP&L Cost of revenues:
Fuel and power purchased from AES Ohio Generation	$	—		$	5.4		$	8.7
DP&L Operation & Maintenance Expenses:
Premiums charged for insurance services provided by MVIC (a)	$	2.7		$	3.1		$	3.4
Transactions with the Service Company:
Charges for services provided	$	25.7		$	39.0		$	38.7
Charges to the Service Company	$	4.9		$	4.2		$	4.5
Transactions with other AES affiliates:
Charges for health, welfare and benefit plans	$	8.7		$	14.3		$	9.4
Charges to affiliates for non-power goods or services (b)	$	7.1		$	3.7		$	5.7
Consulting services	$	2.0		$	—		$	—
Balances with related parties:	At December 31, 2018			At December 31, 2017
Net payable to the Service Company	$	(4.8	)	$	(3.9	)
Net receivable from / (payable) to other AES affiliates	$	(0.5	)	$	4.8

(a) MVIC, a wholly-owned captive insurance subsidiary of DPL, provides insurance coverage to DP&L and other DPL subsidiaries for workers’ compensation, general liability, property damages and directors’ and officers’ liability. These amounts represent insurance premiums charged by MVIC to DP&L.

(b) In the normal course of business DP&L incurred and recorded expenses on behalf of DPL affiliates. Such expenses included but were not limited to employee-related expenses, accounting, information technology, payroll, legal and other administration expenses. DP&L subsequently charged these expenses to the affiliates at DP&L’s cost and credited the expense in which they were initially recorded.

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Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2018

Subsidiaries [Member]

Schedule of Regulatory Assets and Liabilities [Table Text Block]

The following table presents DP&L’s Regulatory assets and liabilities:

	Type of Recovery	Amortization Through	December 31,
$ in millions			2018		2017
Regulatory assets, current:
Undercollections to be collected through rate riders	A/B	2019	$	40.5	$	23.9
Rate case expenses being recovered in base rates	B	2019	0.6		—
Total regulatory assets, current			41.1		23.9
Regulatory assets, non-current:
Pension benefits	B	Ongoing	87.5		92.4
Unrecovered OVEC charges	C	Undetermined	28.7		27.8
Fuel costs	B	2020	3.3		9.3
Regulatory compliance costs	B	2020	6.1		9.2
Smart grid and AMI costs	B	Undetermined	8.5		7.3
Unamortized loss on reacquired debt	B	Various	6.0		7.0
Deferred storm costs	A	Undetermined	4.7		2.1
Deferred vegetation management and other	A/B	Undetermined	7.8		8.1
Total regulatory assets, non-current			152.6		163.2
Total regulatory assets			$	193.7	$	187.1
Regulatory liabilities, current:
Overcollection of costs to be refunded through rate riders	A/B	2018	$	34.9	$	14.8
Total regulatory liabilities, current			34.9		14.8
Regulatory liabilities, non-current:
Estimated costs of removal - regulated property		Not Applicable	139.1		132.8
Deferred income taxes payable through rates		Various	116.3		83.4
PJM transmission enhancement settlement	A	2025	16.9		—
Postretirement benefits	B	Ongoing	6.0		5.0
Total regulatory liabilities, non-current			278.3		221.2
Total regulatory liabilities			$	313.2	$	236.0

A – Recovery of incurred costs plus rate of return.

B – Recovery of incurred costs without a rate of return.

C – Recovery not yet determined, but recovery is probable of occurring in future rate proceedings.

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Debt (Tables) - THE DAYTON POWER AND LIGHT COMPANY [Member]

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Debt Instrument [Line Items]

Debt Disclosure [Text Block]

The following table summarizes DP&L's long-term debt.

	Interest		September 30,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	—		$	436.1
First Mortgage Bonds	3.95%	2049	425.0			—
Tax-exempt First Mortgage Bonds - rates from 2.97% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.20%	2061	17.6			17.7
Unamortized deferred financing costs			(5.7		)	(6.3		)
Unamortized debt discounts and premiums, net			(2.7		)	(1.4		)
Total long-term debt			574.2			586.1
Less: current portion			(139.6		)	(4.6		)
Long-term debt, net of current portion			$	434.6		$	581.5

(a) Range of interest rates for the nine months ended September 30, 2019.

(b)

Range of interest rates for the year ended December 31, 2018.

Long-term Debt

Long-term debt is as follows:

Long-term debt
$ in millions	Interest Rate	Maturity	December 31, 2018			December 31, 2017
Term loan - rates from: 3.57% - 4.82% (a) and 4.00% - 4.60% (b)		2022	$	436.1		$	440.6
Tax-exempt First Mortgage Bonds - rates from: 2.49% - 2.93% (a) and 1.29% - 1.42% (b)		2020	140.0			200.0
U.S. Government note	4.2%	2061	17.7			17.8
Unamortized deferred financing costs			(6.3		)	(9.8		)
Unamortized debt discount			(1.4		)	(2.0		)
Total long-term debt			586.1			646.6
Less: current portion			(4.6		)	(4.6		)
Long-term debt, net of current portion			$	581.5		$	642.0

(a) Range of interest rates for the year ended December 31, 2018.

(b)

Range of interest rates for the year ended

Long-term Debt Maturities

At December 31, 2018, maturities of long-term debt are summarized as follows:

Due during the years ending December 31,
$ in millions
2019	$	4.6
2020	144.7
2021	4.7
2022	422.8
2023	0.2
Thereafter	16.8
	593.8
Unamortized discounts and premiums, net	(1.4		)
Deferred financing costs, net	(6.3		)
Total long-term debt	$	586.1

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Debt

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Debt Instrument [Line Items]

Debt

Long-term Debt

The following table summarizes DP&L's long-term debt.

	Interest		September 30,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	—		$	436.1
First Mortgage Bonds	3.95%	2049	425.0			—
Tax-exempt First Mortgage Bonds - rates from 2.97% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.20%	2061	17.6			17.7
Unamortized deferred financing costs			(5.7		)	(6.3		)
Unamortized debt discounts and premiums, net			(2.7		)	(1.4		)
Total long-term debt			574.2			586.1
Less: current portion			(139.6		)	(4.6		)
Long-term debt, net of current portion			$	434.6		$	581.5

(a) Range of interest rates for the nine months ended September 30, 2019.

(b) Range of interest rates for the year ended December 31, 2018.

Deferred financing costs are amortized over the remaining life of the debt using the effective interest method. Premiums or discounts on long-term debt are amortized over the remaining life of the debt using the effective interest method.

Line of credit

At September 30, 2019 and December 31, 2018, DP&L had outstanding borrowings on its line of credit of $60.0 million and $0.0 million, respectively.

Significant transactions

On June 19, 2019, DP&L amended and restated its unsecured revolving credit facility. The revolving credit facility has a $175.0 million borrowing limit, with a $75.0 million letter of credit sublimit, a feature that provides DP&L the ability to increase the size of the facility by an additional $100.0 million, a maturity date of June 2024, and a provision that provides DP&L the option to request up to two one-year extensions of the maturity date.

On June 6, 2019, DP&L closed on a $425.0 million issuance of First Mortgage Bonds due 2049. These new bonds carry an interest rate of 3.95%. The proceeds of this issuance were used to repay in full the outstanding principal of $435.0 million of DP&L's variable rate Term Loan B credit agreement.

On March 30, 2018, DP&L commenced a redemption of $60.0 million of outstanding tax exempt First Mortgage Bonds due 2020 at par value (plus accrued and unpaid interest). These bonds were redeemed at par plus accrued interest on April 30, 2018 with cash on hand.

Long-term debt covenants and restrictions

DP&L’s Bond Purchase and Covenants Agreement (financing document entered into in connection with the sale of $200.0 million of variable rate tax-exempt First Mortgage Bonds, dated as of August 1, 2015) has two financial covenants. The first measures Total Debt to Total Capitalization and is calculated, at the end of each fiscal quarter, by dividing total debt at the end of the quarter by total capitalization at the end of the quarter. DP&L’s Total Debt to Total Capitalization ratio shall not be greater than 0.65 to 1.00. Except that, after Generation Separation and the twelve-month period following (October 1, 2017 to September 30, 2018) the ratio shall be a) increased to 0.75 to 1.00 or b) suspended if DP&L’s long-term indebtedness is less than or equal to $750.0 million. Additionally, this covenant shall be suspended any time after separation during which DP&L maintains a rating of BBB- (or in the case of Moody’s Investors Service, Inc. Baa3) or higher with a stable outlook from at least one of Fitch Investors Service Inc., Standard & Poor’s Ratings Services or Moody’s Investors Service, Inc. The Total Debt to Capitalization covenant is calculated as the sum of DP&L’s current and long-term portion of debt, divided by the total of DP&L’s net worth and total debt. As of September 30, 2019, DP&L's ratings meet those requirements and this covenant is suspended for the quarter ended September 30, 2019.

The second financial covenant measures EBITDA to Interest Expense. The Total EBITDA to Interest Charges ratio is calculated, at the end of each fiscal quarter, by dividing EBITDA for the four prior fiscal quarters by the interest charges for the same period. The ratio, per the agreement, is to be not less than 2.50 to 1.00. This financial covenant was met with a ratio of 9.36 to 1.00 as of September 30, 2019.

DP&L's unsecured revolving credit facility has one financial covenant. The covenant measures Total Debt to Total Capitalization and is calculated, at the end of each fiscal quarter, by dividing total debt at the end of the quarter by total capitalization at the end of the quarter. DP&L’s Total Debt to Total Capitalization ratio shall not be greater than 0.67 to 1.00. This financial covenant was met with a ratio of 0.58 to 1.00 as of September 30, 2019.

As of September 30, 2019, DP&L was in compliance with all debt covenants, including the financial covenants described above.

DP&L does not have any meaningful restrictions in its debt financing documents prohibiting dividends to its parent, DPL.

Substantially all property, plant & equipment of DP&L is subject to the lien of the mortgage securing DP&L’s First and Refunding Mortgage.

Long-term debt is as follows:

Long-term debt
$ in millions	Interest Rate	Maturity	December 31, 2018			December 31, 2017
Term loan - rates from: 3.57% - 4.82% (a) and 4.00% - 4.60% (b)		2022	$	436.1		$	440.6
Tax-exempt First Mortgage Bonds - rates from: 2.49% - 2.93% (a) and 1.29% - 1.42% (b)		2020	140.0			200.0
U.S. Government note	4.2%	2061	17.7			17.8
Unamortized deferred financing costs			(6.3		)	(9.8		)
Unamortized debt discount			(1.4		)	(2.0		)
Total long-term debt			586.1			646.6
Less: current portion			(4.6		)	(4.6		)
Long-term debt, net of current portion			$	581.5		$	642.0

(a) Range of interest rates for the year ended December 31, 2018.

(b) Range of interest rates for the year ended December 31, 2017.

At December 31, 2018, maturities of long-term debt are summarized as follows:

Due during the years ending December 31,
$ in millions
2019	$	4.6
2020	144.7
2021	4.7
2022	422.8
2023	0.2
Thereafter	16.8
	593.8
Unamortized discounts and premiums, net	(1.4		)
Deferred financing costs, net	(6.3		)
Total long-term debt	$	586.1

Significant Transactions

On January 3, 2018, DP&L and its lenders amended DP&L's Term Loan B credit agreement. The amendment (a) modified the definition of "applicable rate", from 2.25% per annum to 1.00% per annum - in the case of the Base Rate, and from 3.25% per annum to 2.00% per annum - in the case of the Eurodollar Rate, and (b) included a "call protection" provision which stated that in the event the loan was repriced or any portion of the loans were prepaid, repaid, refinanced, substituted, or replaced on or prior July 3, 2018, such prepayment, acceleration, repayment, refinancing, substitution or replacement would be made at 101% of the principal amount so prepaid, repaid, refinanced, substituted or replaced. After July 3, 2018 any such transaction would occur at 100% of the principal amount of the then outstanding loans. There were no such transactions prior to July 3, 2018.

On March 30, 2018, DP&L commenced a redemption of $60.0 million of outstanding tax exempt First Mortgage Bonds due 2020 at par value (plus accrued and unpaid interest). These bonds were redeemed at par plus accrued interest on April 30, 2018 with cash on hand.

Debt Covenants and Restrictions

DP&L’s unsecured revolving credit agreement and Bond Purchase and Covenants Agreement (financing document entered into in connection with the sale of $200.0 million of variable rate tax-exempt First Mortgage Bonds, dated as of August 1, 2015) have two financial covenants. The first measures Total Debt to Total Capitalization and is calculated, at the end of each fiscal quarter, by dividing total debt at the end of the quarter by total capitalization at the end of the quarter. DP&L’s Total Debt to Total Capitalization ratio shall not be greater than 0.65 to 1.00; except that, the ratio shall be suspended if DP&L’s long-term indebtedness is less than or equal to $750.0 million. Additionally, the ratio shall be suspended any time after separation during which DP&L maintains a rating of BBB- (or in the case of Moody’s Investors Service, Inc. Baa3) or higher with a stable outlook from at least one of Fitch Investors Service Inc., Standard & Poor’s Ratings Services or Moody’s Investors Service, Inc. As of December 31, 2018, DP&L's ratings meet those requirements and this ratio is suspended for the quarter ended December 31, 2018.

The second financial covenant measures EBITDA to Interest Expense. The Total Consolidated EBITDA to Consolidated Interest Charges ratio is calculated, at the end of each fiscal quarter, by dividing consolidated EBITDA for the four prior fiscal quarters by the consolidated interest charges for the same period. The ratio, per the agreement, is to be not less than 2.50 to 1.00. This covenant was met with a ratio of 8.09 to 1.00 as of December 31, 2018.

DP&L does not have any meaningful restrictions in its debt financing documents prohibiting dividends to its parent, DPL.

As of December 31, 2018, DP&L was in compliance with all debt covenants, including the financial covenants described above.

Substantially all property, plant & equipment of DP&L is subject to the lien of the mortgage securing DP&L’s First and Refunding Mortgage. All generation assets were released from the lien of DP&L's first and refunding mortgage in connection with the completion of Generation Separation on October 1, 2017.

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Regulatory Matters (Notes)

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Subsidiaries [Member]

Schedule of Regulatory Assets and Liabilities [Text Block]

Note 3 – Regulatory Matters

DMR

On October 20, 2017, the PUCO approved DP&L’s 2017 ESP.  On January 7, 2019, the Ohio Consumers' Counsel appealed to the Supreme Court of Ohio the 2017 ESP with respect to the bypassability of the Reconciliation Rider and the exclusion of the DMR from the SEET. That proceeding has been stayed pending an appeal in a related case involving another utility.

Pursuant to the 2017 ESP, on January 22, 2019, DP&L filed a request with the PUCO for a two-year extension of its DMR through October 2022, in the proposed amount of $199.0 million for each of the two additional years. The extension request was set at a level expected to reduce debt obligations at both DP&L and DPL and to position DP&L to make capital expenditures to maintain and modernize its electric grid. DP&L’s DMP investments are contingent upon the PUCO approving the two-year extension of its DMR.

A rehearing process in DP&L's 2017 ESP case, including the DMR, remains pending. On August 1, 2019, DP&L filed a supplemental brief with the PUCO focused on the applicability of a recent court decision involving another Ohio utility’s DMR which is similar to, but not identical to, DP&L’s DMR.

Ohio House Bill 6

On July 23, 2019, the Governor of Ohio signed Ohio House Bill 6, which, among other things, does the following:

• beginning January 1, 2020, replaces DP&L’s non-bypassable Reconciliation Rider, permitting DP&L to defer, recover or credit the net proceeds from selling energy and capacity received as part of DP&L’s interest in OVEC and its OVEC-related costs through 2023, with a non-bypassable recovery mechanism for recovery of prudently incurred OVEC costs through 2030;

• eliminates the annual energy efficiency targets for Ohio utilities after 2020; and

• allows Ohio utilities to construct customer-sited renewable generation for mercantile customers or groups of mercantile customers, the costs of which may only be recovered from those customers.

Regulatory impact of tax reform

On January 10, 2018, the PUCO initiated a proceeding to consider the impacts of the TCJA to determine the appropriate course of action to pass benefits resulting from the legislation on to ratepayers. The PUCO also directed Ohio utilities to record deferred liabilities for the estimated reduction in federal income tax resulting from the TCJA beginning January 1, 2018. Beginning October 1, 2018, the new distribution rates approved in the DRO include the impacts of the decrease in current federal income taxes as a result of the TCJA. Under the terms of the stipulation approved in the DRO, DP&L agreed to file an application at the PUCO to refund eligible excess accumulated deferred income taxes and any related regulatory liability over a ten-year period. DP&L made such a filing on March 1, 2019. DP&L negotiated a unanimous stipulation with the parties in the proceeding, agreeing to return a total of $65.1 million, $83.2 million when including taxes associated with the refunds. This stipulation was approved by the PUCO on September 26, 2019. See Note 7 – Income Taxes for additional information. In connection with this stipulation, we reduced our long-term regulatory liability related to deferred income taxes by $23.4 million.

Distribution Rate Order

On September 26, 2018 the PUCO issued the DRO establishing new base distribution rates for DP&L, which became effective October 1, 2018. The DRO approved, without modification, a stipulation and recommendation previously filed by DP&L, along with various intervening parties and the PUCO staff. The DRO established a

revenue requirement of $248.0 million for DP&L's electric service base distribution rates which reflects an increase to distribution revenues of approximately $29.8 million per year. In addition to the increase in base distribution rates, and among other matters, the DRO provides for a return on equity of 9.999% and a cost of long-term debt of 4.8% and for the following items:

DIR – The DRO authorized DP&L to begin charging a Distribution Investment Rider ("DIR") set initially at $12.2 million annually, effective October 1, 2018. The DIR revenue requirement shall be updated quarterly and will increase as DP&L makes qualified investments in its distribution network, subject to annual revenue limits which increase each year; the revenue limit for 2019 is $22.0 million. The DIR will expire in November 2022 unless DP&L files a base distribution rate case on or before October 31, 2022, in which case the DIR will expire in November 2023.

Decoupling Rider – The DRO eliminated provisions in the existing decoupling rider which allowed DP&L to recover lost revenues resulting from the implementation of energy efficiency programs and replaced it with a revenue requirement that attempts to eliminate the impacts of weather and demand on DP&L’s revenues from residential and commercial distribution customers beginning January 1, 2019. As a result, in years with very mild weather and/or decreased demand, DP&L will be able to accrue a regulatory asset for recovery through the rider to normalize the revenues. Conversely, in periods of extreme temperatures or high demand for electricity, DP&L may record a liability for future reimbursement to customers. The rider also includes a one-time $3.7 million revenue requirement based on the increase in the number of DP&L’s residential and commercial customers from the rate case test year until September 30, 2018. Such amount was accrued and included in revenues in the third quarter of 2018 and will be collected by DP&L in 2019.

TCJA – The DRO partially resolved the TCJA impacts. The new distribution rates include the impacts of the decrease in current federal income taxes beginning October 1, 2018. The DRO did not designate how much DP&L may owe for any overcollection of taxes from January 1, 2018 through September 30, 2018, nor did it resolve any decrease in future rates related to amortization of excess accumulated deferred income taxes (“ADIT”). The DRO did, however, stipulate that DP&L must refund its customers an amount no less than $4.0 million per year for the first five years of the amortization period unless all balances owed are fully returned within the first five years. For more on the impacts of the TCJA, see below.

Vegetation Management Costs – The DRO authorizes DP&L to defer as a regulatory asset, with no carrying costs, annual expenses for vegetation management performed by third-party vendors. For calendar year 2018 annual expenses which are incremental to the baseline of $10.7 million can be deferred up to a $4.6 million cap. For calendar years 2019 and thereafter, annual expenses in excess of $15.7 million can be deferred up to a $4.6 million annual cap. Annual spending of less than the vegetation management baseline amounts will result in a reduction to the regulatory asset or creation of a regulatory liability. For 2018, DP&L accrued a regulatory asset for the maximum amount of $4.6 million based upon such provisions and spending above the baseline.

In December 2018, DP&L filed a Distribution Modernization Plan (“DMP”) with the PUCO proposing to invest $576.0 million in capital projects over the next 10 years. There are eight principal components of DP&L’s DMP: 1) Smart Meters, 2) Self-Healing Grid, 3) Customer Engagement, 4) Enhancing Sustainability and Embracing Innovation. 5) Telecommunications, 6) Physical and Cyber Security, 7) Governance and Analytics, and 8) Grid Modernization R&D.

ESP Order

On March 13, 2017, DP&L filed an amended stipulation to its 2017 ESP, which was subject to approval by the PUCO. A final decision was issued by the PUCO on October 20, 2017, modifying and adopting the amended stipulation and recommendation. The six-year 2017 ESP establishes DP&L's framework for providing retail service on a going-forward basis including rate structures, non-bypassable charges and other specific rate recovery true-up mechanisms which include, but are not limited to, the following:

• Bypassable standard offer energy rates for DP&L’s customers based on competitive bid auctions;

• The establishment of a three year non-bypassable Distribution Modernization Rider (DMR) designed to collect $105.0 million in revenue per year to pay debt obligations at DPL and DP&L and position DP&L to modernize and/or maintain its transmission and distribution infrastructure with an option for DP&L to file for an extension of the rider for an additional two years in an amount subject to approval by the PUCO.

Consistent with that settlement and the PUCO order, on January 22, 2019, DP&L filed a request to extend the DMR for the additional two years at an annual revenue amount of $199.0 million. That request is pending PUCO review;

• The establishment of a non-bypassable Distribution Investment Rider to recover incremental distribution capital investments, the amount of which was established in the DP&L DRO;

• A non-bypassable Reconciliation Rider permitting DP&L to defer, recover or credit the net proceeds from selling energy and capacity received as part of DP&L’s investment in OVEC and DP&L's OVEC related costs;

• Implementation by DP&L of a Smart Grid Rider, Economic Development Rider, Economic Development Fund, Regulatory Compliance Rider and certain other new, or changes to existing, rates, riders and competitive retail market enhancements, with tariffs consistent with the order. These riders became effective November 1, 2017;

• A commitment to commence a sale process to sell our ownership interests in the Miami Fort, Zimmer and Conesville coal-fired generation plants, with all sales proceeds used to pay debt of DPL and DP&L;

• Restrictions on DPL making dividend or tax sharing payments and an obligation to convert then existing tax payments owed by DPL to AES into equity investments in DPL. See ; Note 8 – Income Taxes and Note 10 – Equity for more information on the tax sharing payment restrictions; and

• Various other riders and competitive retail market enhancements.

On October 19, 2018 IGS, a retail electricity supplier, filed a Notice of Withdrawal from the amended settlement, citing a material modification by the PUCO's October 2017 order. To address the withdrawal, the PUCO established a new procedural schedule, including a hearing currently scheduled to begin April 1, 2019. Additionally, on January 7, 2019, the Ohio Consumers' Counsel appealed the 2017 ESP Order to the Supreme Court of Ohio. That appeal is pending.

DP&L is subject to a SEET threshold and is required to apply general rules for calculating earnings and comparing them to a comparable group to determine whether there were significantly excessive earnings during a given calendar year. The 2017 ESP maintains DP&L’s return on equity SEET threshold at 12% and provides that DMR amounts are excluded from the SEET calculation. On October 22, 2018, a stipulation was reached agreeing that DP&L did not exceed the SEET threshold for 2016 or 2017. That stipulation is pending PUCO approval. In future years, the SEET could have a material effect on results of operations, financial condition and cash flows.

Impact of Tax Reform

On January 10, 2018 the PUCO initiated a proceeding to consider the impacts of the TCJA to determine the appropriate course of action to pass benefits resulting from the legislation on to ratepayers. The PUCO also directed Ohio utilities to record deferred liabilities for the estimated reduction in federal income tax resulting from the TCJA beginning January 1, 2018. Under the terms of the ESP, DPL will not make tax sharing payments. Under the terms of the stipulation in the distribution rate case mentioned above, DP&L agreed to file an application at the PUCO by March 1, 2019 to refund eligible excess accumulated deferred income taxes (ADIT) and any related regulatory liability over a ten-year period. Excess ADIT related to depreciation life and method differences will be returned to customers in accordance with federal tax law and related regulations. DP&L’s rates were set using the new tax rate as a result of the distribution rate case.

FERC Proceedings

On May 8, 2018, DP&L filed to adjust its FERC jurisdictional transmission rates to reflect the effects of the decrease in federal income tax rates on the current portion of income tax expense as part of the TCJA, resulting in a decrease of approximately $2.4 million annually. The revised rates are in effect and all DP&L over and undercollections dating back to the March 21st effective date were settled in December 2018.

On November 15, 2018 FERC issued a Notice of Proposed Rulemaking to address amortization of excess accumulated deferred income taxes resulting from the TCJA and their impact on transmission rates. Such notice requires all public utility transmission providers with stated transmission rates under an Open Access Transmission Tariff (OATT) to determine the amount of excess deferred income taxes caused by the TCJA. DP&L is unable to predict the outcome of this notice or the impact it may have on our Financial Statements

PJM Transmission Enhancement Settlement

On May 31, 2018, the FERC issued an Order on Contested Settlement regarding the cost allocation method for existing and new transmission facilities contained in the PJM Interconnection’s OATT. The FERC order approved the settlement which reduces DP&L’s transmission costs through PJM beginning in August 2018, including credits

to reimburse DP&L for amounts overcharged in prior years. DP&L estimates the prior overcharge by PJM to be $41.6 million, of which approximately $14.3 million has been repaid to DP&L through December 31, 2018 and $16.5 million is classified as current in "Accounts receivable, net" and $10.8 million is classified as non-current in "Other deferred assets" on the accompanying Balance Sheet. All of the transmission charges and credits impacted by this FERC order are items that are included for full recovery in DP&L’s nonbypassable TCRR. Accordingly, DP&L has also established offsetting regulatory liabilities. While this development will have a temporary cash flow benefit to DP&L, there is no impact to operating income or net income as all credits will be passed to DP&L’s customers through the TCRR, which began in November 2018.

Regulatory Assets and Liabilities

In accordance with FASC 980, we have recognized total regulatory assets of $193.7 million and $187.1 million at December 31, 2018 and 2017, respectively, and total regulatory liabilities of $313.2 million and $236.0 million at December 31, 2018 and 2017, respectively. Regulatory assets and liabilities are classified as current or non-current based on the term in which recovery is expected. See Note 1 – Overview and Summary of Significant Accounting Policies for accounting policies regarding Regulatory Assets and Liabilities.

The following table presents DP&L’s Regulatory assets and liabilities:

	Type of Recovery	Amortization Through	December 31,
$ in millions			2018		2017
Regulatory assets, current:
Undercollections to be collected through rate riders	A/B	2019	$	40.5	$	23.9
Rate case expenses being recovered in base rates	B	2019	0.6		—
Total regulatory assets, current			41.1		23.9
Regulatory assets, non-current:
Pension benefits	B	Ongoing	87.5		92.4
Unrecovered OVEC charges	C	Undetermined	28.7		27.8
Fuel costs	B	2020	3.3		9.3
Regulatory compliance costs	B	2020	6.1		9.2
Smart grid and AMI costs	B	Undetermined	8.5		7.3
Unamortized loss on reacquired debt	B	Various	6.0		7.0
Deferred storm costs	A	Undetermined	4.7		2.1
Deferred vegetation management and other	A/B	Undetermined	7.8		8.1
Total regulatory assets, non-current			152.6		163.2
Total regulatory assets			$	193.7	$	187.1
Regulatory liabilities, current:
Overcollection of costs to be refunded through rate riders	A/B	2018	$	34.9	$	14.8
Total regulatory liabilities, current			34.9		14.8
Regulatory liabilities, non-current:
Estimated costs of removal - regulated property		Not Applicable	139.1		132.8
Deferred income taxes payable through rates		Various	116.3		83.4
PJM transmission enhancement settlement	A	2025	16.9		—
Postretirement benefits	B	Ongoing	6.0		5.0
Total regulatory liabilities, non-current			278.3		221.2
Total regulatory liabilities			$	313.2	$	236.0

A – Recovery of incurred costs plus rate of return.

B – Recovery of incurred costs without a rate of return.

C – Recovery not yet determined, but recovery is probable of occurring in future rate proceedings.

Current regulatory assets and liabilities primarily represent costs that are being recovered per specific rate order; recovery for the remaining costs is probable, but not certain. DP&L is earning a net return on $5.5 million of this net deferral. These items include undercollection of: (i) Distribution Modernization Rider revenues, (ii) decoupling rider (see above), (iii) uncollectible rider and (iv) energy efficiency rider. It also includes the current portion of the following deferred costs which are described in greater detail below: unbilled fuel, regulatory compliance rider costs and deferred storm costs. As current liabilities, this includes overcollection of: (i) competitive bidding energy and auction costs, (ii) energy efficiency program costs, (iii) alternative energy rider, (iv) economic development rider, (v) certain transmission related costs including current portion of PJM transmission enhancement settlement (see above) and (vi) reconciliation rider.

Pension benefits represent the qualifying FASC 715 “Compensation - Retirement Benefits” costs of our regulated operations that for ratemaking purposes are deferred for future recovery. We recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of OCI, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. This regulatory asset represents the regulated portion that would otherwise be charged as a loss to OCI. As per PUCO and FERC precedents, these costs are probable of future rate recovery.

Unrecovered OVEC charges includes the portion of charges from OVEC that were not recoverable through DP&L’s fuel rider from October 2014 through October 2017. DP&L expects to recover these costs through a future rate proceeding. Beginning on November 1, 2017, such costs are being recovered through DP&L’s Reconciliation Rider which was authorized as part of the 2017 ESP.

Fuel costs represent unrecovered fuel costs related to DP&L’s fuel rider from 2010 through 2015 resulting from a declining SSO customer base. DP&L was granted recovery of these costs without a return through the SSO as approved in the 2017 ESP. These costs are being recovered over the three-year period that began November 1, 2017.

Regulatory compliance rider represents the long-term portion of the regulatory compliance rider which was established by the 2017 ESP to recover the following costs: (i) Consumer Education Campaign, (ii) Retail Settlement System, (iii) Generation Separation, (iv) Bill Format Redesign, (v) Green Pricing Tariff and (vi) Supplier Consolidated Billing. All of these costs except for Generation Separation earn a return. These costs are being recovered over a three-year period.

Rate case costs represents costs associated with preparing a distribution rate case. DP&L was granted recovery of these costs which do not earn a return, as part of the DRO.

Smart Grid and AMI costs represent costs incurred as a result of studying and developing distribution system upgrades and implementation of AMI. On October 19, 2010, DP&L elected to withdraw its case pertaining to the Smart Grid and AMI programs. The PUCO accepted the withdrawal in an order issued on January 5, 2011. The PUCO also indicated that it expects DP&L to continue to monitor other utilities’ Smart Grid and AMI programs and to explore the potential benefits of investing in Smart Grid and AMI programs and that DP&L will, when appropriate, file new Smart Grid and/or AMI business cases in the future. DP&L requested recovery of these costs as part of the December 2018 DMP filing with the PUCO described earlier.

Unamortized loss on reacquired debt represents losses on long-term debt reacquired or redeemed in prior periods that have been deferred. These deferred losses are being amortized over the lives of the original issues in accordance with the rules of the FERC and the PUCO.

Deferred storm costs represent the long-term portion of deferred costs for major storms which occurred during 2017 and 2018. The 2017 ESP granted DP&L approval to establish a rider by which to seek recovery of these types of costs with a return. DP&L plans to file petitions seeking recovery of each calendar year of storm costs in the following calendar year. Recovery of these costs is probable by 2020, but not certain.

Estimated costs of removal - regulated property reflect an estimate of amounts collected in customer rates for costs that are expected to be incurred in the future to remove existing transmission and distribution property from service when the property is retired.

Deferred income taxes payable through rates represent deferred income tax liabilities recognized from the normalization of flow-through items as the result of taxes previously charged to customers. A deferred income tax asset or liability is created from a difference in income recognition between tax laws and accounting methods. As a regulated utility, DP&L includes in ratemaking the impacts of current income taxes and changes in deferred income tax liabilities or assets. On December 22, 2017, the TCJA was signed, which includes a provision to, among other things, reduce the federal corporate income tax rate to 21%, beginning January 1, 2018. As required by GAAP, on December 31, 2017, DP&L remeasured its deferred income tax assets and liabilities using the new expected tax rate. DP&L believes that the portion of the reduction in the net deferred tax liability which is related to deferred taxes considered in ratemaking will be used in future ratemaking to reduce jurisdictional retail rates. Accordingly, this liability reflects the estimated deferred taxes DP&L expects to return to customers in future periods.

Postretirement benefits represent the qualifying FASC 715 “Compensation – Retirement Benefits” gains related to our regulated operations that, for ratemaking purposes, are probable of being reflected in future rates. We recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of OCI, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. This regulatory liability represents the regulated portion that would otherwise be reflected as a gain to OCI.

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Generation Separation (Notes)

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Discontinued Operations

Dispositions

Beckjord Facility – On February 26, 2018, DP&L and its co-owners of the retired Beckjord Facility agreed to transfer their interests in the retired Facility to a third party, including their obligations to remediate the Facility and its site, and the transfer occurred on that same date. As a result, DP&L recognized a loss on the transfer of $12.4 million and made cash expenditures of $14.5 million, inclusive of cash expenditures for the transfer charges. The Beckjord Facility was retired in 2014, and, as such, the income / (loss) from continuing operations before income tax related to the Beckjord Facility was immaterial for the three and nine months ended September 30, 2018, excluding the loss on transfer noted above.

On October 1, 2017, DP&L completed the transfer of its generating plants, the real property on which the generation plants and generation-related assets are sited, step-up transformers and other transmission plant assets used to interconnect with the electric transmission grid, fuel inventory, equipment inventory and spare parts, working capital, and other miscellaneous generation-related assets and liabilities to AES Ohio Generation. The transfer was completed as a contribution through an asset contribution agreement to a wholly-owned subsidiary of DP&L after which DP&L then distributed all of the outstanding equity in the subsidiary to DPL and then the subsidiary was merged into AES Ohio Generation.

The following table summarizes the carrying amounts of DP&L's Generation assets that were transferred to AES Ohio Generation on October 1, 2017:

$ in millions	October 1, 2017
ASSETS
Restricted cash	$	2.0
Accounts receivable, net	31.3
Inventories	42.0
Taxes applicable to subsequent years	1.8
Property, plant & equipment, net	87.0
Intangible assets, net	0.7
Other assets	15.5
Total assets	$	180.3
LIABILITIES
Accounts payable	$	12.4
Accrued taxes (b)	(3.9		)
Long-term debt (a)	0.3
Deferred taxes (b)	(91.9		)
Pension, retiree and other benefits	9.6
Unamortized investment tax credit	15.1
Asset retirement obligations	126.3
Other liabilities	24.1
Total liabilities	$	92.0
Total accumulated other comprehensive income	2.1
Net assets transferred to AES Ohio Generation	$	86.2

(a) Long-term debt that transferred to AES Ohio Generation relates to capital leases.

(b) Accrued taxes and deferred taxes transferred to AES Ohio Generation represent the tax asset position netted with liabilities on DP&L prior to Generation Separation.

DP&L's generation business met the criteria to be classified as a discontinued operation, and, accordingly, the historical activity has been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016.

The following table summarizes the revenues, cost of revenues, operating and other expenses and income tax of discontinued operations for the periods indicated:

	Years ended December 31,
$ in millions	2017			2016
Revenues	$	358.4		$	557.9
Cost of revenues	(191.6		)	(341.1		)
Operating and other expenses	(156.8		)	(202.0		)
Fixed-asset impairment	(66.3		)	(1,353.5		)
Loss from discontinued operations	(56.3		)	(1,338.7		)
Income tax benefit from discontinued operations	(15.9		)	(468.4		)
Net loss from discontinued operations	$	(40.4	)	$	(870.3	)

In 2018, DP&L transferred additional deferred taxes to AES Ohio Generation under the provisions of SAB 118 through an equity transaction with DPL in the amount of $10.0 million. See Note 8 – Income Taxes for additional information.

Cash flows related to discontinued operations are included in the Statements of Cash Flows. Cash flows from operating activities for discontinued operations were $21.8 million and $29.9 million for the years ended December 31, 2017 and 2016, respectively. Cash flows from investing activities for discontinued operations were $(3.5) million and $(39.0) million for the years ended December 31, 2017 and 2016, respectively.

The PUCO authorized DP&L to maintain long-term debt of $750 million or 75% of its rate base, whichever is greater, until January 1, 2018, or to file an application to explain why it would not achieve those metrics. Accordingly, $750.0 million of debt and the pro rata interest expense associated with that debt were allocated to continuing operations. All remaining interest expense is included in discontinued operations above. The interest expense included in discontinued operations was $0.2 million and $0.5 million for the years ended December 31, 2017 and 2016, respectively.

Beckjord Facility – On February 26, 2018, DP&L and its co-owners of the retired Beckjord Facility agreed to transfer their interests in the retired Facility to a third party, including their obligations to remediate the Facility and its site, and the transfer occurred on that same date. As a result, DP&L recognized a loss on the transfer of $12.4 million and made cash expenditures of $14.5 million, inclusive of cash expenditures for the transfer charges. The Beckjord Facility was retired in 2014, and, as such, the income / (loss) from continuing operations before income tax related to the Beckjord Facility was immaterial for the years ended December 31, 2018, 2017 and 2016, excluding the loss on transfer noted above.

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Contractual Obligations, Commercial Commitments and Contingencies

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Contractual Obligations, Commercial Commitments and Contingencies

Note 10 – Contractual Obligations, Commercial Commitments and Contingencies

Equity Ownership Interest

DP&L has a 4.9% equity ownership interest in OVEC, which is recorded using the cost method of accounting under GAAP. DP&L, along with several non-affiliated energy companies party to an OVEC arrangement, receive and pay for OVEC capacity and energy and are responsible for OVEC debt obligations and other fixed costs in proportion to their power participation ratios under the arrangement which, for DP&L, is the same as its equity ownership interest. At September 30, 2019, DP&L could be responsible for the repayment of 4.9%, or $67.2 million, of $1,371.3 million OVEC debt obligations if they came due, comprised of both fixed and variable rate securities with maturities from 2022 to 2040. OVEC could also seek additional contributions from DP&L to avoid a default in the event that other OVEC members defaulted on their respective OVEC obligations. One of the other OVEC members, with a 4.85% interest in OVEC, filed for bankruptcy protection and the bankruptcy court approved that member's rejection of the OVEC arrangement and its related obligations on July 31, 2018. We do not expect these events to have a material impact on our financial condition, results of operations or cash flows.

Contingencies

In the normal course of business, we are subject to various lawsuits, actions, proceedings, claims and other matters asserted under various laws and regulations. We believe the amounts provided in our Condensed Financial Statements, as prescribed by GAAP, are adequate considering the probable and estimable contingencies. However, there can be no assurances that the actual amounts required to satisfy alleged liabilities from various legal proceedings, claims, tax examinations and other matters discussed below, and to comply with applicable laws and regulations, will not exceed the amounts reflected in our Condensed Financial Statements. As such, costs, if any, that may be incurred in excess of those amounts provided as of September 30, 2019, cannot be reasonably determined.

Environmental Matters

DP&L’s facilities and operations are subject to a wide range of federal, state and local environmental regulations and laws. The environmental issues that may affect us include:

• The federal CAA and state laws and regulations (including State Implementation Plans) which require compliance, obtaining permits and reporting as to air emissions;

• Litigation with federal and certain state governments and certain special interest groups;

• Rules and future rules issued by the USEPA, the Ohio EPA or other authorities associated with the federal Clean Water Act, which prohibits the discharge of pollutants into waters of the United States except pursuant to appropriate permits; and

• Solid and hazardous waste laws and regulations, which govern the management and disposal of certain waste.

In addition to imposing continuing compliance obligations, these laws and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. In the normal course of business, we have investigatory and remedial activities underway at our facilities to comply, or to determine compliance, with such regulations. We record liabilities for loss contingencies related to environmental matters when a loss is probable of occurring and can be reasonably estimated in accordance with the provisions of GAAP. Accordingly, we have immaterial accruals for loss contingencies for environmental matters. We also have several environmental matters for which we have not accrued loss contingencies because the risk of loss is not probable, or a loss cannot be reasonably estimated. We evaluate the potential liability related to environmental matters quarterly and may revise our estimates. Such revisions in the estimates of the potential liabilities could have a material adverse effect on our results of operations, financial condition and cash flows.

DP&L – Equity Ownership Interest

DP&L has a 4.9% equity ownership interest in OVEC which is recorded using the cost method of accounting under GAAP. At December 31, 2018, DP&L could be responsible for the repayment of 4.9%, or $68.1 million, of a $1,389.6 million debt obligation comprised of both fixed and variable rate securities with maturities between 2019 and 2040. OVEC could also seek additional contributions from us to avoid a default in the event that other OVEC members defaulted on their respective OVEC obligations. One of the other OVEC members, with a 4.85% interest in OVEC, filed for bankruptcy protection and the bankruptcy court approved that member's rejection of the OVEC arrangement and its related obligations on July 31, 2018. We do not expect these events to have a material impact on our financial condition, results of operations or cash flows.

Contractual Obligations and Commercial Commitments

We enter into various contractual obligations and other commercial commitments that may affect the liquidity of our operations. At December 31, 2018, these include:

	Payments due in:
$ in millions	Total		Less than 1 year		2 - 3 years		4 - 5 years		More than 5 years
Electricity purchase commitments	$	209.4	$	139.5	$	69.9	$	—	$	—
Purchase orders and other contractual obligations	$	39.8	$	11.3	$	14.7	$	13.8	$	—

Electricity purchase commitments:

DP&L enters into long-term contracts for the purchase of electricity. In general, these contracts are subject to variable quantities or prices and are terminable only in limited circumstances.

Purchase orders and other contractual obligations:

At December 31, 2018, DP&L had various other contractual obligations including non-cancelable contracts to purchase goods and services with various terms and expiration dates. Due to uncertainty regarding the timing and payment of future obligations to the Service Company, and DP&L's ability to terminate such obligations upon 90 days' notice, we have excluded such amounts in the contractual obligations table above

Contingencies

In the normal course of business, we are subject to various lawsuits, actions, proceedings, claims and other matters asserted under laws and regulations. We believe the amounts provided in our Financial Statements, as prescribed by GAAP, are adequate in light of the probable and estimable contingencies. However, there can be no assurances that the actual amounts required to satisfy alleged liabilities from various legal proceedings, claims, tax examinations, and other matters, including the matters discussed below, and to comply with applicable laws and regulations, will not exceed the amounts reflected in our Financial Statements. As such, costs, if any, that may be incurred in excess of those amounts provided as of December 31, 2018, cannot be reasonably determined.

Environmental Matters

DP&L's facilities and operations are subject to a wide range of federal, state and local environmental laws, rules and regulations. The environmental issues that may affect us include the following. However, as described further below, as a result of DPL’s retirement of its Stuart and Killen generating stations, the sale of its ownership interest in the Miami Fort and Zimmer generating stations, the planned 2020 retirement of Conesville and our exiting of our generation business, certain of these environmental regulations and laws are now not expected to have a material impact on DPL with respect to these generating stations.

• The federal CAA and state laws and regulations (including SIPs) which require compliance, obtaining permits and reporting as to air emissions;

• Rules and future rules issued by the USEPA, the Ohio EPA or other authorities that require or will require reporting and reductions of GHGs;

• Rules and future rules issued by the USEPA, the Ohio EPA or other authorities associated with the federal Clean Water Act, which prohibits the discharge of pollutants into waters of the United States except pursuant to appropriate permits; and

• Solid and hazardous waste laws and regulations, which govern the management and disposal of certain waste.

In addition to imposing continuing compliance obligations, these laws, rules and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. In the normal course of business, we have investigatory and remedial activities underway at our facilities to comply, or to determine compliance, with such laws, rules and regulations. We record liabilities for loss contingencies related to environmental matters when a loss is probable of occurring and can be reasonably estimated in accordance with the provisions of GAAP. Accordingly, we have immaterial accruals for loss contingencies for environmental matters. We also have a number of environmental matters for which we have not accrued loss contingencies because the risk of loss is not probable, or a loss cannot be reasonably estimated. We evaluate the potential liability related to environmental matters quarterly and may revise our estimates. Such revisions in the estimates of the potential liabilities could have a material adverse effect on our results of operations, financial condition or cash flows.

We have several pending environmental matters associated with our current and previously owned and operated coal-fired generation units. Some of these matters could have material adverse impacts on our results of operations, financial condition or cash flows.

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Generation Separation (Policies)

12 Months Ended

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Discontinued Operations, Policy [Policy Text Block]

Transactions between the businesses determined to be discontinued operations and businesses that are expected to continue to exist after the disposal are not eliminated to appropriately reflect the continuing operations and balances held-for-sale. The results of discontinued operations include any gain or loss recognized on closing or adjustment of the carrying amount to fair value. See Note 14 – Generation Separation for further information.

Generation Separation

With the transfer of DP&L's generation assets to an affiliate (see Note 14 – Generation Separation), DP&L's generation business is presented as a discontinued operation and the operating activities have been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016 and in the notes to the financial statements.

The PUCO authorized DP&L to maintain long-term debt of $750 million or 75% of its rate base, whichever is greater, until January 1, 2018, or to file an application to explain why it would not achieve those metrics. Accordingly, $750.0 million of debt and the pro rata interest expense associated with that debt were allocated to continuing operations. All remaining interest expense is included in discontinued operations above. The interest expense included in discontinued operations was $0.2 million and $0.5 million for the years ended December 31, 2017 and 2016, respectively.

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Consolidated Statements of Comprehensive Income/(Loss) (Parenthetical) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income tax (expense)/benefit on unrealized gains (losses) related to available-for-sale securities	$ 0.0	$ 0.0	$ 0.0	$ 0.0	$ 0.0	$ (0.2)	$ (0.1)
Other Comprehensive Income (Loss), Reclassification Adjustment for Sale of Securities Included in Net Income, Tax	0.0	0.0	0.0	0.0	0.0	0.0	0.0
AOCI reclassed to Retained Earnings, income tax	0.0	0.0	0.0	0.0
Income tax (expense)/benefit on unrealized gains (losses) related to derivative activity	0.0	0.1	(0.2)	0.1	0.1	(7.2)	(8.7)
Income tax (expense)/benefit on reclassification of earnings related to derivative activity	0.0	0.1	0.0	0.6	0.4	0.2	0.2
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives Related to Discontinued Operations, Tax	0.0	0.0	0.0	0.0	0.0	3.0	16.2
Income tax (expense)/benefit on prior service cost related to pension and postretirement activity	0.0	0.0	0.0	0.0	0.6	1.0	0.0
Income tax (expense)/benefit on net loss related to pension and postretirement activity	0.0	0.0	0.0	0.0	(0.4)	0.4	1.1
Income tax (expense)/benefit on reclassification of earnings related to pension and postretirement activity					$ (1.0)	$ (2.3)	$ (1.8)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax	$ 0.9	$ (0.2)	$ (0.5)	$ (0.7)

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Consolidated Statements of Shareholders' Equity - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	Total	Common Stock [Member]	Other Paid-In Capital [Member]	Reclassification out of Accumulated Other Comprehensive Income [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Retained Earnings [Member]	Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]	Generation [Member]
Other Comprehensive Income (Loss), Net of Tax	$ (13.8)
Balance at Dec. 31, 2015	1,212.7	$ 0.4	$ 803.7		$ (28.7)	$ 437.3
Balance (in shares) at Dec. 31, 2015		41,172,173
Net comprehensive income/ (loss)	(786.5)
Net loss	(772.7)
Common stock dividends	(70.0)					(70.0)
Proceeds from Contributions from Parent	0.0
Preferred stock dividends	(0.7)					(0.7)
Other	6.8		7.0			(0.2)
Balance at Dec. 31, 2016	362.3	$ 0.4	810.7		(42.5)	(406.3)
Balance (in shares) at Dec. 31, 2016		41,172,173
Disposal Group, Including Discontinued Operation, Net Assets								$ 0.0
Other Comprehensive Income (Loss), Net of Tax	8.4						$ 6.2
Net comprehensive income/ (loss)	25.4
Net loss	17.0
Common stock dividends	39.0		(39.0)
Stockholders' Equity Note, Spinoff Transaction	2.1						(2.1)
Proceeds from Contributions from Parent	70.0		(70.0)
Preferred stock dividends	(88.3)
Other	0.3		(69.7)			70.0
Balance at Dec. 31, 2017	330.7	$ 0.4	685.8		(36.2)	(319.3)
Balance (in shares) at Dec. 31, 2017		41,172,173
Other Comprehensive Income (Loss), Net of Tax					1.1
Net comprehensive income/ (loss)	16.8
Net loss						15.7
Common stock dividends	(23.8)		(23.8)
Proceeds from Contributions from Parent	80.0		(80.0)
Other	(0.4)		(0.3)		(1.1)	1.0
Balance at Mar. 31, 2018	403.3	$ 0.4	741.7		(36.2)	(302.6)
Balance (in shares) at Mar. 31, 2018		41,172,173
Other Comprehensive Income (Loss), Net of Tax	2.5
Balance at Dec. 31, 2017	330.7	$ 0.4	685.8		(36.2)	(319.3)
Balance (in shares) at Dec. 31, 2017		41,172,173
Net comprehensive income/ (loss)	64.4
Proceeds from Contributions from Parent	80.0
Balance at Sep. 30, 2018	431.0	$ 0.4	721.8		(34.8)	(256.4)
Balance (in shares) at Sep. 30, 2018		41,172,173
AOCI reclassed to Retained Earnings before tax | Adjustments for New Accounting Pronouncement [Member]	1.7
AOCI reclassed to Retained Earnings, net of tax | Adjustments for New Accounting Pronouncement [Member]	1.1
Other Comprehensive Income (Loss), Net of Tax	2.0						(0.8)
Balance at Dec. 31, 2017	330.7	$ 0.4	685.8		(36.2)	(319.3)
Balance (in shares) at Dec. 31, 2017		41,172,173
Net comprehensive income/ (loss)	88.7
Net loss	86.7
Common stock dividends	(43.8)		(43.8)
Proceeds from Contributions from Parent	80.0		(80.0)
Preferred stock dividends	(10.0)
Other	(0.3)		(0.2)	$ (1.1)		1.0
Balance at Dec. 31, 2018	445.3	$ 0.4	711.8		(35.3)	(231.6)
Balance (in shares) at Dec. 31, 2018		41,172,173
AOCI reclassed to Retained Earnings before tax | Adjustments for New Accounting Pronouncement [Member]	1.7
AOCI reclassed to Retained Earnings, net of tax	(1.1)						0.0
AOCI reclassed to Retained Earnings, net of tax | Adjustments for New Accounting Pronouncement [Member]	1.1
Other Comprehensive Income (Loss), Net of Tax	0.8
Balance at Mar. 31, 2018	403.3	$ 0.4	741.7		(36.2)	(302.6)
Balance (in shares) at Mar. 31, 2018		41,172,173
Net comprehensive income/ (loss)	15.8
Net loss	15.0
Balance at Jun. 30, 2018	419.1	$ 0.4	741.7		(35.4)	(287.6)
Balance (in shares) at Jun. 30, 2018		41,172,173
Other Comprehensive Income (Loss), Net of Tax	0.6
Net comprehensive income/ (loss)	31.8
Net loss	31.2
Common stock dividends	(20.0)		(20.0)
Other	0.1		0.1
Balance at Sep. 30, 2018	431.0	$ 0.4	721.8		(34.8)	(256.4)
Balance (in shares) at Sep. 30, 2018		41,172,173
Disposal Group, Including Discontinued Operation, Net Assets								$ (10.0)
Other Comprehensive Income (Loss), Net of Tax					0.4
Balance at Dec. 31, 2018	445.3	$ 0.4	711.8		(35.3)	(231.6)
Balance (in shares) at Dec. 31, 2018		41,172,173
Net comprehensive income/ (loss)	29.4
Net loss						29.0
Other	(0.3)					(0.3)
Balance at Mar. 31, 2019	474.4	$ 0.4	711.8		(34.9)	(202.9)
Balance (in shares) at Mar. 31, 2019		41,172,173
Other Comprehensive Income (Loss), Net of Tax	1.1						$ (1.0)
Balance at Dec. 31, 2018	445.3	$ 0.4	711.8		(35.3)	(231.6)
Balance (in shares) at Dec. 31, 2018		41,172,173
Net comprehensive income/ (loss)	104.8
Proceeds from Contributions from Parent	0.0
Balance at Sep. 30, 2019	459.8	$ 0.4	621.9		(34.2)	(128.3)
Balance (in shares) at Sep. 30, 2019		41,172,173
Other Comprehensive Income (Loss), Net of Tax					(0.9)
Balance at Mar. 31, 2019	474.4	$ 0.4	711.8		(34.9)	(202.9)
Balance (in shares) at Mar. 31, 2019		41,172,173
Net comprehensive income/ (loss)	28.9
Net loss						29.8
Proceeds from Contributions from Parent	(70.0)		70.0
Balance at Jun. 30, 2019	433.3	$ 0.4	641.8		(35.8)	(173.1)
Balance (in shares) at Jun. 30, 2019		41,172,173
Other Comprehensive Income (Loss), Net of Tax	1.6
Net comprehensive income/ (loss)	46.5
Net loss	44.9
Common stock dividends	(20.0)		(20.0)
Other	0.0		(0.1)			0.1
Balance at Sep. 30, 2019	$ 459.8	$ 0.4	$ 621.9		$ (34.2)	$ (128.3)
Balance (in shares) at Sep. 30, 2019		41,172,173

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Income Taxes (Components of Deferred Tax Assets and Liabilities) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Taxes [Line Items]
Depreciation / property basis			$ (130.6)	$ (126.5)
Income taxes recoverable			25.0	11.0
Deferred Tax Liabilities, Regulatory Assets and Liabilities			(16.2)	(23.9)
Investment tax credit			0.5	0.4
Compensation and employee benefits			0.3	17.6
Other			(10.7)	(9.6)
Net non-current liabilities	$ (132.5)		$ (131.7)	$ (131.0)
Estimated Annual Effective Income Tax Rate, Continuing Operations	4.50%	17.10%	21.00%	35.00%
Increase (Decrease) in Income Taxes				$ (0.7)	$ 0.4

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Debt (Long-term Debt) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017	Oct. 01, 2017
THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months		$ 4.6
Debt Issuance Costs, Net	$ 5.7	6.3
Unamortized Deferred Financing Costs			$ (9.8)
Debt Instrument, Unamortized Discount	(2.7)	(1.4)	(2.0)
Long-term Debt	574.2	586.1
Less: current portion	(139.6)	(4.6)	(4.6)
Long-term debt, net of current portion	434.6	581.5	642.0
Long-term Debt, Maturities, Repayments of Principal in Year Two		144.7
Long-term Debt, Maturities, Repayments of Principal in Year Three		4.7
Long-term Debt, Maturities, Repayments of Principal in Year Four		422.8
Long-term Debt, Maturities, Repayments of Principal in Year Five		0.2
Long-term Debt, Maturities, Repayments of Principal after Year Five		16.8
Total Maturities Before Unamortized Adjustments		593.8
Unamortized Deferred Financing Costs, Consolidated		(6.3)
Long Term Debt Maturities Repayments Of Principal, Total		586.1
Term Loan Maturing 2022 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	0.0	436.1
Term Loan Maturing 2022 (DPL) [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		436.1	440.6
Tax-exempt First Mortgage Bonds - rates from: 2.49% - 2.93% (a) and 1.29% - 1.42% (b) | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 140.0	140.0	200.0
U.S. Government note maturing in 2061 - 4.20% [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage	4.20%
U.S. Government note maturing in 2061 - 4.20% [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 17.6	$ 17.7	17.8
Debt instrument interest percentage		4.20%
3.95% Senior Notes due 2049 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 425.0
Debt instrument interest percentage	3.95%
Variable Rate Notes Backed by Term Loan and First Mortgage Bonds [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 140.0	$ 140.0
Minimum [Member] | Term Loan Maturing 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Effective Percentage Rate Range, Minimum (Deprecated 2016-01-31)	4.50%
Debt instrument interest percentage		4.01%
Minimum [Member] | Pollution control series Maturing in 2040 - rates from: 0.02% - 0.12% and 0.04% - 0.15%
Debt Instrument [Line Items]
Debt instrument interest percentage	2.97%
Minimum [Member] | Variable Rate Notes Backed by Term Loan and First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage		1.52%
Maximum [Member] | Term Loan Maturing 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Effective Percentage Rate Range, Minimum (Deprecated 2016-01-31)		4.60%
Debt instrument interest percentage	4.53%
Maximum [Member] | Pollution control series Maturing in 2040 - rates from: 0.02% - 0.12% and 0.04% - 0.15%
Debt Instrument [Line Items]
Debt instrument interest percentage	3.07%
Maximum [Member] | Variable Rate Notes Backed by Term Loan and First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage		1.92%
Debt [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities		$ 586.1	$ 646.6
Generation [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Disposal Group, Including Discontinued Operations, Long-Term Debt				$ (0.3)

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Property, Plant and Equipment (Narrative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Jointly Owned Utility Plant Interests [Line Items]
Proceeds from Sale of Property, Plant, and Equipment	$ 0.0	$ 10.6	$ 10.6	$ 0.0	$ 0.2
Fixed-asset impairment (Note 14)			0.0	66.3	1,353.5
Estimated costs of removal			$ 139.1	$ 132.8	$ 126.5

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Generation Separation (Tables)

12 Months Ended

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Summary of Balance Sheet and Profit and Loss Information for Discontinued Operations

The following table summarizes the carrying amounts of DP&L's Generation assets that were transferred to AES Ohio Generation on October 1, 2017:

$ in millions	October 1, 2017
ASSETS
Restricted cash	$	2.0
Accounts receivable, net	31.3
Inventories	42.0
Taxes applicable to subsequent years	1.8
Property, plant & equipment, net	87.0
Intangible assets, net	0.7
Other assets	15.5
Total assets	$	180.3
LIABILITIES
Accounts payable	$	12.4
Accrued taxes (b)	(3.9		)
Long-term debt (a)	0.3
Deferred taxes (b)	(91.9		)
Pension, retiree and other benefits	9.6
Unamortized investment tax credit	15.1
Asset retirement obligations	126.3
Other liabilities	24.1
Total liabilities	$	92.0
Total accumulated other comprehensive income	2.1
Net assets transferred to AES Ohio Generation	$	86.2

(a) Long-term debt that transferred to AES Ohio Generation relates to capital leases.

(b) Accrued taxes and deferred taxes transferred to AES Ohio Generation represent the tax asset position netted with liabilities on DP&L prior to Generation Separation.

DP&L's generation business met the criteria to be classified as a discontinued operation, and, accordingly, the historical activity has been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016.

The following table summarizes the revenues, cost of revenues, operating and other expenses and income tax of discontinued operations for the periods indicated:

	Years ended December 31,
$ in millions	2017			2016
Revenues	$	358.4		$	557.9
Cost of revenues	(191.6		)	(341.1		)
Operating and other expenses	(156.8		)	(202.0		)
Fixed-asset impairment	(66.3		)	(1,353.5		)
Loss from discontinued operations	(56.3		)	(1,338.7		)
Income tax benefit from discontinued operations	(15.9		)	(468.4		)
Net loss from discontinued operations	$	(40.4	)	$	(870.3	)

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Supplemental Financial Information (Reclassification out of ACOI) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other deductions	$ (6.6)	$ (6.2)	$ (19.8)	$ (23.0)	$ (30.7)	$ (33.6)	$ (25.4)
Operating Expenses					299.9	307.6	317.0
Interest expense	(6.1)	(5.8)	(19.9)	(20.5)	(27.3)	(30.5)	(24.7)
Tax expense (benefit)	7.2	(6.3)	(5.1)	(12.0)	(17.7)	(31.1)	(46.0)
Income / (loss) from discontinued operations before income tax					0.0	(56.3)	(1,338.7)
Income tax expense from discontinued operations					0.0	15.9	468.4
Net income (loss)	44.9	31.2	103.7	61.9	86.7	17.0	(772.7)
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Net income (loss)	1.7	0.6	2.0	2.0	2.6	(1.8)	(24.1)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other deductions					0.0	(0.1)	0.0
Tax expense (benefit)					0.0	0.0	0.0
Net income (loss)					0.0	(0.1)	0.0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Interest expense	0.0	(0.3)	(0.1)	(1.1)	(1.1)	(0.9)	(1.0)
Tax expense (benefit)	0.0	0.1	0.0	0.6	0.4	0.2	0.2
Income / (loss) from discontinued operations before income tax					0.0	(8.5)	(45.4)
Income tax expense from discontinued operations					0.0	3.0	16.2
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax					0.0	(5.5)	(29.2)
Net income (loss)	0.0	(0.2)	(0.1)	(0.5)	(0.7)	(0.7)	(0.8)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other deductions	0.8	1.0	2.6	3.2	4.3	6.8	7.7
Tax expense (benefit)	0.9	(0.2)	(0.5)	(0.7)	(1.0)	(2.3)	(1.8)
Net income (loss)	$ 1.7	$ 0.8	$ 2.1	$ 2.5	$ 3.3	$ 4.5	$ 5.9

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Overview and Summary of Significant Accounting Policies Overview and Summary of Significant Accounting Polices (Tables)

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Schedule of Cash and Cash Equivalents [Table Text Block]

Cash, Cash Equivalents, and Restricted Cash

The following table provides a summary of cash, cash equivalents, and restricted cash amounts reported on the Condensed Balance Sheet that reconcile to the total of such amounts as shown on the Condensed Statements of Cash Flows:

$ in millions	September 30, 2019		December 31, 2018
Cash and cash equivalents	$	14.4	$	45.0
Restricted cash	17.6		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	32.0	$	66.2

Balance Sheet that reconcile to the total of such amounts as shown on the Statements of Cash Flows:

$ in millions	December 31, 2018		December 31, 2017
Cash and cash equivalents	$	45.0	$	5.2
Restricted cash	21.2		0.4
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	66.2	$	5.6

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Assets and Liabilities Held-For-Sale and Dispositions (Notes)

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Discontinued Operations

Dispositions

Beckjord Facility – On February 26, 2018, DP&L and its co-owners of the retired Beckjord Facility agreed to transfer their interests in the retired Facility to a third party, including their obligations to remediate the Facility and its site, and the transfer occurred on that same date. As a result, DP&L recognized a loss on the transfer of $12.4 million and made cash expenditures of $14.5 million, inclusive of cash expenditures for the transfer charges. The Beckjord Facility was retired in 2014, and, as such, the income / (loss) from continuing operations before income tax related to the Beckjord Facility was immaterial for the three and nine months ended September 30, 2018, excluding the loss on transfer noted above.

On October 1, 2017, DP&L completed the transfer of its generating plants, the real property on which the generation plants and generation-related assets are sited, step-up transformers and other transmission plant assets used to interconnect with the electric transmission grid, fuel inventory, equipment inventory and spare parts, working capital, and other miscellaneous generation-related assets and liabilities to AES Ohio Generation. The transfer was completed as a contribution through an asset contribution agreement to a wholly-owned subsidiary of DP&L after which DP&L then distributed all of the outstanding equity in the subsidiary to DPL and then the subsidiary was merged into AES Ohio Generation.

The following table summarizes the carrying amounts of DP&L's Generation assets that were transferred to AES Ohio Generation on October 1, 2017:

$ in millions	October 1, 2017
ASSETS
Restricted cash	$	2.0
Accounts receivable, net	31.3
Inventories	42.0
Taxes applicable to subsequent years	1.8
Property, plant & equipment, net	87.0
Intangible assets, net	0.7
Other assets	15.5
Total assets	$	180.3
LIABILITIES
Accounts payable	$	12.4
Accrued taxes (b)	(3.9		)
Long-term debt (a)	0.3
Deferred taxes (b)	(91.9		)
Pension, retiree and other benefits	9.6
Unamortized investment tax credit	15.1
Asset retirement obligations	126.3
Other liabilities	24.1
Total liabilities	$	92.0
Total accumulated other comprehensive income	2.1
Net assets transferred to AES Ohio Generation	$	86.2

(a) Long-term debt that transferred to AES Ohio Generation relates to capital leases.

(b) Accrued taxes and deferred taxes transferred to AES Ohio Generation represent the tax asset position netted with liabilities on DP&L prior to Generation Separation.

DP&L's generation business met the criteria to be classified as a discontinued operation, and, accordingly, the historical activity has been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016.

The following table summarizes the revenues, cost of revenues, operating and other expenses and income tax of discontinued operations for the periods indicated:

	Years ended December 31,
$ in millions	2017			2016
Revenues	$	358.4		$	557.9
Cost of revenues	(191.6		)	(341.1		)
Operating and other expenses	(156.8		)	(202.0		)
Fixed-asset impairment	(66.3		)	(1,353.5		)
Loss from discontinued operations	(56.3		)	(1,338.7		)
Income tax benefit from discontinued operations	(15.9		)	(468.4		)
Net loss from discontinued operations	$	(40.4	)	$	(870.3	)

In 2018, DP&L transferred additional deferred taxes to AES Ohio Generation under the provisions of SAB 118 through an equity transaction with DPL in the amount of $10.0 million. See Note 8 – Income Taxes for additional information.

Cash flows related to discontinued operations are included in the Statements of Cash Flows. Cash flows from operating activities for discontinued operations were $21.8 million and $29.9 million for the years ended December 31, 2017 and 2016, respectively. Cash flows from investing activities for discontinued operations were $(3.5) million and $(39.0) million for the years ended December 31, 2017 and 2016, respectively.

The PUCO authorized DP&L to maintain long-term debt of $750 million or 75% of its rate base, whichever is greater, until January 1, 2018, or to file an application to explain why it would not achieve those metrics. Accordingly, $750.0 million of debt and the pro rata interest expense associated with that debt were allocated to continuing operations. All remaining interest expense is included in discontinued operations above. The interest expense included in discontinued operations was $0.2 million and $0.5 million for the years ended December 31, 2017 and 2016, respectively.

Beckjord Facility – On February 26, 2018, DP&L and its co-owners of the retired Beckjord Facility agreed to transfer their interests in the retired Facility to a third party, including their obligations to remediate the Facility and its site, and the transfer occurred on that same date. As a result, DP&L recognized a loss on the transfer of $12.4 million and made cash expenditures of $14.5 million, inclusive of cash expenditures for the transfer charges. The Beckjord Facility was retired in 2014, and, as such, the income / (loss) from continuing operations before income tax related to the Beckjord Facility was immaterial for the years ended December 31, 2018, 2017 and 2016, excluding the loss on transfer noted above.

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Related Party Transactions

12 Months Ended

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Related Party Transactions

Service Company

The Service Company allocates the costs for services provided based on cost drivers designed to result in fair and equitable allocations. This includes ensuring that the regulated utilities served, including DP&L, are not subsidizing costs incurred for the benefit of other businesses.

Benefit Plans

DPL participates in an agreement with Health and Welfare Benefit Plans LLC, an affiliate of AES, to participate in a group benefits program, including but not limited to, health, dental, vision and life benefits. Health and Welfare Benefit Plans LLC administers the financial aspects of the group insurance program, receives all premium payments from the participating affiliates, and makes all vendor payments.

Long-term Compensation Plan

During 2018, 2017 and 2016, many of DP&L’s non-union employees received benefits under the AES Long-term Compensation Plan, a deferred compensation program. This type of plan is a common employee retention tool used in our industry. Benefits under this plan are granted in the form of performance units payable in cash and AES restricted stock units. Restricted stock units vest ratably over a three-year period. The performance units payable in cash vest at the end of the three-year performance period and are subject to certain AES performance criteria. Total deferred compensation expense recorded during 2018, 2017 and 2016 was $0.3 million, $0.4 million and $0.5 million, respectively, and was included in “Other Operating Expenses” on DP&L’s Statements of Operations. The value of these benefits is being recognized over the 36-month vesting period and a portion is recorded as miscellaneous deferred credits with the remainder recorded as “Paid in capital” on DP&L’s Balance Sheets in accordance with FASC 718 “Compensation - Stock Compensation.”

The following table provides a summary of our related party transactions:

	Years ended December 31,
$ in millions	2018			2017			2016
DP&L Cost of revenues:
Fuel and power purchased from AES Ohio Generation	$	—		$	5.4		$	8.7
DP&L Operation & Maintenance Expenses:
Premiums charged for insurance services provided by MVIC (a)	$	2.7		$	3.1		$	3.4
Transactions with the Service Company:
Charges for services provided	$	25.7		$	39.0		$	38.7
Charges to the Service Company	$	4.9		$	4.2		$	4.5
Transactions with other AES affiliates:
Charges for health, welfare and benefit plans	$	8.7		$	14.3		$	9.4
Charges to affiliates for non-power goods or services (b)	$	7.1		$	3.7		$	5.7
Consulting services	$	2.0		$	—		$	—
Balances with related parties:	At December 31, 2018			At December 31, 2017
Net payable to the Service Company	$	(4.8	)	$	(3.9	)
Net receivable from / (payable) to other AES affiliates	$	(0.5	)	$	4.8

(a) MVIC, a wholly-owned captive insurance subsidiary of DPL, provides insurance coverage to DP&L and other DPL subsidiaries for workers’ compensation, general liability, property damages and directors’ and officers’ liability. These amounts represent insurance premiums charged by MVIC to DP&L.

(b) In the normal course of business DP&L incurred and recorded expenses on behalf of DPL affiliates. Such expenses included but were not limited to employee-related expenses, accounting, information technology, payroll, legal and other administration expenses. DP&L subsequently charged these expenses to the affiliates at DP&L’s cost and credited the expense in which they were initially recorded.

Income Taxes

AES files federal and state income tax returns which consolidate DPL and its subsidiaries, including DP&L. Under a tax sharing agreement with DPL, DP&L is responsible for the income taxes associated with its own taxable income and records the provision for income taxes using a separate return method. Under this agreement, DP&L had a net receivable balance of $19.6 million and $6.5 million at December 31, 2018 and 2017, respectively, which is

recorded in Taxes receivable on the accompanying Balance Sheets. During 2018, 2017 and 2016, DP&L made net payments of $14.6 million, $28.1 million and $0.0 million respectively, to DPL for its share of income taxes.

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Consolidated Statements of Shareholders' Equity (Parenthetical) - THE DAYTON POWER AND LIGHT COMPANY [Member] - $ / shares	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018	Dec. 31, 2017
Common stock, par value (in USD per share)	$ 0.01	$ 0.01	$ 0.01	$ 0.01
Common stock, shares authorized	50,000,000	50,000,000	50,000,000	50,000,000

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Document and Entity Information	12 Months Ended
	Dec. 31, 2018 USD ($) shares
Entity Registrant Name	THE DAYTON POWER & LIGHT CO
Entity Central Index Key	0000027430
Document Type	S-4
Amendment Flag	false
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding | shares	41,172,173
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Public Float | $	$ 0

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Consolidated Balance Sheets - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 14.4	$ 45.0	$ 5.2
Restricted cash	17.6	21.2	0.4
Accounts receivable, net	71.7	90.4	70.8
Inventories	9.8	7.7	7.3
Taxes applicable to subsequent years	18.1	72.4	71.1
Regulatory Assets, Current	40.2	41.1	23.9
Income Taxes Receivable, Current	17.4	19.6	6.5
Other prepayments and current assets	8.6	13.3	14.6
Total current assets	197.8	310.7	199.8
Property, plant and equipment:
Property, plant and equipment	2,306.5	2,274.4	2,247.2
Less: Accumulated depreciation and amortization	(1,010.4)	(988.0)	(987.3)
Property, plant and equipment, net of depreciation	1,296.1	1,286.4	1,259.9
Construction work in process	93.0	31.7	41.5
Total net property, plant and equipment	1,389.1	1,318.1	1,301.4
Other non-current assets:
Regulatory Assets, Noncurrent	154.7	152.6	163.2
Intangible assets, net of amortization	18.1	17.2	18.8
Other deferred assets	19.7	21.0	12.7
Total other non-current assets	192.5	190.8	194.7
Total Assets	1,779.4	1,819.6	1,695.9
LIABILITIES AND SHAREHOLDER'S EQUITY
Current portion - long-term debt	199.6	4.6	4.6
Short-term debt		0.0	10.0
Accounts payable	51.1	55.8	46.6
Accrued interest	6.5	0.4	0.8
Accrued taxes	78.5	75.7	76.6
Customer security deposits	20.3	21.3	21.8
Regulatory Liability, Current	36.5	34.9	14.8
Other current liabilities	16.8	17.5	12.9
Total current liabilities	409.3	210.2	188.1
Non-current liabilities:
Long-term debt	434.6	581.5	642.0
Deferred taxes	132.5	131.7	131.0
Taxes payable	4.9	77.1	75.8
Regulatory Liability, Noncurrent	252.3	278.3	221.2
Pension, retiree and other benefits	73.9	83.2	91.1
Asset Retirement Obligations, Noncurrent		4.7	8.0
Other deferred credits	7.4	7.6	8.0
Total non-current liabilities	910.3	1,164.1	1,177.1
Commitments and contingencies
Common shareholder's equity:
Common stock	0.4	0.4	0.4
Other paid-in capital	621.9	711.8	685.8
Accumulated other comprehensive income/(loss)	(34.2)	(35.3)	(36.2)
Retained earnings / (deficit)	(128.3)	(231.6)	(319.3)
Total common shareholder's equity	459.8	445.3	330.7
Total Liabilities and Shareholder's Equity	1,779.4	1,819.6	1,695.9
Asset Retirement Obligation	$ 4.7	$ 4.7	$ 8.0

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Income Taxes (Tax or Benefit credited to AOCI) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
THE DAYTON POWER AND LIGHT COMPANY [Member]
Income Taxes [Line Items]
Tax expense/ (benefit)	$ (0.3)	$ 4.0	$ (7.0)

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Debt (Long-term Debt Maturities) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017	Oct. 01, 2017
Debt Instrument [Line Items]
Unamortized Deferred Financing Costs, Consolidated		$ (6.3)
Current portion - long-term debt		4.6
Long-term Debt, Maturities, Repayments of Principal in Year Two		144.7
2018		4.7
2019		422.8
2020		0.2
Thereafter		16.8
Total Maturities		593.8
Debt Instrument, Unamortized Discount	$ (2.7)	(1.4)	$ (2.0)
Total long-term debt		586.1
Unamortized Deferred Financing Costs			(9.8)
Current portion - long-term debt	139.6	4.6	4.6
Long-term Debt, Excluding Current Maturities	434.6	581.5	642.0
Term Loan Maturing 2022 (DPL) [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		436.1	440.6
One Point One Three To One Point One Seven Bonds Maturing In August Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	140.0	140.0	200.0
Four Point Two Zero Percentage Of U S Government Note Maturing In February Two Thousand Sixty One [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 17.6	17.7	17.8
Generation [Member]
Debt Instrument [Line Items]
Disposal Group, Including Discontinued Operations, Long-Term Debt				$ 0.3
Debt [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities		$ 586.1	$ 646.6

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Revenue (Tables)

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Disaggregation of Revenue [Table Text Block]

DP&L's revenue from contracts with customers was $187.0 million and $186.1 million for the three months ended September 30, 2019 and 2018, respectively, and $554.4 million and $532.1 million for the nine months ended September 30, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue for the three and nine months ended September 30, 2019 and 2018:

	Three months ended				Nine months ended
	September 30,				September 30,
$ in millions	2019		2018		2019		2018
Retail revenue
Retail revenue from contracts with customers	$	170.5	$	168.4	$	503.8	$	469.3
Other retail revenue (a)	3.8		12.6		14.9		31.4
Wholesale revenue
Wholesale revenue from contracts with customers	4.4		4.9		12.8		24.6
RTO ancillary revenue	11.0		10.8		32.8		32.4
Capacity revenue	1.1		2.0		5.0		5.8
Miscellaneous revenue	0.3		—		0.9		—
Total revenues	$	191.1	$	198.7	$	570.2	$	563.5

(a)

Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606.

DP&L's revenue from contracts with customers was $706.6 million for the year ended December 31, 2018. The following table presents our revenue from contracts with customers and other revenue by segment for the year ended December 31, 2018:

	Year ended December 31,
$ in millions	2018
Retail Revenue
Retail revenue from contracts with customers	$	625.8
Other retail revenues (a)	32.1
Wholesale Revenue
Wholesale revenue from contracts with customers	29.9
RTO revenue	43.1
RTO capacity revenues	7.8
Total revenues	$	738.7

(a)

Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606.

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Supplemental Financial Information (Supplemental Financial Information) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Aug. 01, 2018
Supplemental Financial Information [Line Items]
Unbilled revenue	$ 15.2		$ 15.2		$ 16.8	$ 18.0
Amounts due from partners in jointly-owned plants	3.2		3.2		0.0	5.0
Customer receivables	50.0		50.0		53.3	44.2
Due from PJM transmission settlement	2.4		2.4		16.5	0.0		$ 41.6
Amounts due from affiliates					2.3	0.6
Other	1.3		1.3		2.4	4.1
Provision for uncollectible accounts	(0.4)		(0.4)		(0.9)	(1.1)
Total accounts receivable, net	71.7		71.7		90.4	70.8
Plant materials and supplies	9.8		9.8		7.1	6.9
Other	0.0		0.0		0.6	0.4
Total inventories, at average cost	9.8		9.8		7.7	7.3
Gain (Loss) on Disposition of Business	$ 0.0	$ 0.0	$ 0.0	$ 12.4	12.4	0.0	$ 0.0
Gain (Loss) on Sale of Assets and Asset Impairment Charges					$ 0.2	$ 15.7	$ (0.1)

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Property, Plant and Equipment with Corresponding Depreciation Rates (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant and equipment in service	$ 2,274.4	$ 2,247.2
Total property, plant and equipment in service, Composite Rate	3.00%	3.40%	4.60%
Regulated Operation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	$ 386.7	$ 414.6
Distribution	1,796.4	1,735.9
General	30.9	31.2
Non-depreciable	60.4	64.6
Total property, plant and equipment in service	$ 2,274.4	$ 2,246.3
Transmission, Composite Rate	2.40%	2.40%
Distribution, Composite Rate	3.20%	3.40%
General, Composite Rate	3.60%	3.10%
Unregulated Operation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Non-depreciable	$ 0.0	$ 0.9
Production / Generation	0.0	$ 0.2
Production/Generation, Composite Rate		2.70%
Other	$ 0.0	$ 0.7

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Contractual Obligations, Commercial Commitments and Contingenciesl (Schedule Of Contractual Obligations And Commercial Commitments) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] $ in Millions	Dec. 31, 2018 USD ($)
Electricity Purchase Commitments [Member]
Contractual Obligations, Commercial Commitments And Contingencies [Line Items]
Electricity Purchase Commitments	$ 209.4
Electricity Purchase Agreements Less Than 1 Year	139.5
Electricity Purchase Agreements in Years 2 and 3	69.9
Electricity Purchase Agreements in Years 4 and 5	0.0
Electricity Purchase Agreements, After Year 5	0.0
Other Intangible Assets [Member]
Contractual Obligations, Commercial Commitments And Contingencies [Line Items]
Total Purchase orders and other contractual obligations	39.8
Purchase orders and other contractual obligations, Less than 1 year	11.3
Purchase orders and other contractual obligations, 2 - 3 years	14.7
Purchase orders and other contractual obligations, 4 - 5 years	13.8
Purchase orders and other contractual obligations, More than 5 years	$ 0.0

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Benefit Plans (Net Periodic Benefit Cost (Income)) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - Pension [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Service cost	$ 0.9	$ 1.5	$ 2.7	$ 4.5	$ 6.1	$ 5.7	$ 5.7
Interest cost	3.7	3.4	11.2	10.3	13.8	14.2	14.7
Expected return on assets	(5.0)	(5.3)	(15.0)	(15.9)	(21.2)	(22.8)	(22.8)
Defined Benefit Plan, Curtailments					0.0	5.6	5.7
Actuarial gain / (loss)	1.8	2.4	5.3	7.1	9.4	8.7	7.2
Prior service cost	0.4	0.4	1.3	1.1	1.4	1.5	3.0
Net Periodic benefit cost / (income) before adjustments					$ 9.5	$ 12.9	$ 13.5
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate					3.66%	4.28%	4.49%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets					6.25%	6.50%	6.50%
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)	$ 1.8	$ 2.4	$ 5.5	$ 7.1

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Benefit Plans (Defined Benefits Plan Assets, Target Allocations) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member]	Dec. 31, 2018	Dec. 31, 2017
Equity Securities [Member]
Target Allocation	38.00%
Percentage of plan assets	33.00%	35.00%
Debt Securities [Member]
Target Allocation	56.00%
Percentage of plan assets	58.00%	55.00%
Cash and Cash Equivalents [Member]
Target Allocation	0.00%
Percentage of plan assets	1.00%	0.00%
Real Estate [Member]
Target Allocation	6.00%
Percentage of plan assets	8.00%	10.00%

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Revenue (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017
Revenue from Contract with Customer, Excluding Assessed Tax	$ 187.0	$ 186.1	$ 554.4	$ 532.1	$ 706.6
Revenues	191.1	198.7	570.2	563.5	738.7
RTO Revenue	11.0	10.8	32.8	32.4	43.1
RTO Capacity Revenue	1.1	2.0	5.0	5.8	7.8
Contract with Customer, Asset, Gross	65.2		65.2		70.1	$ 62.1
Alternative Revenue Programs Accounts Receivable, Gross	0.0		0.0		0.0
Wholesale Revenue [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4.4	4.9	12.8	24.6	29.9
Other Revenues [Member]
Other non-606 revenue	0.3	0.0	0.9	0.0
Retail Revenue [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	170.5	168.4	503.8	469.3	625.8
Other non-606 revenue	$ 3.8	$ 12.6	$ 14.9	$ 31.4	$ 32.1

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Derivative Instruments and Hedging Activities (Classification within the Condensed Consolidated Statements of Results of Operations or Balance Sheets of the Gains and Losses) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Other Noncurrent Assets [Member] | Designated as Hedging Instrument [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Swap [Member]
Derivative Liability, Fair Value, Gross Liability	$ 0.6	$ 1.5

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Fair Value Measurements (Fair Value of Assets and Liabilities Measured on a Nonrecurring Basis) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Sep. 30, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Carrying Value	$ 1,318.1	$ 1,301.4		$ 1,389.1
Fixed-asset impairment (Note 14)	$ 0.0	$ 66.3	$ 1,353.5

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Property, Plant and Equipment (Changes in the Liability for Transmission and Distribution Asset Removal Costs) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Changes in Liability for Transmission and Distribution Asset Removal Costs [Roll Forward]
Balance at January 1	$ 132.8	$ 126.5
Additions	14.3	12.0
Settlements	(8.0)	(5.7)
Balance at December 31	$ 139.1	$ 132.8

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Supplemental Financial Information (Tables) - THE DAYTON POWER AND LIGHT COMPANY [Member]

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Supplemental Financial Information [Line Items]

Supplemental Financial Information

Accounts receivable and Inventories are as follows at September 30, 2019 and December 31, 2018:

	September 30,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	50.0		$	53.3
Unbilled revenue	15.2			16.8
Amounts due from affiliates	3.2			2.3
Due from PJM transmission enhancement settlement	2.4			16.5
Other	1.3			2.4
Provision for uncollectible accounts	(0.4		)	(0.9		)
Total accounts receivable, net	$	71.7		$	90.4
Inventories, at average cost:
Materials and supplies	$	9.8		$	7.1
Other	—			0.6
Total inventories, at average cost	$	9.8		$	7.7

	December 31,
$ in millions	2018			2017
Accounts receivable, net
Customer receivables	$	53.3		$	44.2
Unbilled revenue	16.8			18.0
Amounts due from partners in jointly-owned stations	—			5.0
Due from PJM transmission enhancement settlement (a)	16.5			—
Due from affiliates	2.3			0.6
Other	2.4			4.1
Provisions for uncollectible accounts	(0.9		)	(1.1		)
Total accounts receivable, net	$	90.4		$	70.8
Inventories, at average cost
Materials and supplies	$	7.1		$	6.9
Other	0.6			0.4
Total inventories, at average cost	$	7.7		$	7.3

(a) - See Note 3 – Regulatory Matters

Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three and nine months ended September 30, 2019 and 2018 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) components	Affected line item in the Condensed Statements of Operations	Three months ended					Nine months ended
		September 30,					September 30,
$ in millions		2019		2018			2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	—	$	(0.3	)	$	(0.1	)	$	(1.1	)
	Income tax expense	—		0.1			—			0.6
	Net of income taxes	—		(0.2		)	(0.1		)	(0.5		)
Amortization of defined benefit pension items (Note 8):
	Other expense	0.8		1.0			2.6			3.2
	Income tax expense / (benefit)	0.9		(0.2		)	(0.5		)	(0.7		)
	Net of income taxes	1.7		0.8			2.1			2.5
Total reclassifications for the period, net of income taxes		$	1.7	$	0.6		$	2.0		$	2.0

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the years ended December 31, 2018, 2017 and 2016 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) Components	Affected line item in the Statements of Operations	Years ended December 31,
$ in millions		2018			2017			2016
Gains and losses on equity securities activity (Note 5):
	Other deductions	$	—		$	(0.1	)	$	—
	Income tax expense	—			—			—
	Net of income taxes	—			(0.1		)	—
Gains and losses on cash flow hedges (Note 6):
	Interest expense	(1.1		)	(0.9		)	(1.0		)
	Income tax benefit	0.4			0.2			0.2
	Net of income taxes	(0.7		)	(0.7		)	(0.8		)
	Loss from discontinued operations	—			(8.5		)	(45.4		)
	Income tax benefit from discontinued operations	—			3.0			16.2
	Net of income taxes	—			(5.5		)	(29.2		)
Amortization of defined benefit pension items (Note 9):
	Other income	4.3			6.8			7.7
	Income tax expense	(1.0		)	(2.3		)	(1.8		)
	Net of income taxes	3.3			4.5			5.9
Total reclassifications for the period, net of income taxes		$	2.6		$	(1.8	)	$	(24.1	)

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the nine months ended September 30, 2019 are as follows:

$ in millions	Gains / (losses) on cash flow hedges			Change in unfunded pension and postretirement benefit obligation			Total
Balance at January 1, 2019	$	0.6		$	(35.9	)	$	(35.3	)
Other comprehensive loss before reclassifications	(0.9		)	—			(0.9		)
Amounts reclassified from AOCI to earnings	(0.1		)	2.1			2.0
Net current period other comprehensive income / (loss)	(1.0		)	2.1			1.1
Balance at September 30, 2019	$	(0.4	)	$	(33.8	)	$	(34.2	)

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the years ended December 31, 2018 and 2017 are as follows:

$ in millions	Gains / (losses) on equity securities			Gains / (losses) on cash flow hedges			Change in unfunded pension obligation			Total
Balance at December 31, 2016	$	0.7		$	(2.7	)	$	(40.5	)	$	(42.5	)
Other comprehensive income / (loss) before reclassifications	0.5			12.4			(2.7		)	10.2
Amounts reclassified from accumulated other comprehensive income / (loss)	(0.1		)	(6.2		)	4.5			(1.8		)
Net current period other comprehensive income	0.4			6.2			1.8			8.4
Transfer of generation assets to subsidiary of parent	—			(2.1		)	—			(2.1		)
Balance at December 31, 2017	1.1			1.4			(38.7		)	(36.2		)
Other comprehensive loss before reclassifications	—			(0.1		)	(0.5		)	(0.6		)
Amounts reclassified from accumulated other comprehensive income / (loss) to earnings	—			(0.7		)	3.3			2.6
Net current period other comprehensive income / (loss)	—			(0.8		)	2.8			2.0
Amounts reclassified from accumulated other comprehensive income to accumulated deficit (a)	(1.1		)	—			—			(1.1		)
Balance at December 31, 2018	$	—		$	0.6		$	(35.9	)	$	(35.3	)

(a) ASU 2016-01 “Recognition and Measurement of Financial Assets and Financial Liabilities” was effective as of January 1, 2018. This ASU requires the change in the fair value of equity instruments to be recorded in income rather than in OCI. Equity Instruments were defined to include all mutual funds, regardless of the underlying investments.

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Derivative Instruments and Hedging Activities (Tables)

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Schedule of Interest Rate Derivatives [Table Text Block]

The fair value derivative position of DP&L's interest rate swaps are as follows:

			December 31,
	Hedging Designation	Balance sheet classification	2018		2017
Interest rate hedges in a Current asset position	Cash Flow Hedge	Other prepayments and current assets
Gross Fair Value as presented in the Balance Sheets			$	0.9	$	—
Interest rate hedges in a non-current asset position	Cash Flow Hedge	Other deferred assets
Gross Fair Value as presented in the Balance Sheets			$	0.6	$	1.5

THE DAYTON POWER AND LIGHT COMPANY [Member]

Gains or Losses Recognized in AOCI for the Cash Flow Hedges

The following tables provide information concerning gains or losses recognized in AOCI for the cash flow hedges for the three and nine months ended September 30, 2019 and 2018:

	Three months ended
	September 30, 2019			September 30, 2018
	Interest			Interest
$ in millions (net of tax)	Rate Hedge			Rate Hedge
Beginning accumulated derivative gains / (losses) in AOCI	$	(0.3	)	$	1.6
Net losses associated with current period hedging transactions	(0.1		)	—
Net gains reclassified to earnings
Interest expense	—			(0.2		)
Ending accumulated derivative gains / (losses) in AOCI	$	(0.4	)	$	1.4
	Nine months ended
	September 30, 2019			September 30, 2018
	Interest			Interest
$ in millions (net of tax)	Rate Hedge			Rate Hedge
Beginning accumulated derivative gains in AOCI	$	0.6		$	1.4
Net gains / (losses) associated with current period hedging transactions	(0.9		)	0.5
Net gains reclassified to earnings
Interest expense	(0.1		)	(0.5		)
Ending accumulated derivative gains / (losses) in AOCI	$	(0.4	)	$	1.4
Portion expected to be reclassified to earnings in the next twelve months	$	(0.2	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	11

	Years ended December 31,
	2018			2017						2016
$ in millions (net of tax)	Interest Rate Hedges			Power			Interest Rate Hedges			Power			Interest Rate Hedges
Beginning accumulated derivative gain / (loss) in AOCI	$	1.4		$	(4.3	)	$	1.6		$	9.2		$	2.0
Net gains / (losses) associated with current period hedging transactions	(0.1		)	11.9			0.5			15.7			0.4
Net gains / (losses) reclassified to earnings:
Interest expense	(0.7		)	—			(0.7		)	—			(0.8		)
Loss from discontinued operations	—			(5.5		)	—			(29.2		)	—
Transfer of generation assets to subsidiary of parent	—			(2.1		)	—			—			—
Ending accumulated derivative gain / (loss) in AOCI	$	0.6		$	—		$	1.4		$	(4.3	)	$	1.6
Portion expected to be reclassified to earnings in the next twelve months	$	0.7
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	20

Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location

DP&L has elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivative agreements. The fair value derivative position of DP&L's interest rate swaps are as follows:

Fair Values of Derivative Instruments
at September 30, 2019
				Gross Amounts Not Offset in the Condensed Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Prepayments and other current assets)
Interest rate swap	Designated	$	0.2	$	—	$	—	$	0.2
Total assets		$	0.2	$	—	$	—	$	0.2

(a)    Includes credit valuation adjustment.

Fair Values of Derivative Instruments
at December 31, 2018
				Gross Amounts Not Offset in the Condensed Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Prepayments and other current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other non-current assets)
Interest rate swaps	Designated	0.6		—		—		0.6
Total assets		$	1.5	$	—	$	—	$	1.5

(a)    Includes credit valuation adjustment.

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Contractual Obligations, Commercial Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Schedule Of Contractual Obligations And Commercial Commitments

We enter into various contractual obligations and other commercial commitments that may affect the liquidity of our operations. At December 31, 2018, these include:

	Payments due in:
$ in millions	Total		Less than 1 year		2 - 3 years		4 - 5 years		More than 5 years
Electricity purchase commitments	$	209.4	$	139.5	$	69.9	$	—	$	—
Purchase orders and other contractual obligations	$	39.8	$	11.3	$	14.7	$	13.8	$	—

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Income Taxes

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Income Taxes [Line Items]

Income Taxes

Income Taxes

The following table details the effective tax rates for the three and nine months ended September 30, 2019 and 2018.

	Three months ended		Nine months ended
	September 30,		September 30,
	2019	2018	2019	2018
DP&L	(19.1)%	16.8%	4.7%	16.2%

Income tax expense for the nine months ended September 30, 2019 and 2018 was calculated using the estimated annual effective income tax rates for 2019 and 2018 of 4.5% and 17.1%, respectively. Management estimates the annual effective tax rate based on its forecast of annual pre-tax income. To the extent that actual pre-tax results for the year differ from the forecasts applied to the most recent interim period, the estimated rates could be materially different from the actual effective tax rates. DP&L’s effective combined state and federal income tax rate was (19.1)% and 4.7% for the three and nine months ended September 30, 2019, respectively. This is lower than the combined federal and state statutory rate of 21.6% primarily due to the net tax benefit related to the reversal of excess deferred taxes and the impact of the September 26, 2019 PUCO order which finalized the amount of excess deferred tax balances allocable to DP&L’s utility customers.

For the nine months ended September 30, 2019, DP&L’s current period effective tax rate for all operations was not materially different than the estimated annual effective rate.

DP&L’s components of income tax expense on continuing operations were as follows:

	Years ended December 31,
$ in millions	2018			2017			2016
Computation of tax expense
Federal income tax expense (a)	$	22.2		$	31.0		$	50.1
Increases (decreases) in tax resulting from:
State income taxes, net of federal effect	0.6			0.4			0.4
Depreciation of flow-through differences	(4.3		)	1.2			3.0
Investment tax credit amortized	(0.3		)	(0.3		)	(0.4		)
Accrual (settlement) for open tax years	—			(0.5		)	3.4
Other, net (b)	(0.5		)	(0.7		)	(10.5		)
Total tax expense	$	17.7		$	31.1		$	46.0
Components of tax expense
Federal - current	$	1.4		$	13.5		$	37.7
State and Local - current	—			0.2			0.5
Total current	1.4			13.7			38.2
Federal - deferred	15.5			17.0			7.7
State and local - deferred	0.8			0.4			0.1
Total deferred	16.3			17.4			7.8
Total tax expense	$	17.7		$	31.1		$	46.0

(a) The statutory tax rate of 21% in 2018 and 35% in 2017 and 2016 was applied to pre-tax earnings.

(b) Includes expense / (benefit) of $(0.7) million and $(0.4) million in the years ended December 31, 2017 and 2016, respectively, of income tax related to adjustments from prior years.

Effective and Statutory Rate Reconciliation

The following table summarizes a reconciliation of the U.S. statutory federal income tax rate to DP&L's effective tax rate, as a percentage of income from continuing operations before taxes for the years ended December 31, 2018, 2017 and 2016:

	Years ended December 31,
	2018		2017		2016
Statutory Federal tax rate	21.0	%	35.0	%	35.0	%
State taxes, net of Federal tax benefit	0.6	%	0.4	%	0.3	%
AFUDC - Equity	(0.1	)%	1.4	%	2.1	%
Amortization of investment tax credits	(0.3	)%	(0.4	)%	(0.3	)%
Depreciation of flow-through differences	(4.0	)%	—	%	—	%
Other - net	(0.2	)%	(1.3	)%	(5.1	)%
Effective tax rate	17.0	%	35.1	%	32.0	%

Deferred Income Taxes

Deferred income taxes reflect the net tax effects of (a) temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes and (b) operating loss carryforwards. These items are stated at the enacted tax rates that are expected to be in effect when taxes are actually paid or recovered. Investment tax credits related to utility property have been deferred and are being amortized over the estimated useful lives of the related property.

Components of Deferred Tax Assets and Liabilities
	December 31,
$ in millions	2018			2017
Net non-current assets / (liabilities)
Depreciation / property basis	$	(130.6	)	$	(126.5	)
Income taxes recoverable	25.0			11.0
Regulatory assets	(16.2		)	(23.9		)
Investment tax credit	0.5			0.4
Compensation and employee benefits	0.3			17.6
Other	(10.7		)	(9.6		)
Net non-current liabilities	$	(131.7	)	$	(131.0	)

U.S. Tax Reform

On December 22, 2017, the U.S. enacted the TCJA. The TCJA significantly changes U.S. corporate income tax law.

In 2017, we recognized the income tax effects of the TCJA in accordance with Staff Accounting Bulletin No. 118 (“SAB 118”) which provides SEC guidance on the application of FASC 740, Income Taxes, in the reporting period in which the TCJA was signed into law. Accordingly, our 2017 financial statements reflected the income tax effects of U.S. tax reform for which the accounting was complete and provisional amounts for those impacts for which the accounting under FASC 740 was incomplete, but a reasonable estimate could be determined.

We completed our calculation of the impact of the TCJA in our income tax provision for the year ended December 31, 2018 in accordance with our understanding of the TCJA and guidance available as of the date of this filing. As a result of this remeasurement, certain deferred tax assets and liabilities related to regulated utility property of $17.0 million and $135.2 million at December 31, 2018 and 2017 were recorded as regulatory liabilities and were non-cash adjustments. These amounts result from the remeasurement of certain deferred tax assets and liabilities as the rates changed from 35% to 21%. Additionally, consistent with the provisions of SAB 118, in 2018 we finalized the remeasurement of deferred tax asset balances transferred to AES Ohio Generation as part of Generation Separation which resulted in an additional $10.0 million return of capital to DPL in 2018.

The following table presents the tax expense / (benefit) related to pensions, postemployment benefits, cash flow hedges and financial instruments that were credited to Accumulated other comprehensive loss.

	Years ended December 31,
$ in millions	2018			2017		2016
Tax expense / (benefit)	$	(0.3	)	$	4.0	$	(7.0	)

Uncertain Tax Positions

We apply the provisions of GAAP relating to the accounting for uncertainty in income taxes. A reconciliation of the beginning and ending amount of unrecognized tax benefits for DP&L is as follows:

$ in millions
Balance at December 31, 2016	$	4.9
Calendar 2017
Tax positions taken during prior period	—
Lapse of Statute of Limitations	(0.1		)
Balance at December 31, 2017	4.8
Calendar 2018
Tax positions taken during prior period	—
Lapse of Statute of Limitations	—
Balance at December 31, 2018	$	4.8

Of the December 31, 2018 balance of unrecognized tax benefits, $4.8 million is due to uncertainty in the timing of deductibility.

We recognize interest and penalties related to unrecognized tax benefits in Income tax expense. The amounts accrued and tax expense / (benefit) recorded were not material for each period presented.

Following is a summary of the tax years open to examination by major tax jurisdiction:

U.S. Federal – 2011 and forward

State and Local – 2011 and forward

None of the unrecognized tax benefits are expected to significantly increase or decrease within the next twelve months other than those subject to expiring statute of limitations.

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Property, Plant and Equipment

12 Months Ended

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Property, Plant and Equipment [Line Items]

Property, Plant and Equipment

The following is a summary of DP&L’s Property, plant and equipment with corresponding composite depreciation rates at December 31, 2018 and 2017:

	December 31, 2018			December 31, 2017
$ in millions			Composite Rate			Composite Rate (a)
Regulated:
Transmission	$	386.7	2.4%	$	414.6	2.4%
Distribution	1,796.4		3.2%	1,735.9		3.4%
General	30.9		3.6%	31.2		3.1%
Non-depreciable	60.4		N/A	64.6		N/A
Total regulated	2,274.4			2,246.3
Unregulated:
Other	—		N/A	0.2		2.7%
Non-depreciable	—		N/A	0.7		N/A
Total unregulated	—			0.9
Total property, plant and equipment in service	$	2,274.4	3.0%	$	2,247.2	3.4%

In June 2018, DP&L closed on a transmission asset transaction with Duke and AEP, where ownership stakes in certain previously co-owned transmission assets were exchanged to eliminate co-ownership. Each previously co-owned transmission asset became wholly-owned by one of DP&L, Duke or AEP after the transaction. This transaction also resulted in cash proceeds to DP&L of $10.6 million.

AROs

We recognize AROs in accordance with GAAP which requires legal obligations associated with the retirement of long-lived assets to be recognized at their fair value at the time those obligations are incurred. Upon initial recognition of a legal liability, costs are capitalized as part of the related long-lived asset and depreciated over the useful life of the related asset. The DP&L AROs are for our retired Hutchings EGU and relate primarily to asbestos removal.

Estimating the amount and timing of future expenditures of this type requires significant judgment. Management routinely updates these estimates as additional information becomes available.

Changes in the Liability for Generation AROs

$ in millions
Balance at December 31, 2016	$	8.2
Calendar 2017
Accretion expense	0.1
Settlements	(0.3		)
Balance at December 31, 2017	8.0
Calendar 2018
Settlements (a)	(3.3		)
Balance at December 31, 2018	$	4.7

(a) Primarily includes settlement related to transfer of Beckjord Facility. See Note 15 – Dispositions for additional information.

See Note 5 – Fair Value for further discussion on ARO fair value measurements.

Asset Removal Costs

We continue to record costs of removal for our regulated transmission and distribution assets through our depreciation rates and recover those amounts in rates charged to our customers. There are no known legal AROs associated with these assets. We have recorded $139.1 million and $132.8 million in estimated costs of removal at

December 31, 2018 and 2017, respectively, as regulatory liabilities for our transmission and distribution property. These amounts represent the excess of the cumulative removal costs recorded through depreciation rates versus the cumulative removal costs actually incurred. See Note 3 – Regulatory Matters for additional information.

Changes in the Liability for Transmission and Distribution Asset Removal Costs

$ in millions
Balance at December 31, 2016	$	126.5
Calendar 2017
Additions	12.0
Settlements	(5.7		)
Balance at December 31, 2017	132.8
Calendar 2018
Additions	14.3
Settlements	(8.0		)
Balance at December 31, 2018	$	139.1

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Consolidated Statements of Comprehensive Income/(Loss) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net income (loss)	$ 44.9	$ 31.2	$ 103.7	$ 61.9	$ 86.7	$ 17.0	$ (772.7)
Net income / (loss)	44.9	31.2			86.7	17.0	(772.7)
Equity securities activity:
Change in fair value of available-for-sale securities, net of income tax benefit/(expense)					0.0	0.5	0.2
Reclassification to earnings of available-for-sale securities, net of income tax expense/(benefit)					0.0	(0.1)	0.0
AOCI reclassed to Retained Earnings, net of tax					(1.1)
Total change in fair value of available-for-sale securities					0.0	0.4	0.2
Derivative activity:
Change in derivative fair value, net of income tax benefit/(expense)	(0.1)	0.0	(0.9)	0.5	(0.1)	12.4	16.1
Reclassification of earnings, net of income tax benefit/(expense)	0.0	(0.2)	(0.1)	(0.5)	(0.7)	(0.7)	(0.8)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives Related to Discontinued Operations, Net of Tax					0.0	(5.5)	(29.2)
Total change in fair value of derivatives	(0.1)	(0.2)	(1.0)	0.0	(0.8)	6.2	(13.9)
Pension and postretirement activity:
Prior service cost for the period, net of income tax benefit/(expense)					(2.2)	(1.9)	(0.1)
Net loss for the period, net of income tax benefit/(expense)					1.7	(0.8)	(5.9)
Reclassification to earnings, net of income tax benefit/(expense)	1.7	0.8	2.1	2.5	3.3	4.5	5.9
Total change in unfunded pension obligation	1.7	0.8	2.1	2.5	2.8	1.8	(0.1)
Other comprehensive income / (loss)	1.6	0.6	1.1	2.5	2.0	8.4	(13.8)
Net comprehensive income / (loss)	$ 46.5	$ 31.8	$ 104.8	$ 64.4	$ 88.7	$ 25.4	$ (786.5)

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Consolidated Statements of Cash Flows - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash flows from operating activities:
Net income (loss)	$ 103.7	$ 61.9	$ 86.7	$ 17.0	$ (772.7)
Adjustments to reconcile Net income / (loss) to Net cash from operating activities
Depreciation and amortization	52.9	56.5	74.5	87.2	120.3
Amortization of deferred financing costs			3.1	1.1	2.9
Unrealized loss (gain) on derivatives			0.0	(1.0)	(4.2)
Deferred income taxes	(17.2)	(7.5)	16.3	8.1	(477.5)
Charge for early redemption of debt	0.0	0.6	0.6	1.1	0.5
Impairment of Long-Lived Assets Held-for-use			0.0	66.3	1,353.5
Gain (Loss) on Disposition of Business	0.0	(12.4)	(12.4)	0.0	0.0
Loss / (Gain) on asset disposal, net			0.2	15.7	(0.1)
Changes in certain assets and liabilities:
Accounts receivable	18.9	(3.3)	13.5	14.6	(8.3)
Inventories	(2.1)	(0.2)	(0.3)	10.3	32.2
Prepaid taxes			0.0	0.0	2.7
Taxes applicable to subsequent years	54.3	54.0	(1.3)	6.4	0.0
Deferred regulatory costs, net	2.9	(4.1)	(9.2)	(23.7)	4.1
Accounts payable	(4.8)	(1.1)	3.8	(48.7)	14.6
Accrued taxes payable	(65.6)	(58.7)	(12.7)	(17.5)	(10.5)
Accrued interest payable	6.0	(0.3)	(0.4)	(1.3)	(2.0)
Pension, retiree and other benefits	(9.3)	(3.1)	(2.4)	4.8	3.0
Other	(0.8)	6.1	11.0	(5.0)	(21.3)
Net cash provided by operating activities	138.9	113.2	195.8	135.4	237.2
Cash flows from investing activities:
Capital expenditures	(121.1)	(65.0)	(93.1)	(101.7)	(128.3)
Payments for Removal Costs	0.0	(14.5)	(14.5)	0.0	0.0
Proceeds from Sale of Property, Plant, and Equipment	0.0	10.6	10.6	0.0	0.2
Insurance proceeds	0.0	0.1	0.4	12.5	6.1
Other investing activities, net	(3.5)	(0.2)	(0.3)	(0.3)	0.4
Net cash provided by / (used in) investing activities	(124.6)	(69.0)	(96.9)	(89.5)	(121.6)
Cash flows from financing activities:
Dividends paid on preferred stock			0.0	0.0	(0.7)
Deferred financing costs	(4.6)	0.0	0.0	0.0	(8.5)
Preferred Stock, Redemption Amount			0.0	0.0	(23.5)
Retirement of debt	(436.1)	(63.3)	(64.5)	(104.5)	(445.3)
Proceeds from Contributions from Parent	0.0	80.0	80.0	70.0	0.0
Premium paid for early redemption of debt	(0.1)	0.0	0.0	(0.4)	0.0
Issuance of long-term debt	422.3	0.0	0.0	0.0	442.8
Borrowings from revolving credit facilities	60.0	30.0	30.0	40.0	0.0
Repayment of borrowings from revolving credit facilities	0.0	(40.0)	(40.0)	(30.0)	0.0
Dividends paid on common stock to parent	(90.0)	(43.8)	(43.8)	(39.0)	(70.0)
Borrowings from related party			0.0	30.0	10.0
Repayment of borrowings from related party			0.0	(35.0)	(40.0)
Net cash from financing activities	(48.5)	(37.1)	(38.3)	(68.9)	(135.2)
Net Cash Provided by (Used in) Discontinued Operations			0.0	27.0	15.8
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	(34.2)	7.1
Cash and cash equivalents:
Net increase / (decrease) in cash			60.6	4.0	(3.8)
Restricted Cash and Cash Equivalents	32.0		66.2	5.6	1.6
Supplemental cash flow information:
Interest paid, net of amounts capitalized	10.8	17.0	22.9	28.4	21.4
Income taxes paid / (refunded), net	19.0	8.3	13.1	28.1	0.3
Non-cash financing and investing activities:
Accruals for capital expenditures	$ 2.0	$ 7.2	10.8	19.7	14.8
Subsidiary of Common Parent [Member]
Non-cash financing and investing activities:
Equity Settlement of Related Party Payable			0.0	$ 0.0	7.5
Generation [Member]
Non-cash financing and investing activities:
Disposal Group, Including Discontinued Operation, Net Assets			$ (10.0)		$ 0.0

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Overview and Summary of Significant Accounting Policies (Policy) - THE DAYTON POWER AND LIGHT COMPANY [Member]

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Significant Accounting Policies [Line Items]

Description of Business

Description of Business

DP&L is a public utility incorporated in 1911 under the laws of Ohio. Beginning in 2001, Ohio law gave Ohio consumers the right to choose the electric generation supplier from whom they purchase retail generation service; however, retail transmission and distribution services are still regulated. DP&L has the exclusive right to provide such transmission and distribution services to approximately 524,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a 6,000-square mile area of West Central Ohio. As a result of Generation Separation, DP&L now only has one reportable segment, the Utility segment. In addition to DP&L's electric transmission and distribution businesses, the Utility segment includes revenues and costs associated with DP&L's investment in OVEC and the historical results of DP&L’s Beckjord and Hutchings Coal generating facilities, which have either been closed or sold. Principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, health care, data management, manufacturing and defense. Following the issuance of the DRO in September 2018 and the resulting changes to the decoupling rider effective January 1, 2019, DP&L's distribution sales are primarily impacted by customer growth within our service territory. DP&L sells its proportional share of energy and capacity from its investment in OVEC into the wholesale market. DP&L is a subsidiary of DPL. The terms “we,” “us,” “our” and “ours” are used to refer to DP&L.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs.

DP&L employed 642 people as of September 30, 2019. Approximately 58% of DP&L employees are under a collective bargaining agreement, which expires October 31, 2020.

DP&L is a public utility incorporated in 1911 under the laws of Ohio. Beginning in 2001, Ohio law gave consumers the right to choose the electric generation supplier from whom they purchase retail generation service, however transmission and distribution services are still regulated. DP&L has the exclusive right to provide such service to its approximately 525,000 customers located in West Central Ohio. DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a 6,000 square mile area of West Central Ohio. Since January 2016, DP&L has been sourcing all of the generation for its SSO customers through a competitive bid process. Through September 30, 2017, DP&L owned undivided interests in multiple coal-fired power stations and multiple peaking electric generating facilities as well as numerous transmission facilities. On October 1, 2017, the DP&L-owned generating facilities, excluding the Beckjord Facility and Hutchings EGU, were transferred to AES Ohio Generation, an affiliate of DP&L and wholly-owned subsidiary of DPL, through an asset contribution agreement to a subsidiary that was merged into AES Ohio Generation. Also, Stuart Station Unit 1 was retired on October 1, 2017. Principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, manufacturing and defense. DP&L's sales reflect the general economic conditions, seasonal weather patterns of the area and the market price of electricity. Through the date of Generation Separation, DP&L sold energy and capacity into the wholesale market. As a result of Generation Separation, DP&L now only has one reportable segment, Transmission and Distribution. In addition to DP&L's electric transmission and distribution businesses, the Transmission and Distribution segment includes revenues and costs associated with DP&L's investment in OVEC and the historical results of DP&L’s Beckjord and Hutchings Coal generating facilities, which were either closed or sold in prior periods.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs or overcollections of riders.

DP&L employed 647 people at January 31, 2019. Approximately 58% of all employees are under a collective bargaining agreement.

Financial Statement Presentation

Financial Statement Presentation

DP&L does not have any subsidiaries.

We have evaluated subsequent events through the date this report is issued.

Certain immaterial amounts from prior periods have been reclassified to conform to the current period presentation.

These financial statements have been prepared in accordance with GAAP for interim financial statements, the instructions of Form 10-Q and Regulation S-X. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with GAAP have been omitted from this interim report. Therefore, our interim financial statements in this report should be read along with the annual financial statements included in our Form 10-K for the fiscal year ended December 31, 2018.

In the opinion of our management, the Condensed Financial Statements presented in this report contain all adjustments necessary to fairly state our financial position as of September 30, 2019; our results of operations for the three and nine months ended September 30, 2019 and 2018, our cash flows for the nine months ended September 30, 2019 and 2018 and the changes in our equity for the three and nine months ended September 30, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three and nine months ended September 30, 2019 may not be indicative of our results that will be realized for the full year ending December 31, 2019.

The preparation of financial statements in conformity with GAAP requires us to make estimates and judgments that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the revenues and expenses of the periods reported. Actual results could differ from these estimates. Significant items subject to such estimates and judgments include: recognition of revenue including unbilled revenues, the carrying value of property, plant and equipment; the valuation of derivative instruments; the valuation of insurance and claims liabilities; the valuation of allowances for receivables and deferred income taxes; regulatory assets and

liabilities; liabilities recorded for income tax exposures; litigation; contingencies; the valuation of AROs; and assets and liabilities related to employee benefits.

DP&L does not have any subsidiaries.

Through June 2018, DP&L had undivided ownership interests in numerous transmission facilities. These undivided interests in jointly-owned facilities were accounted for on a pro rata basis in the Financial Statements. In June 2018, DP&L closed on a transmission asset transaction with Duke and AEP, where ownership stakes in certain previously co-owned transmission assets were exchanged to eliminate co-ownership. Each previously co-owned transmission asset became wholly-owned by one of DP&L, Duke or AEP after the transaction. See Note 4 – Property, Plant and Equipment for more information.

We have evaluated subsequent events through the date this report is issued.

Reclassifications

Discontinued Operations, Policy [Policy Text Block]

Transactions between the businesses determined to be discontinued operations and businesses that are expected to continue to exist after the disposal are not eliminated to appropriately reflect the continuing operations and balances held-for-sale. The results of discontinued operations include any gain or loss recognized on closing or adjustment of the carrying amount to fair value. See Note 14 – Generation Separation for further information.

Generation Separation

With the transfer of DP&L's generation assets to an affiliate (see Note 14 – Generation Separation), DP&L's generation business is presented as a discontinued operation and the operating activities have been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016 and in the notes to the financial statements.

The PUCO authorized DP&L to maintain long-term debt of $750 million or 75% of its rate base, whichever is greater, until January 1, 2018, or to file an application to explain why it would not achieve those metrics. Accordingly, $750.0 million of debt and the pro rata interest expense associated with that debt were allocated to continuing operations. All remaining interest expense is included in discontinued operations above. The interest expense included in discontinued operations was $0.2 million and $0.5 million for the years ended December 31, 2017 and 2016, respectively.

Use of Estimates

and assets and liabilities related to employee benefits.

Revenue Recognition

Revenues are recognized from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Energy sales to customers are based on the reading of their meters that occurs on a systematic basis throughout the month. We recognize the revenues on our Statements of Operations using an accrual method for retail and other energy sales that have not yet been billed, but where electricity has been consumed. This is termed “unbilled revenues” and is a widely recognized and accepted practice for utilities. At the end of each month, unbilled revenues are determined by the estimation of unbilled energy provided to customers since the date of the last meter reading, estimated line losses, the assignment of unbilled energy provided to customer classes and the average rate per customer class.

The power sales and purchases within DP&L’s service territory are reported on a net hourly basis as revenues or purchased power on our Statements of Operations. We record expenses when purchased electricity is received and when expenses are incurred. For additional information, see

Receivables

Property, Plant and Equipment

We record our ownership share of our undivided interest in jointly-owned transmission and distribution property as an asset in property, plant and equipment. New property, plant and equipment additions are stated at cost. For regulated transmission and distribution property, cost includes direct labor and material, allocable overhead expenses and an allowance for funds used during construction (AFUDC). AFUDC represents the cost of borrowed funds and equity used to finance regulated construction projects. For non-regulated property, cost also includes capitalized interest. Capitalization of AFUDC and interest ceases at either project completion or at the date specified by regulators AFUDC and capitalized interest was $0.5 million, $1.5 million and $2.0 million for the years ended December 31, 2018, 2017 and 2016, respectively.

For substantially all depreciable property, when a unit of property is retired, the original cost of that property less any salvage value is charged to Accumulated depreciation and amortization, consistent with composite depreciation practices.

Repairs and Maintenance

Depreciation - Change in Estimate

Depreciation expense is calculated using the straight-line method, which allocates the cost of property over its estimated useful life. For DP&L’s transmission and distribution assets, straight-line depreciation is applied monthly on an average composite basis using group rates. For DP&L’s transmission and distribution assets, straight-line depreciation is applied on an average annual composite basis using group rates that approximated 3.0% in 2018, 3.4% in 2017 and 4.6% in 2016. Depreciation expense was $68.2 million, $69.6 million and $64.3 million for the years ended December 31, 2018, 2017 and 2016, respectively.

Regulatory Accounting

As a regulated utility, DP&L applies the provisions of FASC 980 “Regulated Operations”, which gives recognition to the ratemaking and accounting practices of the PUCO and the FERC. Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in customer rates. Regulatory assets can also represent performance incentives permitted by the regulator. Regulatory assets have been included as allowable costs for ratemaking purposes, as authorized by the PUCO or established regulatory practices. Regulatory liabilities generally represent obligations to make refunds or future rate reductions to

customers for previous over collections or the deferral of revenues collected for costs that DP&L expects to incur in the future.

The deferral of costs (as regulatory assets) is appropriate only when the future recovery of such costs is probable. In assessing probability, we consider such factors as specific orders from the PUCO or FERC, regulatory precedent and the current regulatory environment. To the extent recovery of costs is no longer deemed probable, related regulatory assets would be required to be expensed in current period earnings. Our regulatory assets and liabilities have been created pursuant to a specific order of the PUCO or FERC or established regulatory practices, such as other utilities under the jurisdiction of the PUCO or FERC being granted recovery of similar costs. It is probable, but not certain, that these regulatory assets will be recoverable, subject to PUCO or FERC approval. Regulatory assets and liabilities are classified as current or non-current based on the term in which recovery is expected See Note 3 – Regulatory Matters for more information.

Inventories

Inventories are carried at average cost and include materials and supplies used for utility operations.

Intangibles

Intangibles include software, emission allowances and renewable energy credits. Emission allowances are carried on a first-in, first-out (FIFO) basis for purchased emission allowances. Net gains or losses on the sale of excess emission allowances, representing the difference between the sales proceeds and the cost of emission allowances, are recorded as a component of our fuel costs and are reflected in Operating income when realized. Emission allowances are amortized as they are used in our operations on a FIFO basis. Renewable energy credits are carried on a weighted average cost basis and amortized as they are used or retired.

Software is amortized over seven years. Amortization expense was $6.3 million, $5.7 million and $6.7 million for the years ended December 31, 2018, 2017 and 2016, respectively. The estimated amortization expense of this internal-use software over the next five years is $11.1 million ($3.5 million in 2019, $2.4 million in 2020, $2.2 million in 2021, $1.8 million in 2022 and $1.2 million in 2023).

Income Taxes

Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of the existing assets and liabilities, and their respective income tax bases. We establish an allowance when it is more likely than not that all or a portion of a deferred tax asset will not be realized. Our tax positions are evaluated under a more likely than not recognition threshold and measurement analysis before they are recognized for financial statement reporting. Uncertain tax positions have been classified as noncurrent income tax liabilities unless expected to be paid within one year. Our policy for interest and penalties is to recognize interest and penalties as a component of the provision for income taxes in the Statement of Operations.

Income taxes payable, which are includable in allowable costs for ratemaking purposes in future years, are recorded as regulatory assets or liability with a corresponding deferred tax liability or asset. Investment tax credits that reduced federal income taxes in the years they arose have been deferred and are being amortized to income over the useful lives of the properties in accordance with regulatory treatment See Note 3 – Regulatory Matters for additional information.

DP&L files U.S. federal income tax returns as part of the consolidated U.S. income tax return filed by AES. The consolidated tax liability is allocated to each subsidiary based on the separate return method which is specified in our tax allocation agreement and which provides a consistent, systematic and rational approach See Note 8 – Income Taxes for additional information.

Financial Instruments

Assets and liabilities held-for-sale, policy [Policy Text Block]

Assets and liabilities related to a business classified as held-for-sale are segregated in the current balance sheet in the period in which the business is classified as held-for-sale. Assets and liabilities of held-for-sale businesses are classified as current when they are expected to be disposed of within twelve months. Transactions between the business held-for-sale and businesses that are expected to continue to exist after the disposal are not eliminated to appropriately reflect the continuing operations and balances held-for-sale. See Note 14 – Generation Separation

Accounting for Taxes Collected from Customers and Remitted to Governmental Authorities

Accounting for Taxes Collected from Customers and Remitted to Governmental Authorities

DP&L collects certain excise taxes levied by state or local governments from its customers. These taxes are accounted for on a net basis and not included in revenue. The amounts of such taxes collected for the three months ended September 30, 2019 and 2018 were $13.0 million and $13.8 million, respectively. The amounts of such taxes collected for the nine months ended September 30, 2019 and 2018 were $37.3 million and $39.2 million, respectively.

, 2017 and 2016 were $51.7 million, $49.4 million and $50.9 million, respectively.

Cash and Cash Equivalents

Cash and cash equivalents are stated at cost, which approximates fair value. All highly liquid short-term investments with original maturities of three months or less are considered cash equivalents.

Restricted Cash

Restricted cash includes cash which is restricted as to withdrawal or usage. The nature of the restrictions includes restrictions imposed by agreements related to deposits held as collateral and cash collected under the DMR which is restricted to pay debt obligations at DPL and DP&L and position DP&L to modernize and/or maintain its transmission and distribution infrastructure.

The following table provides a summary of cash, cash equivalents, and restricted cash amounts reported on the Balance Sheet that reconcile to the total of such amounts as shown on the Statements of Cash Flows:

$ in millions	December 31, 2018		December 31, 2017
Cash and cash equivalents	$	45.0	$	5.2
Restricted cash	21.2		0.4
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	66.2	$	5.6

Financial Derivatives

All derivatives are recognized as either assets or liabilities in the balance sheets and are measured at fair value. Changes in the fair value are recorded in earnings unless the derivative is designated as a cash flow hedge of a forecasted transaction.

We use interest rate hedges to manage the interest rate risk of our variable rate debt. We use cash flow hedge accounting when the hedge or a portion of the hedge is deemed to be highly effective, which results in changes in fair value being recorded within accumulated other comprehensive income, a component of shareholder’s equity. We have elected not to offset net derivative positions in the financial statements. Accordingly, we do not offset such derivative positions against the fair value of amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral under master netting agreements. See Note 6 – Derivative Instruments and Hedging Activities for additional information.

Insurance and Claims Costs

In addition to insurance obtained from third-party providers, MVIC, a wholly-owned captive subsidiary of DPL, provides insurance coverage solely to us and other DPL subsidiaries for workers’ compensation, general liability, and property damage on an ongoing basis. DP&L is responsible for claims costs below certain coverage thresholds of MVIC and third-party insurers for the insurance coverage noted above. DP&L has estimated liabilities for medical, life, disability, and other reserves for claims costs below certain coverage thresholds of third-party providers of approximately $4.3 million and $4.4 million at December 31, 2018 and 2017, respectively, within Other current liabilities and Other deferred credits on the balance sheets. The estimated liabilities for workers’ compensation, medical, life and disability costs at DP&L

Pension and Postretirement Benefits

We recognize in our Balance Sheets an asset or liability reflecting the funded status of pension and other postretirement plans with current-year changes from actuarial gains or losses related to our regulated operations, that would otherwise be recognized in AOCI, recorded as a regulatory asset as this can be recovered through future rates. Such changes that are not related to our regulated operations are recognized in AOCI. All plan assets are recorded at fair value. We follow the measurement date provisions of the accounting guidance, which require a year-end measurement date of plan assets and obligations for all defined benefit plans.

We account for and disclose pension and postretirement benefits in accordance with the provisions of GAAP relating to the accounting for pension and other postretirement plans. These GAAP provisions require the use of assumptions, such as the discount rate for liabilities and long-term rate of return on assets, in determining the obligations, annual cost and funding requirements of the plans. Consistent with the requirements of FASC 715, we apply a disaggregated discount rate approach for determining service cost and interest cost for our defined benefit pension plans and postretirement plans.

See Note 9 – Benefit Plans for more information.

Related Party Transactions

In the normal course of business, DP&L enters into transactions with other subsidiaries of DPL or AES. See Note 12 – Related Party Transactions for additional information on Related Party Transactions

Recently Issued Accounting Standards

New accounting pronouncements adopted in 2019 – The following table provides a brief description of recently adopted accounting pronouncements that had an impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or did not have a material impact on our financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
2018-02, Income Statement — Reporting Comprehensive Income (Topic 220), Reclassification of Certain Tax Effects from AOCI	This amendment allows a reclassification of the stranded tax effects resulting from the implementation of the Tax Cuts and Jobs Act from AOCI to retained earnings at the election of the filer. Because this amendment only relates to the reclassification of the income tax effects of the Tax Cuts and Jobs Act, the underlying guidance that requires that the effect of a change in tax laws or rates be included in income from continuing operations is not affected.	January 1, 2019	We have not elected to reclassify any amounts to retained earnings. Our accounting policy for releasing the income tax effects from AOCI occurs on a portfolio basis.
2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities	The standard updates the hedge accounting model to expand the ability to hedge nonfinancial and financial risk components, reduce complexity, and ease certain documentation and assessment requirements. When facts and circumstances are the same as at the previous quantitative test, a subsequent quantitative effectiveness test is not required. The standard also eliminates the requirement to separately measure and report hedge ineffectiveness. For cash flow hedges, this means that the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item. Transition method: modified retrospective with the cumulative effect adjustment recorded to the opening balance of retained earnings as of the initial application date. Prospective for presentation and disclosures.	January 1, 2019	The adoption of this standard had no material impact on our condensed financial statements.
2016-02, 2018-01, 2018-10, 2018-11 Leases (Topic 842)	See "Adoption of FASC Topic 842, Leases" below.	January 1, 2019	See impact upon adoption of the standard below.

Adoption of FASC Topic 842, "Leases"

On January 1, 2019, we adopted ASU 2016-02 Leases and its subsequent corresponding updates (“FASC 842”). Under this standard, lessees are required to recognize assets and liabilities for most leases and recognize expenses in a manner similar to the current accounting method. For lessors, the guidance modifies the lease classification criteria and the accounting for sales-type and direct financing leases. The guidance eliminates current real estate-specific provisions.

Under FASC 842, it is expected that fewer contracts will contain a lease. However, due to the elimination of the real estate-specific guidance and changes to certain lessor classification criteria, more leases will qualify as sales-type leases and direct financing leases. Under these two models, a lessor will derecognize the asset and will recognize a net investment in a lease. According to FASC 842, the net investment in the lease includes the fair value of the

plant after the contract period but does not include variable payments such as margin on the sale of energy. Therefore, the net investment in the lease could be significantly different than the carrying amount of the underlying asset at lease commencement. In such circumstances, the difference between the initially recognized net investment in the lease and the carrying amount of the underlying asset is recognized as a gain/loss at lease commencement.

During the course of adopting FASC 842, we applied various practical expedients including:

• The package of practical expedients (applied to all leases) that allowed lessees and lessors not to reassess:

a. whether any expired or existing contracts are or contain leases,

b. lease classification for any expired or existing leases, and

c. whether initial direct costs for any expired or existing leases qualify for capitalization under FASC 842.

• The transition practical expedient related to land easements, allowing us to carry forward our accounting treatment for land easements on existing agreements, and

• The transition practical expedient for lessees that allowed businesses to not separate lease and non-lease components. We applied the practical expedient to all classes of underlying assets when valuing right-of-use assets and lease liabilities. Contracts where we are the lessor were separated between the lease and non-lease components.

We applied the modified retrospective method of adoption and elected to continue to apply the guidance in FASC 840 Leases to the comparative periods presented in the year of adoption. Under this transition method, we applied the transition provisions starting at the date of adoption.

The adoption of FASC 842 did not have a material impact on our Condensed Financial Statements.

New Accounting Pronouncements Issued But Not Yet Effective – The following table provides a brief description of recent accounting pronouncements that could have a material impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or are expected to have no material impact on our financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
2016-13, 2019-04, 2019-05, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	See discussion of the ASU below.	January 1, 2020	We will adopt the standard on January 1, 2020; see below for the evaluation of the impact of the adoption on the condensed financial statements.

ASU 2016-13 and its subsequent corresponding updates will update the impairment model for financial assets measured at amortized cost. For trade and other receivables, held-to-maturity debt securities, loans and other instruments, entities will be required to use a new forward-looking "expected loss" model that generally will result in the earlier recognition of allowance for losses. For available-for-sale debt securities with unrealized losses, entities will measure credit losses as it is done today, except that the losses will be recognized as an allowance rather than a reduction in the amortized cost of the securities. There are various transition methods available upon adoption.

We are currently evaluating the impact of adopting the standard on our condensed financial statements; however, it is expected that the new current expected credit loss model will primarily impact the calculation of expected credit losses on $72.1 million in gross trade accounts receivable.

The following table provides a brief description of recently adopted accounting pronouncements that had an impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or did not have a material impact on our financial statements.

Accounting Standard	Description	Date of Adoption	Effect on the financial statements upon adoption
New Accounting Standards Adopted
2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract	This standard aligns the accounting for implementation costs incurred for a cloud computing arrangement that is a service with the requirement for capitalizing implementation costs associated with developing or obtaining internal-use software. Transition method: retrospective or prospective.	October 1, 2018	We elected to early-adopt this standard on a prospective basis, effective for fiscal year 2018. The adoption of this standard did not have a material impact on our financial statements.
2018-14, Compensation— Retirement Benefits — Defined Benefit Plans — General (Subtopic 715-20): Disclosure Framework	This standard modifies the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. Transition method: retrospective.	Early adoption elected, January 1, 2018	Impact limited to changes in financial statement disclosures.
2017-07, Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost	This standard changes the presentation of non-service costs associated with defined benefit plans and updates the guidance so that only the service cost component will be eligible for capitalization. Transition method: retrospective for presentation of non-service cost and prospective for the change in capitalization.	January 1, 2018	For the years ended December 31, 2017 and 2016 we reclassified non-service pension costs from Operating expenses to Other expense of ($1.5) million and ($0.9) million, respectively.
2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force)	This standard requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Transition method: retrospective.	January 1, 2018	For the years ended December 31, 2017 and 2016, we reclassified from "Net cash used in investing activities" to "Net increase / (decrease) in cash, cash equivalents and restricted cash" $26.6 million and ($11.9) million, respectively.
2016-01, Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities	The standard significantly revises an entity’s accounting related to (1) classification and measurement of investments in equity securities and (2) the presentation of certain fair value changes for financial liabilities measured at fair value. It also amends certain disclosures of financial instruments. Transition method: modified retrospective. Prospective for equity investments without readily determinable fair value.	January 1, 2018	We adopted this standard January 1, 2018. At that date, we transferred $1.7 million ($1.1 million net of tax) of unrealized gains from AOCI to Retained Earnings.
2014-09, 2015-14, 2016-08, 2016-10, 2016-12, 2016-20, 2017-10, 2017-13, Revenue from Contracts with Customers (Topic 606)	See discussion of the ASU below.	January 1, 2018	See impact upon adoption of the standard below.

Adoption of FASC Topic 606, "Revenue from Contracts with Customers"

On January 1, 2018, we adopted ASU 2014-09, "Revenue from Contracts with Customers", and its subsequent corresponding updates ("FASC 606"). The core principle of this standard is that an entity shall recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. We applied the modified retrospective method of adoption to those contracts which were not completed as of January 1, 2018. Results for reporting periods beginning January 1, 2018 are presented under FASC 606, while prior period amounts were not adjusted and continue to be reported in accordance with our historic accounting under the previous revenue recognition standard. For contracts that were modified before January 1, 2018, we have not retrospectively restated the contracts for modifications. We instead reflected the aggregate effect of all modifications when identifying the satisfied and unsatisfied performance obligations, determining the transaction price and allocating the transaction price. We do not expect the adoption of the new revenue standard to have a material impact to our net income on an ongoing basis.

There was no cumulative effect to our January 1, 2018 Balance Sheet resulting from the adoption of FASC 606.

New accounting pronouncements issued but not yet effective - The following table provides a brief description of recent accounting pronouncements that could have a material impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or are expected to have no material impact on our financial statements.

Accounting Standard	Description	Date of Adoption	Effect on the financial statements upon adoption
New Accounting Standards Issued but Not Yet Effective
2018-02, Income Statement - Reporting Comprehensive Income (Topic 220), Reclassification of Certain Tax Effects from AOCI	This amendment allows a reclassification of the stranded tax effects resulting from the implementation of the Tax Cuts and Jobs Act from AOCI to retained earnings. Because this amendment only relates to the reclassification of the income tax effects of the Tax Cuts and Jobs Act, the underlying guidance that requires that the effect of a change in tax laws or rates be included in income from continuing operations is not affected.	January 1, 2019. Early adoption is permitted.	We do not expect any impact on our financial statements upon adoption of the standard on January 1, 2019.
2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities	The standard updates the hedge accounting model to expand the ability to hedge nonfinancial and financial risk components, reduce complexity, and ease certain documentation and assessment requirements. When facts and circumstances are the same as at the previous quantitative test, a subsequent quantitative effectiveness test is not required. The standard also eliminates the requirement to separately measure and report hedge ineffectiveness. For cash flow hedges, this means that the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item in the period in which it settles. Transition method: modified retrospective with the cumulative effect adjustment recorded to the opening balance of retained earnings as of the initial application date. Prospective for presentation and disclosures.	January 1, 2019. Early adoption is permitted.	We are currently evaluating the impact of adopting the standard on our financial statements.
2018-19, 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	The standard updates the impairment model for financial assets measured at amortized cost. For trade and other receivables, held-to-maturity debt securities, loans and other instruments, entities will be required to use a new forward-looking "expected loss" model that generally will result in the earlier recognition of allowance for losses. For available-for-sale debt securities with unrealized losses, entities will measure credit losses as it is done today, except that the losses will be recognized as an allowance rather than a reduction in the amortized cost of the securities. Transition method: various.	January 1, 2020. Early adoption is permitted only as of January 1, 2019.	We are currently evaluating the impact of adopting the standard on our financial statements.
2016-02, 2018-01, 2018-10, 2018-11, 2018-20 Leases (Topic 842)	See discussion of the ASU below.	January 1, 2019. Early adoption is permitted.	We will adopt the standard on January 1, 2019; see below for the evaluation of the impact of its adoption on our financial statements.

Adoption of FASC Topic 842, "Leases"

ASU 2016-02 and its subsequent corresponding updates require lessees to recognize assets and liabilities for most leases but recognize expenses in a manner similar to today’s accounting. For lessors, the guidance modifies the lease classification criteria and the accounting for sales-type and direct financing leases. The guidance also eliminates today’s real estate-specific provisions.

The standard must be adopted using a modified retrospective approach. The FASB has provided an optional transition method, which we have elected, that allows entities to continue to apply the guidance in FASC 840 Leases to the comparative periods presented in the year of adoption. Under this transition method, we will apply the transition provisions starting on January 1, 2019.

We have elected to apply a package of practical expedients that allow lessees and lessors not to reassess: (1) whether any expired or existing contracts are or contain leases, (2) lease classification for any expired or existing leases, and (3) whether initial direct costs for any expired or existing leases qualify for capitalization under FASC 842. These three practical expedients must be elected as a package and must be consistently applied to all leases. We have also elected to apply an optional transition practical expedient for land easements that allows an entity to

continue applying its current accounting policy for all land easements that exist before the standard’s effective date that were not previously accounted for under FASC 840.

We established a task force focused on the identification of contracts that would be under the scope of the new standard and on the assessment and measurement of the right-of-use assets and related liabilities. Additionally, the implementation team has been working on the configuration of a lease accounting tool that will support the implementation and the subsequent accounting. The implementation team has also evaluated changes to our business processes, systems and controls to support recognition and disclosure under the new standard.

Under FASC 842, it is expected that fewer contracts will contain a lease. However, due to the elimination of the real estate-specific guidance and changes to certain lessor classification criteria, more leases will qualify as sales-type leases and direct financing leases. Under these two models, a lessor will derecognize the asset and will recognize a lease receivable. According to FASC 842, the lease receivable includes the fair value of the plant after the contract period but does not include any variable payments such as margin on the sale of energy. Therefore, the lease receivable could be significantly different than the carrying amount of the underlying asset at lease commencement. In such circumstances, the difference between the initially recognized lease receivable and the carrying amount of the underlying asset is recognized as a gain/loss at lease commencement.

The adoption of FASC 842 did not have a material impact on our financial statements.

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Discontinued Operations

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Discontinued Operations

Dispositions

Beckjord Facility – On February 26, 2018, DP&L and its co-owners of the retired Beckjord Facility agreed to transfer their interests in the retired Facility to a third party, including their obligations to remediate the Facility and its site, and the transfer occurred on that same date. As a result, DP&L recognized a loss on the transfer of $12.4 million and made cash expenditures of $14.5 million, inclusive of cash expenditures for the transfer charges. The Beckjord Facility was retired in 2014, and, as such, the income / (loss) from continuing operations before income tax related to the Beckjord Facility was immaterial for the three and nine months ended September 30, 2018, excluding the loss on transfer noted above.

On October 1, 2017, DP&L completed the transfer of its generating plants, the real property on which the generation plants and generation-related assets are sited, step-up transformers and other transmission plant assets used to interconnect with the electric transmission grid, fuel inventory, equipment inventory and spare parts, working capital, and other miscellaneous generation-related assets and liabilities to AES Ohio Generation. The transfer was completed as a contribution through an asset contribution agreement to a wholly-owned subsidiary of DP&L after which DP&L then distributed all of the outstanding equity in the subsidiary to DPL and then the subsidiary was merged into AES Ohio Generation.

The following table summarizes the carrying amounts of DP&L's Generation assets that were transferred to AES Ohio Generation on October 1, 2017:

$ in millions	October 1, 2017
ASSETS
Restricted cash	$	2.0
Accounts receivable, net	31.3
Inventories	42.0
Taxes applicable to subsequent years	1.8
Property, plant & equipment, net	87.0
Intangible assets, net	0.7
Other assets	15.5
Total assets	$	180.3
LIABILITIES
Accounts payable	$	12.4
Accrued taxes (b)	(3.9		)
Long-term debt (a)	0.3
Deferred taxes (b)	(91.9		)
Pension, retiree and other benefits	9.6
Unamortized investment tax credit	15.1
Asset retirement obligations	126.3
Other liabilities	24.1
Total liabilities	$	92.0
Total accumulated other comprehensive income	2.1
Net assets transferred to AES Ohio Generation	$	86.2

(a) Long-term debt that transferred to AES Ohio Generation relates to capital leases.

(b) Accrued taxes and deferred taxes transferred to AES Ohio Generation represent the tax asset position netted with liabilities on DP&L prior to Generation Separation.

DP&L's generation business met the criteria to be classified as a discontinued operation, and, accordingly, the historical activity has been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016.

The following table summarizes the revenues, cost of revenues, operating and other expenses and income tax of discontinued operations for the periods indicated:

	Years ended December 31,
$ in millions	2017			2016
Revenues	$	358.4		$	557.9
Cost of revenues	(191.6		)	(341.1		)
Operating and other expenses	(156.8		)	(202.0		)
Fixed-asset impairment	(66.3		)	(1,353.5		)
Loss from discontinued operations	(56.3		)	(1,338.7		)
Income tax benefit from discontinued operations	(15.9		)	(468.4		)
Net loss from discontinued operations	$	(40.4	)	$	(870.3	)

In 2018, DP&L transferred additional deferred taxes to AES Ohio Generation under the provisions of SAB 118 through an equity transaction with DPL in the amount of $10.0 million. See Note 8 – Income Taxes for additional information.

Cash flows related to discontinued operations are included in the Statements of Cash Flows. Cash flows from operating activities for discontinued operations were $21.8 million and $29.9 million for the years ended December 31, 2017 and 2016, respectively. Cash flows from investing activities for discontinued operations were $(3.5) million and $(39.0) million for the years ended December 31, 2017 and 2016, respectively.

The PUCO authorized DP&L to maintain long-term debt of $750 million or 75% of its rate base, whichever is greater, until January 1, 2018, or to file an application to explain why it would not achieve those metrics. Accordingly, $750.0 million of debt and the pro rata interest expense associated with that debt were allocated to continuing operations. All remaining interest expense is included in discontinued operations above. The interest expense included in discontinued operations was $0.2 million and $0.5 million for the years ended December 31, 2017 and 2016, respectively.

Beckjord Facility – On February 26, 2018, DP&L and its co-owners of the retired Beckjord Facility agreed to transfer their interests in the retired Facility to a third party, including their obligations to remediate the Facility and its site, and the transfer occurred on that same date. As a result, DP&L recognized a loss on the transfer of $12.4 million and made cash expenditures of $14.5 million, inclusive of cash expenditures for the transfer charges. The Beckjord Facility was retired in 2014, and, as such, the income / (loss) from continuing operations before income tax related to the Beckjord Facility was immaterial for the years ended December 31, 2018, 2017 and 2016, excluding the loss on transfer noted above.

XML

Overview and Summary of Significant Accounting Policies (Narrative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] $ in Millions			3 Months Ended		9 Months Ended		12 Months Ended
	Jan. 31, 2019 employee	Jan. 01, 2018 USD ($)	Sep. 30, 2019 USD ($) employee	Sep. 30, 2018 USD ($)	Sep. 30, 2019 USD ($) mi² employee customer segment	Sep. 30, 2018 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($) mi² customer	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Jun. 30, 2018 USD ($)	Dec. 31, 2015 USD ($)
Significant Accounting Policies [Line Items]
Cash and Cash Equivalents, at Carrying Value			$ 14.4		$ 14.4			$ 45.0	$ 5.2
Restricted Cash and Cash Equivalents, Current			$ 17.6		17.6			21.2	0.4
Payments of Ordinary Dividends, Common Stock					$ 90.0	$ 43.8		43.8	39.0	$ 70.0
Capitalized Software, estimated amortization expense for year after next								$ 2.4
Number of reportable segments | segment					1
Approximate number of retail customers | customer					524,000			525,000
Service area, square miles | mi²					6,000			6,000
Entity number of employees | employee			642		642
Capitalized interest for unregulated generation property								$ 0.5	$ 1.5	$ 2.0
Straight-line depreciation average annual composite basis (percent)								3.00%	3.40%	4.60%
Depreciation and amortization			$ 17.4	$ 19.1	$ 52.9	56.5		$ 74.5	$ 75.3	$ 71.0
Insurance costs below coverage thresholds of third-party providers								$ 4.3	4.4
Percentage Of Employees Under Collective Bargaining Agreement					58.00%
Finite-Lived Intangible Asset, Useful Life								7 years
Capitalized Computer Software, Amortization								$ 6.3	5.7	6.7
Capitalized Software, estimated amortization over remaining useful life								11.1
Capitalized Software, estimated amortization expense for next twelve months								3.5
Capitalized Software, estimated amortization expense for three years in the future								2.2
Capitalized Software, estimated amortization expense for four years in the future								1.8
Capitalized Software, estimated amortization expense for five years in the future								1.2
AOCI reclassed to Retained Earnings before tax		$ 1.7
AOCI reclassed to Retained Earnings, net of tax		$ 1.1						(1.1)
Restricted Cash and Cash Equivalents			32.0		$ 32.0			66.2	5.6	1.6	$ 12.7	$ 5.4
Subsequent Event [Member]
Significant Accounting Policies [Line Items]
Entity number of employees | employee	647
Percentage Of Employees Under Collective Bargaining Agreement	58.00%
Electric Generation, Transmission and Distribution Equipment [Member]
Significant Accounting Policies [Line Items]
Depreciation and amortization								68.2	69.6	64.3
Pension [Member]
Significant Accounting Policies [Line Items]
Service cost			0.9	1.5	2.7	4.5		6.1	5.7	5.7
Interest cost			3.7	$ 3.4	11.2	10.3		13.8	14.2	14.7
Pension [Member] | Scenario, Forecast [Member]
Significant Accounting Policies [Line Items]
Service cost							$ 5.4
Accounting Standards Update 2016-13 [Member]
Significant Accounting Policies [Line Items]
Accounts Receivable, before Allowance for Credit Loss, Current			$ 72.1		$ 72.1
Adjustments for New Accounting Pronouncement [Member]
Significant Accounting Policies [Line Items]
Non-service Pension Costs									(1.5)	(0.9)
Increase (Decrease) in Restricted Cash									$ 26.6	$ (11.9)
AOCI reclassed to Retained Earnings before tax						1.7		1.7
AOCI reclassed to Retained Earnings, net of tax						$ 1.1		$ 1.1

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Supplemental Financial Information (Accumulated Other Comprehensive Income) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions		3 Months Ended						9 Months Ended		12 Months Ended
	Jan. 01, 2018	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other deductions		$ (6.6)			$ (6.2)			$ (19.8)	$ (23.0)	$ (30.7)	$ (33.6)	$ (25.4)
AOCI reclassed to Retained Earnings before tax	$ 1.7
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	(36.2)			$ (35.3)			$ (36.2)	(35.3)	(36.2)	(36.2)	(42.5)
Other comprehensive income / (loss) before reclassifications								(0.9)		(0.6)	10.2
Stockholders' Equity Note, Spinoff Transaction											(2.1)
Amounts reclassified from accumulated other comprehensive income / (loss)								2.0		2.6	(1.8)
Other comprehensive income / (loss)		1.6			0.6	$ 0.8		1.1	2.5	2.0	8.4	(13.8)
Balance, end of period		(34.2)						(34.2)		(35.3)	(36.2)	(42.5)
AOCI reclassed to Retained Earnings, net of tax	1.1									(1.1)
Income Tax Expense (Benefit)		(7.2)			6.3			5.1	12.0	17.7	31.1	46.0
Net income (loss)		44.9			31.2			103.7	61.9	86.7	17.0	(772.7)
Interest and Debt Expense		6.1			5.8			19.9	20.5	27.3	30.5	24.7
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax										0.0	(56.3)	(1,338.7)
Income tax expense / (benefit) from discontinued operations										0.0	(15.9)	(468.4)
Revenues		191.1			198.7			570.2	563.5	738.7
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	1.1			0.0			1.1	0.0	1.1	1.1	0.7
Other comprehensive income / (loss) before reclassifications										0.0	0.5
Stockholders' Equity Note, Spinoff Transaction											0.0
Amounts reclassified from accumulated other comprehensive income / (loss)										0.0	(0.1)
Other comprehensive income / (loss)										0.0	0.4
Balance, end of period										0.0	1.1	0.7
AOCI reclassed to Retained Earnings, net of tax										(1.1)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	1.4			0.6			1.4	0.6	1.4	1.4	(2.7)
Other comprehensive income / (loss) before reclassifications								(0.9)		(0.1)	12.4
Stockholders' Equity Note, Spinoff Transaction											2.1
Amounts reclassified from accumulated other comprehensive income / (loss)								(0.1)		(0.7)	(6.2)
Other comprehensive income / (loss)								(1.0)		(0.8)	6.2
Balance, end of period		(0.4)						(0.4)		0.6	1.4	(2.7)
AOCI reclassed to Retained Earnings, net of tax										0.0
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	$ (38.7)			(35.9)			(38.7)	(35.9)	(38.7)	(38.7)	(40.5)
Other comprehensive income / (loss) before reclassifications								0.0		(0.5)	(2.7)
Stockholders' Equity Note, Spinoff Transaction											0.0
Amounts reclassified from accumulated other comprehensive income / (loss)								2.1		3.3	4.5
Other comprehensive income / (loss)								2.1		2.8	1.8
Balance, end of period		(33.8)						(33.8)		(35.9)	(38.7)	(40.5)
AOCI reclassed to Retained Earnings, net of tax										0.0
Accumulated Other Comprehensive Income/(Loss) [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income / (loss)			$ (0.9)	$ 0.4			$ 1.1
Adjustments for New Accounting Pronouncement [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI reclassed to Retained Earnings before tax									1.7	1.7
AOCI Attributable to Parent, Net of Tax [Roll Forward]
AOCI reclassed to Retained Earnings, net of tax									1.1	1.1
Reclassification out of Accumulated Other Comprehensive Income [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Net income (loss)		1.7			0.6			2.0	2.0	2.6	(1.8)	(24.1)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other deductions										0.0	(0.1)	0.0
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Income Tax Expense (Benefit)										0.0	0.0	0.0
Net income (loss)										0.0	(0.1)	0.0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Income Tax Expense (Benefit)		0.0			(0.1)			0.0	(0.6)	(0.4)	(0.2)	(0.2)
Net income (loss)		0.0			(0.2)			(0.1)	(0.5)	(0.7)	(0.7)	(0.8)
Interest and Debt Expense		0.0			0.3			0.1	1.1	1.1	0.9	1.0
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax										0.0	(8.5)	(45.4)
Income tax expense / (benefit) from discontinued operations										0.0	(3.0)	(16.2)
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax										0.0	(5.5)	(29.2)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other deductions		0.8			1.0			2.6	3.2	4.3	6.8	7.7
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Income Tax Expense (Benefit)		(0.9)			0.2			0.5	0.7	1.0	2.3	1.8
Net income (loss)		$ 1.7			$ 0.8			$ 2.1	$ 2.5	3.3	4.5	5.9
Electricity [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Revenues										738.7	720.0	808.0
Cost of Goods and Services Sold										303.7	290.3	322.0
Electricity, Purchased [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Cost of Goods and Services Sold										$ 301.3	$ 289.8	$ 316.7

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Income Taxes (Effective and Statutory Rate Reconciliation) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member]	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Entity Information [Line Items]
Effective Income Tax Rate Reconciliation, Including Discontinued Operations, Percent	(19.10%)		4.70%
Estimated Annual Effective Income Tax Rate, Continuing Operations			4.50%	17.10%	21.00%	35.00%
Statutory Federal tax rate					21.00%	35.00%	35.00%
State taxes, net of Federal tax benefit					0.60%	0.40%	0.30%
Depreciation of flow-through differences					(0.10%)	1.40%	2.10%
Effective Income Tax Rate Reconciliation, Tax Credit, Investment, Percent					(0.30%)	(0.40%)	(0.30%)
Effective Income Tax Rate Reconciliation, Depreciation of flow-through years					(4.00%)	0.00%	0.00%
Other, net					(0.20%)	(1.30%)	(5.10%)
Effective tax rate		16.80%		16.20%	17.00%	35.10%	32.00%
Effective Income Tax Rate Reconciliation, at Combined Federal and State Statutory Income Tax Rate, Percent			21.60%

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Debt (Narrative) (Details) $ in Millions		6 Months Ended		9 Months Ended		12 Months Ended
	Jun. 06, 2019 USD ($)	Dec. 31, 2018 USD ($) fiscal_quarter	Jul. 03, 2018	Sep. 30, 2019 USD ($) fiscal_quarter debt_covenant	Sep. 30, 2018 USD ($) debt_covenant	Dec. 31, 2018 USD ($) fiscal_quarter	Sep. 30, 2018 USD ($) debt_covenant	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Jan. 03, 2018	Aug. 03, 2015 USD ($)
THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity				$ 175.0
Current portion - long-term debt		$ 4.6				$ 4.6
Letter of credit sublimit				75.0
Line of credit facility, additional borrowing capacity				100.0
Proceeds from Issuance of Long-term Debt				422.3	$ 0.0	0.0		$ 0.0	$ 442.8
Unamortized Deferred Financing Costs								(9.8)
Current portion - long-term debt		4.6		$ 139.6		$ 4.6		4.6
Debt Covenant, Interest Coverage Ratio, Minimum				2.50		2.50
Debt Covenant, Total Debt to Total Capitalization Ratio, Maximum						0.65
Long Term Indebtedness, Less than or Equal to						$ 750.0	$ 750.0	750.0
Long-term Debt, Excluding Current Maturities		581.5		$ 434.6		581.5		642.0
Long-term Debt, Maturities, Repayments of Principal in Year Two		144.7				144.7
3.95% Senior Notes due 2049 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt	$ 425.0
Long-term Debt, Gross				$ 425.0
Extinguishment of debt, amount	$ 435.0
Debt instrument interest percentage				3.95%
Term Loan Maturing 2022 (DPL) [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 436.1				$ 436.1		440.6
Eurodollar rate Term Loan B [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage		3.25%				3.25%				2.00%
Base Rate Term Loan B [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage		2.25%				2.25%				1.00%
Revolving Credit Agreement and Standby Letters of Credit [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Number of financial covenants | debt_covenant				2	2		2
Number of prior quarters included in debt to EBITDA ratio | fiscal_quarter		4		4		4
Interest Coverage Ratio				9.36		8.09
U.S. Government note maturing in 2061 - 4.20% [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage				4.20%
U.S. Government note maturing in 2061 - 4.20% [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 17.7		$ 17.6		$ 17.7		17.8
Debt instrument interest percentage		4.20%				4.20%
Term Loan Maturing 2022 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 436.1		$ 0.0		$ 436.1
Early prepayment rate			101.00%
Standard Repayment Rate		100.00%
First Mortgage Bonds [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt Covenant, Total Debt to Total Capitalization Ratio, Maximum				0.65			0.75
Variable Rate Notes Backed by Term Loan and First Mortgage Bonds [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 140.0		$ 140.0		140.0
Extinguishment of debt, amount				60.0		60.0
Debt Instrument, Face Amount											$ 200.0
One Point One Three To One Point One Seven Bonds Maturing In August Two Thousand Twenty [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		140.0		$ 140.0		140.0		200.0
Revolving Credit Facility [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt Covenant, Total Debt to Total Capitalization Ratio, Maximum				0.67
Total Debt to Total Capitalization Ratio				0.58
Debt [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities		$ 586.1				$ 586.1		$ 646.6
Minimum [Member] | Term Loan Maturing 2022 [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage		4.01%				4.01%
Debt Instrument, Interest Rate, Effective Percentage				4.50%
Minimum [Member] | Pollution control series maturing in November 2040 - variable rates: 0.04% - 0.26% and 0.06% - 0.32% [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage				2.97%
Minimum [Member] | Variable Rate Notes Backed by Term Loan and First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage		1.52%				1.52%
Maximum [Member] | Term Loan Maturing 2022 [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage				4.53%
Debt Instrument, Interest Rate, Effective Percentage		4.60%				4.60%
Maximum [Member] | Pollution control series maturing in November 2040 - variable rates: 0.04% - 0.26% and 0.06% - 0.32% [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage				3.07%
Maximum [Member] | Variable Rate Notes Backed by Term Loan and First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage		1.92%				1.92%

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Income Taxes (Narrative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Income Taxes [Line Items]
Tax rate before change due to Tax Cuts and Jobs Act of 2017	35.00%
Tax rate after Tax Cuts and Jobs Act of 2017	21.00%
Change in deferred tax regulatory asset/liability due to TCJA	$ 17.0	$ 135.2
Unrecognized tax benefits due to uncertainty in timing of deductibility	$ 4.8

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Derivative Instruments and Hedging Activities (Outstanding Derivative Instruments) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jun. 30, 2019	Jun. 30, 2018	Mar. 29, 2018	Dec. 31, 2015
Sale of Derivative Instruments Interest Rate Swap										$ (60.0)
Interest Rate Contract [Member]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	$ (0.4)	$ 1.4	$ (0.4)	$ 1.4	$ 0.6	$ 1.4	$ 1.6	$ (0.3)	$ 1.6		$ 2.0
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax	(0.1)	0.0	(0.9)	0.5	(0.1)	0.5	0.4
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net	(0.2)		$ (0.2)		$ 0.7
Maximum Length of Time Hedged in Cash Flow Hedge			11 months		20 months
Forward Contract Power [Member]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax						0.0	(4.3)				$ 9.2
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax						11.9	15.7
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]
Derivative, Notional Amount, Purchase (Sales), Net	140.0		$ 140.0		$ 140.0	200.0
Interest Expense [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	$ 0.0	$ (0.2)	$ (0.1)	$ (0.5)	$ (0.7)	$ (0.7)	$ (0.8)

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Fair Value Measurements (Fair Value and Cost of Non-Derivative Instruments) (Details) - Subsidiaries [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017
Long-term Debt	$ 574.2	$ 586.1
Carrying Value [Member]
Total Assets	6.8	7.1	$ 7.3
Carrying Value [Member] | Money Market Funds [Member]
Total Master Trust Assets, Cost	0.2	0.4	0.3
Carrying Value [Member] | Equity Securities [Member]
Total Master Trust Assets, Cost	2.3	2.4	2.5
Carrying Value [Member] | Debt Securities [Member]
Total Master Trust Assets, Cost	4.1	4.1	4.3
Carrying Value [Member] | Hedge Funds [Member]
Total Master Trust Assets, Cost	0.1	0.1	0.1
Carrying Value [Member] | Tangible Assets [Member]
Total Master Trust Assets, Cost	0.1	0.1	0.1
Carrying Value [Member] | Debt [Member]
Lines of Credit, Fair Value Disclosure	574.2	586.1
Long-term Debt		586.1	646.6
Fair Value [Member]
Total Master Trust Assets, Fair Value	8.4	8.1	9.1
Total Assets	8.4	8.1	9.1
Fair Value [Member] | Money Market Funds [Member]
Total Master Trust Assets, Fair Value	0.2	0.4	0.3
Fair Value [Member] | Equity Securities [Member]
Total Master Trust Assets, Fair Value	3.9	3.5	4.2
Fair Value [Member] | Debt Securities [Member]
Total Master Trust Assets, Fair Value	4.1	4.0	4.3
Fair Value [Member] | Hedge Funds [Member]
Total Master Trust Assets, Fair Value	0.1	0.1	0.2
Fair Value [Member] | Tangible Assets [Member]
Total Master Trust Assets, Fair Value	0.1	0.1	0.1
Fair Value [Member] | Debt [Member]
Long-term Debt, Fair Value	$ 631.0	$ 593.8	$ 658.4

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Assets and Liabilities Held-For-Sale and Dispositions (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	$ 37.7	$ 37.5	$ 108.8	$ 73.9	$ 104.4	$ 88.5	$ 143.6
Fixed-asset impairment (Note 14)					0.0	66.3	1,353.5
Gain (Loss) on Disposition of Business	$ 0.0	$ 0.0	$ 0.0	(12.4)	(12.4)	$ 0.0	$ 0.0
Beckjord [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest				(12.4)	(12.4)
Property, Plant and Equipment, Additions				$ 14.5	$ 14.5

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Benefit Plans (Estimated Future Benefit Payments and Medicare Part D Reimbursements) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - Pension [Member] $ in Millions	Dec. 31, 2018 USD ($)
2016	$ 26.7
2017	26.5
2018	26.3
2019	26.0
2020	25.9
2021 - 2025	$ 125.1

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Equity (Preferred Shares Outstanding) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member]	Dec. 31, 2018 $ / shares
DP&L Series A [Member]
Temporary Equity [Line Items]
Temporary Equity, Preferred Stock Rate	3.75%
Temporary Equity, Redemption Price Per Share	$ 102.50
DP&L Series B [Member]
Temporary Equity [Line Items]
Temporary Equity, Preferred Stock Rate	3.75%
Temporary Equity, Redemption Price Per Share	$ 103.00
DP&L Series C [Member]
Temporary Equity [Line Items]
Temporary Equity, Preferred Stock Rate	3.90%
Temporary Equity, Redemption Price Per Share	$ 101.00

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Benefit Plans (Narrative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Amount Billed to Service Company						$ 1,800,000	$ 1,100,000
Defined contribution plan, maximum annual contributions per employee (percent)						85.00%
Accumulated benefit obligation for our defined benefit pension plans						$ 378,700,000	428,300,000
Defined Benefit Plan, Amount Billed to AES Ohio Generation						$ 3,300,000	700,000
Defined Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan employee vested percentage						100.00%
Defined benefit plan, percent forfeited if terminated, other than by death or disability, prior to full vesting (percent)						100.00%
Management Employees [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan employee vested percentage						100.00%
Defined benefit plan, percent forfeited if terminated, other than by death or disability, prior to full vesting (percent)						100.00%
Pension [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Contributions by Employer			$ 7,500,000	$ 7,500,000		$ 7,900,000	5,400,000
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)						$ (34,600,000)	$ 28,100,000
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets						6.25%	6.50%	6.50%
Discount rate for obligations						4.35%	3.66%	4.28%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate						3.66%	4.28%	4.49%
Defined Benefit Plan, Plan Assets, Amount						$ 312,900,000	$ 357,500,000	$ 341,000,000.0
Service cost	$ 900,000	$ 1,500,000	2,700,000	4,500,000		6,100,000	5,700,000	5,700,000
Interest cost	3,700,000	$ 3,400,000	11,200,000	$ 10,300,000		13,800,000	14,200,000	$ 14,700,000
Defined Benefit Plan, Funded (Unfunded) Status of Plan						(73,600,000)	(79,400,000)
Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Funded (Unfunded) Status of Plan	$ 9,000,000		$ 9,000,000			$ 9,200,000	$ 12,700,000
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage						38.00%
Scenario, Forecast [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase in pension cost due to change in return on assets					$ 3,200,000
Decrease in pension cost due to change in return on assets					(3,200,000)
Decrease in pension cost due to change in discount rate					(100,000)
Increase in pension cost due to change in discount rate					400,000
Scenario, Forecast [Member] | Pension [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost					5,400,000
Defined Benefit Plan, Plan Assets, Administration Expense					$ 1,900,000
Scenario, Forecast [Member] | SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Allocation Percentage					101.00%
Estimated contribution to the defined benefit plans next year					$ 400,000
Non-union Participant [Member] | First 1% of Eligible Compensation [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined contribution plan, employer matching contribution (percent)						100.00%
Defined contribution plan, employer matching contribution, percent of employees' gross pay (percent)						1.00%
Non-union Participant [Member] | Next 5% of Eligible Compensation [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined contribution plan, employer matching contribution (percent)						50.00%
Defined contribution plan, employer matching contribution, percent of employees' gross pay (percent)						5.00%
Union Participant [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined contribution plan, employer matching contribution, percent of employees' gross pay (percent)						150.00%
Defined contribution plan, employer matching contribution cap						$ 2,400
Subsequent Event [Member] | Pension [Member]
Defined Benefit Plan Disclosure [Line Items]
Payment for Pension Benefits					$ 7,500,000
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets					6.25%
Subsequent Event [Member] | Increase in Expected Rate of Return [Member]
Defined Benefit Plan Disclosure [Line Items]
Change in Expected rate of return on plan assets					1.00%
Subsequent Event [Member] | Decrease in Expected Rate of Return [Member]
Defined Benefit Plan Disclosure [Line Items]
Change in Expected rate of return on plan assets					1.00%
Subsequent Event [Member] | Expected Increase in Discount Rate [Member]
Defined Benefit Plan Disclosure [Line Items]
Change in discount rate for plan assets					25.00%
Subsequent Event [Member] | Expected Decrease in Discount Rate [Member]
Defined Benefit Plan Disclosure [Line Items]
Change in discount rate for plan assets					25.00%
Minimum [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage						24.00%
Minimum [Member] | Fixed Income Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage						47.00%
Maximum [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage						52.00%
Maximum [Member] | Fixed Income Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage						65.00%

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Benefit Plans (Weighted Average Assumptions Used to Determine Benefit Obligations) (Details) - Pension [Member] - THE DAYTON POWER AND LIGHT COMPANY [Member]	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Discount rate for obligations	4.35%	3.66%	4.28%
Rate of compensation increases	3.94%	3.94%	3.94%

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Business Segments (Narrative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member]	9 Months Ended	12 Months Ended
	Sep. 30, 2019 mi² customer	Dec. 31, 2018 mi² customer
Segment Reporting Information [Line Items]
Approximate number of retail customers | customer	524,000	525,000
Service area, square miles | mi²	6,000	6,000

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Derivative Instruments and Hedging Activities

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

In the normal course of business, DP&L enters into interest rate hedges to manage the interest rate risk of our variable rate debt. All of our derivative instruments are used for risk management purposes and are designated as cash flow hedges if they qualify under FASC 815 for accounting purposes. In prior periods, we have used commodity derivatives principally to manage the risk of changes in market prices for commodities.

Cash Flow Hedges

As part of our risk management processes, we identify the relationships between hedging instruments and hedged items, as well as the risk management objective and strategy for undertaking various hedge transactions. The fair values of cash flow hedges determined by current public market prices will continue to fluctuate with changes in market prices up to contract expiration. With the adoption of ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities effective January 1, 2019, we will no longer be required to calculate effectiveness and thus the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item in the period in which it settles.

As of September 30, 2019, we have two interest rate swaps to hedge the variable interest on our $140.0 million variable interest rate tax-exempt First Mortgage Bonds. The interest rate swaps have a combined notional amount of $140.0 million and settle monthly based on a one-month LIBOR. On March 29, 2018, we settled $60.0 million of these interest rate swaps due to the partial repayment of the underlying debt and a gain of $0.8 million was recorded as a reduction to interest expense. Since the swap was partially settled, the remaining swaps were de-designated and then re-designated with a new hypothetical derivative. The AOCI associated with the remaining swaps will be amortized out of AOCI into interest expense over the remaining life of the underlying debt.

The following tables provide information concerning gains or losses recognized in AOCI for the cash flow hedges for the three and nine months ended September 30, 2019 and 2018:

	Three months ended
	September 30, 2019			September 30, 2018
	Interest			Interest
$ in millions (net of tax)	Rate Hedge			Rate Hedge
Beginning accumulated derivative gains / (losses) in AOCI	$	(0.3	)	$	1.6
Net losses associated with current period hedging transactions	(0.1		)	—
Net gains reclassified to earnings
Interest expense	—			(0.2		)
Ending accumulated derivative gains / (losses) in AOCI	$	(0.4	)	$	1.4
	Nine months ended
	September 30, 2019			September 30, 2018
	Interest			Interest
$ in millions (net of tax)	Rate Hedge			Rate Hedge
Beginning accumulated derivative gains in AOCI	$	0.6		$	1.4
Net gains / (losses) associated with current period hedging transactions	(0.9		)	0.5
Net gains reclassified to earnings
Interest expense	(0.1		)	(0.5		)
Ending accumulated derivative gains / (losses) in AOCI	$	(0.4	)	$	1.4
Portion expected to be reclassified to earnings in the next twelve months	$	(0.2	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	11

Net gains or losses associated with the ineffective portion of the hedging transactions were immaterial in the prior year period presented.

Financial Statement Effect

DP&L has elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivative agreements. The fair value derivative position of DP&L's interest rate swaps are as follows:

Fair Values of Derivative Instruments
at September 30, 2019
				Gross Amounts Not Offset in the Condensed Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Prepayments and other current assets)
Interest rate swap	Designated	$	0.2	$	—	$	—	$	0.2
Total assets		$	0.2	$	—	$	—	$	0.2

(a)    Includes credit valuation adjustment.

Fair Values of Derivative Instruments
at December 31, 2018
				Gross Amounts Not Offset in the Condensed Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Prepayments and other current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other non-current assets)
Interest rate swaps	Designated	0.6		—		—		0.6
Total assets		$	1.5	$	—	$	—	$	1.5

(a)    Includes credit valuation adjustment.

Any prior year ineffectiveness on the interest rate hedges and the monthly settlement of the interest rate hedges is recorded in interest expense within the Condensed Statements of Operations.

In the normal course of business, DP&L enters into various financial instruments, including derivative financial instruments. We use derivatives principally to manage the interest rate risk associated with our long-term debt. The derivatives that we use to economically hedge these risks are governed by our risk management policies for forward and futures contracts. Our net positions are continually assessed within our structured hedging programs to determine whether new or offsetting transactions are required. We monitor and value derivative positions monthly as part of our risk management processes. We use published sources for pricing, when possible, to mark positions to market. All of our derivative instruments are used for risk management purposes and are designated as cash flow hedges if they qualify under FASC 815 for accounting purposes.

DP&L's interest rate swaps are designated as a cash flow hedge. At December 31, 2018 and 2017, the principal balance of the interest rate hedges was $140.0 million and $200.0 million, respectively.

Cash Flow Hedges

As part of our risk management processes, we identify the relationships between hedging instruments and hedged items, as well as the risk management objective and strategy for undertaking various hedge transactions. The fair values of cash flow hedges determined by current public market prices will continue to fluctuate with changes in market prices up to contract expiration. The effective portion of the hedging transaction is recognized in AOCI and transferred to earnings using specific identification of each contract when the forecasted hedged transaction takes place or when the forecasted hedged transaction is probable of not occurring. The ineffective portion of the cash flow hedge is recognized in earnings in the current period. All risk components were considered to determine the hedge effectiveness of the cash flow hedges. With the adoption of ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities effective January 1, 2019, we will no longer be required to calculate effectiveness and thus the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item in the period in which it settles.

We have two interest rate swaps to hedge the variable interest on our $140.0 million variable interest rate tax-exempt First Mortgage Bonds. The interest rate swaps have a combined notional amount of $140.0 million and will settle monthly based on a one-month LIBOR. As of December 31, 2017, the interest rate swaps had a combined notional amount of $200.0 million. On March 29, 2018, we settled $60.0 million of these interest rate swaps due to the partial repayment of the underlying debt and a gain of $0.8 million was recorded as a reduction to interest expense. Since the swap was partially settled, the remaining swaps were de-designated and then re-designated with a new hypothetical derivative. The AOCI associated with the remaining swaps will be amortized out of AOCI into interest expense over the remaining life of the underlying debt.

We use the income approach to value the swaps, which consists of forecasting future cash flows based on contractual notional amounts and applicable and available market data as of the valuation date. The most common market data inputs used in the income approach include volatilities, spot and forward benchmark interest rates (LIBOR). Forward rates with the same tenor as the derivative instrument being valued are generally obtained from published sources, with these forward rates being assessed quarterly at a portfolio-level for reasonableness versus comparable published rates. We reclassify gains and losses on the swaps out of AOCI and into earnings in those periods in which hedged interest payments occur.

The following tables provide information on gains or losses recognized in AOCI for the cash flow hedges for the periods indicated:

	Years ended December 31,
	2018			2017						2016
$ in millions (net of tax)	Interest Rate Hedges			Power			Interest Rate Hedges			Power			Interest Rate Hedges
Beginning accumulated derivative gain / (loss) in AOCI	$	1.4		$	(4.3	)	$	1.6		$	9.2		$	2.0
Net gains / (losses) associated with current period hedging transactions	(0.1		)	11.9			0.5			15.7			0.4
Net gains / (losses) reclassified to earnings:
Interest expense	(0.7		)	—			(0.7		)	—			(0.8		)
Loss from discontinued operations	—			(5.5		)	—			(29.2		)	—
Transfer of generation assets to subsidiary of parent	—			(2.1		)	—			—			—
Ending accumulated derivative gain / (loss) in AOCI	$	0.6		$	—		$	1.4		$	(4.3	)	$	1.6
Portion expected to be reclassified to earnings in the next twelve months	$	0.7
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	20

Net gains or losses associated with the ineffective portion of the hedging transactions were immaterial in the periods presented.

DP&L has elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivative agreements. The fair value derivative position of DP&L's interest rate swaps are as follows:

			December 31,
	Hedging Designation	Balance sheet classification	2018		2017
Interest rate hedges in a Current asset position	Cash Flow Hedge	Other prepayments and current assets
Gross Fair Value as presented in the Balance Sheets			$	0.9	$	—
Interest rate hedges in a non-current asset position	Cash Flow Hedge	Other deferred assets
Gross Fair Value as presented in the Balance Sheets			$	0.6	$	1.5

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Supplemental Financial Information - THE DAYTON POWER AND LIGHT COMPANY [Member]

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Supplemental Financial Information [Line Items]

Supplemental Balance Sheet Disclosures [Text Block]

Supplemental Financial Information

Accounts receivable and Inventories are as follows at September 30, 2019 and December 31, 2018:

	September 30,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	50.0		$	53.3
Unbilled revenue	15.2			16.8
Amounts due from affiliates	3.2			2.3
Due from PJM transmission enhancement settlement	2.4			16.5
Other	1.3			2.4
Provision for uncollectible accounts	(0.4		)	(0.9		)
Total accounts receivable, net	$	71.7		$	90.4
Inventories, at average cost:
Materials and supplies	$	9.8		$	7.1
Other	—			0.6
Total inventories, at average cost	$	9.8		$	7.7

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three and nine months ended September 30, 2019 and 2018 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) components	Affected line item in the Condensed Statements of Operations	Three months ended					Nine months ended
		September 30,					September 30,
$ in millions		2019		2018			2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	—	$	(0.3	)	$	(0.1	)	$	(1.1	)
	Income tax expense	—		0.1			—			0.6
	Net of income taxes	—		(0.2		)	(0.1		)	(0.5		)
Amortization of defined benefit pension items (Note 8):
	Other expense	0.8		1.0			2.6			3.2
	Income tax expense / (benefit)	0.9		(0.2		)	(0.5		)	(0.7		)
	Net of income taxes	1.7		0.8			2.1			2.5
Total reclassifications for the period, net of income taxes		$	1.7	$	0.6		$	2.0		$	2.0

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the nine months ended September 30, 2019 are as follows:

$ in millions	Gains / (losses) on cash flow hedges			Change in unfunded pension and postretirement benefit obligation			Total
Balance at January 1, 2019	$	0.6		$	(35.9	)	$	(35.3	)
Other comprehensive loss before reclassifications	(0.9		)	—			(0.9		)
Amounts reclassified from AOCI to earnings	(0.1		)	2.1			2.0
Net current period other comprehensive income / (loss)	(1.0		)	2.1			1.1
Balance at September 30, 2019	$	(0.4	)	$	(33.8	)	$	(34.2	)

Additional Financial Information Disclosure [Text Block]

	December 31,
$ in millions	2018			2017
Accounts receivable, net
Customer receivables	$	53.3		$	44.2
Unbilled revenue	16.8			18.0
Amounts due from partners in jointly-owned stations	—			5.0
Due from PJM transmission enhancement settlement (a)	16.5			—
Due from affiliates	2.3			0.6
Other	2.4			4.1
Provisions for uncollectible accounts	(0.9		)	(1.1		)
Total accounts receivable, net	$	90.4		$	70.8
Inventories, at average cost
Materials and supplies	$	7.1		$	6.9
Other	0.6			0.4
Total inventories, at average cost	$	7.7		$	7.3

(a) - See Note 3 – Regulatory Matters for more information.

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the years ended December 31, 2018, 2017 and 2016 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) Components	Affected line item in the Statements of Operations	Years ended December 31,
$ in millions		2018			2017			2016
Gains and losses on equity securities activity (Note 5):
	Other deductions	$	—		$	(0.1	)	$	—
	Income tax expense	—			—			—
	Net of income taxes	—			(0.1		)	—
Gains and losses on cash flow hedges (Note 6):
	Interest expense	(1.1		)	(0.9		)	(1.0		)
	Income tax benefit	0.4			0.2			0.2
	Net of income taxes	(0.7		)	(0.7		)	(0.8		)
	Loss from discontinued operations	—			(8.5		)	(45.4		)
	Income tax benefit from discontinued operations	—			3.0			16.2
	Net of income taxes	—			(5.5		)	(29.2		)
Amortization of defined benefit pension items (Note 9):
	Other income	4.3			6.8			7.7
	Income tax expense	(1.0		)	(2.3		)	(1.8		)
	Net of income taxes	3.3			4.5			5.9
Total reclassifications for the period, net of income taxes		$	2.6		$	(1.8	)	$	(24.1	)

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the years ended December 31, 2018 and 2017 are as follows:

$ in millions	Gains / (losses) on equity securities			Gains / (losses) on cash flow hedges			Change in unfunded pension obligation			Total
Balance at December 31, 2016	$	0.7		$	(2.7	)	$	(40.5	)	$	(42.5	)
Other comprehensive income / (loss) before reclassifications	0.5			12.4			(2.7		)	10.2
Amounts reclassified from accumulated other comprehensive income / (loss)	(0.1		)	(6.2		)	4.5			(1.8		)
Net current period other comprehensive income	0.4			6.2			1.8			8.4
Transfer of generation assets to subsidiary of parent	—			(2.1		)	—			(2.1		)
Balance at December 31, 2017	1.1			1.4			(38.7		)	(36.2		)
Other comprehensive loss before reclassifications	—			(0.1		)	(0.5		)	(0.6		)
Amounts reclassified from accumulated other comprehensive income / (loss) to earnings	—			(0.7		)	3.3			2.6
Net current period other comprehensive income / (loss)	—			(0.8		)	2.8			2.0
Amounts reclassified from accumulated other comprehensive income to accumulated deficit (a)	(1.1		)	—			—			(1.1		)
Balance at December 31, 2018	$	—		$	0.6		$	(35.9	)	$	(35.3	)

(a)

ASU 2016-01 “Recognition and Measurement of Financial Assets and Financial Liabilities” was effective as of January 1, 2018. This ASU requires the change in the fair value of equity instruments to be recorded in income rather than in OCI. Equity Instruments were defined to include all mutual funds, regardless of the underlying investments.

Supplemental Financial Information

Accounts receivable and Inventories are as follows at September 30, 2019 and December 31, 2018:

	September 30,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	50.0		$	53.3
Unbilled revenue	15.2			16.8
Amounts due from affiliates	3.2			2.3
Due from PJM transmission enhancement settlement	2.4			16.5
Other	1.3			2.4
Provision for uncollectible accounts	(0.4		)	(0.9		)
Total accounts receivable, net	$	71.7		$	90.4
Inventories, at average cost:
Materials and supplies	$	9.8		$	7.1
Other	—			0.6
Total inventories, at average cost	$	9.8		$	7.7

	December 31,
$ in millions	2018			2017
Accounts receivable, net
Customer receivables	$	53.3		$	44.2
Unbilled revenue	16.8			18.0
Amounts due from partners in jointly-owned stations	—			5.0
Due from PJM transmission enhancement settlement (a)	16.5			—
Due from affiliates	2.3			0.6
Other	2.4			4.1
Provisions for uncollectible accounts	(0.9		)	(1.1		)
Total accounts receivable, net	$	90.4		$	70.8
Inventories, at average cost
Materials and supplies	$	7.1		$	6.9
Other	0.6			0.4
Total inventories, at average cost	$	7.7		$	7.3

(a) - See Note 3 – Regulatory Matters

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Equity

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Equity

Shareholder's Equity

Capital Contribution and Returns of Capital

During the nine months ended September 30, 2019, DP&L made returns of capital payments of $90.0 million to DPL.

During the nine months ended September 30, 2018, DP&L received an $80.0 million capital contribution from its parent, DPL. In addition, DP&L made returns of capital payments of $43.8 million to DPL.

Redeemable Preferred Stock

On October 13, 2016 (the "Redemption Date"), DP&L redeemed all of its issued and outstanding preferred stock, consisting of the following series: Preferred Stock, 3.75% Series A, Cumulative (the “Series A Stock”); Preferred Stock, 3.75% Series B, Cumulative (the “Series B Stock”); and Preferred Stock, 3.90% Series C, Cumulative (the “Series C Stock” and, together with the Series A Stock and the Series B Stock, the “Preferred Stock”). On the Redemption Date, the Preferred Stock of each series was redeemed at the following prices as specified in DP&L’s Amended and Restated Articles of Incorporation, plus, in each case an amount equal to all accrued dividends payable with respect to such Preferred Stock to the Redemption Date: a price of $102.50 per share for the Series A Stock, a price of $103.00 per share for the Series B Stock, and a price of $101.00 per share for the Series C Stock. Dividends on the Preferred Stock ceased to accrue on the Redemption Date. Upon redemption, the Preferred Stock was no longer outstanding, and all rights of the holders thereof as shareholders of DP&L, except the right to payment of the redemption price, ceased to exist. The difference between the carrying value of the Redeemable Preferred Stock and the redemption amount was charged to Other paid-in capital.

Common Stock

DP&L has 50,000,000 authorized common shares, of which 41,172,173 are outstanding at December 31, 2018. All common shares are held by DP&L’s parent, DPL.

Equity Settlement of Related Party Payable

In 2016, DP&L settled a $7.5 million payable to DPL relating to income taxes. This payable balance was settled through equity and DPL's investment in DP&L was increased by $7.5 million as consideration for extinguishing the payable.

Capital Contribution and Returns of Capital

In 2018, DP&L received an $80.0 million capital contribution from its parent, DPL. In addition, DP&L made returns of capital payments of $43.8 million to DPL. In addition, DP&L recorded $10.0 million in 2018 as a return of capital to transfer additional deferred tax amounts under Generation Separation. See Note 8 – Income Taxes and Note 14 – Generation Separation for more information.

In 2017, DP&L received a $70.0 million capital contribution from its parent, DPL. In addition, DP&L made returns of capital payments of $39.0 million to DPL. In connection with Generation Separation, DP&L recorded $86.2 million as a return of capital. See Note 14 – Generation Separation for more information.

In 2016, DP&L made a dividend payment of $70.0 million to DPL.

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Property, Plant and Equipment (Tables) - THE DAYTON POWER AND LIGHT COMPANY [Member]

12 Months Ended

Dec. 31, 2018

Property, Plant and Equipment [Line Items]

Summary of Property, Plant, and Equipment

The following is a summary of DP&L’s Property, plant and equipment with corresponding composite depreciation rates at December 31, 2018 and 2017:

	December 31, 2018			December 31, 2017
$ in millions			Composite Rate			Composite Rate (a)
Regulated:
Transmission	$	386.7	2.4%	$	414.6	2.4%
Distribution	1,796.4		3.2%	1,735.9		3.4%
General	30.9		3.6%	31.2		3.1%
Non-depreciable	60.4		N/A	64.6		N/A
Total regulated	2,274.4			2,246.3
Unregulated:
Other	—		N/A	0.2		2.7%
Non-depreciable	—		N/A	0.7		N/A
Total unregulated	—			0.9
Total property, plant and equipment in service	$	2,274.4	3.0%	$	2,247.2	3.4%

Changes in the Liability for Generation AROs

Changes in the Liability for Generation AROs

$ in millions
Balance at December 31, 2016	$	8.2
Calendar 2017
Accretion expense	0.1
Settlements	(0.3		)
Balance at December 31, 2017	8.0
Calendar 2018
Settlements (a)	(3.3		)
Balance at December 31, 2018	$	4.7

(a)

Primarily includes settlement related to transfer of Beckjord Facility. See Note 15 – Dispositions for additional information.

Changes in the Liability for Transmission and Distribution Asset Removal Costs

Changes in the Liability for Transmission and Distribution Asset Removal Costs

$ in millions
Balance at December 31, 2016	$	126.5
Calendar 2017
Additions	12.0
Settlements	(5.7		)
Balance at December 31, 2017	132.8
Calendar 2018
Additions	14.3
Settlements	(8.0		)
Balance at December 31, 2018	$	139.1

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Income Taxes (Tables) - THE DAYTON POWER AND LIGHT COMPANY [Member]

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Income Taxes [Line Items]

Schedule of Effective Income Tax Rates [Table Text Block]

The following table details the effective tax rates for the three and nine months ended September 30, 2019 and 2018.

	Three months ended		Nine months ended
	September 30,		September 30,
	2019	2018	2019	2018
DP&L	(19.1)%	16.8%	4.7%	16.2%

Components of Income Tax Expense

DP&L’s components of income tax expense on continuing operations were as follows:

	Years ended December 31,
$ in millions	2018			2017			2016
Computation of tax expense
Federal income tax expense (a)	$	22.2		$	31.0		$	50.1
Increases (decreases) in tax resulting from:
State income taxes, net of federal effect	0.6			0.4			0.4
Depreciation of flow-through differences	(4.3		)	1.2			3.0
Investment tax credit amortized	(0.3		)	(0.3		)	(0.4		)
Accrual (settlement) for open tax years	—			(0.5		)	3.4
Other, net (b)	(0.5		)	(0.7		)	(10.5		)
Total tax expense	$	17.7		$	31.1		$	46.0
Components of tax expense
Federal - current	$	1.4		$	13.5		$	37.7
State and Local - current	—			0.2			0.5
Total current	1.4			13.7			38.2
Federal - deferred	15.5			17.0			7.7
State and local - deferred	0.8			0.4			0.1
Total deferred	16.3			17.4			7.8
Total tax expense	$	17.7		$	31.1		$	46.0

(a) The statutory tax rate of 21% in 2018 and 35% in 2017 and 2016 was applied to pre-tax earnings.

(b)

Includes expense / (benefit) of $(0.7) million and $(0.4) million in the years ended December 31, 2017 and 2016, respectively, of income tax related to adjustments from prior years.

Schedule of Effective Income Tax Rate Reconciliation

The following table summarizes a reconciliation of the U.S. statutory federal income tax rate to DP&L's effective tax rate, as a percentage of income from continuing operations before taxes for the years ended December 31, 2018, 2017 and 2016:

	Years ended December 31,
	2018		2017		2016
Statutory Federal tax rate	21.0	%	35.0	%	35.0	%
State taxes, net of Federal tax benefit	0.6	%	0.4	%	0.3	%
AFUDC - Equity	(0.1	)%	1.4	%	2.1	%
Amortization of investment tax credits	(0.3	)%	(0.4	)%	(0.3	)%
Depreciation of flow-through differences	(4.0	)%	—	%	—	%
Other - net	(0.2	)%	(1.3	)%	(5.1	)%
Effective tax rate	17.0	%	35.1	%	32.0	%

Components of Deferred Tax Assets and Liabilities

Components of Deferred Tax Assets and Liabilities
	December 31,
$ in millions	2018			2017
Net non-current assets / (liabilities)
Depreciation / property basis	$	(130.6	)	$	(126.5	)
Income taxes recoverable	25.0			11.0
Regulatory assets	(16.2		)	(23.9		)
Investment tax credit	0.5			0.4
Compensation and employee benefits	0.3			17.6
Other	(10.7		)	(9.6		)
Net non-current liabilities	$	(131.7	)	$	(131.0	)

Schedule of Tax Expense Benefit That Were Credited To Accumulated Other Comprehensive Loss (Text Block)

The following table presents the tax expense / (benefit) related to pensions, postemployment benefits, cash flow hedges and financial instruments that were credited to Accumulated other comprehensive loss.

	Years ended December 31,
$ in millions	2018			2017		2016
Tax expense / (benefit)	$	(0.3	)	$	4.0	$	(7.0	)

Reconciliation of Unrecognized Tax Benefits

A reconciliation of the beginning and ending amount of unrecognized tax benefits for DP&L is as follows:

$ in millions
Balance at December 31, 2016	$	4.9
Calendar 2017
Tax positions taken during prior period	—
Lapse of Statute of Limitations	(0.1		)
Balance at December 31, 2017	4.8
Calendar 2018
Tax positions taken during prior period	—
Lapse of Statute of Limitations	—
Balance at December 31, 2018	$	4.8

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Derivative Instruments and Hedging Activities (Narrative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2018 USD ($)	Dec. 31, 2018 USD ($)	Sep. 30, 2019 USD ($) Number_of_interest_rate_swaps	Sep. 30, 2018 Number_of_interest_rate_swaps	Mar. 29, 2018 USD ($)	Dec. 31, 2017 USD ($)
Number of Interest Rate Swaps | Number_of_interest_rate_swaps			2	2
Sale of Derivative Instruments Interest Rate Swap					$ 60.0
Gain on sale of Derivative Instruments Interest Rate Swap	$ 0.8	$ 0.8
Tax-exempt First Mortgage Bonds - rates from: 2.49% - 2.93% (a) and 1.29% - 1.42% (b)
Long-term Debt, Gross		140.0	$ 140.0			$ 200.0
Interest Rate Swap [Member] | Designated as Hedging Instrument [Member]
Derivative, Notional Amount, Purchase (Sales), Net		$ 140.0	$ 140.0			$ 200.0

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Fair Value Measurements (Narrative) (Details) - USD ($) $ in Millions		12 Months Ended
	Jan. 01, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Sep. 30, 2019
Proceeds from Sale of Debt Securities, Available-for-sale		$ 0.5
AvailableForSaleSecuritiesGross Realized Gains Losses Sale Proceeds Net of Tax		0.4
THE DAYTON POWER AND LIGHT COMPANY [Member]
Asset Retirement Obligation		4.7	$ 8.0	$ 8.2	$ 4.7
Asset Retirement Obligations, Noncurrent		4.7	8.0
Unrealized gains and immaterial losses on Master Trust assets in AOCI, after tax		0.0	$ 0.4	$ 0.2
AOCI reclassed to Retained Earnings before tax	$ 1.7
AOCI reclassed to Retained Earnings, net of tax	$ 1.1	(1.1)
Carrying Value [Member] | Debt [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Lines of Credit, Fair Value Disclosure		$ 586.1			$ 574.2

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Contractual Obligations, Commercial Commitments and Contingencies (Narative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Debt Obligation on 4.9% Equity Ownership [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Equity ownership interest	4.90%	4.90%
Equity Ownership Interest - Guaranteed Portion of Long-term Debt Obligation	$ 67.2
Equity ownership interest aggregate cost		$ 68.1
Electric Generation Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Debt obligation	$ 1,371.3	$ 1,389.6
Other OVEC Member [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Equity ownership interest	4.85%	4.85%

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Benefit Plans (Pension and Postretirement Benefit Plans' Obligations and Assets) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Noncurrent liabilities	$ (73.9)		$ (73.9)		$ (83.2)	$ (91.1)
Postretirement [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Funded (Unfunded) Status of Plan	9.0		9.0		9.2	12.7
Pension [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement and Curtailment					0.0	(5.6)	$ (5.7)
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit obligation at January 1			386.5	$ 436.9	436.9	419.6
Service cost	0.9	$ 1.5	2.7	4.5	6.1	5.7	5.7
Interest cost	$ 3.7	$ 3.4	11.2	10.3	13.8	14.2	14.7
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment					5.1	0.0
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Curtailment					0.0	3.0
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)					(34.6)	28.1
Benefit obligation at December 31					386.5	436.9	419.6
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at January 1			312.9	357.5	357.5	341.0
Actual return / (loss) on plan assets					(11.7)	44.8
Defined Benefit Plan, Plan Assets, Contributions by Employer			$ 7.5	$ 7.5	7.9	5.4
Fair value of plan assets at December 31					312.9	357.5	$ 341.0
Defined Benefit Plan, Funded (Unfunded) Status of Plan					(73.6)	(79.4)
Current liabilities					(0.4)	(0.4)
Noncurrent liabilities					(73.2)	(79.0)
Net asset / (liability) at December 31					(73.6)	(79.4)
Prior service cost					10.4	6.7
Net actuarial loss					137.2	148.3
Accumulated other comprehensive income, regulatory assets and regulatory liabilities, pre-tax					147.6	155.0
Defined Benefit Plan, Plan Assets, Benefits Paid					40.8	33.7
Defined Benefit Plan, Benefit Obligation, Benefits Paid					40.8	33.7
Regulatory Asset [Member] | Pension [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Accumulated other comprehensive income, regulatory assets and regulatory liabilities, pre-tax					87.3	92.2
Accumulated Other Comprehensive Income/(Loss) [Member] | Pension [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Accumulated other comprehensive income, regulatory assets and regulatory liabilities, pre-tax					$ 60.3	$ 62.8

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Benefit Plans (Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost (Income)) (Details) - Pension [Member] - THE DAYTON POWER AND LIGHT COMPANY [Member]	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.66%	4.28%	4.49%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets	6.25%	6.50%	6.50%

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Business Segments (Segment Financial Information) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Fuel Costs	$ 0.6	$ 0.1	$ 2.0	$ 1.7	$ 2.4	$ 0.5	$ 5.3
Depreciation and amortization	17.4	19.1	52.9	56.5	74.5	75.3	71.0
Interest expense	6.1	5.8	19.9	20.5	27.3	30.5	24.7
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	37.7	37.5	108.8	73.9	104.4	88.5	143.6
Net loss from continuing operations					86.7	57.4	97.6
Discontinued operations, net of tax					0.0	(40.4)	(870.3)
Net income (loss)	44.9	$ 31.2	103.7	$ 61.9	86.7	17.0	(772.7)
Total assets (end of year)	$ 1,779.4		$ 1,779.4		1,819.6	1,695.9
Fixed-asset impairment (Note 14)					$ 0.0	66.3	1,353.5
Generation [Member]
Segment Reporting Information [Line Items]
Discontinued operations, net of tax						$ (40.4)	$ (870.3)

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Schedule II Valuation And Qualifying Accounts (Details) - Provision for Uncollectible Accounts [Member] - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at Beginning of Period	$ 1,053	$ 1,159	$ 835
Additions	3,411	3,141	4,113
Deductions	3,574	3,247	3,789
Balance at End of Period	$ 890	$ 1,053	$ 1,159

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Equity (Narrative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ / shares in Units, $ in Millions	3 Months Ended				9 Months Ended		12 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Sep. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Oct. 01, 2017	Jan. 01, 2016
Class of Stock [Line Items]
Retained earnings / (deficit)	$ (128.3)				$ (128.3)		$ (231.6)	$ (319.3)
Common stock, shares authorized	50,000,000		50,000,000		50,000,000	50,000,000	50,000,000	50,000,000
Common stock, shares outstanding	41,172,173				41,172,173		41,172,173	41,172,173
Accounts Payable, Related Parties, Current							$ 4.8	$ 3.9
Proceeds from Contributions from Parent		$ (70.0)		$ 80.0	$ 0.0	$ 80.0	80.0	70.0	$ 0.0
Dividends, Common Stock, Cash	$ 20.0		$ 20.0	23.8			43.8	(39.0)	70.0
Payments of Ordinary Dividends, Common Stock					$ 90.0	$ 43.8	$ 43.8	39.0	70.0
DP&L Series A [Member]
Class of Stock [Line Items]
Temporary Equity, Preferred Stock Rate							3.75%
Temporary Equity, Redemption Price Per Share							$ 102.50
DP&L Series B [Member]
Class of Stock [Line Items]
Temporary Equity, Preferred Stock Rate							3.75%
Temporary Equity, Redemption Price Per Share							$ 103.00
DP&L Series C [Member]
Class of Stock [Line Items]
Temporary Equity, Preferred Stock Rate							3.90%
Temporary Equity, Redemption Price Per Share							$ 101.00
Subsidiary of Common Parent [Member]
Class of Stock [Line Items]
Accounts Payable, Related Parties, Current											$ 7.5
Equity Settlement of Related Party Payable							$ 0.0	0.0	7.5
Other Paid-In Capital [Member]
Class of Stock [Line Items]
Proceeds from Contributions from Parent		$ 70.0		(80.0)			(80.0)	(70.0)
Dividends, Common Stock, Cash	$ 20.0		$ 20.0	$ 23.8			43.8	$ 39.0
Generation [Member]
Class of Stock [Line Items]
Disposal Group, Including Discontinued Operation, Net Assets							$ 10.0		$ 0.0	$ 86.2

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Benefit Plans

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Benefit Plans

Benefit Plans

DP&L sponsors a defined benefit pension plan for the majority of its employees.

We generally fund pension plan benefits as accrued in accordance with the minimum funding requirements of ERISA and, in addition, make voluntary contributions from time to time. There were $7.5 million in employer contributions during each of the nine months ended September 30, 2019 and 2018.

The amounts presented in the following tables for pension include the collective bargaining plan formula, the traditional management plan formula, the cash balance plan formula and the SERP, in the aggregate. The pension costs below have not been adjusted for amounts billed to the Service Company for former DP&L employees who are now employed by the Service Company or for amounts billed to AES Ohio Generation for employees employed by AES Ohio Generation that are still participants in the DP&L plan.

The net periodic benefit cost of the pension benefit plans for the three and nine months ended September 30, 2019 and 2018 was:

	Three months ended						Nine months ended
	September 30,						September 30,
$ in millions	2019			2018			2019			2018
Service cost	$	0.9		$	1.5		$	2.7		$	4.5
Interest cost	3.7			3.4			11.2			10.3
Expected return on plan assets	(5.0		)	(5.3		)	(15.0		)	(15.9		)
Amortization of unrecognized:
Prior service cost	0.4			0.4			1.3			1.1
Actuarial loss	1.8			2.4			5.3			7.1
Net periodic benefit cost	$	1.8		$	2.4		$	5.5		$	7.1

In addition, DP&L provides postretirement health care and life insurance benefits to certain retired employees, their spouses and eligible dependents. We have funded a portion of the union-eligible benefits using a Voluntary Employee Beneficiary Association Trust. These postretirement health care benefits and the related unfunded obligation of $9.0 million at September 30, 2019 and $9.2 million at December 31, 2018 were not material to the financial statements in the periods covered by this report.

Defined Contribution Plans

DP&L sponsors two defined contribution plans. One is for non-union employees (the management plan) and one is for collective bargaining employees (the union plan). Both plans are qualified under Section 401 of the Internal Revenue Code.

Certain non-union and union employees become eligible to participate in their respective plan upon date of hire.

Participants may elect to contribute up to 85% of eligible compensation to their plan. Non-union participant contributions are matched 100% on the first 1% of eligible compensation and 50% on the next 5% of eligible compensation and they are fully vested in their employer contributions after two years of service. Union participant contributions are matched 150% but are capped at $2,400 for 2018 and they are fully vested in their employer contributions after three years of service. All participants are fully vested in their own contributions.

We contributed $3.7 million, $3.1 million and $5.1 million for the years ended December 31, 2018, 2017 and 2016, respectively. DP&L matching contributions are paid quarterly, in arrears. Therefore, the contributions by year include the fourth quarter matching contribution that is paid in the following year. DP&L also contributes an annual bonus to the accounts of its union participants. This payment is typically made in January of the following year.

Defined Benefit Plans

DP&L sponsors a traditional defined benefit pension plan for most of the employees of DPL and its subsidiaries. For collective bargaining employees, the defined benefits are based on a specific dollar amount per year of service. For all other employees (management employees), the traditional defined benefit pension plan is based primarily on compensation and years of service. As of December 31, 2010, this traditional pension plan formula was closed to new management employees. A participant is 100% vested in all amounts credited to his or her account upon the completion of five-years vesting, as defined in The Dayton Power and Light Company Retirement Income Plan, or the participant’s death or disability. If a participant’s employment is terminated, other than by death or disability, prior to such participant becoming 100% vested in his or her account, the account shall be forfeited as of the date of termination. Employees that transferred from DP&L to the Service Company maintain their previous eligibility to participate in the DP&L pension plan. In addition, employees that transferred from DP&L to AES Ohio Generation due to Generation Separation maintain their previous eligibility to participate in the DP&L pension plan.

Almost all management employees beginning employment on or after January 1, 2011 participate in a cash balance pension plan formula. Similar to the traditional pension plan for management employees, the cash balance benefits are based on compensation and years of service. A participant shall become 100% vested in all amounts credited to his or her account upon the completion of three vesting years, as defined in The Dayton Power and Light Company Retirement Income Plan, or the participant’s death or disability. If a participant’s employment is terminated, other than by death or disability, prior to such participant becoming 100% vested in his or her account, the account shall be forfeited as of the date of termination. Vested benefits in the cash balance plan are fully portable upon termination of employment.

In addition, we have a Supplemental Executive Retirement Plan (SERP) for certain retired key executives. The SERP has an immaterial unfunded liability related to agreements for retirement benefits of certain terminated and retired key executives. We also include our net liability to our partners in our co-owned generating plants related to our share of their pension liabilities within Pension, retiree and other benefits on our Balance Sheets.

We recognize an asset for a plan’s overfunded status and a liability for a plan’s underfunded status and recognize, as a component of OCI, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. For the transmission and distribution areas of our electric business, these amounts are recorded as regulatory assets and liabilities which represent the regulated portion that would otherwise be charged or credited to AOCI. We have historically recorded these costs on the accrual basis and this is how these costs have been historically recovered through customer rates. This factor, combined with the historical precedents from the PUCO and FERC, make these costs probable of future rate recovery.

Postretirement Benefits

Qualified employees who retired prior to 1987 and their dependents are eligible for health care and life insurance benefits until their death, while qualified employees who retired after 1987 are eligible for life insurance benefits and partially subsidized health care. The partially subsidized health care is at the election of the employee, who pays the majority of the cost, and is available only from their retirement until they are covered by Medicare. We have funded a portion of the union-eligible benefits using a Voluntary Employee Beneficiary Association Trust. These postretirement health care benefits and the related unfunded obligation of $9.2 million and $12.7 million at December 31, 2018 and 2017, respectively, were not material to the financial statements in the periods covered by this report.

The following tables set forth the changes in our pension plan's obligations and assets recorded on the Balance Sheets at December 31, 2018 and 2017. The amounts presented in the following tables for pension obligations include the collective bargaining plan formula, traditional management plan formula and cash balance plan formula and the SERP in the aggregate and have not been adjusted for $1.8 million and $1.1 million of costs billed to the Service Company for the years ended December 31, 2018 and 2017 or $3.3 million and $0.7 million of costs billed to AES Ohio Generation for the years ended December 31, 2018 and 2017.

$ in millions	Years ended December 31,
Change in benefit obligation	2018			2017
Benefit obligation at January 1	$	436.9		$	419.6
Service cost	6.1			5.7
Interest cost	13.8			14.2
Plan amendments	5.1			—
Plan curtailment	—			3.0
Actuarial (gain) / loss	(34.6		)	28.1
Benefits paid	(40.8		)	(33.7		)
Benefit obligation at December 31	386.5			436.9
Change in plan assets
Fair value of plan assets at January 1	357.5			341.0
Actual return on plan assets	(11.7		)	44.8
Employer contributions	7.9			5.4
Benefits paid	(40.8		)	(33.7		)
Fair value of plan assets at December 31	312.9			357.5
Unfunded status of plan	$	(73.6	)	$	(79.4	)
	December 31,
Amounts recognized in the Balance sheets	2018			2017
Current liabilities	$	(0.4	)	$	(0.4	)
Non-current liabilities	(73.2		)	(79.0		)
Net liability at end of year	$	(73.6	)	$	(79.4	)
Amounts recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax
Components:
Prior service cost	$	10.4		$	6.7
Net actuarial loss	137.2			148.3
Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax	$	147.6		$	155.0
Recorded as:
Regulatory asset	$	87.3		$	92.2
Accumulated other comprehensive income	60.3			62.8
Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax	$	147.6		$	155.0

The accumulated benefit obligation for our defined benefit pension plans was $378.7 million and $428.3 million at December 31, 2018 and 2017, respectively.

The net periodic benefit cost of the pension plans was:

	Years ended December 31,
$ in millions	2018			2017			2016
Service cost	$	6.1		$	5.7		$	5.7
Interest cost	13.8			14.2			14.7
Expected return on assets	(21.2		)	(22.8		)	(22.8		)
Plan curtailment (a)	—			5.6			5.7
Amortization of unrecognized:
Actuarial loss	9.4			8.7			7.2
Prior service cost	1.4			1.5			3.0
Net periodic benefit cost	$	9.5		$	12.9		$	13.5
Rates relevant to each year's expense calculations
Discount rate	3.66		%	4.28		%	4.49		%
Expected return on plan assets	6.25		%	6.50		%	6.50		%

(a)    As a result of the decision to retire certain coal-fired plants, we recognized a plan curtailment of $5.6 million and $5.7 million in 2017 and 2016, respectively.

Other Changes in Plan Assets and Benefit Obligation Recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities

	Years ended December 31,
$ in millions	2018			2017			2016
Net actuarial loss	$	3.4		$	9.1		$	20.9
Plan curtailment (a)	—			(5.6		)	(5.7		)
Reversal of amortization item:
Net actuarial loss	(9.4		)	(8.7		)	(7.2		)
Prior service cost	(1.4		)	(1.5		)	(3.0		)
Total recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities	$	(7.4	)	$	(6.7	)	$	5.0
Total recognized in net periodic benefit cost and Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities	$	2.1		$	6.2		$	18.5

(a)    As a result of the decision to retire certain coal-fired plants, we recognized a plan curtailment of $5.6 million and $5.7 million in 2017 and 2016, respectively.

Significant Gains and Losses Related to Changes in the Benefit Obligation

The actuarial gain of $34.6 million decreased the benefit obligation for the year ended December 31, 2018 and an actuarial loss of $28.1 million increased the benefit obligation for the year ended December 31, 2017. The actuarial gain in 2018 was primarily due to an increase in the discount rate, while the actuarial loss in 2017 was primarily due to a decrease in the discount rate.

Assumptions

Our expected return on plan asset assumptions, used to determine benefit obligations, are based on historical long-term rates of return on investments, which use the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current market factors, such as inflation and interest rates, as well as asset diversification and portfolio rebalancing, are evaluated when long-term capital market assumptions are determined. Peer data and historical returns are reviewed to verify reasonableness and appropriateness.

At December 31, 2018, we are maintaining our long-term rate of return assumption of 6.25% for pension plan assets. The rate of return represents our long-term assumptions based on our long-term portfolio mix. Also, at December 31, 2018, we have increased our assumed discount rate to 4.35% from 3.66% for pension expense to reflect current duration-based yield curve discount rates. A one percent increase in the rate of return assumption for pension would result in a decrease in 2019 pension expense of approximately $3.2 million. A one percent decrease in the rate of return assumption for pension would result in an increase in 2019 pension expense of approximately $3.2 million. A 25-basis point increase in the discount rate for pension would result in a decrease of approximately $0.1 million to 2019 pension expense. A 25-basis point decrease in the discount rate for pension would result in an increase of approximately $0.4 million to 2019 pension expense.

In determining the discount rate to use for valuing liabilities, we used a market yield curve on high-quality fixed income investments as of December 31, 2018. We project the expected benefit payments under the plan based on participant data and based on certain assumptions concerning mortality, retirement rates, termination rates, etc. The expected benefit payments for each year are then discounted back to the measurement date using the appropriate spot rate for each half-year from the yield curve, thereby obtaining a present value of all expected future benefit payments using the yield curve. Finally, an equivalent single discount rate is determined which produces a present value equal to the present value determined using the full yield curve.

In future periods, differences in the actual return on pension plan assets and assumed return, or changes in the discount rate, will affect the timing of contributions, if any, to the plans.

The weighted average assumptions used to determine benefit obligations at December 31, 2018, 2017 and 2016 were:

Benefit Obligation Assumptions	Pension
	2018	2017	2016
Discount rate for obligations	4.35%	3.66%	4.28%
Rate of compensation increases	3.94%	3.94%	3.94%

Pension Plan Assets

Plan assets are invested using a total return investment approach whereby a mix of equity securities, debt securities and other investments are used to preserve asset values, diversify risk and achieve our target investment return benchmark. Investment strategies and asset allocations are based on careful consideration of plan liabilities, the plan's funded status and our financial condition. Investment performance and asset allocation are measured and monitored on an ongoing basis.

Plan assets are managed in a balanced portfolio comprised of two major components: an equity portion and a fixed income portion. The expected role of plan equity investments is to maximize the long-term real growth of plan assets, while the role of fixed income investments is to generate current income, provide for more stable periodic returns and provide some protection against a prolonged decline in the market value of plan equity investments.

Long-term strategic asset allocation guidelines, as well as short-term tactical asset allocation guidelines, are determined by a Risk/Advisory Committee and approved by a Fiduciary Committee. These allocations consider the plan’s long-term objectives. The long-term target allocations for plan assets are 24% – 52% for equity securities and 47% – 65% for fixed income securities. Equity securities include U.S. and international equity, while fixed income securities include long-duration and high-yield bond funds and emerging market debt funds.

Tactically, the committees, on a short-term basis, will make asset allocations that are outside the long-term allocation guidelines. The short-term allocation positions are likely to not exceed one-year in duration. In addition to the equity and fixed income investments, the short-term allocation may also include a relatively small allocation to alternative investments. The plan currently has a small target allocation in a core property fund.

Most of our plan assets are measured using quoted, observable prices which are considered Level One inputs in the Fair Value Hierarchy. The Core Property Collective Fund is measured using Level Two inputs that are quoted prices for identical assets in markets that are less active.

The following table summarizes our target pension plan allocation for 2018:

	Long-Term Mid-Point Target Allocation	Percentage of plan assets as of December 31,
Asset category		2018	2017
Equity Securities	38%	33%	35%
Debt Securities	56%	58%	55%
Cash and Cash Equivalents	—%	1%	—%
Real Estate	6%	8%	10%

The fair values of our pension plan assets at December 31, 2018 by asset category are as follows:

Fair Value Measurements for Pension Plan Assets at December 31, 2018
$ in millions	Market Value at December 31, 2018		Quoted prices in active markets for identical assets		Significant observable inputs		Significant unobservable inputs
Asset category			(Level 1)		(Level 2)		(Level 3)
Mutual funds:
U.S. equities (a)	$	79.3	$	79.3	$	—	$	—
International equities (a)	25.9		25.9		—		—
Fixed income (b)	143.7		143.7		—		—
Fixed income securities:
U.S. Treasury securities	37.5		37.5		—		—
Cash and cash equivalents:
Money market funds (c)	2.4		2.4		—		—
Other investments:
Core property collective fund (d)	24.1		—		24.1		—
Total pension plan assets	$	312.9	$	288.8	$	24.1	$	—

(a) This category includes investments in equity securities of large, small and medium sized U.S. companies and equity securities of foreign companies including those in developing countries. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(b) This category includes investments in investment-grade fixed-income instruments, U.S. dollar-denominated debt securities of emerging market issuers and high yield fixed-income securities that are rated below investment grade. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(c) This category is comprised of investments in U.S. treasury obligations that seek to preserve principal and maintain liquidity while providing current income. The funds are valued at the assets’ amortized cost to maintain a stable per share net asset value.

(d) This category represents a property fund that invests in commercial real estate. The fair value of the fund is valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

The fair values of our pension plan assets at December 31, 2017 by asset category are as follows:

Fair Value Measurements for Pension Plan Assets at December 31, 2017
$ in millions	Market Value at December 31, 2017		Quoted prices in active markets for identical assets		Significant observable inputs		Significant unobservable inputs
Asset category			(Level 1)		(Level 2)		(Level 3)
Mutual funds:
U.S. equities (a)	$	78.2	$	78.2	$	—	$	—
International equities (a)	46.3		46.3		—		—
Fixed income (b)	163.3		163.3		—		—
Fixed income securities:
U.S. Treasury securities	33.5		33.5		—		—
Other investments: (c)
Core property collective fund	36.2		—		36.2		—
Total pension plan assets	$	357.5	$	321.3	$	36.2	$	—

(a) This category includes investments in equity securities of large, small and medium sized U.S. companies and equity securities of foreign companies including those in developing countries. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(b) This category includes investments in investment-grade fixed-income instruments, U.S. dollar-denominated debt securities of emerging market issuers and high yield fixed-income securities that are rated below investment grade. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(c) This category represents a property fund that invests in commercial real estate. The fair value of the fund is valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

Pension Funding

We generally fund pension plan benefits as accrued in accordance with the minimum funding requirements of the Employee Retirement Income Security Act of 1974 (ERISA) and, in addition, make voluntary contributions from time to time. We contributed $7.5 million to the pension plan in the year ended December 31, 2018 and $5.0 million to the pension plan in each of the years ended December 31, 2017 and 2016.

We expect to make contributions of $0.4 million to our SERP in 2019 to cover benefit payments. We also expect to make contributions of $7.5 million to our pension plan during 2019.

Funding for the qualified Defined Benefit Pension Plan is based upon actuarially determined contributions that consider the amount deductible for income tax purposes and the minimum contribution required under ERISA, as amended by the Pension Protection Act of 2006, as well as targeted funding levels necessary to meet certain thresholds.

From an ERISA funding perspective, DP&L’s funded target liability percentage was estimated to be 101%. In addition, DP&L must also contribute the normal service cost earned by active participants during the plan year. The funding of normal cost is expected to be approximately $5.4 million in 2019, which includes $1.9 million for plan expenses. Each year thereafter, if the plan’s underfunding increases to more than the present value of the remaining annual installments, the excess is separately amortized over seven years. DP&L’s funding policy for the pension plans is to contribute annually no less than the minimum required by applicable law, and no more than the maximum amount that can be deducted for federal income tax purposes.

Benefit payments, which reflect future service, are expected to be paid as follows:

Estimated future benefit payments
$ in millions due within the following years:	Pension
2019	$	26.7
2020	$	26.5
2021	$	26.3
2022	$	26.0
2023	$	25.9
2024 - 2028	$	125.1

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Fair Value Measurements

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Fair Value Measurements

Fair Value

The fair value of current financial assets and liabilities, debt service reserves and other deposits approximate their reported carrying amounts. The estimated fair values of our assets and liabilities have been determined using available market information. By virtue of these amounts being estimates and based on hypothetical transactions to sell assets or transfer liabilities, the use of different market assumptions and/or estimation methodologies may have a material effect on the estimated fair value amounts. For further information on our valuation techniques and policies, see Note 5—Fair Value in Item 8.—Financial Statements and Supplementary Data of our Form 10-K.

The following table presents the fair value, carrying value and cost of our non-derivative instruments at September 30, 2019 and December 31, 2018. Further information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	September 30, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.2	$	0.2	$	0.4	$	0.4
Equity securities	2.3		3.9		2.4		3.5
Debt securities	4.1		4.1		4.1		4.0
Hedge funds	0.1		0.1		0.1		0.1
Tangible assets	0.1		0.1		0.1		0.1
Total assets	$	6.8	$	8.4	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	574.2	$	631.0	$	586.1	$	593.8

These financial instruments are not subject to master netting agreements or collateral requirements and as such are presented in the Condensed Balance Sheet at their gross fair value, except for Long-term debt, which is presented at amortized carrying value.

We did not have any transfers of the fair values of our financial instruments between Level 1, Level 2 or Level 3 of the fair value hierarchy during the nine months ended September 30, 2019 or 2018.

Master Trust Assets

DP&L established a Master Trust to hold assets that could be used for the benefit of employees participating in employee benefit plans and these assets are not used for general operating purposes. On January 1, 2018, AOCI of $1.7 million ($1.1 million net of tax) was reversed to Accumulated Deficit and all future changes to fair value on the Master Trust Assets will be included in income in the period that the changes occur. Changes to fair value were not material for the nine months ended September 30, 2019 or 2018. These assets are primarily comprised of open-ended mutual funds, which are valued using the net asset value per unit. These investments are recorded at fair value within Other deferred assets on the Condensed Balance Sheets and classified as available for sale.

Long-term debt

The fair value of debt is based on current public market prices for disclosure purposes only. Unrealized gains or losses are not recognized in the financial statements as long-term debt is presented at carrying value, net of unamortized premium or discount and unamortized deferred financing costs in the financial statements. The long-term debt amounts include the current portion payable in the next twelve months and have maturities that range from 2020 to 2061.

The fair value of assets and liabilities at September 30, 2019 and December 31, 2018 and the respective category within the fair value hierarchy for DP&L is as follows:

$ in millions	Fair value at September 30, 2019 (a)								Fair value at December 31, 2018 (a)
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Master Trust assets
Money market funds	$	0.2	$	—	$	—	$	0.2	$	0.4	$	—	$	—	$	0.4
Equity securities	—		3.9		—		3.9		—		3.5		—		3.5
Debt securities	—		4.1		—		4.1		—		4.0		—		4.0
Hedge funds	—		0.1		—		0.1		—		0.1		—		0.1
Tangible assets	—		0.1		—		0.1		—		0.1		—		0.1
Total Master Trust assets	0.2		8.2		—		8.4		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		0.2		—		0.2		—		1.5		—		1.5
Total derivative assets	—		0.2		—		0.2		—		1.5		—		1.5
Total assets	$	0.2	$	8.4	$	—	$	8.6	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	613.4	$	17.6	631.0		$	—	$	576.1	$	17.7	$	593.8
Total liabilities	$	—	$	613.4	$	17.6	$	631.0	$	—	$	576.1	$	17.7	$	593.8

(a) Includes credit valuation adjustment

Our financial instruments are valued using the market approach in the following categories:

• Level 1 inputs are used for money market accounts that are considered cash equivalents. The fair value is determined by reference to quoted market prices and other relevant information generated by market transactions.

• Level 2 inputs are used to value derivatives such as interest rate hedge contracts which are valued using a benchmark interest rate. Other Level 2 assets include open-ended mutual funds in the Master Trust, which are valued using the end of day NAV per unit.

• Level 3 inputs such as certain debt balances are considered a Level 3 input because the notes are not publicly traded. Our long-term debt is fair valued for disclosure purposes only.

All of the inputs to the fair value of our derivative instruments are from quoted market prices.

Our long-term debt is fair valued for disclosure purposes only and most of the fair values are determined using quoted market prices in inactive markets. These fair value inputs are considered Level 2 in the fair value hierarchy. As the Wright-Patterson Air Force Base note is not publicly traded, fair value is assumed to equal carrying value. These fair value inputs are considered Level 3 in the fair value hierarchy as there are no observable inputs. Additional Level 3 disclosures are not presented since our long-term debt is not recorded at fair value.

The fair values of our financial instruments are based on published sources for pricing when possible. We rely on valuation models only when no other method is available to us. The fair value of our financial instruments represents estimates of possible value that may or may not be realized in the future.

The table below presents the fair value and cost of our non-derivative instruments at December 31, 2018 and 2017. See also Note 6 – Derivative Instruments and Hedging Activities for the fair values of our derivative instruments.

	December 31, 2018				December 31, 2017
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.4	$	0.4	$	0.3	$	0.3
Equity securities	2.4		3.5		2.5		4.2
Debt securities	4.1		4.0		4.3		4.3
Hedge funds	0.1		0.1		0.1		0.2
Tangible assets	0.1		0.1		0.1		0.1
Total assets	$	7.1	$	8.1	$	7.3	$	9.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	586.1	$	593.8	$	646.6	$	658.4

Fair Value Hierarchy

Fair value is defined as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. The fair value hierarchy requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. These inputs are then categorized as:

• Level 1 (quoted prices in active markets for identical assets or liabilities);

• Level 2 (observable inputs such as quoted prices for similar assets or liabilities or quoted prices in markets that are not active); or

• Level 3 (unobservable inputs reflecting management’s own assumptions about the inputs used in pricing the asset or liability).

Valuations of assets and liabilities reflect the value of the instrument including the values associated with counterparty risk. We include our own credit risk and our counterparty’s credit risk in our calculation of fair value using global average default rates based on an annual study conducted by a large rating agency.

We did not have any transfers of the fair values of our financial instruments among Level 1, Level 2 or Level 3 of the fair value hierarchy during the years ended December 31, 2018 and 2017.

Debt

The fair value of debt is based on current public market prices for disclosure purposes only. Unrealized gains or losses are not recognized in the financial statements as debt is presented at the carrying value, net of unamortized premium or discount, in the financial statements. The debt amounts include the current portion payable in the next twelve months and have maturities that range from 2020 to 2061.

Master Trust Assets

DP&L established a Master Trust to hold assets that could be used for the benefit of employees participating in employee benefit plans and these assets are not used for general operating purposes. ASU 2016-01 “Recognition and Measurement of Financial Assets and Financial Liabilities” was effective as of January 1, 2018. This ASU requires the change in the fair value of equity instruments to be recorded in income rather than in OCI. Equity Instruments were defined to include all mutual funds, regardless of the underlying investments. Therefore, as of January 1, 2018, AOCI of $1.7 million ($1.1 million net of tax) was reversed to Accumulated Deficit and all future changes to fair value on the Master Trust Assets will be included in income in the period that the changes occur. These changes to fair value were not material for the year ended December 31, 2018. These assets are primarily comprised of open-ended mutual funds, which are valued using the net asset value per unit. These investments are recorded at fair value within Other deferred assets on the balance sheets and classified as available for sale.

During the year ended December 31, 2018, $0.5 million ($0.4 million after tax) of various investments were sold to facilitate the distribution of benefits.

The fair value of assets and liabilities at December 31, 2018 and 2017 and the respective category within the fair value hierarchy for DP&L was determined as follows:

$ in millions	Fair Value at December 31, 2018 (a)								Fair Value at December 31, 2017 (a)
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Master trust assets
Money market funds	$	0.4	$	—	$	—	$	0.4	$	0.3	$	—	$	—	$	0.3
Equity securities	—		3.5		—		3.5		—		4.2		—		4.2
Debt securities	—		4.0		—		4.0		—		4.3		—		4.3
Hedge funds	—		0.1		—		0.1		—		0.2		—		0.2
Tangible assets	—		0.1		—		0.1		—		0.1		—		0.1
Total Master trust assets	0.4		7.7		—		8.1		0.3		8.8		—		9.1
Derivative assets
Interest rate hedges	—		1.5		—		1.5		—		1.5		—		1.5
Total derivative assets	—		1.5		—		1.5		—		1.5		—		1.5
Total assets	$	0.4	$	9.2	$	—	$	9.6	$	0.3	$	10.3	$	—	$	10.6
Liabilities
Long-term debt	$	—	$	576.1	$	17.7	$	593.8	$	—	$	640.6	$	17.8	658.4
Total liabilities	$	—	$	576.1	$	17.7	$	593.8	$	—	$	640.6	$	17.8	$	658.4

(a) Includes credit valuation adjustment

Our financial instruments are valued using the market approach in the following categories:

Level 1 inputs are used for money market accounts that are considered cash equivalents. The fair value is determined by reference to quoted market prices and other relevant information generated by market transactions.

• Level 2 inputs are used to value derivatives such as interest rate hedge contracts which are valued using a benchmark interest rate. Other Level 2 assets include open-ended mutual funds in the Master Trust, which are valued using the end of day NAV per unit.

• Level 3 inputs such as certain debt balances are considered a Level 3 input because the notes are not publicly traded. Our long-term debt is fair valued for disclosure purposes only.

All of the inputs to the fair value of our derivative instruments are from quoted market prices.

Our long-term debt is fair valued for disclosure purposes only and most of the fair values are determined using quoted market prices in inactive markets. These fair value inputs are considered Level 2 in the fair value hierarchy. As the Wright-Patterson Air Force Base note is not publicly traded, fair value is assumed to equal carrying value. These fair value inputs are considered Level 3 in the fair value hierarchy as there are no observable inputs. Additional Level 3 disclosures are not presented since our long-term debt is not recorded at fair value.

Non-recurring Fair Value Measurements

We use the cost approach to determine the fair value of our AROs, which are estimated by discounting expected cash outflows to their present value at the initial recording of the liability. Cash outflows are based on the approximate future disposal cost as determined by market information, historical information or other management estimates. These inputs to the fair value of the AROs would be considered Level 3 inputs under the fair value hierarchy. The balance of AROs was $4.7 million and $8.0 million at December 31, 2018 and 2017, respectively.

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Overview and Summary of Significant Accounting Policies

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Significant Accounting Policies [Line Items]

Overview and Summary of Significant Accounting Policies

Overview and Summary of Significant Accounting Policies

Description of Business

DP&L is a public utility incorporated in 1911 under the laws of Ohio. Beginning in 2001, Ohio law gave Ohio consumers the right to choose the electric generation supplier from whom they purchase retail generation service; however, retail transmission and distribution services are still regulated. DP&L has the exclusive right to provide such transmission and distribution services to approximately 524,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a 6,000-square mile area of West Central Ohio. As a result of Generation Separation, DP&L now only has one reportable segment, the Utility segment. In addition to DP&L's electric transmission and distribution businesses, the Utility segment includes revenues and costs associated with DP&L's investment in OVEC and the historical results of DP&L’s Beckjord and Hutchings Coal generating facilities, which have either been closed or sold. Principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, health care, data management, manufacturing and defense. Following the issuance of the DRO in September 2018 and the resulting changes to the decoupling rider effective January 1, 2019, DP&L's distribution sales are primarily impacted by customer growth within our service territory. DP&L sells its proportional share of energy and capacity from its investment in OVEC into the wholesale market. DP&L is a subsidiary of DPL. The terms “we,” “us,” “our” and “ours” are used to refer to DP&L.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs.

DP&L employed 642 people as of September 30, 2019. Approximately 58% of DP&L employees are under a collective bargaining agreement, which expires October 31, 2020.

Financial Statement Presentation

DP&L does not have any subsidiaries.

We have evaluated subsequent events through the date this report is issued.

Certain immaterial amounts from prior periods have been reclassified to conform to the current period presentation.

These financial statements have been prepared in accordance with GAAP for interim financial statements, the instructions of Form 10-Q and Regulation S-X. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with GAAP have been omitted from this interim report. Therefore, our interim financial statements in this report should be read along with the annual financial statements included in our Form 10-K for the fiscal year ended December 31, 2018.

In the opinion of our management, the Condensed Financial Statements presented in this report contain all adjustments necessary to fairly state our financial position as of September 30, 2019; our results of operations for the three and nine months ended September 30, 2019 and 2018, our cash flows for the nine months ended September 30, 2019 and 2018 and the changes in our equity for the three and nine months ended September 30, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three and nine months ended September 30, 2019 may not be indicative of our results that will be realized for the full year ending December 31, 2019.

The preparation of financial statements in conformity with GAAP requires us to make estimates and judgments that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the revenues and expenses of the periods reported. Actual results could differ from these estimates. Significant items subject to such estimates and judgments include: recognition of revenue including unbilled revenues, the carrying value of property, plant and equipment; the valuation of derivative instruments; the valuation of insurance and claims liabilities; the valuation of allowances for receivables and deferred income taxes; regulatory assets and

liabilities; liabilities recorded for income tax exposures; litigation; contingencies; the valuation of AROs; and assets and liabilities related to employee benefits.

Cash, Cash Equivalents, and Restricted Cash

The following table provides a summary of cash, cash equivalents, and restricted cash amounts reported on the Condensed Balance Sheet that reconcile to the total of such amounts as shown on the Condensed Statements of Cash Flows:

$ in millions	September 30, 2019		December 31, 2018
Cash and cash equivalents	$	14.4	$	45.0
Restricted cash	17.6		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	32.0	$	66.2

Accounting for Taxes Collected from Customers and Remitted to Governmental Authorities

DP&L collects certain excise taxes levied by state or local governments from its customers. These taxes are accounted for on a net basis and not included in revenue. The amounts of such taxes collected for the three months ended September 30, 2019 and 2018 were $13.0 million and $13.8 million, respectively. The amounts of such taxes collected for the nine months ended September 30, 2019 and 2018 were $37.3 million and $39.2 million, respectively.

New accounting pronouncements adopted in 2019 – The following table provides a brief description of recently adopted accounting pronouncements that had an impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or did not have a material impact on our financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
2018-02, Income Statement — Reporting Comprehensive Income (Topic 220), Reclassification of Certain Tax Effects from AOCI	This amendment allows a reclassification of the stranded tax effects resulting from the implementation of the Tax Cuts and Jobs Act from AOCI to retained earnings at the election of the filer. Because this amendment only relates to the reclassification of the income tax effects of the Tax Cuts and Jobs Act, the underlying guidance that requires that the effect of a change in tax laws or rates be included in income from continuing operations is not affected.	January 1, 2019	We have not elected to reclassify any amounts to retained earnings. Our accounting policy for releasing the income tax effects from AOCI occurs on a portfolio basis.
2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities	The standard updates the hedge accounting model to expand the ability to hedge nonfinancial and financial risk components, reduce complexity, and ease certain documentation and assessment requirements. When facts and circumstances are the same as at the previous quantitative test, a subsequent quantitative effectiveness test is not required. The standard also eliminates the requirement to separately measure and report hedge ineffectiveness. For cash flow hedges, this means that the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item. Transition method: modified retrospective with the cumulative effect adjustment recorded to the opening balance of retained earnings as of the initial application date. Prospective for presentation and disclosures.	January 1, 2019	The adoption of this standard had no material impact on our condensed financial statements.
2016-02, 2018-01, 2018-10, 2018-11 Leases (Topic 842)	See "Adoption of FASC Topic 842, Leases" below.	January 1, 2019	See impact upon adoption of the standard below.

Adoption of FASC Topic 842, "Leases"

On January 1, 2019, we adopted ASU 2016-02 Leases and its subsequent corresponding updates (“FASC 842”). Under this standard, lessees are required to recognize assets and liabilities for most leases and recognize expenses in a manner similar to the current accounting method. For lessors, the guidance modifies the lease classification criteria and the accounting for sales-type and direct financing leases. The guidance eliminates current real estate-specific provisions.

Under FASC 842, it is expected that fewer contracts will contain a lease. However, due to the elimination of the real estate-specific guidance and changes to certain lessor classification criteria, more leases will qualify as sales-type leases and direct financing leases. Under these two models, a lessor will derecognize the asset and will recognize a net investment in a lease. According to FASC 842, the net investment in the lease includes the fair value of the

plant after the contract period but does not include variable payments such as margin on the sale of energy. Therefore, the net investment in the lease could be significantly different than the carrying amount of the underlying asset at lease commencement. In such circumstances, the difference between the initially recognized net investment in the lease and the carrying amount of the underlying asset is recognized as a gain/loss at lease commencement.

During the course of adopting FASC 842, we applied various practical expedients including:

• The package of practical expedients (applied to all leases) that allowed lessees and lessors not to reassess:

a. whether any expired or existing contracts are or contain leases,

b. lease classification for any expired or existing leases, and

c. whether initial direct costs for any expired or existing leases qualify for capitalization under FASC 842.

• The transition practical expedient related to land easements, allowing us to carry forward our accounting treatment for land easements on existing agreements, and

• The transition practical expedient for lessees that allowed businesses to not separate lease and non-lease components. We applied the practical expedient to all classes of underlying assets when valuing right-of-use assets and lease liabilities. Contracts where we are the lessor were separated between the lease and non-lease components.

We applied the modified retrospective method of adoption and elected to continue to apply the guidance in FASC 840 Leases to the comparative periods presented in the year of adoption. Under this transition method, we applied the transition provisions starting at the date of adoption.

The adoption of FASC 842 did not have a material impact on our Condensed Financial Statements.

New Accounting Pronouncements Issued But Not Yet Effective – The following table provides a brief description of recent accounting pronouncements that could have a material impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or are expected to have no material impact on our financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
2016-13, 2019-04, 2019-05, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	See discussion of the ASU below.	January 1, 2020	We will adopt the standard on January 1, 2020; see below for the evaluation of the impact of the adoption on the condensed financial statements.

ASU 2016-13 and its subsequent corresponding updates will update the impairment model for financial assets measured at amortized cost. For trade and other receivables, held-to-maturity debt securities, loans and other instruments, entities will be required to use a new forward-looking "expected loss" model that generally will result in the earlier recognition of allowance for losses. For available-for-sale debt securities with unrealized losses, entities will measure credit losses as it is done today, except that the losses will be recognized as an allowance rather than a reduction in the amortized cost of the securities. There are various transition methods available upon adoption.

We are currently evaluating the impact of adopting the standard on our condensed financial statements; however, it is expected that the new current expected credit loss model will primarily impact the calculation of expected credit losses on $72.1 million in gross trade accounts receivable.

Description of Business

DP&L is a public utility incorporated in 1911 under the laws of Ohio. Beginning in 2001, Ohio law gave consumers the right to choose the electric generation supplier from whom they purchase retail generation service, however transmission and distribution services are still regulated. DP&L has the exclusive right to provide such service to its approximately 525,000 customers located in West Central Ohio. DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a 6,000 square mile area of West Central Ohio. Since January 2016, DP&L has been sourcing all of the generation for its SSO customers through a competitive bid process. Through September 30, 2017, DP&L owned undivided interests in multiple coal-fired power stations and multiple peaking electric generating facilities as well as numerous transmission facilities. On October 1, 2017, the DP&L-owned generating facilities, excluding the Beckjord Facility and Hutchings EGU, were transferred to AES Ohio Generation, an affiliate of DP&L and wholly-owned subsidiary of DPL, through an asset contribution agreement to a subsidiary that was merged into AES Ohio Generation. Also, Stuart Station Unit 1 was retired on October 1, 2017. Principal industries located in DP&L’s service territory include automotive, food processing, paper, plastic, manufacturing and defense. DP&L's sales reflect the general economic conditions, seasonal weather patterns of the area and the market price of electricity. Through the date of Generation Separation, DP&L sold energy and capacity into the wholesale market. As a result of Generation Separation, DP&L now only has one reportable segment, Transmission and Distribution. In addition to DP&L's electric transmission and distribution businesses, the Transmission and Distribution segment includes revenues and costs associated with DP&L's investment in OVEC and the historical results of DP&L’s Beckjord and Hutchings Coal generating facilities, which were either closed or sold in prior periods.

DP&L’s electric transmission and distribution businesses are subject to rate regulation by federal and state regulators. Accordingly, DP&L applies the accounting standards for regulated operations to its electric transmission and distribution businesses and records regulatory assets when incurred costs are expected to be recovered in future customer rates, and regulatory liabilities when current cost recoveries in customer rates relate to expected future costs or overcollections of riders.

DP&L employed 647 people at January 31, 2019. Approximately 58% of all employees are under a collective bargaining agreement.

Financial Statement Presentation

DP&L does not have any subsidiaries.

Through June 2018, DP&L had undivided ownership interests in numerous transmission facilities. These undivided interests in jointly-owned facilities were accounted for on a pro rata basis in the Financial Statements. In June 2018, DP&L closed on a transmission asset transaction with Duke and AEP, where ownership stakes in certain previously co-owned transmission assets were exchanged to eliminate co-ownership. Each previously co-owned transmission asset became wholly-owned by one of DP&L, Duke or AEP after the transaction. See Note 4 – Property, Plant and Equipment for more information.

We have evaluated subsequent events through the date this report is issued.

Certain amounts from prior periods have been reclassified to conform to the current period presentation.

The preparation of financial statements in conformity with GAAP requires us to make estimates and judgments that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the revenues and expenses of the periods reported. Actual results could differ from these estimates. Significant items subject to such estimates and judgments include: the carrying value of Property, plant and equipment; unbilled revenues; the valuation of derivative instruments; the valuation of insurance and claims liabilities; the valuation of allowances for receivables and deferred income taxes; regulatory assets and liabilities; reserves recorded for income tax exposures; litigation; contingencies; the valuation of AROs; and assets and liabilities related to employee benefits.

Revenue Recognition

Revenues are recognized from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Energy sales to customers are based on the reading of their meters that occurs on a systematic basis throughout the month. We recognize the revenues on our Statements of Operations using an accrual method for retail and other energy sales that have not yet been billed, but where electricity has been consumed. This is termed “unbilled revenues” and is a widely recognized and accepted practice for utilities. At the end of each month, unbilled revenues are determined by the estimation of unbilled energy provided to customers since the date of the last meter reading, estimated line losses, the assignment of unbilled energy provided to customer classes and the average rate per customer class.

The power sales and purchases within DP&L’s service territory are reported on a net hourly basis as revenues or purchased power on our Statements of Operations. We record expenses when purchased electricity is received and when expenses are incurred. For additional information, see Note 13 – Revenue.

Allowance for Uncollectible Accounts

We establish provisions for uncollectible accounts by using both historical average loss percentages to project future losses and by establishing specific provisions for known credit issues. Amounts are written off when reasonable collections efforts have been exhausted.

Property, Plant and Equipment

We record our ownership share of our undivided interest in jointly-owned transmission and distribution property as an asset in property, plant and equipment. New property, plant and equipment additions are stated at cost. For regulated transmission and distribution property, cost includes direct labor and material, allocable overhead expenses and an allowance for funds used during construction (AFUDC). AFUDC represents the cost of borrowed funds and equity used to finance regulated construction projects. For non-regulated property, cost also includes capitalized interest. Capitalization of AFUDC and interest ceases at either project completion or at the date specified by regulators AFUDC and capitalized interest was $0.5 million, $1.5 million and $2.0 million for the years ended December 31, 2018, 2017 and 2016, respectively.

For substantially all depreciable property, when a unit of property is retired, the original cost of that property less any salvage value is charged to Accumulated depreciation and amortization, consistent with composite depreciation practices.

Property is evaluated for impairment when events or changes in circumstances indicate that its carrying amount may not be recoverable.

Repairs and Maintenance

Costs associated with maintenance activities are recognized at the time the work is performed. These costs, which include labor, materials and supplies, and outside services required to maintain equipment and facilities, are capitalized or expensed based on defined units of property.

Depreciation

Depreciation expense is calculated using the straight-line method, which allocates the cost of property over its estimated useful life. For DP&L’s transmission and distribution assets, straight-line depreciation is applied monthly on an average composite basis using group rates. For DP&L’s transmission and distribution assets, straight-line depreciation is applied on an average annual composite basis using group rates that approximated 3.0% in 2018, 3.4% in 2017 and 4.6% in 2016. Depreciation expense was $68.2 million, $69.6 million and $64.3 million for the years ended December 31, 2018, 2017 and 2016, respectively.

Regulatory Accounting

As a regulated utility, DP&L applies the provisions of FASC 980 “Regulated Operations”, which gives recognition to the ratemaking and accounting practices of the PUCO and the FERC. Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in customer rates. Regulatory assets can also represent performance incentives permitted by the regulator. Regulatory assets have been included as allowable costs for ratemaking purposes, as authorized by the PUCO or established regulatory practices. Regulatory liabilities generally represent obligations to make refunds or future rate reductions to

customers for previous over collections or the deferral of revenues collected for costs that DP&L expects to incur in the future.

The deferral of costs (as regulatory assets) is appropriate only when the future recovery of such costs is probable. In assessing probability, we consider such factors as specific orders from the PUCO or FERC, regulatory precedent and the current regulatory environment. To the extent recovery of costs is no longer deemed probable, related regulatory assets would be required to be expensed in current period earnings. Our regulatory assets and liabilities have been created pursuant to a specific order of the PUCO or FERC or established regulatory practices, such as other utilities under the jurisdiction of the PUCO or FERC being granted recovery of similar costs. It is probable, but not certain, that these regulatory assets will be recoverable, subject to PUCO or FERC approval. Regulatory assets and liabilities are classified as current or non-current based on the term in which recovery is expected See Note 3 – Regulatory Matters for more information.

Inventories

Inventories are carried at average cost and include materials and supplies used for utility operations.

Intangibles

Intangibles include software, emission allowances and renewable energy credits. Emission allowances are carried on a first-in, first-out (FIFO) basis for purchased emission allowances. Net gains or losses on the sale of excess emission allowances, representing the difference between the sales proceeds and the cost of emission allowances, are recorded as a component of our fuel costs and are reflected in Operating income when realized. Emission allowances are amortized as they are used in our operations on a FIFO basis. Renewable energy credits are carried on a weighted average cost basis and amortized as they are used or retired.

Software is amortized over seven years. Amortization expense was $6.3 million, $5.7 million and $6.7 million for the years ended December 31, 2018, 2017 and 2016, respectively. The estimated amortization expense of this internal-use software over the next five years is $11.1 million ($3.5 million in 2019, $2.4 million in 2020, $2.2 million in 2021, $1.8 million in 2022 and $1.2 million in 2023).

Income Taxes

Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of the existing assets and liabilities, and their respective income tax bases. We establish an allowance when it is more likely than not that all or a portion of a deferred tax asset will not be realized. Our tax positions are evaluated under a more likely than not recognition threshold and measurement analysis before they are recognized for financial statement reporting. Uncertain tax positions have been classified as noncurrent income tax liabilities unless expected to be paid within one year. Our policy for interest and penalties is to recognize interest and penalties as a component of the provision for income taxes in the Statement of Operations.

Income taxes payable, which are includable in allowable costs for ratemaking purposes in future years, are recorded as regulatory assets or liability with a corresponding deferred tax liability or asset. Investment tax credits that reduced federal income taxes in the years they arose have been deferred and are being amortized to income over the useful lives of the properties in accordance with regulatory treatment See Note 3 – Regulatory Matters for additional information.

DP&L files U.S. federal income tax returns as part of the consolidated U.S. income tax return filed by AES. The consolidated tax liability is allocated to each subsidiary based on the separate return method which is specified in our tax allocation agreement and which provides a consistent, systematic and rational approach See Note 8 – Income Taxes for additional information.

Financial Instruments

Our Master Trust investments in debt and equity financial instruments of publicly traded entities are classified as equity investments. These equity securities are carried at fair value and unrealized gains and losses on these securities are recorded in Other income. As these financial instruments are held to be used for the benefit of employees participating in employee benefit plans and are not used for general operating purposes, they are classified as non-current in Other deferred assets on the Balance Sheets.

Held-for-sale Businesses

A business classified as held-for-sale is reflected on the balance sheet at the lower of its carrying amount or estimated fair value less cost to sell. A loss is recognized if the carrying amount of the business exceeds its estimated fair value less cost to sell. This loss is limited to the carrying value of long-lived assets until the completion of the sale, at which point, any additional loss is recognized. If the fair value of the business subsequently exceeds the carrying amount while the business is still held-for-sale, any impairment expense previously recognized will be reversed up to the lower of the previously recognized expense or the subsequent excess.

Assets and liabilities related to a business classified as held-for-sale are segregated in the current balance sheet in the period in which the business is classified as held-for-sale. Assets and liabilities of held-for-sale businesses are classified as current when they are expected to be disposed of within twelve months. Transactions between the business held-for-sale and businesses that are expected to continue to exist after the disposal are not eliminated to appropriately reflect the continuing operations and balances held-for-sale. See Note 14 – Generation Separation for further information.

Discontinued Operations

Discontinued operations reporting occurs only when the disposal of a business or a group of assets represents a strategic shift that has (or will have) a major effect on our operations and financial results. We report financial results for discontinued operations separately from continuing operations to distinguish the financial impact of disposal transactions from ongoing operations. Prior period amounts in the statement of operations and balance sheet are retrospectively revised to reflect the businesses determined to be discontinued operations. The cash flows of businesses that are determined to be discontinued operations are included within the relevant categories within operating, investing and financing activities on the face of the Statements of Cash Flows.

Transactions between the businesses determined to be discontinued operations and businesses that are expected to continue to exist after the disposal are not eliminated to appropriately reflect the continuing operations and balances held-for-sale. The results of discontinued operations include any gain or loss recognized on closing or adjustment of the carrying amount to fair value. See Note 14 – Generation Separation for further information.

Generation Separation

With the transfer of DP&L's generation assets to an affiliate (see Note 14 – Generation Separation), DP&L's generation business is presented as a discontinued operation and the operating activities have been reclassified to "Discontinued operations" in the Statements of Operations for the years ended December 31, 2017 and 2016 and in the notes to the financial statements.

Accounting for Taxes Collected from Customers and Remitted to Governmental Authorities

DP&L collects certain excise taxes levied by state or local governments from its customers. DP&L’s excise taxes and certain other taxes are accounted for on a net basis and recorded as a reduction in revenues in the accompanying Statements of Operations. The amounts for the years ended December 31, 2018, 2017 and 2016 were $51.7 million, $49.4 million and $50.9 million, respectively.

Cash and Cash Equivalents

Cash and cash equivalents are stated at cost, which approximates fair value. All highly liquid short-term investments with original maturities of three months or less are considered cash equivalents.

Restricted Cash

Restricted cash includes cash which is restricted as to withdrawal or usage. The nature of the restrictions includes restrictions imposed by agreements related to deposits held as collateral and cash collected under the DMR which is restricted to pay debt obligations at DPL and DP&L and position DP&L to modernize and/or maintain its transmission and distribution infrastructure.

The following table provides a summary of cash, cash equivalents, and restricted cash amounts reported on the Balance Sheet that reconcile to the total of such amounts as shown on the Statements of Cash Flows:

$ in millions	December 31, 2018		December 31, 2017
Cash and cash equivalents	$	45.0	$	5.2
Restricted cash	21.2		0.4
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	66.2	$	5.6

Financial Derivatives

All derivatives are recognized as either assets or liabilities in the balance sheets and are measured at fair value. Changes in the fair value are recorded in earnings unless the derivative is designated as a cash flow hedge of a forecasted transaction.

We use interest rate hedges to manage the interest rate risk of our variable rate debt. We use cash flow hedge accounting when the hedge or a portion of the hedge is deemed to be highly effective, which results in changes in fair value being recorded within accumulated other comprehensive income, a component of shareholder’s equity. We have elected not to offset net derivative positions in the financial statements. Accordingly, we do not offset such derivative positions against the fair value of amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral under master netting agreements. See Note 6 – Derivative Instruments and Hedging Activities for additional information.

Insurance and Claims Costs

In addition to insurance obtained from third-party providers, MVIC, a wholly-owned captive subsidiary of DPL, provides insurance coverage solely to us and other DPL subsidiaries for workers’ compensation, general liability, and property damage on an ongoing basis. DP&L is responsible for claims costs below certain coverage thresholds of MVIC and third-party insurers for the insurance coverage noted above. DP&L has estimated liabilities for medical, life, disability, and other reserves for claims costs below certain coverage thresholds of third-party providers of approximately $4.3 million and $4.4 million at December 31, 2018 and 2017, respectively, within Other current liabilities and Other deferred credits on the balance sheets. The estimated liabilities for workers’ compensation, medical, life and disability costs at DP&L are actuarially determined using certain assumptions. There is uncertainty associated with these loss estimates, and actual results may differ from the estimates. Modification of these loss estimates based on experience and changed circumstances is reflected in the period in which the estimate is re-evaluated.

Pension and Postretirement Benefits

We recognize in our Balance Sheets an asset or liability reflecting the funded status of pension and other postretirement plans with current-year changes from actuarial gains or losses related to our regulated operations, that would otherwise be recognized in AOCI, recorded as a regulatory asset as this can be recovered through future rates. Such changes that are not related to our regulated operations are recognized in AOCI. All plan assets are recorded at fair value. We follow the measurement date provisions of the accounting guidance, which require a year-end measurement date of plan assets and obligations for all defined benefit plans.

We account for and disclose pension and postretirement benefits in accordance with the provisions of GAAP relating to the accounting for pension and other postretirement plans. These GAAP provisions require the use of assumptions, such as the discount rate for liabilities and long-term rate of return on assets, in determining the obligations, annual cost and funding requirements of the plans. Consistent with the requirements of FASC 715, we apply a disaggregated discount rate approach for determining service cost and interest cost for our defined benefit pension plans and postretirement plans.

See Note 9 – Benefit Plans for more information.

Related Party Transactions

In the normal course of business, DP&L enters into transactions with other subsidiaries of DPL or AES. See Note 12 – Related Party Transactions for additional information on Related Party Transactions.

New accounting pronouncements adopted in 2018

The following table provides a brief description of recently adopted accounting pronouncements that had an impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or did not have a material impact on our financial statements.

Accounting Standard	Description	Date of Adoption	Effect on the financial statements upon adoption
New Accounting Standards Adopted
2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract	This standard aligns the accounting for implementation costs incurred for a cloud computing arrangement that is a service with the requirement for capitalizing implementation costs associated with developing or obtaining internal-use software. Transition method: retrospective or prospective.	October 1, 2018	We elected to early-adopt this standard on a prospective basis, effective for fiscal year 2018. The adoption of this standard did not have a material impact on our financial statements.
2018-14, Compensation— Retirement Benefits — Defined Benefit Plans — General (Subtopic 715-20): Disclosure Framework	This standard modifies the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. Transition method: retrospective.	Early adoption elected, January 1, 2018	Impact limited to changes in financial statement disclosures.
2017-07, Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost	This standard changes the presentation of non-service costs associated with defined benefit plans and updates the guidance so that only the service cost component will be eligible for capitalization. Transition method: retrospective for presentation of non-service cost and prospective for the change in capitalization.	January 1, 2018	For the years ended December 31, 2017 and 2016 we reclassified non-service pension costs from Operating expenses to Other expense of ($1.5) million and ($0.9) million, respectively.
2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force)	This standard requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Transition method: retrospective.	January 1, 2018	For the years ended December 31, 2017 and 2016, we reclassified from "Net cash used in investing activities" to "Net increase / (decrease) in cash, cash equivalents and restricted cash" $26.6 million and ($11.9) million, respectively.
2016-01, Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities	The standard significantly revises an entity’s accounting related to (1) classification and measurement of investments in equity securities and (2) the presentation of certain fair value changes for financial liabilities measured at fair value. It also amends certain disclosures of financial instruments. Transition method: modified retrospective. Prospective for equity investments without readily determinable fair value.	January 1, 2018	We adopted this standard January 1, 2018. At that date, we transferred $1.7 million ($1.1 million net of tax) of unrealized gains from AOCI to Retained Earnings.
2014-09, 2015-14, 2016-08, 2016-10, 2016-12, 2016-20, 2017-10, 2017-13, Revenue from Contracts with Customers (Topic 606)	See discussion of the ASU below.	January 1, 2018	See impact upon adoption of the standard below.

Adoption of FASC Topic 606, "Revenue from Contracts with Customers"

On January 1, 2018, we adopted ASU 2014-09, "Revenue from Contracts with Customers", and its subsequent corresponding updates ("FASC 606"). The core principle of this standard is that an entity shall recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. We applied the modified retrospective method of adoption to those contracts which were not completed as of January 1, 2018. Results for reporting periods beginning January 1, 2018 are presented under FASC 606, while prior period amounts were not adjusted and continue to be reported in accordance with our historic accounting under the previous revenue recognition standard. For contracts that were modified before January 1, 2018, we have not retrospectively restated the contracts for modifications. We instead reflected the aggregate effect of all modifications when identifying the satisfied and unsatisfied performance obligations, determining the transaction price and allocating the transaction price. We do not expect the adoption of the new revenue standard to have a material impact to our net income on an ongoing basis.

There was no cumulative effect to our January 1, 2018 Balance Sheet resulting from the adoption of FASC 606.

New accounting pronouncements issued but not yet effective - The following table provides a brief description of recent accounting pronouncements that could have a material impact on our financial statements. Accounting pronouncements not listed below were assessed and determined to be either not applicable or are expected to have no material impact on our financial statements.

Accounting Standard	Description	Date of Adoption	Effect on the financial statements upon adoption
New Accounting Standards Issued but Not Yet Effective
2018-02, Income Statement - Reporting Comprehensive Income (Topic 220), Reclassification of Certain Tax Effects from AOCI	This amendment allows a reclassification of the stranded tax effects resulting from the implementation of the Tax Cuts and Jobs Act from AOCI to retained earnings. Because this amendment only relates to the reclassification of the income tax effects of the Tax Cuts and Jobs Act, the underlying guidance that requires that the effect of a change in tax laws or rates be included in income from continuing operations is not affected.	January 1, 2019. Early adoption is permitted.	We do not expect any impact on our financial statements upon adoption of the standard on January 1, 2019.
2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities	The standard updates the hedge accounting model to expand the ability to hedge nonfinancial and financial risk components, reduce complexity, and ease certain documentation and assessment requirements. When facts and circumstances are the same as at the previous quantitative test, a subsequent quantitative effectiveness test is not required. The standard also eliminates the requirement to separately measure and report hedge ineffectiveness. For cash flow hedges, this means that the entire change in the fair value of a hedging instrument will be recorded in other comprehensive income and amounts deferred will be reclassified to earnings in the same income statement line as the hedged item in the period in which it settles. Transition method: modified retrospective with the cumulative effect adjustment recorded to the opening balance of retained earnings as of the initial application date. Prospective for presentation and disclosures.	January 1, 2019. Early adoption is permitted.	We are currently evaluating the impact of adopting the standard on our financial statements.
2018-19, 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	The standard updates the impairment model for financial assets measured at amortized cost. For trade and other receivables, held-to-maturity debt securities, loans and other instruments, entities will be required to use a new forward-looking "expected loss" model that generally will result in the earlier recognition of allowance for losses. For available-for-sale debt securities with unrealized losses, entities will measure credit losses as it is done today, except that the losses will be recognized as an allowance rather than a reduction in the amortized cost of the securities. Transition method: various.	January 1, 2020. Early adoption is permitted only as of January 1, 2019.	We are currently evaluating the impact of adopting the standard on our financial statements.
2016-02, 2018-01, 2018-10, 2018-11, 2018-20 Leases (Topic 842)	See discussion of the ASU below.	January 1, 2019. Early adoption is permitted.	We will adopt the standard on January 1, 2019; see below for the evaluation of the impact of its adoption on our financial statements.

Adoption of FASC Topic 842, "Leases"

ASU 2016-02 and its subsequent corresponding updates require lessees to recognize assets and liabilities for most leases but recognize expenses in a manner similar to today’s accounting. For lessors, the guidance modifies the lease classification criteria and the accounting for sales-type and direct financing leases. The guidance also eliminates today’s real estate-specific provisions.

The standard must be adopted using a modified retrospective approach. The FASB has provided an optional transition method, which we have elected, that allows entities to continue to apply the guidance in FASC 840 Leases to the comparative periods presented in the year of adoption. Under this transition method, we will apply the transition provisions starting on January 1, 2019.

We have elected to apply a package of practical expedients that allow lessees and lessors not to reassess: (1) whether any expired or existing contracts are or contain leases, (2) lease classification for any expired or existing leases, and (3) whether initial direct costs for any expired or existing leases qualify for capitalization under FASC 842. These three practical expedients must be elected as a package and must be consistently applied to all leases. We have also elected to apply an optional transition practical expedient for land easements that allows an entity to

continue applying its current accounting policy for all land easements that exist before the standard’s effective date that were not previously accounted for under FASC 840.

We established a task force focused on the identification of contracts that would be under the scope of the new standard and on the assessment and measurement of the right-of-use assets and related liabilities. Additionally, the implementation team has been working on the configuration of a lease accounting tool that will support the implementation and the subsequent accounting. The implementation team has also evaluated changes to our business processes, systems and controls to support recognition and disclosure under the new standard.

Under FASC 842, it is expected that fewer contracts will contain a lease. However, due to the elimination of the real estate-specific guidance and changes to certain lessor classification criteria, more leases will qualify as sales-type leases and direct financing leases. Under these two models, a lessor will derecognize the asset and will recognize a lease receivable. According to FASC 842, the lease receivable includes the fair value of the plant after the contract period but does not include any variable payments such as margin on the sale of energy. Therefore, the lease receivable could be significantly different than the carrying amount of the underlying asset at lease commencement. In such circumstances, the difference between the initially recognized lease receivable and the carrying amount of the underlying asset is recognized as a gain/loss at lease commencement.

The adoption of FASC 842 did not have a material impact on our financial statements.

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Fair Value Measurements (Tables) - THE DAYTON POWER AND LIGHT COMPANY [Member]

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Entity Information [Line Items]

Fair Value and Cost of Non-Derivative Instruments

The following table presents the fair value, carrying value and cost of our non-derivative instruments at September 30, 2019 and December 31, 2018. Further information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	September 30, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.2	$	0.2	$	0.4	$	0.4
Equity securities	2.3		3.9		2.4		3.5
Debt securities	4.1		4.1		4.1		4.0
Hedge funds	0.1		0.1		0.1		0.1
Tangible assets	0.1		0.1		0.1		0.1
Total assets	$	6.8	$	8.4	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	574.2	$	631.0	$	586.1	$	593.8

The table below presents the fair value and cost of our non-derivative instruments at December 31, 2018 and 2017. See also Note 6 – Derivative Instruments and Hedging Activities for the fair values of our derivative instruments.

	December 31, 2018				December 31, 2017
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.4	$	0.4	$	0.3	$	0.3
Equity securities	2.4		3.5		2.5		4.2
Debt securities	4.1		4.0		4.3		4.3
Hedge funds	0.1		0.1		0.1		0.2
Tangible assets	0.1		0.1		0.1		0.1
Total assets	$	7.1	$	8.1	$	7.3	$	9.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	586.1	$	593.8	$	646.6	$	658.4

Fair Value of Assets and Liabilities Measured on Recurring Basis

The fair value of assets and liabilities at September 30, 2019 and December 31, 2018 and the respective category within the fair value hierarchy for DP&L is as follows:

$ in millions	Fair value at September 30, 2019 (a)								Fair value at December 31, 2018 (a)
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Master Trust assets
Money market funds	$	0.2	$	—	$	—	$	0.2	$	0.4	$	—	$	—	$	0.4
Equity securities	—		3.9		—		3.9		—		3.5		—		3.5
Debt securities	—		4.1		—		4.1		—		4.0		—		4.0
Hedge funds	—		0.1		—		0.1		—		0.1		—		0.1
Tangible assets	—		0.1		—		0.1		—		0.1		—		0.1
Total Master Trust assets	0.2		8.2		—		8.4		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		0.2		—		0.2		—		1.5		—		1.5
Total derivative assets	—		0.2		—		0.2		—		1.5		—		1.5
Total assets	$	0.2	$	8.4	$	—	$	8.6	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	613.4	$	17.6	631.0		$	—	$	576.1	$	17.7	$	593.8
Total liabilities	$	—	$	613.4	$	17.6	$	631.0	$	—	$	576.1	$	17.7	$	593.8

(a)

Includes credit valuation adjustment

The fair value of assets and liabilities at December 31, 2018 and 2017 and the respective category within the fair value hierarchy for DP&L was determined as follows:

$ in millions	Fair Value at December 31, 2018 (a)								Fair Value at December 31, 2017 (a)
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Master trust assets
Money market funds	$	0.4	$	—	$	—	$	0.4	$	0.3	$	—	$	—	$	0.3
Equity securities	—		3.5		—		3.5		—		4.2		—		4.2
Debt securities	—		4.0		—		4.0		—		4.3		—		4.3
Hedge funds	—		0.1		—		0.1		—		0.2		—		0.2
Tangible assets	—		0.1		—		0.1		—		0.1		—		0.1
Total Master trust assets	0.4		7.7		—		8.1		0.3		8.8		—		9.1
Derivative assets
Interest rate hedges	—		1.5		—		1.5		—		1.5		—		1.5
Total derivative assets	—		1.5		—		1.5		—		1.5		—		1.5
Total assets	$	0.4	$	9.2	$	—	$	9.6	$	0.3	$	10.3	$	—	$	10.6
Liabilities
Long-term debt	$	—	$	576.1	$	17.7	$	593.8	$	—	$	640.6	$	17.8	658.4
Total liabilities	$	—	$	576.1	$	17.7	$	593.8	$	—	$	640.6	$	17.8	$	658.4

(a) Includes credit valuation adjustment

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Benefit Plans (Tables) - THE DAYTON POWER AND LIGHT COMPANY [Member]

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

Schedule of Amounts Recognized in Balance Sheet

and 2017. The amounts presented in the following tables for pension obligations include the collective bargaining plan formula, traditional management plan formula and cash balance plan formula and the SERP in the aggregate and have not been adjusted for $1.8 million and $1.1 million of costs billed to the Service Company for the years ended December 31, 2018 and 2017 or $3.3 million and $0.7 million of costs billed to AES Ohio Generation for the years ended December 31, 2018 and 2017.

$ in millions	Years ended December 31,
Change in benefit obligation	2018			2017
Benefit obligation at January 1	$	436.9		$	419.6
Service cost	6.1			5.7
Interest cost	13.8			14.2
Plan amendments	5.1			—
Plan curtailment	—			3.0
Actuarial (gain) / loss	(34.6		)	28.1
Benefits paid	(40.8		)	(33.7		)
Benefit obligation at December 31	386.5			436.9
Change in plan assets
Fair value of plan assets at January 1	357.5			341.0
Actual return on plan assets	(11.7		)	44.8
Employer contributions	7.9			5.4
Benefits paid	(40.8		)	(33.7		)
Fair value of plan assets at December 31	312.9			357.5
Unfunded status of plan	$	(73.6	)	$	(79.4	)
	December 31,
Amounts recognized in the Balance sheets	2018			2017
Current liabilities	$	(0.4	)	$	(0.4	)
Non-current liabilities	(73.2		)	(79.0		)
Net liability at end of year	$	(73.6	)	$	(79.4	)
Amounts recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax
Components:
Prior service cost	$	10.4		$	6.7
Net actuarial loss	137.2			148.3
Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax	$	147.6		$	155.0
Recorded as:
Regulatory asset	$	87.3		$	92.2
Accumulated other comprehensive income	60.3			62.8
Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax	$	147.6		$	155.0

Schedule of Net Periodic Benefit Cost / (Income)

The net periodic benefit cost of the pension benefit plans for the three and nine months ended September 30, 2019 and 2018 was:

	Three months ended						Nine months ended
	September 30,						September 30,
$ in millions	2019			2018			2019			2018
Service cost	$	0.9		$	1.5		$	2.7		$	4.5
Interest cost	3.7			3.4			11.2			10.3
Expected return on plan assets	(5.0		)	(5.3		)	(15.0		)	(15.9		)
Amortization of unrecognized:
Prior service cost	0.4			0.4			1.3			1.1
Actuarial loss	1.8			2.4			5.3			7.1
Net periodic benefit cost	$	1.8		$	2.4		$	5.5		$	7.1

The net periodic benefit cost of the pension plans was:

	Years ended December 31,
$ in millions	2018			2017			2016
Service cost	$	6.1		$	5.7		$	5.7
Interest cost	13.8			14.2			14.7
Expected return on assets	(21.2		)	(22.8		)	(22.8		)
Plan curtailment (a)	—			5.6			5.7
Amortization of unrecognized:
Actuarial loss	9.4			8.7			7.2
Prior service cost	1.4			1.5			3.0
Net periodic benefit cost	$	9.5		$	12.9		$	13.5
Rates relevant to each year's expense calculations
Discount rate	3.66		%	4.28		%	4.49		%
Expected return on plan assets	6.25		%	6.50		%	6.50		%

(a)    As a result of the decision to retire certain coal-fired plants, we recognized a plan curtailment of $5.6 million and $5.7 million in 2017 and 2016, respectively.

Weighted Average Assumptions Used to Determine Benefit Obligations

The weighted average assumptions used to determine benefit obligations at December 31, 2018, 2017 and 2016 were:

Benefit Obligation Assumptions	Pension
	2018	2017	2016
Discount rate for obligations	4.35%	3.66%	4.28%
Rate of compensation increases	3.94%	3.94%	3.94%

Schedule of Allocation of Plan Assets

The following table summarizes our target pension plan allocation for 2018:

	Long-Term Mid-Point Target Allocation	Percentage of plan assets as of December 31,
Asset category		2018	2017
Equity Securities	38%	33%	35%
Debt Securities	56%	58%	55%
Cash and Cash Equivalents	—%	1%	—%
Real Estate	6%	8%	10%

Fair Value Measurements for Plan Assets

The fair values of our pension plan assets at December 31, 2018 by asset category are as follows:

Fair Value Measurements for Pension Plan Assets at December 31, 2018
$ in millions	Market Value at December 31, 2018		Quoted prices in active markets for identical assets		Significant observable inputs		Significant unobservable inputs
Asset category			(Level 1)		(Level 2)		(Level 3)
Mutual funds:
U.S. equities (a)	$	79.3	$	79.3	$	—	$	—
International equities (a)	25.9		25.9		—		—
Fixed income (b)	143.7		143.7		—		—
Fixed income securities:
U.S. Treasury securities	37.5		37.5		—		—
Cash and cash equivalents:
Money market funds (c)	2.4		2.4		—		—
Other investments:
Core property collective fund (d)	24.1		—		24.1		—
Total pension plan assets	$	312.9	$	288.8	$	24.1	$	—

(a) This category includes investments in equity securities of large, small and medium sized U.S. companies and equity securities of foreign companies including those in developing countries. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(b) This category includes investments in investment-grade fixed-income instruments, U.S. dollar-denominated debt securities of emerging market issuers and high yield fixed-income securities that are rated below investment grade. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(c) This category is comprised of investments in U.S. treasury obligations that seek to preserve principal and maintain liquidity while providing current income. The funds are valued at the assets’ amortized cost to maintain a stable per share net asset value.

(d) This category represents a property fund that invests in commercial real estate. The fair value of the fund is valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

The fair values of our pension plan assets at December 31, 2017 by asset category are as follows:

Fair Value Measurements for Pension Plan Assets at December 31, 2017
$ in millions	Market Value at December 31, 2017		Quoted prices in active markets for identical assets		Significant observable inputs		Significant unobservable inputs
Asset category			(Level 1)		(Level 2)		(Level 3)
Mutual funds:
U.S. equities (a)	$	78.2	$	78.2	$	—	$	—
International equities (a)	46.3		46.3		—		—
Fixed income (b)	163.3		163.3		—		—
Fixed income securities:
U.S. Treasury securities	33.5		33.5		—		—
Other investments: (c)
Core property collective fund	36.2		—		36.2		—
Total pension plan assets	$	357.5	$	321.3	$	36.2	$	—

(a) This category includes investments in equity securities of large, small and medium sized U.S. companies and equity securities of foreign companies including those in developing countries. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(b) This category includes investments in investment-grade fixed-income instruments, U.S. dollar-denominated debt securities of emerging market issuers and high yield fixed-income securities that are rated below investment grade. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(c)

This category represents a property fund that invests in commercial real estate. The fair value of the fund is valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

Estimated Future Benefit Payments and Medicare Part D Reimbursements

Estimated future benefit payments
$ in millions due within the following years:	Pension
2019	$	26.7
2020	$	26.5
2021	$	26.3
2022	$	26.0
2023	$	25.9
2024 - 2028	$	125.1

Pension [Member]

Pension And Postretirement Benefit Plans' Obligations And Assets

The following tables set forth the changes in our pension plan's obligations and assets recorded on the Balance Sheets at December 31, 2018 and 2017. The amounts presented in the following tables for pension obligations include the collective bargaining plan formula, traditional management plan formula and cash balance plan formula and the SERP in the aggregate and have not been adjusted for $1.8 million and $1.1 million of costs billed to the Service Company for the years ended December 31, 2018 and 2017 or $3.3 million and $0.7 million of costs billed to AES Ohio Generation for the years ended December 31, 2018 and 2017.

$ in millions	Years ended December 31,
Change in benefit obligation	2018			2017
Benefit obligation at January 1	$	436.9		$	419.6
Service cost	6.1			5.7
Interest cost	13.8			14.2
Plan amendments	5.1			—
Plan curtailment	—			3.0
Actuarial (gain) / loss	(34.6		)	28.1
Benefits paid	(40.8		)	(33.7		)
Benefit obligation at December 31	386.5			436.9
Change in plan assets
Fair value of plan assets at January 1	357.5			341.0
Actual return on plan assets	(11.7		)	44.8
Employer contributions	7.9			5.4
Benefits paid	(40.8		)	(33.7		)
Fair value of plan assets at December 31	312.9			357.5
Unfunded status of plan	$	(73.6	)	$	(79.4	)
	December 31,
Amounts recognized in the Balance sheets	2018			2017
Current liabilities	$	(0.4	)	$	(0.4	)
Non-current liabilities	(73.2		)	(79.0		)
Net liability at end of year	$	(73.6	)	$	(79.4	)
Amounts recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax
Components:
Prior service cost	$	10.4		$	6.7
Net actuarial loss	137.2			148.3
Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax	$	147.6		$	155.0
Recorded as:
Regulatory asset	$	87.3		$	92.2
Accumulated other comprehensive income	60.3			62.8
Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities, pre-tax	$	147.6		$	155.0

Other Changes in Plan Assets and Benefit Obligation Recognized in Accumulated Other Comprehensive Income, Regulatory Assets And Regulatory Liabilities

Other Changes in Plan Assets and Benefit Obligation Recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities

	Years ended December 31,
$ in millions	2018			2017			2016
Net actuarial loss	$	3.4		$	9.1		$	20.9
Plan curtailment (a)	—			(5.6		)	(5.7		)
Reversal of amortization item:
Net actuarial loss	(9.4		)	(8.7		)	(7.2		)
Prior service cost	(1.4		)	(1.5		)	(3.0		)
Total recognized in Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities	$	(7.4	)	$	(6.7	)	$	5.0
Total recognized in net periodic benefit cost and Accumulated Other Comprehensive Income, Regulatory Assets and Regulatory Liabilities	$	2.1		$	6.2		$	18.5

(a)    As a result of the decision to retire certain coal-fired plants, we recognized a plan curtailment of $5.6 million and $5.7 million in 2017 and 2016, respectively.

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Consolidated Statements of Operations - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues	$ 191.1	$ 198.7	$ 570.2	$ 563.5	$ 738.7
Cost of revenues:
Net fuel cost	0.6	0.1	2.0	1.7	2.4	$ 0.5	$ 5.3
Utilities Operating Expense, Purchased Power	65.9	83.0	193.3	235.7
Gross margin					435.0	429.7	486.0
Utilities Operating Expense, Maintenance and Operations	42.2	33.8	135.2	105.9	139.7	156.5	178.4
Depreciation and amortization	17.4	19.1	52.9	56.5	74.5	75.3	71.0
Taxes, Miscellaneous	20.8	19.0	58.2	54.3	73.1	76.3	68.0
Fixed-asset impairment (Note 14)					0.0	66.3	1,353.5
Gain (Loss) on Sale of Assets and Asset Impairment Charges, excluding Discontinued Operations	0.1	0.0	0.0	(0.1)	0.2	(0.5)	(0.4)
Gain (Loss) on Disposition of Business	0.0	0.0	0.0	12.4	12.4	0.0	0.0
Operating Expenses					299.9	307.6	317.0
Costs and Expenses	146.8	155.0	441.6	466.6
Operating income	44.3	43.7	128.6	96.9	135.1	122.1	169.0
Other income / (expense), net
Interest expense	(6.1)	(5.8)	(19.9)	(20.5)	(27.3)	(30.5)	(24.7)
Charge for early redemption of debt	0.0	0.0	0.0	(0.6)	(0.6)	(1.1)	(0.5)
Other income	(0.5)	(0.4)	0.1	(1.9)	(2.8)	(2.0)	(0.2)
Other expense, net	(6.6)	(6.2)	(19.8)	(23.0)	(30.7)	(33.6)	(25.4)
Income / (loss) from continuing operations before income tax	37.7	37.5	108.8	73.9	104.4	88.5	143.6
Income tax expense / (benefit) from continuing operations	(7.2)	6.3	5.1	12.0	17.7	31.1	46.0
Net income / (loss) from continuing operations					86.7	57.4	97.6
Income / (loss) from discontinued operations before income tax					0.0	(56.3)	(1,338.7)
Income tax expense / (benefit) from discontinued operations					0.0	(15.9)	(468.4)
Net income / (loss) from discontinued operations					0.0	(40.4)	(870.3)
Dividends on preferred stock					0.0	0.0	0.7
Income / (loss) attributable to common stock					86.7	17.0	(773.4)
Net loss	44.9	31.2			86.7	17.0	(772.7)
Net income (loss)	$ 44.9	$ 31.2	$ 103.7	$ 61.9	86.7	17.0	(772.7)
Electricity, Purchased [Member]
Cost of revenues:
Cost of Goods and Services Sold					301.3	289.8	316.7
Electricity [Member]
Revenues					738.7	720.0	808.0
Cost of revenues:
Cost of Goods and Services Sold					$ 303.7	$ 290.3	$ 322.0

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Consolidated Balance Sheets (Parenthetical) - THE DAYTON POWER AND LIGHT COMPANY [Member] - $ / shares	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018	Dec. 31, 2017
Common stock, shares authorized	50,000,000	50,000,000	50,000,000	50,000,000
Common stock, shares outstanding	41,172,173	41,172,173		41,172,173
Common stock, par value (in USD per share)	$ 0.01	$ 0.01	$ 0.01	$ 0.01

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Schedule II Valuation And Qualifying Accounts

12 Months Ended

Dec. 31, 2018

Schedule II Valuation And Qualifying Accounts

Schedule II

    

THE DAYTON POWER AND LIGHT COMPANY
VALUATION AND QUALIFYING ACCOUNTS
For each of the three years ended December 31, 2018
$ in thousands
Description	Balance at Beginning of Period		Additions		Deductions (a)		Balance at End of Period
Year ended December 31, 2018
Deducted from accounts receivable -
Provision for uncollectible accounts	$	1,053	$	3,411	$	3,574	$	890
Year ended December 31, 2017
Deducted from accounts receivable -
Provision for uncollectible accounts	$	1,159	$	3,141	$	3,247	$	1,053
Year ended December 31, 2016
Deducted from accounts receivable -
Provision for uncollectible accounts	$	835	$	4,113	$	3,789	$	1,159

THE DAYTON POWER AND LIGHT COMPANY [Member]

Schedule II Valuation And Qualifying Accounts

THE DAYTON POWER AND LIGHT COMPANY
VALUATION AND QUALIFYING ACCOUNTS
For each of the three years ended December 31, 2018
$ in thousands
Description	Balance at Beginning of Period		Additions		Deductions (a)		Balance at End of Period
Year ended December 31, 2018
Deducted from accounts receivable -
Provision for uncollectible accounts	$	1,053	$	3,411	$	3,574	$	890
Year ended December 31, 2017
Deducted from accounts receivable -
Provision for uncollectible accounts	$	1,159	$	3,141	$	3,247	$	1,053
Year ended December 31, 2016
Deducted from accounts receivable -
Provision for uncollectible accounts	$	835	$	4,113	$	3,789	$	1,159

(a)    Amounts written off, net of recoveries of accounts previously written off

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Revenue (Notes)

9 Months Ended

12 Months Ended

Sep. 30, 2019

Dec. 31, 2018

THE DAYTON POWER AND LIGHT COMPANY [Member]

Revenue from Contract with Customer [Text Block]

Revenue

Revenue is primarily earned from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Revenue is recorded net of any taxes assessed on and collected from customers, which are remitted to the governmental authorities. For further discussion of our Retail, Wholesale, RTO ancillary, and Capacity revenues, see Note 13 — Revenue in Item 8.—Financial Statements and Supplementary Data of our Form 10-K.

DP&L's revenue from contracts with customers was $187.0 million and $186.1 million for the three months ended September 30, 2019 and 2018, respectively, and $554.4 million and $532.1 million for the nine months ended September 30, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue for the three and nine months ended September 30, 2019 and 2018:

	Three months ended				Nine months ended
	September 30,				September 30,
$ in millions	2019		2018		2019		2018
Retail revenue
Retail revenue from contracts with customers	$	170.5	$	168.4	$	503.8	$	469.3
Other retail revenue (a)	3.8		12.6		14.9		31.4
Wholesale revenue
Wholesale revenue from contracts with customers	4.4		4.9		12.8		24.6
RTO ancillary revenue	11.0		10.8		32.8		32.4
Capacity revenue	1.1		2.0		5.0		5.8
Miscellaneous revenue	0.3		—		0.9		—
Total revenues	$	191.1	$	198.7	$	570.2	$	563.5

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606.

The balances of receivables from contracts with customers were $65.2 million and $70.1 million as of September 30, 2019 and December 31, 2018, respectively. Payment terms for all receivables from contracts with customers are typically within 30 days.

Revenue is primarily earned from retail and wholesale electricity sales and electricity transmission and distribution delivery services. Revenue is recognized upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Revenue is recorded net of any taxes assessed on and collected from customers, which are remitted to the governmental authorities.

Retail Revenues – DP&L energy sales to utility customers are based on the reading of meters at the customer's location that occurs on a systematic basis throughout the month. DP&L sells electricity directly to end-users, such as homes and businesses, and bills customers directly. Performance obligations for retail revenues are satisfied over time as energy is delivered and the same method is used to measure progress, and thus the performance obligation meets the criteria to be considered a series. This includes both the promise to transfer energy and other distribution and/or transmission services.

In exchange for the exclusive right to sell or distribute electricity in our service area, DP&L is subject to rate regulation by federal and state regulators. This regulation sets the framework for the prices (“tariffs”) that DP&L is allowed to charge customers for electricity. Since tariffs are approved by the regulator, the price that DP&L has the right to bill corresponds directly with the value to the customer of DP&L's performance completed in each period. Therefore, revenue under these contracts is recognized using an output method measured by the MWhs delivered each month at the approved tariff.

In cases where a customer chooses to receive generation services from a CRES provider, the price for generation services is negotiated between the customer and the CRES provider, and DP&L only serves as a billing agent if requested by the CRES provider. As such, DP&L recognizes the consolidated billing arrangement with the CRES provider on a net basis, thereby recording no revenue for the generation component. Retail revenue from these customers would only be related to transmission and distribution charges.

Wholesale Revenues – DP&L's share of the power produced at OVEC is sold to PJM and is classified as Wholesale revenues.

In PJM, the promise to sell energy as wholesale revenue is separately identifiable from participation in the capacity market and the two products can be transacted independently of one another. Therefore, wholesale revenues are a separate contract with a single performance obligation. Revenue is recorded based on the quantities (MWh) delivered in each hour during each month at the spot price, making the contract effectively “month-to-month”.

RTO Revenues – Compensation for use of DP&L’s transmission assets and compensation for various ancillary services are classified as RTO revenues. As DP&L owns and operates transmission lines in southwest Ohio within PJM, demand charges collected from network customers by PJM are then allocated to the appropriate transmission owners (i.e. DP&L) and recognized as transmission revenues. Additionally, as an owner of generation and transmission assets within PJM, DPL is compensated for various ancillary services; such as reactive supply, regulation services, scheduling reserves, operating reserves, spinning/synchronized reserves as well as congestion credits that are provided to PJM via these assets.

Transmission revenues have a single performance obligation, as transmission services represent a distinct service. Additionally, as the performance obligation is satisfied over time and the same method is used to measure progress, the performance obligation meets the criteria to be considered a series. The price that DP&L, as the transmission operator, has the right to bill (received as a credit from PJM) corresponds directly with the value to the customer of performance completed in each period, as the price paid is the allocation of the tariff rate (as approved by the regulator) charged to network participants.

RTO Capacity Revenues – Compensation received from PJM for making installed generation capacity available to satisfy system integrity and reliability requirements is classified as RTO capacity revenues. Capacity, which is a stand-ready obligation to deliver energy when called upon by the RTO, is measured using MWs. If plant availability exceeds a contractual target, we may receive a performance bonus payment, or if the plant availability falls below a guaranteed minimum target, we may incur a non-availability penalty. Such bonuses or penalties represent a form of

variable consideration and are estimated and recognized when it is probable that there will not be a significant reversal and therefore the transaction price is recognized on an output basis based on the MWs.

RTO capacity revenues have a single performance obligation, as capacity is a distinct good. Additionally, as the performance obligation is satisfied over time and the same method is used to measure progress, the performance obligation meets the criteria to be considered a series. The capacity price is set through a competitive auction process established by PJM.

DP&L's revenue from contracts with customers was $706.6 million for the year ended December 31, 2018. The following table presents our revenue from contracts with customers and other revenue by segment for the year ended December 31, 2018:

	Year ended December 31,
$ in millions	2018
Retail Revenue
Retail revenue from contracts with customers	$	625.8
Other retail revenues (a)	32.1
Wholesale Revenue
Wholesale revenue from contracts with customers	29.9
RTO revenue	43.1
RTO capacity revenues	7.8
Total revenues	$	738.7

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606.

The balances of receivables from contracts with customers were $70.1 million and $62.1 million as of December 31, 2018 and January 1, 2018, respectively. Payment terms for all receivables from contracts with customers are typically within 30 days.

We have elected to apply the optional disclosure exemptions under FASC 606. Therefore, we have no disclosures pertaining to revenue expected to be recognized in any future year related to remaining performance obligations, as we exclude contracts with an original length of one year or less, contracts for which we recognize revenue based on the amount we have the right to invoice for services performed, and variable consideration allocated entirely to a wholly unsatisfied performance obligation when the consideration relates specifically to our efforts to satisfy the performance obligation and depicts the amount to which we expect to be entitled for DP&L.

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Overview and Summary of Significant Accounting Policies (Accounting for Taxes Collected from Customers and Remitted to Governmental Authorities) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
THE DAYTON POWER AND LIGHT COMPANY [Member]
Excise Taxes Collected	$ 13.0	$ 13.8	$ 37.3	$ 39.2	$ 51.7	$ 49.4	$ 50.9

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Regulatory Matters (Details) - USD ($)					1 Months Ended	9 Months Ended		12 Months Ended
	Mar. 01, 2019	Jan. 22, 2019	Oct. 01, 2018	Jan. 30, 2017	Dec. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2019	Dec. 31, 2018	Aug. 01, 2018	Dec. 31, 2017
DRO Vegetation Management Cost Baseline									$ 10,700,000
Subsidiaries [Member]
Regulatory assets earning a return					$ 5,500,000				5,500,000
DRO revenue requirement			$ 248,000,000.0
Regulatory Assets, Noncurrent					152,600,000	$ 154,700,000			152,600,000		$ 163,200,000
Distribution Modernization Plan Cost of capital projects					576,000,000.0
Regulatory Assets, Current					41,100,000	40,200,000			41,100,000		23,900,000
Regulatory Assets					193,700,000				193,700,000		187,100,000
Regulatory Liability, Noncurrent					278,300,000	252,300,000			278,300,000		221,200,000
Regulatory Liability, Current					34,900,000	36,500,000			34,900,000		14,800,000
Regulatory Liabilities					313,200,000				313,200,000		236,000,000.0
Public Utilities, Approved Rate Increase (Decrease), Amount			$ 29,800,000
Public Utilities, Approved Return on Equity, Percentage			9.999%
Public Utilities, Approved Debt Capital Structure, Percentage			4.80%
Distribution Investment Rider			$ 12,200,000
One-time Decoupling Rider Revenue Requirement							$ 3,700,000
TCJA Yearly Refund to Customers Per DRO			$ 4,000,000.0
DRO Vegetation Management Cost Deferral Cap									$ 4,600,000
Distribution Modernization Rider				$ 105,000,000.0
Requested Distribution Modernization Rider annual revenue through filing		$ 199,000,000.0
Return on Equity SEET Threshold									12.00%
Proposed annual reduction in transmission rates to reflect effects of TCJA									$ 2,400,000
Due from PJM transmission settlement					16,500,000	2,400,000			16,500,000	$ 41,600,000	0
PJM transmission enhancement repayment amount									$ 14,300,000
Tax rate after Tax Cuts and Jobs Act of 2017									21.00%
Refund of eligible excess ADIT and any related regulatory liability as required by the PUCO	$ 65,100,000
Refund of eligible excess ADIT and any related regulatory liability as required by the PUCO, including taxes						83,200,000
Reduction of Long-term regulatory liability related to deferred income taxes						$ 23.4
Subsidiaries [Member] | Vegetation Management and Other [Member]
Regulatory Assets, Noncurrent					7,800,000				$ 7,800,000
Subsidiaries [Member] | Undercollections to be collected [Member]
Regulatory Assets Type of Recovery									A/B
Regulatory Current Asset, End Date for Recovery									2019
Regulatory Assets, Current					40,500,000				$ 40,500,000		23,900,000
Subsidiaries [Member] | Amounts being recovered through base rates [Member]
Regulatory Assets Type of Recovery									B
Regulatory Current Asset, End Date for Recovery									2019
Regulatory Assets, Current					600,000				$ 600,000		0
Subsidiaries [Member] | Pension Costs [Member]
Regulatory Assets Type of Recovery									B
Regulatory Current Asset, End Date for Recovery									Ongoing
Regulatory Assets, Noncurrent					87,500,000				$ 87,500,000		92,400,000
Subsidiaries [Member] | Unrecovered OVEC Charges [Member]
Regulatory Assets Type of Recovery									C
Regulatory Current Asset, End Date for Recovery									Undetermined
Regulatory Assets, Noncurrent					28,700,000				$ 28,700,000		27,800,000
Subsidiaries [Member] | Deferred Fuel Costs [Member]
Regulatory Assets Type of Recovery									B
Regulatory Current Asset, End Date for Recovery									2020
Regulatory Assets, Noncurrent					3,300,000				$ 3,300,000		9,300,000
Subsidiaries [Member] | Deferred Regulatory Compliance Costs [Member]
Regulatory Assets Type of Recovery									B
Regulatory Current Asset, End Date for Recovery									2020
Regulatory Assets, Noncurrent					6,100,000				$ 6,100,000		9,200,000
Subsidiaries [Member] | Ccem Smart Grid And Advanced Metering Infrastructure Cost [Member]
Regulatory Assets Type of Recovery									B
Regulatory Current Asset, End Date for Recovery									Undetermined
Regulatory Assets, Noncurrent					8,500,000				$ 8,500,000		7,300,000
Subsidiaries [Member] | Loss on Reacquired Debt [Member]
Regulatory Assets Type of Recovery									B
Regulatory Current Asset, End Date for Recovery									Various
Regulatory Assets, Noncurrent					6,000,000.0				$ 6,000,000.0		7,000,000.0
Subsidiaries [Member] | Storm Costs [Member]
Regulatory Assets Type of Recovery									A
Regulatory Current Asset, End Date for Recovery									Undetermined
Regulatory Assets, Noncurrent					4,700,000				$ 4,700,000		2,100,000
Subsidiaries [Member] | Vegetation Management [Member]
Regulatory Assets Type of Recovery									A/B
Regulatory Current Asset, End Date for Recovery									Undetermined
Regulatory Assets, Noncurrent					4,600,000				$ 4,600,000		8,100,000
Postretirement Benefit Costs [Member] | Subsidiaries [Member]
Regulatory Liabilities Type of Recovery									B
Regulatory Liability, Amortization Through									Ongoing
Regulatory Liability, Noncurrent					6,000,000.0				$ 6,000,000.0		5,000,000.0
PJM transmission enhancement settlement repayment amount [Member] | Subsidiaries [Member]
Regulatory Liabilities Type of Recovery									A
Regulatory Liability, Amortization Through									2025
Regulatory Liability, Noncurrent					16,900,000				$ 16,900,000		0
Deferred Income Tax Charge [Member] | Subsidiaries [Member]
Regulatory Liability, Amortization Through									Various
Regulatory Liability, Noncurrent					116,300,000				$ 116,300,000		83,400,000
Removal Costs [Member] | Subsidiaries [Member]
Regulatory Liability, Amortization Through									Not Applicable
Regulatory Liability, Noncurrent					139,100,000				$ 139,100,000		132,800,000
Overcollection of costs to be refunded [Member] | Subsidiaries [Member]
Regulatory Liabilities Type of Recovery									A/B
Regulatory Liability, Amortization Through									2018
Regulatory Liability, Noncurrent					34,900,000				$ 34,900,000		$ 14,800,000
Scenario, Forecast [Member] | Subsidiaries [Member]
Distribution Investment Rider								$ 22,000,000.0
DRO Vegetation Management Cost Baseline								15,700,000
Requested Distribution Modernization Rider annual revenue through filing		$ 199,000,000.0
Subsequent Event [Member] | Subsidiaries [Member]
DRO Vegetation Management Cost Deferral Cap								$ 4,600,000
Long-term [Member] | Subsidiaries [Member]
Due from PJM transmission settlement					10,800,000				10,800,000
Short-term [Member] | Subsidiaries [Member]
Due from PJM transmission settlement					$ 16,500,000				$ 16,500,000

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Income Taxes (Reconciliation of Unrecognized Tax Benefits) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of year	$ 4.8	$ 4.9
Tax positions taken during prior periods	0.0	0.0
Lapse of applicable statute of limitations	0.0	(0.1)
Balance at end of year	$ 4.8	$ 4.8

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Income Taxes (Components of Income Tax Expense) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Taxes [Line Items]
Change in deferred tax regulatory asset/liability due to TCJA					$ 17.0	$ 135.2
Estimated Annual Effective Income Tax Rate, Continuing Operations			4.50%	17.10%	21.00%	35.00%
Federal income tax					$ 22.2	$ 31.0	$ 50.1
State income taxes, net of federal effect					0.6	0.4	0.4
Depreciation of AFUDC - Equity					(4.3)	1.2	3.0
Investment tax credit amortized					(0.3)	(0.3)	(0.4)
Effective income tax rate reconciliation, accrual for open tax years					0.0	(0.5)	3.4
Other, net					(0.5)	(0.7)	(10.5)
Tax expense / (benefit)	$ (7.2)	$ 6.3	$ 5.1	$ 12.0	17.7	31.1	46.0
Federal - Current					1.4	13.5	37.7
State and Local - Current					0.0	0.2	0.5
Total Current					1.4	13.7	38.2
Federal - Deferred					15.5	17.0	7.7
State and Local - Deferred					0.8	0.4	0.1
Total Deferred					$ 16.3	17.4	7.8
Increase (Decrease) in Income Taxes						$ (0.7)	$ 0.4
Tax rate before change due to Tax Cuts and Jobs Act of 2017					35.00%
Tax rate after Tax Cuts and Jobs Act of 2017					21.00%

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Derivative Instruments and Hedging Activities (Fair Value and Balance Sheet Location (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017
Total Assets [Member]
Derivative Asset, Fair Value	$ 0.2	$ 1.5
Derivative, Collateral, Obligation to Return Securities	0.0	0.0
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Derivative Asset, Fair Value, Amount Offset Against Collateral	0.2	1.5
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Other Current Assets [Member]
Derivative Asset, Fair Value		0.9	$ 0.0
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Other Noncurrent Assets [Member]
Derivative Liability, Fair Value		0.6	$ 1.5
Cash Flow Hedging [Member] | Interest Rate Swap [Member] | Short-term Derivative Positions [Member] | Other Prepayments and Current Assets [Member]
Derivative Asset, Fair Value	0.2	0.9
Derivative, Collateral, Obligation to Return Securities	0.0	0.0
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Derivative Asset, Fair Value, Amount Offset Against Collateral	$ 0.2	0.9
Cash Flow Hedging [Member] | Interest Rate Swap [Member] | Long-term Derivative Positions [Member] | Other Deferred Asset [Member]
Derivative Asset, Fair Value		0.6
Derivative, Collateral, Obligation to Return Securities		0.0
Derivative, Collateral, Obligation to Return Cash		0.0
Derivative Asset, Fair Value, Amount Offset Against Collateral		$ 0.6