10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(x) QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2019

OR

( ) TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

DPL INC. (an Ohio corporation)	THE DAYTON POWER AND LIGHT COMPANY (an Ohio corporation)
Commission file number 1-9052	Commission file number 1-2385
1065 Woodman Drive Dayton, Ohio 45432	1065 Woodman Drive Dayton, Ohio 45432
937-259-7215	937-259-7215
I.R.S. Employer Identification No. 31-1163136	I.R.S. Employer Identification No. 31-0258470

Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class	Trading Symbol(s)	Name of Each Exchange on Which Registered
N/A	N/A	N/A

Indicate by check mark whether each registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

DPL Inc.	Yes o	No x
The Dayton Power and Light Company	Yes o	No x

Each of DPL Inc. and The Dayton Power and Light Company is a voluntary filer that has filed all applicable reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months.

Indicate by check mark whether each registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

DPL Inc.	Yes x	No o
The Dayton Power and Light Company	Yes x	No o

1

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

	Large accelerated filer	Accelerated filer	Non- accelerated filer (Do not check if a smaller reporting company)	Smaller reporting company	Emerging growth company
DPL Inc.	o	o	x	o	o
The Dayton Power and Light Company	o	o	x	o	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 13(a) of the Exchange Act.

DPL Inc.	o
The Dayton Power and Light Company	o

Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

DPL Inc.	Yes o	No x
The Dayton Power and Light Company	Yes o	No x

All of the outstanding common stock of DPL Inc. is indirectly owned by The AES Corporation. All of the outstanding common stock of The Dayton Power and Light Company is owned by DPL Inc.

As of May 6, 2019, each registrant had the following shares of common stock outstanding:

Registrant	Description	Shares Outstanding
DPL Inc.	Common Stock, no par value	1
The Dayton Power and Light Company	Common Stock, $0.01 par value	41,172,173

This combined Form 10-Q is separately filed by DPL Inc. and The Dayton Power and Light Company. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. Each registrant makes no representation as to information relating to a registrant other than itself.

2

DPL Inc. and The Dayton Power and Light Company

Quarter Ended March 31, 2019

	Table of Contents	Page No.
Glossary of Terms		4
Forward-Looking Statements		5
Part I Financial Information
Item 1	Financial Statements – DPL Inc. and The Dayton Power and Light Company (Unaudited)
	DPL Inc.
	Condensed Consolidated Statements of Operations	8
	Condensed Consolidated Statements of Comprehensive Income	9
	Condensed Consolidated Balance Sheets	10
	Condensed Consolidated Statements of Cash Flows	11
	Condensed Consolidated Statements of Shareholder's Equity	12
	Notes to Condensed Consolidated Financial Statements	13
	Note 1 – Overview and Summary of Significant Accounting Policies	13
	Note 2 – Supplemental Financial Information	16
	Note 3 – Regulatory Matters	16
	Note 4 – Fair Value	17
	Note 5 – Derivative Instruments and Hedging Activities	18
	Note 6 – Long-term Debt	20
	Note 7 – Income Taxes	22
	Note 8 – Benefit Plans	22
	Note 9 – Shareholder's Equity	23
	Note 10 – Contractual Obligations, Commercial Commitments and Contingencies	23
	Note 11 – Business Segments	24
	Note 12 – Revenue	26
	Note 13 – Dispositions	26
	Note 14 – Discontinued Operations	26
	The Dayton Power and Light Company
	Condensed Statements of Operations	30
	Condensed Statements of Comprehensive Income	31
	Condensed Balance Sheets	32
	Condensed Statements of Cash Flows	33
	Condensed Statements of Shareholder's Equity	34
	Notes to Condensed Financial Statements	35
	Note 1 – Overview and Summary of Significant Accounting Policies	35
	Note 2 – Supplemental Financial Information	37
	Note 3 – Regulatory Matters	38
	Note 4 – Fair Value	38
	Note 5 – Derivative Instruments and Hedging Activities	40
	Note 6 – Long-term Debt	42
	Note 7 – Income Taxes	43
	Note 8 – Benefit Plans	43
	Note 9 – Contractual Obligations, Commercial Commitments and Contingencies	44
	Note 10 – Revenue	44
	Note 11 – Dispositions	45
Item 2	Management's Discussion and Analysis of Financial Condition and Results of Operations	46
Item 3	Quantitative and Qualitative Disclosures about Market Risk	62
Item 4	Controls and Procedures	62
Part II Other Information
Item 1	Legal Proceedings	62
Item 1A	Risk Factors	63
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds	63
Item 3	Defaults Upon Senior Securities	63
Item 4	Mine Safety Disclosures	63
Item 5	Other Information	63
Item 6	Exhibits	64
	Signatures	65

3

GLOSSARY OF TERMS 

The following terms are used in this Form 10-Q:

Term	Definition
2017 ESP	DP&L's ESP, approved October 20, 2017, effective November 1, 2017
AES	The AES Corporation, a global power company and the ultimate parent company of DPL
AES Ohio Generation	AES Ohio Generation, LLC, a wholly-owned subsidiary of DPL that owns an interest in a coal-fired EGU and previously operated EGUs from which it makes wholesale sales
AOCI	Accumulated Other Comprehensive Income
ARO	Asset Retirement Obligation
ASU	Accounting Standards Update
CAA	U.S. Clean Air Act
Conesville	AES Ohio Generation's interest in Unit 4 at the Conesville EGU
CPP	The Clean Power Plan, the USEPA's final carbon dioxide emission rules for existing power plants under Clean Air Act Section 111(d)
CSAPR	Cross-State Air Pollution Rule
DIR	Distribution Investment Rider as authorized in the DRO
DMP	Distribution Modernization Plan
DMR	Distribution Modernization Rider
DPL	DPL Inc.
DP&L	The Dayton Power and Light Company, the principal subsidiary of DPL and a public utility that delivers electricity to residential, commercial, industrial and governmental customers in a 6,000-square mile area of West Central Ohio
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
EBITDA	Earnings before interest, taxes, depreciation and amortization. EBITDA also excludes the Fixed-asset impairment
EGU	Electric Generating Unit
ELG	Steam Electric Power Effluent Limitations Guidelines
ERISA	The Employee Retirement Income Security Act of 1974
ESP	The Electric Security Plan is a plan that a utility must file with the PUCO to establish SSO rates pursuant to Ohio law
FASB	Financial Accounting Standards Board
FASC	FASB Accounting Standards Codification
Form 10-K	DPL’s and DP&L’s combined Annual Report on Form 10-K for the fiscal year ended December 31, 2018, which was filed on February 26, 2019
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
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 pursuant to an asset contribution agreement with a subsidiary that was then merged into AES Ohio Generation
kV	Kilovolt, 1,000 volts
kWh	Kilowatt-hours
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.
MVIC	Miami Valley Insurance Company, a wholly-owned insurance subsidiary of DPL that provides insurance services to DPL and its subsidiaries and, in some cases, insurance services to partner companies related to the jointly-owned facility operated by AES Ohio Generation
MW	Megawatt
NAAQS	National Ambient Air Quality Standards
NERC	North American Electric Reliability Corporation
Ohio EPA	Ohio Environmental Protection Agency
OVEC	Ohio Valley Electric Corporation, an electric generating company in which DP&L holds a 4.9% equity 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 that were sold on March 27, 2018
PJM	PJM Interconnection, LLC, an RTO
PUCO	Public Utilities Commission of Ohio
RTO	Regional Transmission Organization
SEC	Securities and Exchange Commission

4

GLOSSARY OF TERMS (cont.)
Term	Definition
SERP	Supplemental Executive Retirement Plan
Service Company	AES US Services, LLC, the shared services affiliate providing accounting, finance, and other support services to AES’ U.S. SBU businesses
SSO	Standard Service Offer represents the regulated rates, authorized by the PUCO, charged to DP&L retail customers that take retail generation service from DP&L within DP&L’s service territory
TCJA	The Tax Cuts and Jobs Act of 2017, signed on December 22, 2017
TCRR	Transmission Cost Recovery Rider
U.S.	United States of America
USEPA	U.S. Environmental Protection Agency
USF	The Universal Service Fund 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. and Utilities Strategic Business Unit, AES’ reporting unit covering the businesses in the United States, including DPL
Utility segment	DPL's Utility segment is made up of DP&L’s electric transmission and distribution businesses, which distribute electricity to residential, commercial, industrial and governmental customers

FORWARD-LOOKING STATEMENTS

Certain statements contained in this report are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. Matters discussed in this report that relate to events or developments that are expected to occur in the future, including management’s expectations, strategic objectives, business prospects, anticipated economic performance and financial condition and other similar matters constitute forward-looking statements. Forward-looking statements are based on management’s beliefs, assumptions and expectations of future economic performance, considering the information currently available to management. These statements are not statements of historical fact and are typically identified by terms and phrases such as “anticipate,” “believe,” “intend,” “estimate,” “expect,” “continue,” “should,” “could,” “may,” “plan,” “project,” “predict,” “will” and similar expressions. Such forward-looking statements are subject to risks and uncertainties and investors are cautioned that outcomes and results may vary materially from those projected due to various factors beyond our control, including but not limited to:

• 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;

• the ability of subsidiaries to pay dividends or distributions to DPL;

• 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;

5

• 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;

• 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 snow storms, droughts or other similar occurrences; and

• the risks and other factors discussed in this report and other DPL and DP&L filings with the SEC.

Forward-looking statements speak only as of the date of the document in which they are made. We disclaim any obligation or undertaking to provide any updates or revisions to any forward-looking statement to reflect any change in our expectations or any change in events, conditions or circumstances on which the forward-looking statement is based. 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.

All such factors are difficult to predict, contain uncertainties that may materially affect actual results, and many are beyond our control. See Item 1A - Risk Factors in our Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” section in such report and this Quarterly Report on Form 10-Q 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.

Our SEC filings are available to the public from the SEC’s website at www.sec.gov.

COMPANY WEBSITES

DPL’s public internet site is www.dplinc.com. DP&L’s public internet site is www.dpandl.com. The information on these websites is not incorporated by reference into this report.

Part I – Financial Information

This report includes the combined filing of DPL and DP&L. Throughout this report, 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 report that apply only to DPL or DP&L will be clearly noted in the applicable section.

Item 1 – Financial Statements

6

FINANCIAL STATEMENTS

DPL INC.

7

DPL INC.
Condensed Consolidated Statements of Operations
(Unaudited)
	Three months ended
	March 31,
$ in millions	2019			2018
Revenues	$	209.0		$	207.4
Cost of revenues:
Net fuel cost	3.5			4.5
Net purchased power cost	74.2			86.0
Total cost of revenues	77.7			90.5
Gross margin	131.3			116.9
Operating expenses:
Operation and maintenance	51.0			36.0
Depreciation and amortization	18.4			18.8
General taxes	19.5			19.4
Loss on asset disposal	0.9			0.1
Loss on disposal of business (Note 13)	—			11.7
Total operating expenses	89.8			86.0
Operating income	41.5			30.9
Other income / (expense), net:
Interest expense	(23.7		)	(27.8		)
Charge for early redemption of debt	—			(0.7		)
Other income	1.4			0.1
Total other expense, net	(22.3		)	(28.4		)
Income from continuing operations before income tax	19.2			2.5
Income tax expense from continuing operations	2.7			0.2
Net income from continuing operations	16.5			2.3
Discontinued operations (Note 14):
Income from discontinued operations before income tax	29.8			20.0
Gain / (loss) from disposal of discontinued operations	0.1			(1.9		)
Income tax expense from discontinued operations	4.3			3.5
Net income from discontinued operations	25.6			14.6
Net income	$	42.1		$	16.9

See Notes to Condensed Consolidated Financial Statements.

8

DPL INC.
Condensed Consolidated Statements of Comprehensive Income
(Unaudited)
	Three months ended March 31,
$ in millions	2019			2018
Net income	$	42.1		$	16.9
Derivative activity:
Change in derivative fair value, net of income tax (expense) / benefit of $0.1 and $(0.1) for each respective period	(0.3		)	0.9
Reclassification to earnings, net of income tax expense of $0.1 and $0.6 for each respective period	(0.2		)	(0.4		)
Reclassification of earnings related to discontinued operations, net of income tax benefit of $0.0 and $(1.4) for each respective period	—			2.7
Total change in fair value of derivatives	(0.5		)	3.2
Pension and postretirement activity:
Reclassification to earnings, net of income tax benefit of $0.0 and $(0.1) for each respective period	0.1			0.1
Total change in unfunded pension and postretirement obligations	0.1			0.1
Other comprehensive income / (loss)	(0.4		)	3.3
Net comprehensive income	$	41.7		$	20.2

See Notes to Condensed Consolidated Financial Statements.

9

DPL INC.
Condensed Consolidated Balance Sheets
(Unaudited)
$ in millions	March 31, 2019			December 31, 2018
ASSETS
Current assets:
Cash and cash equivalents	$	70.8		$	90.5
Restricted cash	42.0			21.2
Accounts receivable, net (Note 2)	87.7			90.5
Inventories (Note 2)	11.9			10.7
Taxes applicable to subsequent years	54.5			72.6
Regulatory assets, current	34.8			41.1
Other prepayments and current assets	12.9			12.9
Current assets of discontinued operations and held-for-sale businesses	6.5			8.7
Total current assets	321.1			348.2
Property, plant & equipment:
Property, plant & equipment	1,637.9			1,615.6
Less: Accumulated depreciation and amortization	(324.3		)	(310.8		)
	1,313.6			1,304.8
Construction work in process	35.3			32.2
Total net property, plant & equipment	1,348.9			1,337.0
Other non-current assets:
Regulatory assets, non-current	151.2			152.6
Intangible assets, net of amortization	18.2			18.4
Other deferred assets	21.0			21.6
Non-current assets of discontinued operations and held-for-sale businesses	5.3			5.3
Total other non-current assets	195.7			197.9
Total assets	$	1,865.7		$	1,883.1
LIABILITIES AND SHAREHOLDER'S DEFICIT
Current liabilities:
Current portion of long-term debt (Note 6)	$	103.6		$	103.6
Accounts payable	39.5			58.1
Accrued taxes	78.1			76.7
Accrued interest	30.0			14.3
Customer security deposits	29.0			21.3
Regulatory liabilities, current	39.0			34.9
Other current liabilities	17.9			22.0
Current liabilities of discontinued operations and held-for-sale businesses	9.0			12.2
Total current liabilities	346.1			343.1
Non-current liabilities:
Long-term debt (Note 6)	1,372.1			1,372.3
Deferred taxes	113.0			116.1
Taxes payable	39.9			76.1
Regulatory liabilities, non-current	279.0			278.3
Pension, retiree and other benefits	74.2			82.3
Asset retirement obligations	9.4			9.4
Other deferred credits	7.9			8.0
Non-current liabilities of discontinued operations and held-for-sale businesses	52.5			69.2
Total non-current liabilities	1,948.0			2,011.7
Commitments and contingencies (Note 10)
Common shareholder's deficit
Common stock:
1,500 shares authorized; 1 share issued and outstanding at March 31, 2019 and December 31, 2018	—			—
Other paid-in capital	2,372.1			2,370.5
Accumulated other comprehensive income	1.8			2.2
Accumulated deficit	(2,802.3		)	(2,844.4		)
Total common shareholder's deficit	(428.4		)	(471.7		)
Total liabilities and shareholder's deficit	$	1,865.7		$	1,883.1

See Notes to Condensed Consolidated Financial Statements.

10

DPL INC.
Condensed Consolidated Statements of Cash Flows
(Unaudited)
	Three months ended March 31,
$ in millions	2019			2018
Cash flows from operating activities:
Net income	$	42.1		$	16.9
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	(3.1		)	20.1
Charge for early redemption of debt	—			0.7
Deferred income taxes	5.2			(41.7		)
Loss / (gain) on disposal and sale of business, net	(0.1		)	13.6
Loss on asset disposal, net	0.9			0.6
Changes in certain assets and liabilities:
Accounts receivable, net	4.1			5.9
Inventories	(1.2		)	3.2
Taxes applicable to subsequent years	18.7			19.7
Deferred regulatory costs, net	7.7			(2.1		)
Accounts payable	(14.0		)	(0.9		)
Accrued taxes	(35.2		)	8.2
Accrued interest	15.6			17.6
Customer security deposits	7.7			0.6
Pension, retiree and other benefits	(6.9		)	(5.9		)
Other	(4.9		)	(5.9		)
Net cash provided by operating activities	36.6			50.6
Cash flows from investing activities:
Capital expenditures	(34.3		)	(27.3		)
Proceeds from disposal and sale of business	—			234.9
Payments on disposal and sale of business	—			(14.5		)
Other investing activities, net	—			2.3
Net cash provided by / (used in) investing activities	(34.3		)	195.4
Cash flows from financing activities:
Repayment of long-term debt	(1.1		)	(131.1		)
Borrowings from revolving credit facilities	—			25.0
Repayment of borrowings from revolving credit facilities	—			(15.0		)
Other financing activities, net	(0.1		)	—
Net cash used in financing activities	(1.2		)	(121.1		)
Decrease in cash and restricted cash of discontinued operations and held-for-sale businesses	—			(1.3		)
Cash, cash equivalents, and restricted cash:
Net change	1.1			123.6
Balance at beginning of period	111.7			24.9
Cash, cash equivalents, and restricted cash at end of period	$	112.8		$	148.5
Supplemental cash flow information:
Interest paid, net of amounts capitalized	$	6.7		$	7.0
Non-cash financing and investing activities:
Accruals for capital expenditures	$	4.4		$	8.9
Non-cash proceeds from sale of business	$	—		$	4.1
Non-cash capital contribution (Note 9)	$	1.5		$	44.6

See Notes to Condensed Consolidated Financial Statements.

11

DPL INC.

Condensed Consolidated Statements of Shareholder's Equity

(Unaudited)

	Common Stock (a)
$ in millions	Outstanding Shares	Amount		Other Paid-in Capital		Accumulated Other Comprehensive Income / (Loss)			Retained earnings / (accumulated deficit)			Total
Balance, January 1, 2018	1	$	—	$	2,330.4	$	0.8		$	(2,915.5	)	$	(584.3	)
Net comprehensive income						3.3			16.9			20.2
Capital contributions (b)				44.6								44.6
Other (c)						(1.0		)	1.0			—
Balance, March 31, 2018	1	$	—	$	2,375.0	$	3.1		$	(2,897.6	)	$	(519.5	)

(a) 1,500 shares authorized.

(b) Represents the conversion of a tax sharing payable to AES to contributed capital, as DP&L's 2017 ESP restricts tax sharing payments to AES during the term of the ESP. See Note 9 – Shareholder's Equity.

(c) 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 $1.6 million ($1.0 million net of tax) was reversed to Accumulated deficit.

	Common Stock (a)
$ in millions	Outstanding Shares	Amount		Other Paid-in Capital		Accumulated Other Comprehensive Income / (Loss)			Retained earnings / (accumulated deficit)			Total
Balance, January 1, 2019	1	$	—	$	2,370.5	$	2.2		$	(2,844.4	)	$	(471.7	)
Net comprehensive income						(0.4		)	42.1			41.7
Capital contributions (b)				1.5								1.5
Other				0.1								0.1
Balance, March 31, 2019	1	$	—	$	2,372.1	$	1.8		$	(2,802.3	)	$	(428.4	)

(a) 1,500 shares authorized.

(b) Represents the conversion of a tax sharing payable to AES to contributed capital, as DP&L's 2017 ESP restricts tax sharing payments to AES during the term of the ESP. See Note 9 – Shareholder's Equity.

See Notes to Condensed Consolidated Financial Statements.

12

DPL Inc.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 1 – Overview and Summary of Significant Accounting Policies

Description of Business

DPL is a diversified regional energy company organized in 1985 under the laws of Ohio. DPL has one reportable segment: the Utility segment. See Note 11 – Business Segments for more information relating to this reportable segment. The terms “we,” “us,” “our” and “ours” are used to refer to DPL and its subsidiaries.

DPL is an indirectly wholly-owned subsidiary of AES.

DP&L, a wholly-owned subsidiary of DPL, 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 526,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a6,000-square mile area of West Central Ohio. 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 will primarily be 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.

DPL’s other primary subsidiaries include MVIC and AES Ohio Generation. MVIC is our captive insurance company that provides insurance services to DPL and our other subsidiaries. AES Ohio Generation's only operating asset is an undivided interest in Conesville. AES Ohio Generation sells all of its energy and capacity into the wholesale market. DPL's subsidiaries are all wholly-owned.

DPL also has a wholly-owned business trust, DPL Capital Trust II, formed for the purpose of issuing trust capital securities to investors.

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.

DPL and its subsidiaries employed 629 people as of March 31, 2019, of which 617 were employed by DP&L. Approximately 58% of all DPLemployees are under a collective bargaining agreement, which expires October 31, 2020.

Financial Statement Presentation

DPL’s Condensed Consolidated Financial Statements include the accounts of DPL and its wholly-owned subsidiaries except for DPL Capital Trust II, which is not consolidated, consistent with the provisions of GAAP. As of March 31, 2019, AES Ohio Generation has an undivided ownership interest in one coal-fired generating facility, which is included in the financial statements at a carrying value of zero as it has been fully impaired. Operating revenues and expenses of this facility are included on a pro rata basis in the corresponding lines in the Condensed Consolidated Statements of Operations.

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

All material intercompany accounts and transactions are eliminated in consolidation. We have evaluated subsequent events through the date this report is issued.

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

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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 Consolidated Financial Statements presented in this report contain all adjustments necessary to fairly state our financial position as of March 31, 2019; our results of operations for the three months ended March 31, 2019 and 2018, our cash flows for the three months ended March 31, 2019 and 2018 and the changes in our equity for the three months ended March 31, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three months ended March 31, 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 Consolidated Balance Sheet that reconcile to the total of such amounts as shown on the Condensed Consolidated Statements of Cash Flows:

$ in millions	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	70.8	$	90.5
Restricted cash	42.0		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	112.8	$	111.7

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 March 31, 2019 and 2018 were $13.9 million and $13.1 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 consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 consolidated 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

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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 consolidated 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 consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 condensed consolidated financial statements.

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Note 2 – Supplemental Financial Information

Accounts receivable and Inventories are as follows at March 31, 2019 and December 31, 2018:

	March 31,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	60.5		$	55.8
Unbilled revenue	15.7			16.8
Amounts due from affiliates	0.7			—
Due from PJM transmission enhancement settlement	9.8			16.5
Other	1.6			2.3
Provision for uncollectible accounts	(0.6		)	(0.9		)
Total accounts receivable, net	$	87.7		$	90.5
Inventories, at average cost:
Fuel and limestone	$	3.5		$	1.9
Materials and supplies	8.4			8.3
Other	—			0.5
Total inventories, at average cost	$	11.9		$	10.7

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three months ended March 31, 2019 and 2018 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) components	Affected line item in the Condensed Consolidated Statements of Operations	Three months ended March 31,
$ in millions		2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	(0.3	)	$	(1.0	)
	Income tax expense	0.1			0.6
	Net of income taxes	(0.2		)	(0.4		)
	Loss from discontinued operations	—			4.1
	Income tax benefit from discontinued operations	—			(1.4		)
	Net of income taxes	—			2.7
Amortization of defined benefit pension items (Note 8):
	Other expense	0.1			0.2
	Income tax benefit	—			(0.1		)
	Net of income taxes	0.1			0.1
Total reclassifications for the period, net of income taxes		$	(0.1	)	$	2.4

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the three months endedMarch 31, 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	$	17.0		$	(14.8	)	$	2.2
Other comprehensive loss before reclassifications	(0.3		)	—			(0.3		)
Amounts reclassified from AOCI to earnings	(0.2		)	0.1			(0.1		)
Net current period other comprehensive income / (loss)	(0.5		)	0.1			(0.4		)
Balance at March 31, 2019	$	16.5		$	(14.7	)	$	1.8

Note 3 – Regulatory Matters

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

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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.

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 ("ADIT") and any related regulatory liability over a 10-year period. DP&L made such a filing on March 1, 2019 and proposed to return a total of $65.1 million to customers. The timing and final amount to be returned to customers is unknown at this time. Excess ADIT related to depreciation life and method differences will be returned to customers in accordance with federal tax law and related regulations.

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 March 31, 2019 and December 31, 2018. Information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	March 31, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.1	$	0.1	$	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	$	6.7	$	8.3	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	1,475.7	$	1,544.9	$	1,475.9	$	1,519.6

These financial instruments are not subject to master netting agreements or collateral requirements and as such are presented in the Condensed Consolidated 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 three months ended March 31, 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 $1.6 million ($1.0 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 three months ended March 31, 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 consolidated balance sheets and classified as available for sale.

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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 2019 to 2061.

The fair value of assets and liabilities at March 31, 2019 and December 31, 2018 and the respective category within the fair value hierarchy for DPL is as follows:

$ in millions	Fair value at March 31, 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	$	0.1	$	—	$	—	$	0.1	$	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	0.1		8.2		—		8.3		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		1.1		—		1.1		—		1.5		—		1.5
Total Derivative assets	—		1.1		—		1.1		—		1.5		—		1.5
Total Assets	$	0.1	$	9.3	$	—	$	9.4	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	1,527.3	$	17.6	$	1,544.9	$	—	$	1,501.9	$	17.7	$	1,519.6
Total Liabilities	$	—	$	1,527.3	$	17.6	$	1,544.9	$	—	$	1,501.9	$	17.7	$	1,519.6

(a) Includes credit valuation adjustment

Note 5 – Derivative Instruments and Hedging Activities

In the normal course of business, DPL 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 March 31, 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.

We had previously entered into interest rate derivative contracts to manage interest rate exposure related to anticipated borrowings of fixed-rate debt. These interest rate derivative contracts were settled in 2013 and we continue to amortize amounts out of AOCI into interest expense.

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The following tables provide information concerning gains or losses recognized in AOCI for the cash flow hedges for the three months ended March 31, 2019 and 2018:

	Three months ended					Three months ended
	March 31, 2019					March 31, 2018
			Interest						Interest
$ in millions (net of tax)	Power		Rate Hedge			Power			Rate Hedge
Beginning accumulated derivative gains / (losses) in AOCI	$	0.4	$	16.6		$	(2.8	)	$	17.5
Net gains / (losses) associated with current period hedging transactions	—		(0.3		)	—			0.9
Net gains / (losses) reclassified to earnings
Interest expense	—		(0.2		)	—			(0.4		)
Income / (loss) from discontinued operations	—		—			2.7			—
Ending accumulated derivative gains / (losses) in AOCI	$	0.4	$	16.1		$	(0.1	)	$	18.0
Portion expected to be reclassified to earnings in the next twelve months			$	(0.8	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)			17

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

Financial Statement Effect

DPL 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 DPL's interest rate swaps are as follows:

Fair Values of Derivative Instruments
at March 31, 2019
				Gross Amounts Not Offset in the Condensed Consolidated Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Consolidated Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Other prepayments and current assets)
Interest rate swap	Designated	$	0.8	$	—	$	—	$	0.8
Long-term derivative positions (presented in Other deferred assets)
Interest rate swap	Designated	0.3		—		—		0.3
Total assets		$	1.1	$	—	$	—	$	1.1

(a) Includes credit valuation adjustment.

Fair Values of Derivative Instruments
at December 31, 2018
				Gross Amounts Not Offset in the Condensed Consolidated Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Consolidated Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Other prepayments and current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other deferred assets)
Interest rate swaps	Designated	0.6		—		—		0.6
Total assets		$	1.5	$	—	$	—	$	1.5

(a) Includes credit valuation adjustment.

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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 Consolidated Statements of Operations.

Note 6 – Long-term Debt

The following table summarizes DPL's outstanding long-term debt.

	Interest		March 31,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	435.0		$	436.1
Tax-exempt First Mortgage Bonds - rates from 3.05% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.2%	2061	17.6			17.7
Unamortized deferred financing costs			(5.8		)	(6.3		)
Unamortized debt discounts and premiums, net			(1.3		)	(1.4		)
Total long-term debt at consolidated subsidiary			585.5			586.1
Senior unsecured notes	6.75%	2019	99.0			99.0
Senior unsecured notes	7.25%	2021	780.0			780.0
Note to DPL Capital Trust II (c)	8.125%	2031	15.6			15.6
Unamortized deferred financing costs			(3.9		)	(4.3		)
Unamortized debt discounts and premiums, net			(0.5		)	(0.5		)
Total long-term debt			1,475.7			1,475.9
Less: current portion			(103.6		)	(103.6		)
Long-term debt, net of current portion			$	1,372.1		$	1,372.3

(a) Range of interest rates for the three months endedMarch 31, 2019.

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

(c) Note payable to related party.

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 March 31, 2019 and December 31, 2018, DPLhad no outstanding borrowings on its line of credit. At March 31, 2019 and December 31, 2018, DP&Lhad no outstanding borrowings on its line of credit.

Significant transactions

On March 4, 2019, DPL issued a Notice of Partial Redemption to the Trustee (U.S. Bank) on the DPL6.75% Senior Notes due 2019. DPL notified the trustee that it was calling the remaining $99.0 million outstanding principal amount of these notes. The redemption date was April 4, 2019. These bonds were redeemed at par plus accrued interest and a make-whole premium of $1.5 million with cash on hand.

On April 17, 2019, DPL closed a $400.0 million issuance of senior unsecured bonds. These new bonds were priced at 4.35% and mature on April 15, 2029. Proceeds from the issuance and cash on hand will be used to settle a partial redemption for $400.0 million of DPL's7.25% senior unsecured notes maturing October 15, 2021, as discussed below. After the redemption, the DPL7.25% senior notes due in 2021 will have an outstanding balance of $380.0 million.

On April 8, 2019, DPL issued a Notice of Partial Redemption to the Trustee (Wells Fargo Bank N.A.) on the DPL7.25% Senior Notes due 2021. DPL notified the trustee that it was calling $400.0 million of the $780.0 million outstanding principal amount of these notes. The redemption date will be May 7, 2019. These bonds will be redeemed at par plus accrued interest and a make-whole premium.

On March 30, 2018, DPL issued a Notice of Partial Redemption to the Trustee (U.S. Bank) on the DPL6.75% Senior Notes due 2019. DPL notified the trustee that it was calling $101.0 million of the $200.0 million outstanding principal amount of these notes. These bonds were redeemed at par plus accrued interest and a make-whole premium of $5.1 million on April 30, 2018 with cash on hand.

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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.

On March 27, 2018, DPL made a $70.0 million prepayment to eliminate the outstanding balance of its bank term loan in full. As of March 31, 2018, the term loan was fully paid off.

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) modified a "call protection" provision which as modified 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 have been 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.

Long-term debt covenants and restrictions

DPL’s revolving credit agreement has two financial covenants. The first financial covenant, a Total Debt to EBITDA ratio, is calculated at the end of each fiscal quarter by dividing total debt at the end of the current quarter by consolidated EBITDA for the four prior fiscal quarters. The ratio in the agreement is not to exceed 7.25 to 1.00 for any fiscal quarter ending September 30, 2015 through December 31, 2018; it then steps down not to exceed 7.00 to 1.00 for any fiscal quarter ending January 1, 2019 through June 30, 2019; it then steps down not to exceed 6.75 to 1.00 for any fiscal quarter ending July 1, 2019 through December 31, 2019; and it then steps down not to exceed 6.50 to 1.00 for any fiscal quarter ending January 1, 2020 and afterward. As of March 31, 2019, this financial covenant was met with a ratio of 5.83 to 1.00.

The second financial covenant is an EBITDA to Interest Expense ratio that is calculated, at the end of each fiscal quarter, by dividing 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 2.10 to 1.00 for any fiscal quarter ending September 30, 2015 through December 31, 2018; it then steps up to be not less than 2.25 to 1.00 for any fiscal quarter ending January 1, 2019 and afterward. As of March 31, 2019, this financial covenant was met with a ratio of 2.73 to 1.00.

DPL’s secured revolving credit agreement and senior unsecured notes due 2019 also restrict dividend payments from DPL to AES, such that DPL cannot make dividend payments unless at the time of, and/or as a result of the distribution, (i) DPL’s leverage ratio does not exceed 0.67 to 1.00 and DPL’s interest coverage ratio is not less than 2.50 to 1.00 or, if such ratios are not within the parameters, (ii) DPL’s senior long-term debt rating from two of the three major credit rating agencies is at least investment grade. As of March 31, 2019, DPL’s leverage ratio was at 1.40 to 1.00. As a result, as of March 31, 2019, DPL was prohibited under each of these agreements from making a distribution to its shareholder or making a loan to any of its affiliates (other than its subsidiaries). DPL is also restricted from making dividend and tax sharing payments from DPL to AES per its 2017 ESP. This order restricts dividend payments from DPL to AES during the term of the 2017 ESP and restricts tax sharing payments from DPL to AES during the term of the DMR.

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 than0.65 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 March 31, 2019, DP&L's ratings meet those requirements and this covenant is suspended for the quarter ended March 31, 2019.

The second financial covenant measures EBITDA to Interest Expense. The TotalConsolidated EBITDA to Consolidated Interest Charges ratio is calculated, at the end of each fiscal quarter, by dividing consolidated EBITDA

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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 financial covenant was met with a ratio of 8.99 to 1.00 as of March 31, 2019.

As of March 31, 2019, DPL and DP&L were 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 months ended March 31, 2019 and 2018.

	Three months ended
	March 31,
	2019	2018
DPL	14.1%	8.0%

Income tax expense for the three months endedMarch 31, 2019 and 2018 was calculated using the estimated annual effective income tax rates for 2019 and 2018 of 14.1% and 19.2%, 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.DPL’s effective combined state and federal income tax rate was 14.1% for the three months ended March 31, 2019. This is lower than the combined federal and state statutory rate of 21.6% primarily due to the flowthrough of the net tax benefit related to the reversal of excess deferred taxes of DP&L.

For the three months ended March 31, 2019, DPL’s current period effective tax rate was not materially different than the estimated annual effective rate.

Per the terms of DP&L's 2017 ESP, DPL will not make any tax-sharing payments to AES and AES will forgo collection of the payments during the term of the DMR. As such, during the three months endedMarch 31, 2019 and 2018, DPL converted $1.5 million and $44.6 million, respectively, of accrued tax sharing liabilities with AES to additional equity investment in DPL.

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 three months ended March 31, 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 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 months ended March 31, 2019 and 2018 was:

	Three months ended
	March 31,
$ in millions	2019			2018
Service cost	$	0.9		$	1.5
Interest cost	3.7			3.4
Expected return on plan assets	(5.0		)	(5.2		)
Amortization of unrecognized:
Prior service cost	0.3			0.2
Actuarial loss	1.1			1.6
Net periodic benefit cost	$	1.0		$	1.5

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 March 31, 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 Contributions from AES

DP&L's approved six-year 2017 ESP restricts DPL from making dividend payments to its parent company, AES, during the term of the ESP, as well as from making tax-sharing payments to AES during the term of the DMR. The 2017 ESP also requires that existing tax payments owed by DPL to AES, and similar tax payments that accrue during the term of the DMR, be converted into equity investments in DPL.

For the three months ended March 31,2019 and 2018, AES made capital contributions of $1.5 million and $44.6 million, respectively, by converting the amount owed to it by DPL related to tax-sharing payments for current tax liabilities.

Note 10 – Contractual Obligations, Commercial Commitments and Contingencies

Guarantees

In the normal course of business, DPL enters into various agreements with its wholly-owned subsidiary, AES Ohio Generation, providing financial or performance assurance to third parties. These agreements are entered into primarily to support or enhance the creditworthiness otherwise attributed to this subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish this subsidiary's intended commercial purposes.

At March 31, 2019, DPL had $21.6 million of guarantees on behalf of AES Ohio Generation to third parties for future financial or performance assurance under such agreements. The guarantee arrangements entered into by DPL with these third parties cover select present and future obligations of AES Ohio Generation to such beneficiaries and are terminable by DPL upon written notice to the beneficiaries within a certain time. At March 31, 2019 and December 31, 2018, we had no outstanding balance of obligations covered by these guarantees.

To date, DPL has not incurred any losses related to the guarantees of AES Ohio Generation’s obligations and we believe it is unlikely that DPL would be required to perform or incur any losses in the future associated with any of the above guarantees.

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 March 31, 2019, DP&L could be responsible for the repayment of 4.9%, or $67.5 million, of $1,378.5 million OVEC debt obligations if they came due, comprised of both fixed and variable rate securities with maturities from 2019 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

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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 Consolidated 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 Consolidated Financial Statements. As such, costs, if any, that may be incurred in excess of those amounts provided as of March 31, 2019, cannot be reasonably determined.

Environmental Matters

DPL’s and 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. The majority of solid waste created from the combustion of coal and fossil fuels consists of fly ash and other coal combustion by-products.

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

Note 11 – Business Segments

DPL has presented the results of operations of Miami Fort Station, Zimmer Station, the Peaker Assets, Stuart Station, and Killen Station as discontinued operations as a group of components for all periods presented. For more information, see Note 14 – Discontinued Operations of Notes to DPL's Condensed Consolidated Financial Statements. As such, AES Ohio Generation only has operating activity coming from its undivided ownership interest in Conesville, which does not meet the thresholds to be a separate reportable operating segment. DPL manages its business through one reportable operating segment, the Utility segment. The primary segment performance measure is income / (loss) from continuing operations before income tax as management has concluded that this measure best reflects the underlying business performance of DPL and is the most relevant measure considered in DPL’s internal evaluation of the financial performance of its segment. The Utility segment is discussed further below.

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Utility Segment

The Utility segment is comprised of DP&L’s electric transmission and distribution businesses, which distribute electricity to residential, commercial, industrial and governmental customers. DP&L distributes electricity to more than 526,000 retail customers located in a 6,000-square mile area of West Central Ohio. 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 recording 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. The Utility segment includes revenues and costs associated with our investment in OVEC and the historical results of DP&L’s Beckjord Facility, which was closed in 2014 and transferred to a third party in the first quarter of 2018, and Hutchings Coal generating facility, which was closed in 2013. These assets did not transfer to AES Ohio Generation as part of DP&L's Generation Separation on October 1, 2017. Thus, they are grouped within the Utility segment for segment reporting purposes. In addition, regulatory deferrals and collections, which include fuel deferrals in historical periods, are included in the Utility segment.

Included within the “Other” column are other businesses that do not meet the GAAP requirements for disclosure as reportable segments as well as certain corporate costs, which include interest expense on DPL’s long-term debt and adjustments related to purchase accounting from the Merger. DPL's undivided interest in Conesville is now included within the "Other" column as it no longer meets the requirement for disclosure as a reportable operating segment, since the results of operations of the other EGUs are now presented as discontinued operations. The accounting policies of the reportable segment are the same as those described in Note 1 – Overview and Summary of Significant Accounting Policies of our 10-K. Intersegment sales, costs of sales and expenses are eliminated in consolidation. Certain shared and corporate costs are allocated between "Other" and the Utility reporting segment.

The following tables present financial information for DPL’s Utility reportable business segment:

$ in millions	Utility		Other (a)			Adjustments and Eliminations			DPL Consolidated
Three months ended March 31, 2019
Revenues from external customers	$	201.1	$	7.9		$	—		$	209.0
Intersegment revenues	0.3		0.8			(1.1		)	—
Total revenues	$	201.4	$	8.7		$	(1.1	)	$	209.0
Depreciation and amortization	$	18.0	$	0.4		$	—		$	18.4
Interest expense	$	7.1	$	16.6		$	—		$	23.7
Income / (loss) from continuing operations before income tax	$	35.1	$	(15.9	)	$	—		$	19.2
Cash capital expenditures	$	33.7	$	0.6		$	—		$	34.3
At March 31, 2019
Total assets	$	1,792.9	$	607.9		$	(535.1	)	$	1,865.7
$ in millions	Utility		Other (a)			Adjustments and Eliminations			DPL Consolidated
Three months ended March 31, 2018
Revenues from external customers	$	195.8	$	11.6		$	—		$	207.4
Intersegment revenues	0.2		0.6			(0.8		)	—
Total revenues	$	196.0	$	12.2		$	(0.8	)	$	207.4
Depreciation and amortization	$	18.6	$	0.2		$	—		$	18.8
Interest expense	$	8.2	$	19.6		$	—		$	27.8
Income / (loss) from continuing operations before income tax	$	19.3	$	(16.8	)	$	—		$	2.5
Cash capital expenditures	$	24.6	$	2.7		$	—		$	27.3
At December 31, 2018
Total assets	$	1,819.6	$	545.9		$	(482.4	)	$	1,883.1

(a) "Other" includes Cash capital expenditures and Total assets related to the assets of discontinued operations and held-for-sale businesses for all periods presented.

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Note 12 – 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, and RTO Capacity revenues, see Note 14—Revenue in Item 8.—Financial Statements and Supplementary Data of our Form 10-K.

DPL's revenue from contracts with customers was $208.3 million and $198.2 million for the three months ended March 31, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue by segment for the three months ended March 31, 2019 and 2018:

$ in millions	Utility		Other		Adjustments and Eliminations			Total
	Three months ended March 31, 2019
Retail Revenue
Retail revenue from contracts with customers	$	182.7	$	—	$	(0.3	)	$	182.4
Other retail revenues (a)	0.7		—		—			0.7
Wholesale Revenue
Wholesale revenue from contracts with customers	5.0		3.4		—			8.4
RTO revenue	10.9		—		—			10.9
RTO capacity revenues	2.1		1.6		—			3.7
Other revenues from contracts with customers (b)	—		2.9		—			2.9
Other revenues	—		0.8		(0.8		)	—
Total revenues	$	201.4	$	8.7	$	(1.1	)	$	209.0
	Three months ended March 31, 2018
Retail Revenue
Retail revenue from contracts with customers	$	161.2	$	—	$	(0.2	)	$	161.0
Other retail revenues (a)	9.2		—		—			9.2
Wholesale Revenue
Wholesale revenue from contracts with customers	12.6		7.7		—			20.3
RTO revenue	11.1		0.1		—			11.2
RTO capacity revenues	1.9		1.4		—			3.3
Other revenues from contracts with customers (b)	—		2.4		—			2.4
Other revenues	—		0.6		(0.6		)	—
Total revenues	$	196.0	$	12.2	$	(0.8	)	$	207.4

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606. Accounts receivable balances associated with these revenues were $1.5 million at March 31, 2019, and there were no balances at December 31, 2018.

(b) Other revenues from contracts with customers primarily includes revenues for various services provided by Miami Valley Lighting.

The balances of receivables from contracts with customers were $74.8 million and $72.6 million as of March 31, 2019 and December 31, 2018, respectively. Payment terms for all receivables from contracts with customers are typically within 30 days.

Note 13 – 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, DPL recognized a loss on the transfer of $11.7 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 months ended March 31, 2018, excluding the loss on transfer noted above. Prior to the transfer, the Beckjord Facility was included in the Utility segment.

Note 14 – Discontinued Operations

On December 8, 2017, DPL and AES Ohio Generation completed the sale transaction of their entire undivided interest in the Miami Fort Station and the Zimmer Station. On March 27, 2018, DPL and AES Ohio Generation completed the sale transaction of the Peaker assets to Kimura Power, LLC, and this transaction resulted in a loss

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on sale of $1.9 million for the three months ended March 31, 2018. Further, on May 31, 2018, DPL and AES Ohio Generation retired the Stuart Station coal-fired and diesel-fired generating units and the Killen Station coal-fired generating unit and combustion turbine, as planned.

Consequently, DPL determined that the disposal of this group of components as a whole represents a strategic shift by us to exit generation, and, as such, qualifies to be presented as discontinued operations. Therefore, the results of operations and financial position for this group of components were reported as such in the Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets for all periods presented.

The following table summarizes the major categories of assets and liabilities at the dates indicated:

$ in millions	March 31, 2019			December 31, 2018
Accounts receivable, net	$	3.3		$	4.0
Taxes applicable to subsequent years	1.7			2.3
Other prepayments and current assets	1.5			2.4
Intangible assets, net	5.3			5.3
Total assets of the disposal group classified as assets of discontinued operations and held-for-sale businesses in the balance sheets	$	11.8		$	14.0
Accounts payable	$	2.9		$	3.9
Accrued taxes	2.4			3.1
Other current liabilities	3.7			5.2
Deferred taxes (a)	(33.8		)	(39.8		)
Taxes payable	1.1			2.3
Pension, retiree and other benefits	9.6			9.7
Asset retirement obligations	68.9			90.4
Other deferred credits	6.7			6.6
Total liabilities of the disposal group classified as liabilities of discontinued operations and held-for-sale businesses in the balance sheets	$	61.5		$	81.4

(a) Deferred taxes represent the tax asset position of the discontinued group of components, which were netted with liabilities on DPL prior to classification as discontinued operations.

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

	Three months ended
	March 31,
$ in millions	2019			2018
Revenues	$	16.3		$	85.8
Cost of revenues	(6.6		)	(41.1		)
Operating and other expenses	20.1			(24.7		)
Income from discontinued operations	29.8			20.0
Gain / (loss) from disposal of discontinued operations	0.1			(1.9		)
Income tax expense from discontinued operations	4.3			3.5
Net income from discontinued operations	$	25.6		$	14.6

Cash flows related to discontinued operations are included in our Condensed Consolidated Statements of Cash Flows. Cash flows from operating activities for discontinued operations were $8.1 million and $9.0 million for the three months ended March 31,2019 and 2018, respectively. Cash flows from investing activities for discontinued operations were $235.8 million for the three months ended March 31,2018. For the three months ended March 31,2019, there were no cash flows from investing activities.

AROs of Discontinued Operations

DPL's retired Stuart and Killen generating facilities continue to carry ARO liabilities consisting primarily of river intake and discharge structures, coal unloading facilities, landfills and ash disposal facilities. In the first quarter of 2019, DPL reduced the ARO liability related to the Stuart and Killen ash ponds and landfills by a combined $22.5 million based on updated internal analyses that reduced estimated closure costs associated with these ash ponds and landfills. The remaining ARO liability related to Stuart and Killen is included in the Asset retirement obligations balance in the total liabilities of the disposal group classified as liabilities of discontinued operations and held-for-sale businesses in the balance sheets as of March 31, 2019 above. As these plants are no longer in service, the reduction to the ARO liability was also recorded as a credit to depreciation and amortization expense in the same

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amount. The credit to depreciation and amortization expense is included in operating and other expenses of discontinued operations for the three months ended March 31, 2019 in the table above.

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FINANCIAL STATEMENTS

The Dayton Power and Light Company

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THE DAYTON POWER AND LIGHT COMPANY
Condensed Statements of Operations
(Unaudited)
	Three months ended
	March 31,
$ in millions	2019			2018
Revenues	$	201.4		$	196.0
Cost of revenues:
Net fuel cost	0.9			0.9
Net purchased power cost	73.3			83.8
Total cost of revenues	74.2			84.7
Gross margin	127.2			111.3
Operating expenses:
Operation and maintenance	48.2			32.2
Depreciation and amortization	18.0			18.6
General taxes	19.4			19.3
Loss on disposal of business (Note 11)	—			12.4
Total operating expenses	85.6			82.5
Operating income	41.6			28.8
Other income / (expense), net:
Interest expense	(7.1		)	(8.2		)
Charge for early redemption of debt	—			(0.5		)
Other income / (expense)	0.6			(0.8		)
Total other expense, net	(6.5		)	(9.5		)
Income before income tax	35.1			19.3
Income tax expense	6.1			3.6
Net income	$	29.0		$	15.7

See Notes to Condensed Financial Statements.

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THE DAYTON POWER AND LIGHT COMPANY
Condensed Statements of Comprehensive Income
(Unaudited)
	Three months ended March 31,
$ in millions	2019			2018
Net income	$	29.0		$	15.7
Derivative activity:
Change in derivative fair value, net of income tax (expense) / benefit of $0.1 and $(0.1) for each respective period	(0.2		)	0.5
Reclassification to earnings, net of income tax expense of $0.0 and $0.5 for each respective period	(0.1		)	(0.3		)
Total change in fair value of derivatives	(0.3		)	0.2
Pension and postretirement activity:
Reclassification to earnings, net of income tax benefit of $(0.2) and $(0.2) for each respective period	0.7			0.9
Total change in unfunded pension and postretirement obligations	0.7			0.9
Other comprehensive income	0.4			1.1
Net comprehensive income	$	29.4		$	16.8

See Notes to Condensed Financial Statements.

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THE DAYTON POWER AND LIGHT COMPANY
Condensed Balance Sheets
(Unaudited)
$ in millions	March 31, 2019			December 31, 2018
ASSETS
Current assets:
Cash and cash equivalents	$	18.8		$	45.0
Restricted cash	42.0			21.2
Accounts receivable, net (Note 2)	88.4			90.4
Inventories (Note 2)	8.1			7.7
Taxes applicable to subsequent years	54.3			72.4
Regulatory assets, current	34.8			41.1
Taxes receivable	12.9			19.6
Other prepayments and current assets	14.9			13.3
Total current assets	274.2			310.7
Property, plant & equipment:
Property, plant & equipment	2,292.4			2,274.4
Less: Accumulated depreciation and amortization	(997.2		)	(988.0		)
	1,295.2			1,286.4
Construction work in process	34.7			31.7
Total net property, plant & equipment	1,329.9			1,318.1
Other non-current assets:
Regulatory assets, non-current	151.2			152.6
Intangible assets, net of amortization	17.1			17.2
Other deferred assets	20.5			21.0
Total other non-current assets	188.8			190.8
Total assets	$	1,792.9		$	1,819.6
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Current portion of long-term debt (Note 6)	$	4.6		$	4.6
Accounts payable	37.1			55.8
Accrued taxes	77.8			75.7
Accrued interest	0.7			0.4
Customer security deposits	29.0			21.3
Regulatory liabilities, current	39.0			34.9
Other current liabilities	13.5			17.5
Total current liabilities	201.7			210.2
Non-current liabilities:
Long-term debt (Note 6)	580.9			581.5
Deferred taxes	128.7			131.7
Taxes payable	41.0			77.1
Regulatory liabilities, non-current	279.0			278.3
Pension, retiree and other benefits	75.0			83.2
Asset retirement obligations	4.7			4.7
Other deferred credits	7.5			7.6
Total non-current liabilities	1,116.8			1,164.1
Commitments and contingencies (Note 9)
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	711.8			711.8
Accumulated other comprehensive loss	(34.9		)	(35.3		)
Accumulated deficit	(202.9		)	(231.6		)
Total common shareholder's equity	474.4			445.3
Total liabilities and shareholder's equity	$	1,792.9		$	1,819.6

See Notes to Condensed Financial Statements.

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THE DAYTON POWER AND LIGHT COMPANY
Condensed Statements of Cash Flows
(Unaudited)
	Three months ended March 31,
$ in millions	2019			2018
Cash flows from operating activities:
Net income	$	29.0		$	15.7
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	18.0			18.6
Charge for early redemption of debt	—			0.5
Deferred income taxes	(0.9		)	3.6
Loss on disposal of business	—			12.4
Changes in certain assets and liabilities:
Accounts receivable, net	2.6			(2.3		)
Inventories	(0.5		)	(0.2		)
Taxes applicable to subsequent years	18.1			17.8
Deferred regulatory costs, net	7.7			(2.1		)
Accounts payable	(12.7		)	7.7
Accrued taxes payable / receivable	(27.4		)	(36.3		)
Accrued interest	0.1			0.3
Customer security deposits	7.7			0.6
Pension, retiree and other benefits	(6.8		)	(5.5		)
Other	(5.4		)	(0.2		)
Net cash provided by operating activities	29.5			30.6
Cash flows from investing activities:
Capital expenditures	(33.7		)	(24.6		)
Payments on disposal of business	—			(14.5		)
Other investing activities, net	—			(0.3		)
Net cash used in investing activities	(33.7		)	(39.4		)
Cash flows from financing activities:
Returns of capital paid to parent	—			(23.8		)
Capital contributions from parent	—			80.0
Borrowings from revolving credit facilities	—			25.0
Repayment of borrowings from revolving credit facilities	—			(15.0		)
Retirement of long-term debt	(1.1		)	(61.1		)
Other financing activities, net	(0.1		)	—
Net cash provided by / (used in) financing activities	(1.2		)	5.1
Cash, cash equivalents, and restricted cash:
Net change	(5.4		)	(3.7		)
Balance at beginning of period	66.2			5.6
Cash, cash equivalents, and restricted cash at end of period	$	60.8		$	1.9
Supplemental cash flow information:
Interest paid, net of amounts capitalized	$	5.9		$	5.5
Non-cash financing and investing activities:
Accruals for capital expenditures	$	4.8		$	4.6

See Notes to Condensed Financial Statements.

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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 Income / (Loss)			Retained Earnings / 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

(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 Income / (Loss)			Retained Earnings / 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

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

See Notes to Condensed Financial Statements.

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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&Lis 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 526,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a6,000-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 will primarily be 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 617 people as of March 31, 2019. Approximately 59% of DP&Lemployees 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 March 31, 2019; our results of operations for the three months ended March 31, 2019 and 2018, our cash flows for the three months ended March 31, 2019 and 2018 and the changes in our equity for the three months ended March 31, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three months ended March 31, 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

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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	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	18.8	$	45.0
Restricted cash	42.0		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	60.8	$	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 March 31, 2019 and 2018 were $13.9 million and $13.1 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
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:

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• 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 consolidated 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, 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 condensed financial statements.

Note 2 – Supplemental Financial Information

Accounts receivable and Inventories are as follows at March 31, 2019 and December 31, 2018:

	March 31,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	58.0		$	53.3
Unbilled revenue	15.7			16.8
Amounts due from affiliates	3.9			2.3
Due from PJM transmission enhancement settlement	9.8			16.5
Other	1.6			2.4
Provision for uncollectible accounts	(0.6		)	(0.9		)
Total accounts receivable, net	$	88.4		$	90.4
Inventories, at average cost:
Materials and supplies	$	8.1		$	7.1
Other	—			0.6
Total inventories, at average cost	$	8.1		$	7.7

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Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three months ended March 31, 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 March 31,
$ in millions		2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	(0.1	)	$	(0.8	)
	Income tax expense	—			0.5
	Net of income taxes	(0.1		)	(0.3		)
Amortization of defined benefit pension items (Note 8):
	Other expense	0.9			1.1
	Income tax benefit	(0.2		)	(0.2		)
	Net of income taxes	0.7			0.9
Total reclassifications for the period, net of income taxes		$	0.6		$	0.6

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the three months ended March 31, 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	(0.2		)	—			(0.2		)
Amounts reclassified from AOCI to earnings	(0.1		)	0.7			0.6
Net current period other comprehensive income / (loss)	(0.3		)	0.7			0.4
Balance at March 31, 2019	$	0.3		$	(35.2	)	$	(34.9	)

Note 3 – Regulatory Matters

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.

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 ("ADIT") and any related regulatory liability over a 10-year period. DP&L made such a filing on March 1, 2019 and proposed to return a total of $65.1 million to customers. The timing and final amount to be returned to customers is unknown at this time. Excess ADIT related to depreciation life and method differences will be returned to customers in accordance with federal tax law and related regulations.

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

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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 March 31, 2019 and December 31, 2018. Information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	March 31, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.1	$	0.1	$	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	$	6.7	$	8.3	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	585.5	$	592.6	$	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 three months ended March 31, 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 three months ended March 31, 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.

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The fair value of assets and liabilities at March 31, 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 March 31, 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	$	0.1	$	—	$	—	$	0.1	$	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	0.1		8.2		—		8.3		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		1.1		—		1.1		—		1.5		—		1.5
Total derivative assets	—		1.1		—		1.1		—		1.5		—		1.5
Total assets	$	0.1	$	9.3	$	—	$	9.4	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	575.0	$	17.6	592.6		$	—	$	576.1	$	17.7	$	593.8
Total liabilities	$	—	$	575.0	$	17.6	$	592.6	$	—	$	576.1	$	17.7	$	593.8

(a) Includes credit valuation adjustment

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 March 31, 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.

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The following tables provide information concerning gains or losses recognized in AOCI for the cash flow hedges for the three months ended March 31, 2019 and 2018:

	Three months ended
	March 31, 2019			March 31, 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	(0.2		)	0.5
Net losses reclassified to earnings
Interest expense	(0.1		)	(0.3		)
Ending accumulated derivative gains in AOCI	$	0.3		$	1.6
Portion expected to be reclassified to earnings in the next twelve months	$	(0.8	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	17

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 March 31, 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 Other prepayments and current assets)
Interest rate swap	Designated	$	0.8	$	—	$	—	$	0.8
Long-term derivative positions (presented in Other deferred assets)
Interest rate swap	Designated	0.3		—		—		0.3
Total assets		$	1.1	$	—	$	—	$	1.1

(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 Other prepayments and current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other deferred 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 outstanding long-term debt.

	Interest		March 31,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	435.0		$	436.1
Tax-exempt First Mortgage Bonds - rates from 3.05% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.2%	2061	17.6			17.7
Unamortized deferred financing costs			(5.8		)	(6.3		)
Unamortized debt discounts and premiums, net			(1.3		)	(1.4		)
Total long-term debt			585.5			586.1
Less: current portion			(4.6		)	(4.6		)
Long-term debt, net of current portion			$	580.9		$	581.5

(a) Range of interest rates for the three months ended March 31, 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 March 31, 2019 and December 31, 2018, DP&Lhad no outstanding borrowings on its line of credit.

Significant transactions

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.

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) modified a "call protection" provision which as modified 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 have been 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.

Long-term 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 than0.65 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 March 31, 2019, DP&L's ratings meet those requirements and this covenant is suspended for the quarter ended March 31, 2019.

The second financial covenant measures EBITDA to Interest Expense. The TotalConsolidated 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 financial covenant was met with a ratio of 8.99 to 1.00 as of March 31, 2019.

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As of March 31, 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 months ended March 31, 2019 and 2018.

	Three months ended
	March 31,
	2019	2018
DP&L	17.4%	18.7%

Income tax expense for the three months endedMarch 31, 2019 and 2018 was calculated using the estimated annual effective income tax rates for 2019 and 2018 of 17.3% and 19.8%, 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 17.4% for the three months ended March 31, 2019. 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.

For the three months ended March 31, 2019, DP&L’s current period effective tax rate 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 three months ended March 31, 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 months ended March 31, 2019 and 2018 was:

	Three months ended
	March 31,
$ in millions	2019			2018
Service cost	$	0.9		$	1.5
Interest cost	3.7			3.4
Expected return on plan assets	(5.0		)	(5.2		)
Amortization of unrecognized:
Prior service cost	0.5			0.4
Actuarial loss	1.7			2.3
Net periodic benefit cost	$	1.8		$	2.4

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

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obligation of $9.0 million at March 31, 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 – 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 March 31, 2019, DP&L could be responsible for the repayment of 4.9%, or $67.5 million, of $1,378.5 million OVEC debt obligations if they came due, comprised of both fixed and variable rate securities with maturities from 2019 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 March 31, 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.

Note 10 – 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

44

further discussion of our Retail, Wholesale, RTO, and RTO 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 $200.7 million and $186.8 million for the three months ended March 31, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue for the three months ended March 31, 2019 and 2018:

	Three months ended
$ in millions	March 31, 2019		March 31, 2018
Retail Revenue
Retail revenue from contracts with customers	$	182.7	$	161.2
Other retail revenues (a)	0.7		9.2
Wholesale Revenue
Wholesale revenue from contracts with customers	5.0		12.6
RTO revenue	10.9		11.1
RTO capacity revenues	2.1		1.9
Total revenues	$	201.4	$	196.0

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606. Accounts receivable balances associated with these revenues were $1.5 million at March 31, 2019, and there were no balances at December 31, 2018.

The balances of receivables from contracts with customers were $72.4 million and $70.1 million as of March 31, 2019 and December 31, 2018, respectively. Payment terms for all receivables from contracts with customers are typically within 30 days.

Note 11 – 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 months ended March 31, 2018, excluding the loss on transfer noted above.

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Item 2 – Management's Discussion and Analysis of Financial Condition and Results of Operations

This report includes the combined filing of DPL and DP&L. On November 28, 2011, DPL became an indirectly wholly-owned subsidiary of AES, a global power company. Throughout this report, the terms “we,” “us,” “our” and “ours” are used to refer to both DPL and DP&L, respectively and together, unless the context indicates otherwise. Discussions or areas of this report that apply only to DPL or DP&L will clearly be noted in the section.

FORWARD-LOOKING INFORMATION

The following discussion contains forward-looking statements and should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and related footnotes of DPL and the Condensed Financial Statements and related footnotes of DP&L included in Part I – Financial Information, the risk factors in Item 1A to Part I of our Form 10-K for the fiscal year ended December 31, 2018 and in Item 1A to Part II of this Quarterly Report on Form 10-Q, and our “Forward-Looking Statements” section of this Form 10-Q. For a list of certain abbreviations or acronyms in this discussion, see the Glossary at the beginning of this Form 10-Q.

OVERVIEW OF OUR BUSINESS

DPL is an indirectly wholly-owned subsidiary of AES.

DPL has three primary subsidiaries, DP&L, AES Ohio Generation and MVIC. DP&L is a public utility providing electric transmission and distribution services in West Central Ohio. AES Ohio Generation owns an undivided interest in a coal-fired generating facility and sells all of its energy and capacity into the wholesale market. AES Ohio Generation also owns two retired coal-fired facilities. MVIC is our captive insurance company that provides insurance services to DP&L and our other subsidiaries. For additional information, see Item 1 – Business of our Form 10-K. All of DPL's subsidiaries are wholly-owned.

As an electric public utility in Ohio, DP&L provides regulated transmission and distribution services to its customers as well as retail SSO electric service. DP&L's sales reflect the general economic conditions, seasonal weather patterns and the growth of energy efficiency initiatives.

EXECUTIVE SUMMARY

DPL

DPL'sincome from continuing operations before income tax for the three months ended March 31, 2019 increased by $16.7 million, from pre-tax income of $2.5 million for the three months ended March 31, 2018 to pre-tax income of $19.2 million for the three months ended March 31, 2019, primarily due to factors including, but not limited to:

	Three months ended
	March 31,
$ in millions	2019 vs. 2018
Higher rates due to the distribution rate order, including the decoupling rider	$	5.6
Increase due to the loss on transfer of the Beckjord facility in the first quarter of 2018	11.7
Increase due to lower interest expense from debt payments made in 2018	4.1
Decrease due to higher maintenance of overhead transmission and distribution lines	(2.7		)
Other	(2.0		)
Net change in income from continuing operations before income tax	$	16.7

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DP&L

DP&L'sincome before income tax for the three months ended March 31, 2019 increased by $15.8 million, from pre-tax income of $19.3 million for the three months ended March 31, 2018 to pre-tax income of $35.1 million for the three months ended March 31, 2019, primarily due to factors including, but not limited to:

	Three months ended
	March 31,
$ in millions	2019 vs. 2018
Higher rates due to the distribution rate order, including the decoupling rider	$	5.6
Increase due to the loss on transfer of the Beckjord facility in the first quarter of 2018	12.4
Increase due to lower interest expense from debt payments made in 2018	1.1
Decrease due to higher maintenance of overhead transmission and distribution lines	(2.7		)
Other	(0.6		)
Net change in income before income tax	$	15.8

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RESULTS OF OPERATIONS HIGHLIGHTS – DPL

DPL’s results of operations include the results of its subsidiaries, including its principal subsidiary DP&L. All material intercompany accounts and transactions have been eliminated in consolidation. A separate discussion of the results of operations for DP&L is presented elsewhere in this report.

	Three months ended
	March 31,
$ in millions	2019			2018
Revenues:
Retail	$	183.1		$	170.2
Wholesale	8.4			20.3
RTO revenues	10.9			11.2
RTO capacity revenues	3.7			3.3
Other revenues	2.9			2.4
Total revenues	209.0			207.4
Cost of revenues:
Net fuel cost	3.5			4.5
Purchased power:
Purchased power	66.5			65.8
RTO charges	7.3			18.9
RTO capacity charges	0.4			1.3
Net purchased power cost	74.2			86.0
Total cost of revenues	77.7			90.5
Gross margin	131.3			116.9
Operating expenses:
Operation and maintenance	51.0			36.0
Depreciation and amortization	18.4			18.8
General taxes	19.5			19.4
Loss on asset disposal	0.9			0.1
Loss on disposal of business	—			11.7
Total operating expenses	89.8			86.0
Operating income	41.5			30.9
Other income / (expense), net:
Interest expense	(23.7		)	(27.8		)
Charge for early redemption of debt	—			(0.7		)
Other income	1.4			0.1
Total other expense, net	(22.3		)	(28.4		)
Income from continuing operations before income tax (a)	$	19.2		$	2.5

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

DPL – 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) and because DPL's generation has greatly decreased in recent years due to plant sales and closures, weather and other factors influencing demand have minimal impact on our net operating results.

	Three months ended March 31,
	2019	2018
Heating degree-days (a)	2,692	2,858
Cooling degree-days (a)	—	3

(a) Heating and cooling degree-days are a measure of the relative heating or cooling required for a home or business. The heating degrees in a day are calculated as the degrees that the average actual daily temperature is below 65 degrees Fahrenheit. For example, if the average temperature on March 20th was 40 degrees Fahrenheit, the heating degrees for that day would be the 25-

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degree difference between 65 degrees and 40 degrees. Similarly, cooling degrees in a day are calculated as the degrees that the average actual daily temperature is above 65 degrees Fahrenheit.

DPL's electric sales and billed customers were as follows:

ELECTRIC SALES AND CUSTOMERS (a)
	Three months ended
	March 31,
	2019	2018
Retail electric sales (b)	3,670	3,608
Wholesale electric sales (c)	261	397
Total electric sales	3,931	4,005
Billed electric customers (end of period)	525,957	523,280

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

(b) DPLretail electric sales represent the total transmission and distribution retail sales for the periods presented. SSO sales were 1,109 KWh for the three months ended March 31, 2019, and 1,039 KWh for the three months ended March 31, 2018.

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

We sell our share of the generation from Conesville and 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; availability of our generating plant and non-affiliated generating plants to sell into the wholesale market; contracted wholesale sales and our variable generation costs. Our goal is to make wholesale sales when it is profitable to do so.

During the three months ended March 31, 2019, revenue increased $1.6 million to $209.0 million compared to $207.4 million in the same period of the prior year. This change was primarily the result of changes in the components of revenue shown below:

	Three months ended
	March 31,
$ in millions	2019 vs. 2018
Retail
Rate
Increase in energy efficiency and USF revenue rate riders	$	11.4
Increase in base distribution rates due to the DRO	8.0
Increase due to the DIR, which was effective with the DRO	6.2
Decrease in the TCRR as DP&L passes back the benefits of the PJM Transmission Enhancement Settlement to customers	(7.9		)
Other	0.4
Net change in retail rate	18.1
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.	(5.4		)
Other miscellaneous	0.2
Total retail change	12.9
Wholesale
Decrease due to lower volumes attributable to a 20% decrease at Conesville and DP&L no longer serving the load of certain other parties through their competitive bid process, as well as lower wholesale prices	(11.9		)
RTO revenues and RTO capacity revenues
RTO revenues and RTO capacity revenues	0.1
Other
Other revenues	0.5
Net change in revenues	$	1.6

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DPL – Cost of Revenues

During the three months ended March 31, 2019, cost of revenues decreased $12.8 million to $77.7 million compared to $90.5 million in the same period of the prior year. This change was primarily the result of changes in the components of cost of revenues shown below:

	Three months ended
	March 31,
$ in millions	2019 vs. 2018
Fuel
Net fuel costs
Decrease due to 20% lower internal generation at Conesville	$	(1.0	)
Net purchased power
Purchased power
Rate
Variance driven by pricing in the competitive bid process	6.1
Volume
Decrease due to lower purchases as DP&L is no longer serving the load of certain other parties through their competitive bid process	(5.4		)
Total purchased power change	0.7
RTO charges
Decrease due to lower transmission and congestion charges, including a $7.0 million 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	(11.6		)
RTO capacity charges	(0.9		)
Net change in purchased power	(11.8		)
Net change in cost of revenues	$	(12.8	)

DPL – Operation and Maintenance

During the three months ended March 31, 2019, Operation and Maintenance expense increased $15.0 million compared to the same period in the prior year. The main drivers of this change are as follows:

	Three months ended
	March 31,
$ in millions	2019 vs. 2018
Increase in alternative energy and energy efficiency programs (a)	$	6.5
Increase in uncollectible expenses for the low-income payment program, which is funded by the USF revenue rate rider (a)	4.4
Increase in maintenance of overhead transmission and distribution lines	2.7
Other, net	1.4
Net change in operation and maintenance expense	$	15.0

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

DPL – Loss on Disposal of Business

During the three months ended March 31, 2018, DPL recorded a loss on disposal of business of $11.7 million due to the loss on the transfer of business interests in the Beckjord facility.

DPL – Interest Expense

During the three months ended March 31, 2019, Interest expense decreased $4.1 million compared to the same period in the prior year. The decrease was primarily the result of debt repayments at DPL and DP&L in 2018.

DPL – Income Tax Expense From Continuing Operations

Income tax expense of $0.2 million during the three months ended March 31, 2018 changed to Income tax expense of $2.7 million during the three months ended March 31, 2019. The increase of $2.5 million was primarily due to higher pre-tax income in the current year versus the prior year.

DPL– Discontinued Operations

Net income from discontinued operations was $25.6 million for the three months ended March 31, 2019, compared to $14.6 million for the three months ended March 31, 2018. This income relates to the generation components of Miami Fort, Zimmer, Stuart, Killen and the Peaker assets, which were disposed of either by sale or retirement in recent years. The increase is primarily due to a $22.5 million reduction to the Stuart and Killen ARO liabilities in

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March 2019, which was recorded as a credit to depreciation and amortization expense, partially offset by lower capacity earnings compared to the prior year period. See Part I, Item 1, Note 14 – Discontinued Operations in the Notes to DPL's Condensed Consolidated Financial Statements.

RESULTS OF OPERATIONS BY SEGMENT - DPL

DPL has presented the results of operations of Miami Fort Station, Zimmer Station, the Peaker Assets, Stuart Station, and Killen Station as discontinued operations as a group of components for all periods presented. For more information, see Part I, Item 1, Note 14 – Discontinued Operations of Notes to DPL's Condensed Consolidated Financial Statements. As such, AES Ohio Generation only has operating activity coming from its undivided ownership interest in Conesville, which does not meet the thresholds to be a separate reportable operating segment. DPL manages its business through one reportable operating segment, the Utility segment. The primary segment performance measure is income / (loss) from continuing operations before income tax as management has concluded that this measure best reflects the underlying business performance of DPL and is the most relevant measure considered in DPL’s internal evaluation of the financial performance of its segment. The Utility segment is discussed further below.

Utility Segment

The Utility segment is comprised of DP&L’s electric transmission and distribution businesses, which distribute electricity to residential, commercial, industrial and governmental customers. DP&L distributes electricity to more than 526,000 retail customers located in a 6,000-square mile area of West Central Ohio. 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 recording 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. The Utility segment includes revenues and costs associated with our investment in OVEC and the historical results of DP&L’s Beckjord Facility, which was closed in 2014 and transferred to a third party in the first quarter of 2018, and Hutchings Coal generating facility, which was closed in 2013. These assets did not transfer to AES Ohio Generation as part of DP&L's Generation Separation on October 1, 2017. Thus, they are grouped within the Utility segment for segment reporting purposes. In addition, regulatory deferrals and collections, which include fuel deferrals in historical periods, are included in the Utility segment.

Included within the “Other” column are other businesses that do not meet the GAAP requirements for disclosure as reportable segments as well as certain corporate costs, which include interest expense on DPL’s long-term debt and adjustments related to purchase accounting from the Merger. DPL's undivided interest in Conesville is now included within the "Other" column as it no longer meets the requirement for disclosure as a reportable operating segment, since the results of operations of the other EGUs are now presented as discontinued operations. The accounting policies of the reportable segment are the same as those described in Note 1 – Overview and Summary of Significant Accounting Policies of our 10-K. Intersegment sales, costs of sales and expenses are eliminated in consolidation. Certain shared and corporate costs are allocated between "Other" and the Utility reporting segment.

See Part I, Item 1, Note 11 – Business Segments of Notes to DPL's Condensed Consolidated Financial Statements for additional information regarding DPL’s reportable segment.

The following table presents DPL’s Income / (loss) from continuing operations before income tax by business segment:

	Three months ended
	March 31,
$ in millions	2019			2018
Utility	$	35.1		$	19.3
Other	(15.9		)	(16.8		)
Income from continuing operations before income tax (a)	$	19.2		$	2.5

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

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RESULTS OF OPERATIONS HIGHLIGHTS – DPL – Utility Segment

The results of operations of the Utility segment for DPL are identical in all material respects and for all periods presented to those of DP&L,which are included in Part I, Item 2, Management's Discussion and Analysis of Financial Condition and Results of Operations (RESULTS OF OPERATIONS HIGHLIGHTS – DP&L) of this Form 10-Q.

RESULTS OF OPERATIONS HIGHLIGHTS – DP&L

	Three months ended
	March 31,
$ in millions	2019			2018
Revenues:
Retail	$	183.4		$	170.4
Wholesale	5.0			12.6
RTO revenues	10.9			11.1
RTO capacity revenues	2.1			1.9
Total revenues	201.4			196.0
Cost of revenues:
Net fuel cost	0.9			0.9
Purchased power:
Purchased power	66.1			65.5
RTO charges	7.2			17.0
RTO capacity charges	—			1.3
Net purchased power cost	73.3			83.8
Total cost of revenues	74.2			84.7
Gross margin	127.2			111.3
Operating expenses:
Operation and maintenance	48.2			32.2
Depreciation and amortization	18.0			18.6
General taxes	19.4			19.3
Loss on disposal of business	—			12.4
Total operating expenses	85.6			82.5
Operating income	41.6			28.8
Other income / (expense), net:
Interest expense	(7.1		)	(8.2		)
Charge for early redemption of debt	—			(0.5		)
Other expense	0.6			(0.8		)
Total other expense, net	(6.5		)	(9.5		)
Income before income tax (a)	$	35.1		$	19.3

(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 and other factors influencing demand have 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
	March 31,
	2019	2018
Retail electric sales (b)	3,670	3,608
Wholesale electric sales (c)	160	271
Total electric sales	3,830	3,879
Billed electric customers (end of period)	525,957	523,280

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

(b) DP&Lretail electric sales represent the total transmission and distribution retail sales for the periods presented. SSO sales were 1,109 KWh for the three months ended March 31, 2019, and 1,039 KWh for the three months ended March 31, 2018.

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

During the three months ended March 31, 2019, revenue increased $5.4 million to $201.4 million compared to $196.0 million in the same period of the prior year. This change was primarily the result of changes in the components of revenue shown below:

	Three months ended
	March 31,
$ in millions	2019 vs. 2018
Retail
Rate
Increase in energy efficiency and USF revenue rate riders	$	11.4
Increase in base distribution rates due to the DRO	8.0
Increase due to the DIR, which was effective with the DRO	6.2
Decrease in the TCRR as DP&L passes back the benefits of the PJM Transmission Enhancement Settlement to customers	(7.9		)
Other	0.5
Net change in retail rate	18.2
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.	(5.4		)
Other miscellaneous	0.2
Total retail change	13.0
Wholesale
Decrease in volumes due to no longer serving the load of certain other parties through their competitive bid process and lower wholesale prices	(7.6		)
Net change in revenues	$	5.4

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DP&L – Cost of Revenues

During the three months ended March 31, 2019, cost of revenues decreased $10.5 million to $74.2 million compared to $84.7 million in the same period of the prior year. This change was primarily the result of changes in the components of cost of revenues shown below:

	Three months ended
	March 31,
$ in millions	2019 vs. 2018
Cost of revenues
Purchased power
Rate
Variance driven by pricing in the competitive bid process	$	6.0
Volume
Decrease due to lower purchases as DP&L is no longer serving the load of certain other parties through their competitive bid process	(5.4		)
Total purchased power change	0.6
RTO charges
Decrease due to lower transmission and congestion charges, including a $7.0 million 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		)
RTO capacity charges	(1.3		)
Net change in cost of revenues	$	(10.5	)

DP&L – Operation and Maintenance

During the three months ended March 31, 2019, Operation and Maintenance expense increased $16.0 million compared to the same period in the prior year. The main drivers of this change are as follows:

	Three months ended
	March 31,
$ in millions	2019 vs. 2018
Increase in alternative energy and energy efficiency programs (a)	$	6.5
Increase in uncollectible expenses for the low-income payment program, which is funded by the USF revenue rate rider (a)	4.4
Increase in maintenance of overhead transmission and distribution lines	2.7
Other, net	2.4
Net change in operation and maintenance expense	$	16.0

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

DP&L – Loss on Disposal of Business

During the three months ended March 31, 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.

DP&L – Interest Expense

During the three months ended March 31, 2019, Interest expense decreased $1.1 million compared to the same period in the prior year. The decrease was primarily the result of debt repayments at DP&L in 2018.

DP&L – Income Tax Expense

During the three months ended March 31, 2019, Income tax expense increased $2.5 million compared to the same period in the prior year primarily due to higher pre-tax income in the current year versus the prior year.

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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. See further discussion on these changes in Part I, Item 1, Note 3 – Regulatory Matters of Notes to DPL's Condensed Consolidated Financial Statements and Part I, Item 1, Note 3 – Regulatory Matters of Notes to DP&L's Condensed Financial Statements. In addition, DPL's and 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;

• timely recovery of transmission and distribution expenditures; and

• exiting generation assets currently owned by AES Ohio Generation.

Regulatory Environment

DPL’s, DP&L’s and our other subsidiaries’ 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 previously filed with the SEC during 2019 describes other regulatory matters which have not materially changed since that filing.

Ohio Regulatory Proceedings

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.

See Part I, Item 1, Note 3 – Regulatory Matters of Notes to DPL's Condensed Consolidated Financial Statements and Part I, Item 1, Note 3 – Regulatory Matters of Notes to DP&L's Condensed Financial Statements.

United States Tax Law Reform

In light of 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.

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

As a result of DPL’s decision to retire its Stuart and Killen generating stations, the sale of its ownership interest in the Miami Fort and Zimmer generating stations and the planned 2020 retirement of Conesville, the following environmental, regulations and requirements are now not expected to have a material impact on DPL:

• The CAA and the following regulations:

• CSAPR and associated updates;

• MATS and any associated regulatory or judicial processes;

• NAAQS; and

• CPP or a potential replacement rule, for example, the Affordable Clean Energy Rule.

Additionally, as a result of the retirement of Stuart and Killen noted above, the following environmental regulations and requirements are not expected to have a material impact on DPL with respect to either of the two generating stations:

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

• the appeal of the NPDES permit governing the discharge of water from the Stuart Station; and

• revised technology-based regulations governing water discharges from steam electric generating facilities, finalized by the USEPA on November 3, 2015

On November 3, 2015, the USEPA finalized revised technology-based regulations governing water discharges from steam electric generating facilities, commonly referred to as the ELG rule. On April 12, 2019, the U.S. Court of Appeals for the Fifth Circuit vacated and remanded portions of the USEPA’s 2015 ELG Rule related to legacy wastewaters and combustion residual leachate. It is too early to determine whether any outcome of this decision might have a material impact on our business, financial condition and results of operations.

CAPITAL RESOURCES AND LIQUIDITY

DPL and DP&L had unrestricted cash and cash equivalents of $70.8 million and $18.8 million, respectively, at March 31, 2019. At that date, neither DPL nor DP&L had short-term investments. DPL and DP&L had aggregate principal amounts of long-term debt outstanding of $1,487.2 million and $592.6 million, respectively.

Approximately $103.6 million of DPL's long-term debt, including $4.6 million of DP&L's long-term debt, matures within twelve months of the balance sheet date. On April 4, 2019, the $99.0 million outstanding principal on DPL's 6.75% Senior Notes due October 1, 2019 was redeemed at par plus accrued interest and a make-whole premium of $1.5 million with cash on hand and borrowings on our current revolving credit facility. See Part I, Item 1, Note 6 – Long-term Debt of Notes to DPL's Condensed Consolidated Financial Statements. 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.

Our discussion of DPL’s financial condition, liquidity and capital requirements include the results of its principal subsidiary DP&L.

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CASH FLOWS

DPL’s financial condition, liquidity and capital requirements include the consolidated results of its principal subsidiary DP&L. All material intercompany accounts and transactions have been eliminated in consolidation.

Cash Flow Analysis - DPL

The following table summarizes the cash flows of DPL:

DPL	Three months ended March 31,
$ in millions	2019			2018
Net cash provided by operating activities	$	36.6		$	50.6
Net cash provided by / (used in) investing activities	(34.3		)	195.4
Net cash used in financing activities	(1.2		)	(121.1		)
Decrease in cash and restricted cash of discontinued operations and held-for-sale businesses	—			(1.3		)
Net change	1.1			123.6
Balance at beginning of period	111.7			24.9
Cash, cash equivalents, and restricted cash at end of period	$	112.8		$	148.5

DPL– Change in cash flows from operating activities

	Three months ended March 31,						$ change
$ in millions	2019			2018			2019 vs. 2018
Net income	$	42.1		$	16.9		$	25.2
Depreciation and amortization	(3.1		)	20.1			(23.2		)
Deferred income taxes	5.2			(41.7		)	46.9
Other adjustments to Net income	0.8			14.9			(14.1		)
Net income, adjusted for non-cash items	45.0			10.2			34.8
Net change in operating assets and liabilities	(8.4		)	40.4			(48.8		)
Net cash provided by operating activities	$	36.6		$	50.6		$	(14.0	)

The net change in operating assets and liabilities during the three months ended March 31, 2019 compared to the three months ended March 31, 2018 was driven by the following:

$ in millions	$ Change
Decrease from accrued taxes primarily due to a larger current portion of income tax expense in prior year	$	(43.4	)
Other	(5.4		)
Net decrease in cash from changes in operating assets and liabilities	$	(48.8	)

DPL– Cash flows from investing activities

Net cash provided by / (used in) investing activities was $(34.3) million for the three months endedMarch 31, 2019 compared to $195.4 million for the three months endedMarch 31, 2018. The three months endedMarch 31, 2019 investing activity relates to capital expenditures of $34.3 million. The three months endedMarch 31, 2018 investing activity primarily relates to proceeds from the sale of business of $234.9 million due to the sale of the Peaker assets. This was partially offset by capital expenditures of $27.3 million and a payment on the disposal of Beckjord of $14.5 million.

DPL– Cash flows from financing activities

Net cash used in financing activities was $(1.2) million for thethree months endedMarch 31, 2019 compared to $(121.1) million from financing activities for the three months endedMarch 31, 2018. The three months endedMarch 31, 2019 financing activity is primarily due to a $1.1 million quarterly term loan payment. The three months endedMarch 31, 2018 financing activity is primarily comprised of the repayment of the remaining balance on the DPL term loan of $70.0 million and a $60.0 million repayment on the DP&L tax-exempt term loan. This was partially offset by net revolving credit facility borrowings of $10.0 million.

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Cash Flow Analysis - DP&L

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

DP&L	Three months ended March 31,
$ in millions	2019			2018
Net cash provided by operating activities	$	29.5		$	30.6
Net cash used in investing activities	(33.7		)	(39.4		)
Net cash provided by / (used in) financing activities	(1.2		)	5.1
Net change	(5.4		)	(3.7		)
Balance at beginning of period	66.2			5.6
Cash, cash equivalents, and restricted cash at end of period	$	60.8		$	1.9

DP&L– Change in cash flows from operating activities

	Three months ended March 31,						$ change
$ in millions	2019			2018			2019 vs. 2018
Net income	$	29.0		$	15.7		$	13.3
Depreciation and amortization	18.0			18.6			(0.6		)
Other adjustments to Net income	(0.9		)	16.5			(17.4		)
Net income, adjusted for non-cash items	46.1			50.8			(4.7		)
Net change in operating assets and liabilities	(16.6		)	(20.2		)	3.6
Net cash provided by operating activities	$	29.5		$	30.6		$	(1.1	)

The net change in operating assets and liabilities during the three months ended March 31, 2019 compared to the three months ended March 31, 2018 was driven by the following:

$ in millions	$ Change
Decrease from accounts payable primarily due to timing of payments	$	(20.4	)
Increase from deferred regulatory costs, net, due to higher collections on regulatory assets and liabilities	9.8
Increase from accrued taxes is primarily due to higher current portion of income tax expense in 2019	8.9
Increase from customer security deposits is primarily due to current year deposits for collateral in the DP&L SSO auction	7.1
Other	(1.8		)
Net increase in cash from changes in operating assets and liabilities	$	3.6

DP&L– Cash flows from investing activities

Net cash used in investing activities was $(33.7) million for thethree months endedMarch 31, 2019 compared to $(39.4) million for the three months endedMarch 31, 2018. The three months endedMarch 31, 2019 investing activity represents capital expenditures of $33.7 million. The three months endedMarch 31, 2018 investing activity is primarily capital expenditures of $24.6 million and a payment on the disposal of Beckjord of $14.5 million.

DP&L– Cash flows from financing activities

Net cash provided by / (used in) financing activities was $(1.2) million for the three months endedMarch 31, 2019 compared to $5.1 million from financing activities for the three months endedMarch 31, 2018. The three months endedMarch 31, 2019 financing activity is primarily a $1.1 million quarterly term loan payment. The three months endedMarch 31, 2018 financing activity is primarily driven by a $80.0 million capital contribution from DPL and net revolving credit facility borrowings of $10.0 million. This was partially offset by $61.1 million of payments on long-term debt, primarily relating to a $60.0 million repayment on the DP&L tax-exempt term loan, and returns of capital paid to parent of $23.8 million.

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. 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.

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At March 31, 2019, DP&L and DPL have access to the following revolving credit facilities:

$ in millions	Type	Maturity	Commitment		Amounts available as of March 31, 2019
DP&L	Revolving	July 2020	$	175.0	$	173.9
DPL	Revolving	July 2020	205.0		191.6
			$	380.0	$	365.5

DP&L has an unsecured revolving credit agreement with a syndicated bank group with a borrowing limit of $175.0 million and a $50.0 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 July 2020. At March 31, 2019, there was one letter of credit in the amount of $1.1 million outstanding under this facility, and no borrowings, with the remaining $173.9 million available to DP&L. Fees associated with this letter of credit facility were not material during the three months endedMarch 31, 2019 or 2018.

DPL has a revolving credit facility of $205.0 million, with a $200.0 million letter of credit sublimit and a feature that provides DPL the ability to increase the size of the facility by an additional $95.0 million. This facility is secured by a pledge of common stock that DPL owns in DP&L, limited to the amount permitted to be pledged under certain Indentures dated October 3, 2011 and October 6, 2014 between DPL and Wells Fargo Bank, NA and U.S. Bank National Association, respectively, as Trustee. The facility expires in July 2020. The springing maturity feature of this facility has been satisfied since the DPL Term Loan was paid in full on March 27, 2018 and $101.0 million of the DPL senior unsecured bonds due October 1, 2019 were redeemed on April 30, 2018. At March 31, 2019, there were six letters of credit in the aggregate amount of $13.4 million outstanding and no borrowings, with the remaining $191.6 million available to DPL. Fees associated with this facility were not material during the three months endedMarch 31, 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.

DPL is projecting to spend an estimated $628.0 million in capital projects for the period 2019 through 2021, of which $621.0 million is projected to be spent by DP&L. 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 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 Part I, Item 1, Note 6 – Long-term Debt of Notes to DPL's Condensed Consolidated Financial Statements and Part I, Item 1, Note 6 – Long-term Debt of Notes to DP&L's Condensed Financial Statements.

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Debt and Credit Ratings

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

	DPL	DP&L	Outlook	Effective or Affirmed
Fitch Ratings	BBB(a) / BBB-(b)	A- (c)	Stable	October 2018
Moody's Investors Service, Inc.	Ba1 (b)	A3 (c)	Positive	October 2018
Standard & Poor's Financial Services LLC	BBB- (b)	BBB+ (c)	Stable	March 2018

(a) Rating relates to DPL’s Senior secured debt.

(b) Rating relates to DPL's Senior unsecured debt.

(c) 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 DPL and DP&L, along with the effective or affirmed date of each rating.

	DPL	DP&L	Outlook	Effective or Affirmed
Fitch Ratings	BBB-	BBB	Stable	October 2018
Moody's Investors Service, Inc.	Ba1	Baa2	Positive	October 2018
Standard & Poor's Financial Services LLC	BBB-	BBB-	Stable	March 2018

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 may 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 Part I, Item 1, Note 10 – Contractual Obligations, Commercial Commitments and Contingencies of Notes to DPL's Condensed Consolidated Financial Statements and Part I, Item 1, Note 9 – Contractual Obligations, Commercial Commitments and Contingencies of Notes to DP&L's Condensed Financial Statements.

MARKET RISK

We are subject to certain market risks including, but not limited to, changes in commodity prices for electricity and fluctuations in interest rates. Our Risk Management Committee (RMC), comprised of members of senior management, is responsible for establishing risk management policies and the monitoring and reporting of risk exposures. The RMC meets on a regular basis with the objective of identifying, assessing and quantifying material risk issues and developing strategies to manage these risks.

The disclosures presented in this section are based upon a number of assumptions; actual effects may differ. The safe harbor provided in Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 shall apply to the disclosures contained in this section. For further information regarding market risk, see Item 1A.—Risk Factors and Item 7A - Quantitative and Qualitative Disclosures about Market Risk of our Form 10-K. Our businesses may incur substantial costs and liabilities and be exposed to price volatility as a result of risks associated with the electricity markets, which could have a material adverse effect on our results of operations, financial condition and cash flows. In addition, we may not be adequately hedged against our exposure to changes in interest rates.

Interest Rate Risk

Because of our normal investing and borrowing activities, our financial results are exposed to fluctuations in interest rates which we manage through our regular financing activities. We maintain both cash on deposit and investments in cash equivalents that may be affected by adverse interest rate fluctuations. DP&L has both fixed-rate and variable-rate long-term debt. The variable-rate debt is comprised of bank held tax-exempt bonds and a variable rate term loan B. The variable-rate bonds and term loan B bear interest based on an underlying interest rate index, typically LIBOR. Market indexes can be affected by market demand, supply, market interest rates and other economic conditions. See Part I, Item 1, Note 6 – Long-term Debt of Notes to DPL's Condensed Consolidated Financial Statements and Part I, Item 1, Note 6 – Long-term Debt of Notes to DP&L's Condensed Financial Statements.

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As of March 31, 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.

Principal Payments and Interest Rate Detail by Contractual Maturity Date

The principal value of DPL’s long-term debt was $1,487.2 million at March 31, 2019, consisting of DPL’s unsecured notes, along with DP&L’s first mortgage bonds, tax-exempt bonds and the Wright-Patterson Air Force Base note. All of DPL’s long-term debt was adjusted to fair value at the date of the Merger. The fair value of this long-term debt at March 31, 2019 was $1,544.9 million, based on current market prices or discounted cash flows using current rates for similar issues with similar terms and remaining maturities. The following table provides information about DPL’s long-term debt obligations that are sensitive to interest rate changes:

DPL
	Principal payments due												At March 31, 2019
	during the twelve months ending
	March 31,												Principal		Fair
$ in millions	2020		2021		2022		2023		2024		Thereafter		Amount		Value
Long-term debt
Variable-rate debt	$	4.5	$	144.5	$	4.4	$	421.6	$	—	$	—	$	575.0	$	575.0
Average interest rate (a)	4.5%		3.1%		4.5%		4.5%		—%		—%
Fixed-rate debt	$	99.1	$	0.1	$	780.2	$	0.2	$	0.2	$	32.4	912.2		969.9
Average interest rate	6.7%		4.2%		7.2%		4.2%		4.2%		6.1%
Total													$	1,487.2	$	1,544.9

(a) Based on rates in effect at March 31, 2019

The principal value of DP&L’s long-term debt was $592.6 million at March 31, 2019, consisting of its first mortgage bonds, tax-exempt bonds and the Wright-Patterson Air Force Base note. The fair value of this long-term debt was $592.6 million, based on current market prices or discounted cash flows using current rates for similar issues with similar terms and remaining maturities. The following table provides information about DP&L’s debt obligations that are sensitive to interest rate changes. DP&L’s debt was not revalued because of the Merger.

DP&L
	Principal payments due												At March 31, 2019
	during the twelve months ending
	March 31,												Principal		Fair
$ in millions	2020		2021		2022		2023		2024		Thereafter		Amount		Value
Long-term debt
Variable-rate debt	$	4.5	$	144.5	$	4.4	$	421.6	$	—	$	—	$	575.0	$	575.0
Average interest rate (a)	4.5%		3.1%		4.5%		4.5%		—%		—%
Fixed-rate debt	$	0.1	$	0.1	$	0.2	$	0.2	$	0.2	$	16.8	17.6		17.6
Average interest rate	4.2%		4.2%		4.2%		4.2%		4.2%		4.2%
Total													$	592.6	$	592.6

(a) Based on rates in effect at March 31, 2019

Long-term debt maturities and repayments occurring in the next twelve months are discussed under "CAPITAL RESOURCES AND LIQUIDITY".

Critical Accounting Estimates

DPL’s Condensed Consolidated Financial Statements and DP&L’s Condensed 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.

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

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results. Significant items subject to such 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; liabilities recorded for income tax exposures; litigation; contingencies; the valuation of AROs; assets and liabilities related to employee benefits and intangible assets. Refer to our Form 10-K for the year ended December 31, 2018 for a complete listing of our critical accounting policies and estimates. We have reviewed and determined that these remain as critical accounting policies as of and for the three months ended March 31, 2019.

Item 3 – Quantitative and Qualitative Disclosures about Market Risk

See the “MARKET RISK” section in Item 2 of this Part I, which is incorporated by reference into this item.

Item 4 – Controls and Procedures

Disclosure Controls and Procedures

DPL and DP&L, under the supervision and with the participation of its management, including our Chief Executive Officer (CEO) and Chief Financial Officer (CFO), evaluated the effectiveness of our “disclosure controls and procedures,” as such term is defined in Rule 13a-15(e) under the Securities Act of 1934, as amended (the “Exchange Act”), as of the end of the period covered by this Quarterly Report on Form 10-Q. Based on that evaluation, our CEO and CFO concluded that our disclosure controls and procedures were effective as of March 31, 2019, to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act, is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms, and include controls and procedures designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosures.

Changes in Internal Controls over Financial Reporting

There were no changes that occurred during the fiscal quarter covered by this Quarterly Report on Form 10-Q that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Part II – Other Information

Item 1 – Legal Proceedings

In the normal course of business, we are subject to various lawsuits, actions, claims, and other proceedings. We are also, from time to time, involved in other reviews, investigations and proceedings by governmental and regulatory agencies regarding our business, certain of which may result in adverse judgments, settlements, fines, penalties, injunctions or other relief. We have accrued in our Financial Statements for litigation and claims where it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. We believe the amounts provided in our Financial Statements, as prescribed by GAAP, for these matters 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 and other matters (including those matters noted 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 for in our Financial Statements, cannot be reasonably determined, but could be material.

Our Form 10-K for the fiscal year ended December 31, 2018 and the Notes to DPL’s Consolidated Financial Statements and DP&L’s Financial Statements included therein contain descriptions of certain legal proceedings in which we are or were involved. The information in or incorporated by reference into this Item 1 to Part II is limited to certain recent developments concerning our legal proceedings and new legal proceedings, since the filing of such Form 10-K, and should be read in conjunction with such Form 10-K.

The following information is incorporated by reference into this Item: information about the legal proceedings contained in Part I, Item 2 – Management's Discussion and Analysis of Financial Condition and Results of Operations and Part I, Item 1, Note 3 – Regulatory Matters of Notes to DPL's Condensed Consolidated Financial Statements and Part I, Item 1, Note 3 – Regulatory Matters of Notes to DP&L's Condensed Financial Statements of this Quarterly Report on Form 10-Q.

62

Item 1A – Risk Factors

A listing of the risk factors that we consider to be the most significant to a decision to invest in our securities is provided in our Form 10-K for the fiscal year ended December 31, 2018. As of March 31, 2019, there have been no material changes with respect to the risk factors disclosed in our Form 10-K. If any of the events described in our risk factors occur, it could have a material adverse effect on our results of operations, financial condition and cash flows.

The risks and uncertainties described in our risk factors are not the only ones we face. In addition, new risks may emerge at any time, and we cannot predict those risks or estimate the extent to which they may affect our business or financial performance. Our risk factors should be read in conjunction with the other detailed information concerning DPL and DP&L set forth in the Notes to DPL’s and DP&L’s Financial Statements found in Part I, Item 1, and the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” sections included in our filings.

Item 2 – Unregistered Sale of Equity Securities and Use of Proceeds

None

Item 3 – Defaults Upon Senior Securities

None

Item 4 – Mine Safety Disclosures

Not applicable.

Item 5 – Other Information

None

63

Item 6 – Exhibits

DPL	DP&L	Exhibit Number	Exhibit	Location
X		4.1	Indenture, dated April 17, 2019, between DPL Inc. and U.S. Bank National Association.	Exhibit 4.1 to Report on Form 8-K filed April 17, 2019 (File No. 1-9052)
X		4.2	Registration Rights Agreement, dated as of April 17, 2019, by and between DPL Inc. and J.P. Morgan Securities LLC and Morgan Stanley & Co. LLC, as representatives of the initial purchasers.	Exhibit 4.1 to Report on Form 8-K filed April 17, 2019 (File No. 1-9052)
X		31(a)	Certification of Chief Executive Officer pursuant to Rule 13a-14(a)/Rule 15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith as Exhibit 31(a)
X		31(b)	Certification of Chief Financial Officer pursuant to Rule 13a-14(a)/Rule 15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith as Exhibit 31(b)
	X	31(c)	Certification of Chief Executive Officer pursuant to Rule 13a-14(a)/Rule 15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith as Exhibit 31(c)
	X	31(d)	Certification of Chief Financial Officer pursuant to Rule 13a-14(a)/Rule 15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith as Exhibit 31(d)
X		32(a)	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002	Filed herewith as Exhibit 32(a)
X		32(b)	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002	Filed herewith as Exhibit 32(b)
	X	32(c)	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002	Filed herewith as Exhibit 32(c)
	X	32(d)	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002	Filed herewith as Exhibit 32(d)
X	X	101.INS	XBRL Instance	Filed herewith as Exhibit 101.INS
X	X	101.SCH	XBRL Taxonomy Extension Schema	Filed herewith as Exhibit 101.SCH
X	X	101.CAL	XBRL Taxonomy Extension Calculation Linkbase	Filed herewith as Exhibit 101.CAL
X	X	101.DEF	XBRL Taxonomy Extension Definition Linkbase	Filed herewith as Exhibit 101.DEF
X	X	101.LAB	XBRL Taxonomy Extension Label Linkbase	Filed herewith as Exhibit 101.LAB
X	X	101.PRE	XBRL Taxonomy Extension Presentation Linkbase	Filed herewith as Exhibit 101.PRE

Exhibits referencing File No. 1-9052 have been filed by DPL Inc. and those referencing File No. 1-2385 have been filed by The Dayton Power and Light Company.

64

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, DPL Inc. has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		DPL Inc.
		(Registrant)
Date:	May 6, 2019	/s/ Gustavo Garavaglia
		Gustavo Garavaglia
		Chief Financial Officer
		(principal financial officer)
	May 6, 2019	/s/ Karin M. Nyhuis
		Karin M. Nyhuis
		Controller
		(principal accounting officer)

65

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, The Dayton Power and Light Company has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		The Dayton Power and Light Company
		(Registrant)
Date:	May 6, 2019	/s/ Gustavo Garavaglia
		Gustavo Garavaglia
		Vice President and Chief Financial Officer
		(principal financial officer)
	May 6, 2019	/s/ Karin M. Nyhuis
		Karin M. Nyhuis
		Controller
		(principal accounting officer)

66

EX-31.A

Exhibit 31(a)

CERTIFICATIONS

I, Barry J. Bentley, certify that:

1. I have reviewed this quarterly report on Form 10-Q of DPL Inc. ;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 6, 2019

/s/ Barry J. Bentley

Barry J. Bentley

Interim President and Chief Executive Officer

EX-31.B

Exhibit 31(b)

CERTIFICATIONS

I, Gustavo Garavaglia, certify that:

1. I have reviewed this quarterly report on Form 10-Q of DPL Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 6, 2019

/s/ Gustavo Garavaglia

Gustavo Garavaglia

Chief Financial Officer

EX-31.C

 Exhibit 31(c)

CERTIFICATIONS

I, Barry J. Bentley, certify that:

1. I have reviewed this quarterly report on Form 10-Q of The Dayton Power and Light Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 6, 2019

/s/ Barry J. Bentley

Barry J. Bentley

Interim President and Chief Executive Officer

EX-31.D

Exhibit 31(d)

CERTIFICATIONS

I, Gustavo Garavaglia, certify that:

1. I have reviewed this quarterly report on Form 10-Q of The Dayton Power and Light Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 6, 2019

/s/ Gustavo Garavaglia

Gustavo Garavaglia

Vice President and Chief Financial Officer

EX-32.A

Exhibit 32(a)

DPL Inc.

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

The undersigned officer of DPL Inc. (the “Issuer”) hereby certifies pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Issuer’s Quarterly Report on Form 10-Q for the period ended March 31, 2019, which this certificate accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that the information contained therein fairly presents, in all material respects, the financial condition and results of operations of the Issuer as of the dates and for the periods expressed therein.

A signed original of this written statement required by Section 906 of the Sarbanes-Oxley Act of 2002, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this statement required by Section 906 of the Sarbanes-Oxley Act of 2002, has been provided to the Issuer and will be retained by the Issuer and furnished to the Securities and Exchange Commission or its staff upon request.

Signed:

/s/ Barry J. Bentley

Barry J. Bentley

Interim President and Chief Executive Officer

Date: May 6, 2019

The foregoing certificate is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of the Issuer’s Annual Report or as a separate disclosure document.

EX-32.B

Exhibit 32(b)

DPL Inc.

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

The undersigned officer of DPL Inc. (the “Issuer”) hereby certifies pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Issuer’s Quarterly Report on Form 10-Q for the period ended March 31, 2019, which this certificate accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that the information contained therein fairly presents, in all material respects, the financial condition and results of operations of the Issuer as of the dates and for the periods expressed therein.

A signed original of this written statement required by Section 906 of the Sarbanes-Oxley Act of 2002, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this statement required by Section 906 of the Sarbanes-Oxley Act of 2002, has been provided to the Issuer and will be retained by the Issuer and furnished to the Securities and Exchange Commission or its staff upon request.

Signed:

/s/ Gustavo Garavaglia

Gustavo Garavaglia

Chief Financial Officer

Date: May 6, 2019

The foregoing certificate is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of the Issuer’s Annual Report or as a separate disclosure document.

EX-32.C

Exhibit 32(c)

The Dayton Power and Light Company

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

The undersigned officer of The Dayton Power and Light Company (the “Issuer”) hereby certifies pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Issuer’s Quarterly Report on Form 10-Q for the period ended March 31, 2019, which this certificate accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that the information contained therein fairly presents, in all material respects, the financial condition and results of operations of the Issuer as of the dates and for the periods expressed therein.

A signed original of this written statement required by Section 906 of the Sarbanes-Oxley Act of 2002, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this statement required by Section 906 of the Sarbanes-Oxley Act of 2002, has been provided to the Issuer and will be retained by the Issuer and furnished to the Securities and Exchange Commission or its staff upon request.

Signed:

/s/ Barry J. Bentley

Barry J. Bentley

Interim President and Chief Executive Officer

Date: May 6, 2019

The foregoing certificate is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of the Issuer’s Annual Report or as a separate disclosure document.

EX-32.D

Exhibit 32(d)

The Dayton Power and Light Company

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

The undersigned officer of The Dayton Power and Light Company (the “Issuer”) hereby certifies pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Issuer’s Quarterly Report on Form 10-Q for the period ended March 31, 2019, which this certificate accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that the information contained therein fairly presents, in all material respects, the financial condition and results of operations of the Issuer as of the dates and for the periods expressed therein.

A signed original of this written statement required by Section 906 of the Sarbanes-Oxley Act of 2002, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this statement required by Section 906 of the Sarbanes-Oxley Act of 2002, has been provided to the Issuer and will be retained by the Issuer and furnished to the Securities and Exchange Commission or its staff upon request.

Signed:

/s/ Gustavo Garavaglia

Gustavo Garavaglia

Vice President and Chief Financial Officer

Date: May 6, 2019

The foregoing certificate is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of the Issuer’s Annual Report or as a separate disclosure document.

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	May 06, 2019
Entity Registrant Name	DPL INC
Entity Central Index Key	0000787250
Document Type	10-Q
Document Period End Date	Mar. 31, 2019
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		1
Entity Emerging Growth Company	false
Entity Small Business	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
THE DAYTON POWER AND LIGHT COMPANY [Member]
Entity Registrant Name	DAYTON POWER & LIGHT CO
Entity Central Index Key	0000027430
Document Type	10-Q
Amendment Flag	false
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		41,172,173
Entity Emerging Growth Company	false
Entity Small Business	false

XML

Condensed Consolidated Statements of Operations - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Revenues	$ 209.0	$ 207.4
Cost of revenues:
Net fuel cost	3.5	4.5
Cost of Goods and Services Sold	77.7	90.5
Gross margin	131.3	116.9
Operating expenses:
Operation and maintenance	51.0	36.0
Depreciation and amortization	18.4	18.8
General taxes	19.5	19.4
Gain (Loss) on Sale of Assets and Asset Impairment Charges, excluding Discontinued Operations	0.9	0.1
Other, net (Note 2):	(0.9)	(0.6)
Gain (Loss) on Disposition of Business	0.0	(11.7)
Total operating expenses	89.8	86.0
Operating income	41.5	30.9
Other income / (expense), net
Interest expense	(23.7)	(27.8)
Charge for early redemption of debt	0.0	(0.7)
Other income	1.4	0.1
Total other expense, net	(22.3)	(28.4)
Income / (loss) from continuing operations before income tax	19.2	2.5
Income tax expense / (benefit) from continuing operations	2.7	0.2
Net income / (loss) from continuing operations	16.5	2.3
Income / (loss) from discontinued operations before income tax	29.8	20.0
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax	0.1	(1.9)
Income tax expense / (benefit) from discontinued operations	4.3	3.5
Net income / (loss) from discontinued operations	25.6	14.6
Net income / (loss)	42.1	16.9
THE DAYTON POWER AND LIGHT COMPANY [Member]
Revenues	201.4	196.0
Cost of revenues:
Net fuel cost	0.9	0.9
Cost of Goods and Services Sold	74.2	84.7
Gross margin	127.2	111.3
Operating expenses:
Operation and maintenance	48.2	32.2
Depreciation and amortization	18.0	18.6
General taxes	19.4	19.3
Gain (Loss) on Disposition of Business	0.0	(12.4)
Total operating expenses	85.6	82.5
Operating income	41.6	28.8
Other income / (expense), net
Interest expense	(7.1)	(8.2)
Charge for early redemption of debt	0.0	(0.5)
Other income	0.6	(0.8)
Total other expense, net	(6.5)	(9.5)
Income / (loss) from continuing operations before income tax	35.1	19.3
Income tax expense / (benefit) from continuing operations	6.1	3.6
Net income / (loss)	29.0	15.7
Electricity, Purchased [Member]
Cost of revenues:
Cost of Goods and Services Sold	74.2	86.0
Electricity, Purchased [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Cost of revenues:
Cost of Goods and Services Sold	$ 73.3	$ 83.8

XML

Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Net income	$ 42.1	$ 16.9
Derivative activity:
Change in derivative fair value, net of income tax	(0.3)	0.9
Reclassification of earnings, net of income tax	(0.2)	(0.4)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives Related to Discontinued Operations, Net of Tax	0.0	2.7
Total change in fair value of derivatives	(0.5)	3.2
Pension and postretirement activity:
Reclassification to earnings, net of income tax	0.1	0.1
Total change in unfunded pension obligation	0.1	0.1
Other comprehensive income / (loss)	(0.4)
Net comprehensive income / (loss)	41.7	20.2
THE DAYTON POWER AND LIGHT COMPANY [Member]
Net income	29.0	15.7
Derivative activity:
Change in derivative fair value, net of income tax	(0.2)	0.5
Reclassification of earnings, net of income tax	(0.1)	(0.3)
Total change in fair value of derivatives	(0.3)	0.2
Pension and postretirement activity:
Reclassification to earnings, net of income tax	0.7	0.9
Total change in unfunded pension obligation	0.7	0.9
Other comprehensive income / (loss)	0.4	1.1
Net comprehensive income / (loss)	$ 29.4	$ 16.8

XML

Condensed Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income tax (expense)/benefit on unrealized gains (losses) related to available-for-sale securities	$ 0.0	$ 0.0
Income tax (expense) benefit on reclassification to earnings	0.0	0.0
AOCI reclassed to Retained Earnings, income tax	0.0	0.0
Income tax (expense)/benefit on unrealized gains (losses) related to derivative activity	0.1	(0.1)
Income tax (expense)/benefit on reclassification of earnings related to derivative activity	0.1	0.6
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives Related to Discontinued Operations, Tax	0.0	(1.4)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, Tax	0.0	0.0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss) Arising During Period, Tax	0.0	0.0
Income tax (expense)/benefit on reclassification of earnings related to pension and postretirement activity	0.0	(0.1)
THE DAYTON POWER AND LIGHT COMPANY [Member]
Income tax (expense)/benefit on unrealized gains (losses) related to available-for-sale securities	0.0	0.0
Income tax (expense) benefit on reclassification to earnings	0.0	0.0
AOCI reclassed to Retained Earnings, income tax	0.0	0.6
Income tax (expense)/benefit on unrealized gains (losses) related to derivative activity	0.1	(0.1)
Income tax (expense)/benefit on reclassification of earnings related to derivative activity	0.0	0.5
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives Related to Discontinued Operations, Tax	0.0	0.0
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, Tax	0.0	0.0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss) Arising During Period, Tax	0.0	0.0
Income tax (expense)/benefit on reclassification of earnings related to pension and postretirement activity	$ (0.2)	$ (0.2)

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Condensed Consolidated Balance Sheets - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 70.8	$ 90.5
Restricted cash	42.0	21.2
Accounts receivable, net	87.7	90.5
Inventories	11.9	10.7
Taxes applicable to subsequent years	54.5	72.6
Regulatory assets, current	34.8	41.1
Other prepayments and current assets	12.9	12.9
Assets Held-for-sale, Not Part of Disposal Group, Current	6.5	8.7
Total current assets	321.1	348.2
Property, plant & equipment:
Property, plant & equipment	1,637.9	1,615.6
Less: Accumulated depreciation and amortization	(324.3)	(310.8)
Property, plant and equipment, net of depreciation	1,313.6	1,304.8
Construction work in process	35.3	32.2
Total net property, plant & equipment	1,348.9	1,337.0
Other non-current assets:
Regulatory assets, non-current	151.2	152.6
Intangible assets, net of amortization	18.2	18.4
Other deferred assets	21.0	21.6
Disposal Group, Including Discontinued Operation, Assets, Noncurrent	5.3	5.3
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	(0.2)
Total other non-current assets	195.7	197.9
Total assets	1,865.7	1,883.1
Current liabilities:
Current portion of long-term debt	103.6	103.6
Accounts payable	39.5	58.1
Accrued taxes	78.1	76.7
Accrued interest	30.0	14.3
Security deposits	29.0	21.3
Regulatory liabilities, current	39.0	34.9
Other current liabilities	17.9	22.0
Liabilities Held for Sale, Current	9.0	12.2
Total current liabilities	346.1	343.1
Non-current liabilities:
Long-term debt	1,372.1	1,372.3
Deferred taxes	113.0	116.1
Taxes payable	39.9	76.1
Regulatory liabilities, non-current	279.0	278.3
Pension, retiree and other benefits	74.2	82.3
Asset Retirement Obligations, Noncurrent	9.4	9.4
Other deferred credits	7.9	8.0
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent	52.5	69.2
Total non-current liabilities	1,948.0	2,011.7
Commitments and contingencies
Common shareholder's equity:
Common stock	0.0	0.0
Other paid-in capital	2,372.1	2,370.5
Accumulated other comprehensive income	1.8	2.2
Retained earnings/ (deficit)	(2,802.3)	(2,844.4)
Total common shareholder's equity	(428.4)	(471.7)
Total liabilities and shareholder's equity	1,865.7	1,883.1
THE DAYTON POWER AND LIGHT COMPANY [Member]
Current assets:
Cash and cash equivalents	18.8	45.0
Restricted cash	42.0	21.2
Accounts receivable, net	88.4	90.4
Inventories	8.1	7.7
Taxes applicable to subsequent years	54.3	72.4
Regulatory assets, current	34.8	41.1
Income Taxes Receivable, Current	12.9	19.6
Other prepayments and current assets	14.9	13.3
Total current assets	274.2	310.7
Property, plant & equipment:
Property, plant & equipment	2,292.4	2,274.4
Less: Accumulated depreciation and amortization	(997.2)	(988.0)
Property, plant and equipment, net of depreciation	1,295.2	1,286.4
Construction work in process	34.7	31.7
Total net property, plant & equipment	1,329.9	1,318.1
Other non-current assets:
Regulatory assets, non-current	151.2	152.6
Intangible assets, net of amortization	17.1	17.2
Other deferred assets	20.5	21.0
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	(0.1)
Total other non-current assets	188.8	190.8
Total assets	1,792.9	1,819.6
Current liabilities:
Current portion of long-term debt	4.6	4.6
Accounts payable	37.1	55.8
Accrued taxes	77.8	75.7
Accrued interest	0.7	0.4
Security deposits	29.0	21.3
Regulatory liabilities, current	39.0	34.9
Other current liabilities	13.5	17.5
Total current liabilities	201.7	210.2
Non-current liabilities:
Long-term debt	580.9	581.5
Deferred taxes	128.7	131.7
Taxes payable	41.0	77.1
Regulatory liabilities, non-current	279.0	278.3
Pension, retiree and other benefits	75.0	83.2
Asset Retirement Obligation	4.7	4.7
Other deferred credits	7.5	7.6
Total non-current liabilities	1,116.8	1,164.1
Commitments and contingencies
Common shareholder's equity:
Common stock	0.4	0.4
Other paid-in capital	711.8	711.8
Accumulated other comprehensive income	(34.9)	(35.3)
Retained earnings/ (deficit)	(202.9)	(231.6)
Total common shareholder's equity	474.4	445.3
Total liabilities and shareholder's equity	$ 1,792.9	$ 1,819.6

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Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 2019	Dec. 31, 2018
Common Stock, Shares Authorized	1,500	1,500
Common stock, shares issued	1	1
Common stock, shares outstanding	1	1
THE DAYTON POWER AND LIGHT COMPANY [Member]
Common Stock, Shares Authorized	50,000,000	50,000,000
Common stock, shares outstanding	41,172,173	41,172,173
Common stock, par value (in USD per share)	$ 0.01	$ 0.01

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Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Cash flows from operating activities:
Net income	$ 42.1	$ 16.9
Adjustments to reconcile net income / (loss) to net cash from operating activities:
Depreciation and amortization	(3.1)	20.1
Charge for early retirement of debt	0.0	0.7
Deferred income taxes	5.2	(41.7)
Gain (Loss) on Disposition of Business	0.0	(11.7)
Gain (Loss) on Disposition of Business, Including Discontinued Operation	(0.1)	13.6
Gain (Loss) on Sale of Assets and Asset Impairment Charges	0.9	0.6
Changes in certain assets and liabilities:
Accounts receivable, net	4.1	5.9
Inventories	(1.2)	3.2
Taxes applicable to subsequent years	18.7	19.7
Deferred regulatory costs, net	7.7	(2.1)
Accounts payable	(14.0)	(0.9)
Accrued taxes	(35.2)	8.2
Accrued interest	15.6	17.6
Increase (Decrease) in Security Deposits	7.7	0.6
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits	(6.9)	(5.9)
Other	(4.9)	(5.9)
Net Cash Provided by (Used in) Operating Activities	36.6	50.6
Cash flows from investing activities:
Capital expenditures	(34.3)	(27.3)
Proceeds from disposal and sale of business	0.0	234.9
Payments for Removal Costs	0.0	(14.5)
Other investing activities, net	0.0	2.3
Net cash provided by / (used in) investing activities	(34.3)	195.4
Cash flows from financing activities:
Repayments of Lines of Credit	0.0	(15.0)
Proceeds from Lines of Credit	0.0	25.0
Repayment of long-term debt	(1.1)	(131.1)
Proceeds from (Payments for) Other Financing Activities	(0.1)	0.0
Net cash used in financing activities	(1.2)	(121.1)
Net Cash Provided by (Used in) Discontinued Operations	0.0	(1.3)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	1.1	123.6
Other deferred credits	7.9
Supplemental cash flow information:
Interest paid, net of amounts capitalized	6.7	7.0
Proceeds from Income Tax Refunds	0.0	0.0
Non-cash financing and investing activities:
Accruals for capital expenditures	4.4	8.9
Restricted Cash and Cash Equivalents	112.8	148.5
Non-cash Proceeds from Sale of Business	0.0	4.1
Non-cash capital contribution	1.5	44.6
THE DAYTON POWER AND LIGHT COMPANY [Member]
Cash flows from operating activities:
Net income	29.0	15.7
Adjustments to reconcile net income / (loss) to net cash from operating activities:
Depreciation and amortization	18.0	18.6
Charge for early retirement of debt	0.0	0.5
Deferred income taxes	(0.9)	3.6
Gain (Loss) on Disposition of Business	0.0	(12.4)
Changes in certain assets and liabilities:
Accounts receivable, net	2.6	(2.3)
Inventories	(0.5)	(0.2)
Taxes applicable to subsequent years	18.1	17.8
Deferred regulatory costs, net	7.7	(2.1)
Accounts payable	(12.7)	7.7
Accrued taxes	(27.4)	(36.3)
Accrued interest	0.1	0.3
Increase (Decrease) in Security Deposits	7.7	0.6
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits	(6.8)	(5.5)
Other	(5.4)	(0.2)
Net Cash Provided by (Used in) Operating Activities	29.5	30.6
Cash flows from investing activities:
Capital expenditures	(33.7)	(24.6)
Payments for Removal Costs	0.0	(14.5)
Other investing activities, net	0.0	(0.3)
Net cash provided by / (used in) investing activities	(33.7)	(39.4)
Cash flows from financing activities:
Repayments of Lines of Credit	0.0	(15.0)
Proceeds from Lines of Credit	0.0	25.0
Repayment of long-term debt	(1.1)	(61.1)
Payments of Ordinary Dividends, Common Stock	0.0	(23.8)
Proceeds from Contributions from Parent	0.0	80.0
Proceeds from (Payments for) Other Financing Activities	(0.1)	0.0
Net cash used in financing activities	(1.2)	5.1
Net Cash Provided by (Used in) Discontinued Operations	0.0	0.0
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	(5.4)	(3.7)
Other deferred credits	7.5
Supplemental cash flow information:
Interest paid, net of amounts capitalized	5.9	5.5
Income Taxes Paid, Net	0.0	0.0
Non-cash financing and investing activities:
Accruals for capital expenditures	4.8	4.6
Restricted Cash and Cash Equivalents	$ 60.8	$ 1.9

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Statement of Equity Statement - USD ($) $ in Millions	Total	Common Stock [Member]	Other Additional Capital [Member]	AOCI Attributable to Parent [Member]	Retained Earnings [Member]	Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]	Subsidiaries [Member]	Subsidiaries [Member] Common Stock [Member]	Subsidiaries [Member] Other Additional Capital [Member]	Subsidiaries [Member] AOCI Attributable to Parent [Member]	Subsidiaries [Member] Retained Earnings [Member]	Subsidiaries [Member] Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Shares, Issued		1						41,172,173
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ (584.3)	$ 0.0	$ 2,330.4	$ 0.8	$ (2,915.5)		$ 330.7	$ 0.4	$ 685.8	$ (36.2)	$ (319.3)
Other Comprehensive Income (Loss), Net of Tax				3.3			1.1			1.1
Net income	16.9				16.9		15.7
Net Income (Loss) Attributable to Parent											15.7
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	20.2						16.8
Stockholders' Equity, Other	0.0			(1.0)	1.0		(0.4)		(0.3)	(1.1)	1.0
Dividends, Common Stock, Cash							(23.8)		(23.8)
Proceeds from Contributions from Parent							80.0		(80.0)
Non-cash capital contribution	44.6		44.6
AOCI reclassed to Retained Earnings before tax | Adjustments for New Accounting Pronouncement [Member]	1.6						1.7
AOCI reclassed to Retained Earnings, net of tax | Adjustments for New Accounting Pronouncement [Member]	$ 1.0						$ 1.1
Common stock, par value (in USD per share)							$ 0.01
Common Stock, Shares Authorized	1,500						50,000,000
Shares, Issued		1						41,172,173
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ (519.5)	$ 0.0	2,375.0	3.1	(2,897.6)		$ 403.3	$ 0.4	741.7	(36.2)	(302.6)
Common stock, par value (in USD per share)							$ 0.01
Common Stock, Shares Authorized	1,500						50,000,000
Shares, Issued		1						41,172,173
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ (471.7)	$ 0.0	2,370.5	2.2	(2,844.4)		$ 445.3	$ 0.4	711.8	(35.3)	(231.6)
Other Comprehensive Income (Loss), Net of Tax	(0.4)			(0.4)		$ (0.5)	0.4			0.4		$ (0.3)
Net income	42.1						29.0
Net Income (Loss) Attributable to Parent					42.1						29.0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	41.7						29.4
Stockholders' Equity, Other	0.1		0.1				(0.3)				(0.3)
Proceeds from Contributions from Parent							0.0
Non-cash capital contribution	$ 1.5		1.5
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
Common stock, par value (in USD per share)							$ 0.01
Common Stock, Shares Authorized	1,500						50,000,000
Shares, Issued		1						41,172,173
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ (428.4)	$ 0.0	$ 2,372.1	$ 1.8	$ (2,802.3)		$ 474.4	$ 0.4	$ 711.8	$ (34.9)	$ (202.9)

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Overview and Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2019

Significant Accounting Policies [Line Items]

Overview and Summary of Significant Accounting Policies

Overview and Summary of Significant Accounting Policies

Description of Business

DPL is a diversified regional energy company organized in 1985 under the laws of Ohio. DPL has one reportable segment: the Utility segment. See Note 11 – Business Segments for more information relating to this reportable segment. The terms “we,” “us,” “our” and “ours” are used to refer to DPL and its subsidiaries.

DPL is an indirectly wholly-owned subsidiary of AES.

DP&L, a wholly-owned subsidiary of DPL, 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 526,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a6,000-square mile area of West Central Ohio. 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 will primarily be 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.

DPL’s other primary subsidiaries include MVIC and AES Ohio Generation. MVIC is our captive insurance company that provides insurance services to DPL and our other subsidiaries. AES Ohio Generation's only operating asset is an undivided interest in Conesville. AES Ohio Generation sells all of its energy and capacity into the wholesale market. DPL's subsidiaries are all wholly-owned.

DPL also has a wholly-owned business trust, DPL Capital Trust II, formed for the purpose of issuing trust capital securities to investors.

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.

DPL and its subsidiaries employed 629 people as of March 31, 2019, of which 617 were employed by DP&L. Approximately 58% of all DPLemployees are under a collective bargaining agreement, which expires October 31, 2020.

Financial Statement Presentation

DPL’s Condensed Consolidated Financial Statements include the accounts of DPL and its wholly-owned subsidiaries except for DPL Capital Trust II, which is not consolidated, consistent with the provisions of GAAP. As of March 31, 2019, AES Ohio Generation has an undivided ownership interest in one coal-fired generating facility, which is included in the financial statements at a carrying value of zero as it has been fully impaired. Operating revenues and expenses of this facility are included on a pro rata basis in the corresponding lines in the Condensed Consolidated Statements of Operations.

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

All material intercompany accounts and transactions are eliminated in consolidation. We have evaluated subsequent events through the date this report is issued.

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 Consolidated Financial Statements presented in this report contain all adjustments necessary to fairly state our financial position as of March 31, 2019; our results of operations for the three months ended March 31, 2019 and 2018, our cash flows for the three months ended March 31, 2019 and 2018 and the changes in our equity for the three months ended March 31, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three months ended March 31, 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 Consolidated Balance Sheet that reconcile to the total of such amounts as shown on the Condensed Consolidated Statements of Cash Flows:

$ in millions	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	70.8	$	90.5
Restricted cash	42.0		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	112.8	$	111.7

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 March 31, 2019 and 2018 were $13.9 million and $13.1 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 consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 consolidated 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 consolidated 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 consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 condensed consolidated financial statements.

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&Lis 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 526,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a6,000-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 will primarily be 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 617 people as of March 31, 2019. Approximately 59% of DP&Lemployees 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 March 31, 2019; our results of operations for the three months ended March 31, 2019 and 2018, our cash flows for the three months ended March 31, 2019 and 2018 and the changes in our equity for the three months ended March 31, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three months ended March 31, 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	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	18.8	$	45.0
Restricted cash	42.0		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	60.8	$	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 March 31, 2019 and 2018 were $13.9 million and $13.1 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
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 consolidated 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, 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 condensed financial statements.

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Supplemental Financial Information

3 Months Ended

Mar. 31, 2019

Supplemental Financial Information [Line Items]

Supplemental Financial Information

Supplemental Financial Information

Accounts receivable and Inventories are as follows at March 31, 2019 and December 31, 2018:

	March 31,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	60.5		$	55.8
Unbilled revenue	15.7			16.8
Amounts due from affiliates	0.7			—
Due from PJM transmission enhancement settlement	9.8			16.5
Other	1.6			2.3
Provision for uncollectible accounts	(0.6		)	(0.9		)
Total accounts receivable, net	$	87.7		$	90.5
Inventories, at average cost:
Fuel and limestone	$	3.5		$	1.9
Materials and supplies	8.4			8.3
Other	—			0.5
Total inventories, at average cost	$	11.9		$	10.7

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three months ended March 31, 2019 and 2018 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) components	Affected line item in the Condensed Consolidated Statements of Operations	Three months ended March 31,
$ in millions		2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	(0.3	)	$	(1.0	)
	Income tax expense	0.1			0.6
	Net of income taxes	(0.2		)	(0.4		)
	Loss from discontinued operations	—			4.1
	Income tax benefit from discontinued operations	—			(1.4		)
	Net of income taxes	—			2.7
Amortization of defined benefit pension items (Note 8):
	Other expense	0.1			0.2
	Income tax benefit	—			(0.1		)
	Net of income taxes	0.1			0.1
Total reclassifications for the period, net of income taxes		$	(0.1	)	$	2.4

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the three months endedMarch 31, 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	$	17.0		$	(14.8	)	$	2.2
Other comprehensive loss before reclassifications	(0.3		)	—			(0.3		)
Amounts reclassified from AOCI to earnings	(0.2		)	0.1			(0.1		)
Net current period other comprehensive income / (loss)	(0.5		)	0.1			(0.4		)
Balance at March 31, 2019	$	16.5		$	(14.7	)	$	1.8

THE DAYTON POWER AND LIGHT COMPANY [Member]

Supplemental Financial Information [Line Items]

Supplemental Financial Information

Supplemental Financial Information

Accounts receivable and Inventories are as follows at March 31, 2019 and December 31, 2018:

	March 31,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	58.0		$	53.3
Unbilled revenue	15.7			16.8
Amounts due from affiliates	3.9			2.3
Due from PJM transmission enhancement settlement	9.8			16.5
Other	1.6			2.4
Provision for uncollectible accounts	(0.6		)	(0.9		)
Total accounts receivable, net	$	88.4		$	90.4
Inventories, at average cost:
Materials and supplies	$	8.1		$	7.1
Other	—			0.6
Total inventories, at average cost	$	8.1		$	7.7

Accumulated Other Comprehensive Income / (Loss)

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three months ended March 31, 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 March 31,
$ in millions		2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	(0.1	)	$	(0.8	)
	Income tax expense	—			0.5
	Net of income taxes	(0.1		)	(0.3		)
Amortization of defined benefit pension items (Note 8):
	Other expense	0.9			1.1
	Income tax benefit	(0.2		)	(0.2		)
	Net of income taxes	0.7			0.9
Total reclassifications for the period, net of income taxes		$	0.6		$	0.6

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the three months ended March 31, 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	(0.2		)	—			(0.2		)
Amounts reclassified from AOCI to earnings	(0.1		)	0.7			0.6
Net current period other comprehensive income / (loss)	(0.3		)	0.7			0.4
Balance at March 31, 2019	$	0.3		$	(35.2	)	$	(34.9	)

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Regulatory Matters (Notes)

3 Months Ended

Mar. 31, 2019

Schedule of Regulatory Assets and Liabilities [Text Block]

Regulatory Matters

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.

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 ("ADIT") and any related regulatory liability over a 10-year period. DP&L made such a filing on March 1, 2019 and proposed to return a total of $65.1 million to customers. The timing and final amount to be returned to customers is unknown at this time. Excess ADIT related to depreciation life and method differences will be returned to customers in accordance with federal tax law and related regulations.

Subsidiaries [Member]

Schedule of Regulatory Assets and Liabilities [Text Block]

Regulatory Matters

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.

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 ("ADIT") and any related regulatory liability over a 10-year period. DP&L made such a filing on March 1, 2019 and proposed to return a total of $65.1 million to customers. The timing and final amount to be returned to customers is unknown at this time. Excess ADIT related to depreciation life and method differences will be returned to customers in accordance with federal tax law and related regulations.

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Fair Value

3 Months Ended

Mar. 31, 2019

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value

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 March 31, 2019 and December 31, 2018. Information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	March 31, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.1	$	0.1	$	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	$	6.7	$	8.3	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	1,475.7	$	1,544.9	$	1,475.9	$	1,519.6

These financial instruments are not subject to master netting agreements or collateral requirements and as such are presented in the Condensed Consolidated 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 three months ended March 31, 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 $1.6 million ($1.0 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 three months ended March 31, 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 consolidated 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 2019 to 2061.

The fair value of assets and liabilities at March 31, 2019 and December 31, 2018 and the respective category within the fair value hierarchy for DPL is as follows:

$ in millions	Fair value at March 31, 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	$	0.1	$	—	$	—	$	0.1	$	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	0.1		8.2		—		8.3		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		1.1		—		1.1		—		1.5		—		1.5
Total Derivative assets	—		1.1		—		1.1		—		1.5		—		1.5
Total Assets	$	0.1	$	9.3	$	—	$	9.4	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	1,527.3	$	17.6	$	1,544.9	$	—	$	1,501.9	$	17.7	$	1,519.6
Total Liabilities	$	—	$	1,527.3	$	17.6	$	1,544.9	$	—	$	1,501.9	$	17.7	$	1,519.6

(a) Includes credit valuation adjustment

THE DAYTON POWER AND LIGHT COMPANY [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value

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 March 31, 2019 and December 31, 2018. Information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	March 31, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.1	$	0.1	$	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	$	6.7	$	8.3	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	585.5	$	592.6	$	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 three months ended March 31, 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 three months ended March 31, 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 March 31, 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 March 31, 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	$	0.1	$	—	$	—	$	0.1	$	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	0.1		8.2		—		8.3		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		1.1		—		1.1		—		1.5		—		1.5
Total derivative assets	—		1.1		—		1.1		—		1.5		—		1.5
Total assets	$	0.1	$	9.3	$	—	$	9.4	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	575.0	$	17.6	592.6		$	—	$	576.1	$	17.7	$	593.8
Total liabilities	$	—	$	575.0	$	17.6	$	592.6	$	—	$	576.1	$	17.7	$	593.8

(a) Includes credit valuation adjustment

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Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

In the normal course of business, DPL 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 March 31, 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.

We had previously entered into interest rate derivative contracts to manage interest rate exposure related to anticipated borrowings of fixed-rate debt. These interest rate derivative contracts were settled in 2013 and we continue to amortize amounts out of AOCI into interest expense.

The following tables provide information concerning gains or losses recognized in AOCI for the cash flow hedges for the three months ended March 31, 2019 and 2018:

	Three months ended					Three months ended
	March 31, 2019					March 31, 2018
			Interest						Interest
$ in millions (net of tax)	Power		Rate Hedge			Power			Rate Hedge
Beginning accumulated derivative gains / (losses) in AOCI	$	0.4	$	16.6		$	(2.8	)	$	17.5
Net gains / (losses) associated with current period hedging transactions	—		(0.3		)	—			0.9
Net gains / (losses) reclassified to earnings
Interest expense	—		(0.2		)	—			(0.4		)
Income / (loss) from discontinued operations	—		—			2.7			—
Ending accumulated derivative gains / (losses) in AOCI	$	0.4	$	16.1		$	(0.1	)	$	18.0
Portion expected to be reclassified to earnings in the next twelve months			$	(0.8	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)			17

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

Financial Statement Effect

DPL 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 DPL's interest rate swaps are as follows:

Fair Values of Derivative Instruments
at March 31, 2019
				Gross Amounts Not Offset in the Condensed Consolidated Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Consolidated Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Other prepayments and current assets)
Interest rate swap	Designated	$	0.8	$	—	$	—	$	0.8
Long-term derivative positions (presented in Other deferred assets)
Interest rate swap	Designated	0.3		—		—		0.3
Total assets		$	1.1	$	—	$	—	$	1.1

(a) Includes credit valuation adjustment.

Fair Values of Derivative Instruments
at December 31, 2018
				Gross Amounts Not Offset in the Condensed Consolidated Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Consolidated Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Other prepayments and current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other deferred 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 Consolidated Statements of Operations.

THE DAYTON POWER AND LIGHT COMPANY [Member]

Derivative Instruments and Hedging Activities Disclosures [Line Items]

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 March 31, 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 months ended March 31, 2019 and 2018:

	Three months ended
	March 31, 2019			March 31, 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	(0.2		)	0.5
Net losses reclassified to earnings
Interest expense	(0.1		)	(0.3		)
Ending accumulated derivative gains in AOCI	$	0.3		$	1.6
Portion expected to be reclassified to earnings in the next twelve months	$	(0.8	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	17

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 March 31, 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 Other prepayments and current assets)
Interest rate swap	Designated	$	0.8	$	—	$	—	$	0.8
Long-term derivative positions (presented in Other deferred assets)
Interest rate swap	Designated	0.3		—		—		0.3
Total assets		$	1.1	$	—	$	—	$	1.1

(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 Other prepayments and current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other deferred 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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Debt Obligations

3 Months Ended

Mar. 31, 2019

Debt Instrument [Line Items]

Debt Obligations

Long-term Debt

The following table summarizes DPL's outstanding long-term debt.

	Interest		March 31,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	435.0		$	436.1
Tax-exempt First Mortgage Bonds - rates from 3.05% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.2%	2061	17.6			17.7
Unamortized deferred financing costs			(5.8		)	(6.3		)
Unamortized debt discounts and premiums, net			(1.3		)	(1.4		)
Total long-term debt at consolidated subsidiary			585.5			586.1
Senior unsecured notes	6.75%	2019	99.0			99.0
Senior unsecured notes	7.25%	2021	780.0			780.0
Note to DPL Capital Trust II (c)	8.125%	2031	15.6			15.6
Unamortized deferred financing costs			(3.9		)	(4.3		)
Unamortized debt discounts and premiums, net			(0.5		)	(0.5		)
Total long-term debt			1,475.7			1,475.9
Less: current portion			(103.6		)	(103.6		)
Long-term debt, net of current portion			$	1,372.1		$	1,372.3

(a) Range of interest rates for the three months endedMarch 31, 2019.

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

(c) Note payable to related party.

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 March 31, 2019 and December 31, 2018, DPLhad no outstanding borrowings on its line of credit. At March 31, 2019 and December 31, 2018, DP&Lhad no outstanding borrowings on its line of credit.

Significant transactions

On March 4, 2019, DPL issued a Notice of Partial Redemption to the Trustee (U.S. Bank) on the DPL6.75% Senior Notes due 2019. DPL notified the trustee that it was calling the remaining $99.0 million outstanding principal amount of these notes. The redemption date was April 4, 2019. These bonds were redeemed at par plus accrued interest and a make-whole premium of $1.5 million with cash on hand.

On April 17, 2019, DPL closed a $400.0 million issuance of senior unsecured bonds. These new bonds were priced at 4.35% and mature on April 15, 2029. Proceeds from the issuance and cash on hand will be used to settle a partial redemption for $400.0 million of DPL's7.25% senior unsecured notes maturing October 15, 2021, as discussed below. After the redemption, the DPL7.25% senior notes due in 2021 will have an outstanding balance of $380.0 million.

On April 8, 2019, DPL issued a Notice of Partial Redemption to the Trustee (Wells Fargo Bank N.A.) on the DPL7.25% Senior Notes due 2021. DPL notified the trustee that it was calling $400.0 million of the $780.0 million outstanding principal amount of these notes. The redemption date will be May 7, 2019. These bonds will be redeemed at par plus accrued interest and a make-whole premium.

On March 30, 2018, DPL issued a Notice of Partial Redemption to the Trustee (U.S. Bank) on the DPL6.75% Senior Notes due 2019. DPL notified the trustee that it was calling $101.0 million of the $200.0 million outstanding principal amount of these notes. These bonds were redeemed at par plus accrued interest and a make-whole premium of $5.1 million on April 30, 2018 with cash on hand.

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.

On March 27, 2018, DPL made a $70.0 million prepayment to eliminate the outstanding balance of its bank term loan in full. As of March 31, 2018, the term loan was fully paid off.

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) modified a "call protection" provision which as modified 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 have been 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.

Long-term debt covenants and restrictions

DPL’s revolving credit agreement has two financial covenants. The first financial covenant, a Total Debt to EBITDA ratio, is calculated at the end of each fiscal quarter by dividing total debt at the end of the current quarter by consolidated EBITDA for the four prior fiscal quarters. The ratio in the agreement is not to exceed 7.25 to 1.00 for any fiscal quarter ending September 30, 2015 through December 31, 2018; it then steps down not to exceed 7.00 to 1.00 for any fiscal quarter ending January 1, 2019 through June 30, 2019; it then steps down not to exceed 6.75 to 1.00 for any fiscal quarter ending July 1, 2019 through December 31, 2019; and it then steps down not to exceed 6.50 to 1.00 for any fiscal quarter ending January 1, 2020 and afterward. As of March 31, 2019, this financial covenant was met with a ratio of 5.83 to 1.00.

The second financial covenant is an EBITDA to Interest Expense ratio that is calculated, at the end of each fiscal quarter, by dividing 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 2.10 to 1.00 for any fiscal quarter ending September 30, 2015 through December 31, 2018; it then steps up to be not less than 2.25 to 1.00 for any fiscal quarter ending January 1, 2019 and afterward. As of March 31, 2019, this financial covenant was met with a ratio of 2.73 to 1.00.

DPL’s secured revolving credit agreement and senior unsecured notes due 2019 also restrict dividend payments from DPL to AES, such that DPL cannot make dividend payments unless at the time of, and/or as a result of the distribution, (i) DPL’s leverage ratio does not exceed 0.67 to 1.00 and DPL’s interest coverage ratio is not less than 2.50 to 1.00 or, if such ratios are not within the parameters, (ii) DPL’s senior long-term debt rating from two of the three major credit rating agencies is at least investment grade. As of March 31, 2019, DPL’s leverage ratio was at 1.40 to 1.00. As a result, as of March 31, 2019, DPL was prohibited under each of these agreements from making a distribution to its shareholder or making a loan to any of its affiliates (other than its subsidiaries). DPL is also restricted from making dividend and tax sharing payments from DPL to AES per its 2017 ESP. This order restricts dividend payments from DPL to AES during the term of the 2017 ESP and restricts tax sharing payments from DPL to AES during the term of the DMR.

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 than0.65 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 March 31, 2019, DP&L's ratings meet those requirements and this covenant is suspended for the quarter ended March 31, 2019.

The second financial covenant measures EBITDA to Interest Expense. The TotalConsolidated 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 financial covenant was met with a ratio of 8.99 to 1.00 as of March 31, 2019.

As of March 31, 2019, DPL and DP&L were 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.

THE DAYTON POWER AND LIGHT COMPANY [Member]

Debt Instrument [Line Items]

Debt Obligations

Long-term Debt

The following table summarizes DP&L's outstanding long-term debt.

	Interest		March 31,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	435.0		$	436.1
Tax-exempt First Mortgage Bonds - rates from 3.05% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.2%	2061	17.6			17.7
Unamortized deferred financing costs			(5.8		)	(6.3		)
Unamortized debt discounts and premiums, net			(1.3		)	(1.4		)
Total long-term debt			585.5			586.1
Less: current portion			(4.6		)	(4.6		)
Long-term debt, net of current portion			$	580.9		$	581.5

(a) Range of interest rates for the three months ended March 31, 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 March 31, 2019 and December 31, 2018, DP&Lhad no outstanding borrowings on its line of credit.

Significant transactions

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.

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) modified a "call protection" provision which as modified 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 have been 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.

Long-term 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 than0.65 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 March 31, 2019, DP&L's ratings meet those requirements and this covenant is suspended for the quarter ended March 31, 2019.

The second financial covenant measures EBITDA to Interest Expense. The TotalConsolidated 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 financial covenant was met with a ratio of 8.99 to 1.00 as of March 31, 2019.

As of March 31, 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.

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Income Taxes

3 Months Ended

Mar. 31, 2019

Entity Information [Line Items]

Income Taxes

Income Taxes

The following table details the effective tax rates for the three months ended March 31, 2019 and 2018.

	Three months ended
	March 31,
	2019	2018
DPL	14.1%	8.0%

Income tax expense for the three months endedMarch 31, 2019 and 2018 was calculated using the estimated annual effective income tax rates for 2019 and 2018 of 14.1% and 19.2%, 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.DPL’s effective combined state and federal income tax rate was 14.1% for the three months ended March 31, 2019. This is lower than the combined federal and state statutory rate of 21.6% primarily due to the flowthrough of the net tax benefit related to the reversal of excess deferred taxes of DP&L.

For the three months ended March 31, 2019, DPL’s current period effective tax rate was not materially different than the estimated annual effective rate.

Per the terms of DP&L's 2017 ESP, DPL will not make any tax-sharing payments to AES and AES will forgo collection of the payments during the term of the DMR. As such, during the three months endedMarch 31, 2019 and 2018, DPL converted $1.5 million and $44.6 million, respectively, of accrued tax sharing liabilities with AES to additional equity investment in DPL.

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Income Taxes

Income Taxes

The following table details the effective tax rates for the three months ended March 31, 2019 and 2018.

	Three months ended
	March 31,
	2019	2018
DP&L	17.4%	18.7%

Income tax expense for the three months endedMarch 31, 2019 and 2018 was calculated using the estimated annual effective income tax rates for 2019 and 2018 of 17.3% and 19.8%, 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 17.4% for the three months ended March 31, 2019. 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.

For the three months ended March 31, 2019, DP&L’s current period effective tax rate was not materially different than the estimated annual effective rate.

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Benefit Plans

3 Months Ended

Mar. 31, 2019

Entity Information [Line Items]

Pension and Postretirement Benefits

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 three months ended March 31, 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 that are still participants in the DP&L plan.

The net periodic benefit cost of the pension benefit plans for the three months ended March 31, 2019 and 2018 was:

	Three months ended
	March 31,
$ in millions	2019			2018
Service cost	$	0.9		$	1.5
Interest cost	3.7			3.4
Expected return on plan assets	(5.0		)	(5.2		)
Amortization of unrecognized:
Prior service cost	0.3			0.2
Actuarial loss	1.1			1.6
Net periodic benefit cost	$	1.0		$	1.5

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 March 31, 2019 and $9.2 million at December 31, 2018 were not material to the financial statements in the periods covered by this report.

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Pension and Postretirement Benefits

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 three months ended March 31, 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 months ended March 31, 2019 and 2018 was:

	Three months ended
	March 31,
$ in millions	2019			2018
Service cost	$	0.9		$	1.5
Interest cost	3.7			3.4
Expected return on plan assets	(5.0		)	(5.2		)
Amortization of unrecognized:
Prior service cost	0.5			0.4
Actuarial loss	1.7			2.3
Net periodic benefit cost	$	1.8		$	2.4

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 March 31, 2019 and $9.2 million at December 31, 2018 were not material to the financial statements in the periods covered by this report.

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Shareholder's Equity

3 Months Ended

Mar. 31, 2019

Class of Stock [Line Items]

Shareholder's Equity

Shareholder's Equity

Capital Contributions from AES

DP&L's approved six-year 2017 ESP restricts DPL from making dividend payments to its parent company, AES, during the term of the ESP, as well as from making tax-sharing payments to AES during the term of the DMR. The 2017 ESP also requires that existing tax payments owed by DPL to AES, and similar tax payments that accrue during the term of the DMR, be converted into equity investments in DPL.

For the three months ended March 31,2019 and 2018, AES made capital contributions of $1.5 million and $44.6 million, respectively, by converting the amount owed to it by DPL related to tax-sharing payments for current tax liabilities.

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Contractual Obligations, Commercial Commitments and Contingencies

3 Months Ended

Mar. 31, 2019

Entity Information [Line Items]

Contractual Obligations, Commercial Commitments and Contingencies

Contractual Obligations, Commercial Commitments and Contingencies

Guarantees

In the normal course of business, DPL enters into various agreements with its wholly-owned subsidiary, AES Ohio Generation, providing financial or performance assurance to third parties. These agreements are entered into primarily to support or enhance the creditworthiness otherwise attributed to this subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish this subsidiary's intended commercial purposes.

At March 31, 2019, DPL had $21.6 million of guarantees on behalf of AES Ohio Generation to third parties for future financial or performance assurance under such agreements. The guarantee arrangements entered into by DPL with these third parties cover select present and future obligations of AES Ohio Generation to such beneficiaries and are terminable by DPL upon written notice to the beneficiaries within a certain time. At March 31, 2019 and December 31, 2018, we had no outstanding balance of obligations covered by these guarantees.

To date, DPL has not incurred any losses related to the guarantees of AES Ohio Generation’s obligations and we believe it is unlikely that DPL would be required to perform or incur any losses in the future associated with any of the above guarantees.

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 March 31, 2019, DP&L could be responsible for the repayment of 4.9%, or $67.5 million, of $1,378.5 million OVEC debt obligations if they came due, comprised of both fixed and variable rate securities with maturities from 2019 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 Consolidated 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 Consolidated Financial Statements. As such, costs, if any, that may be incurred in excess of those amounts provided as of March 31, 2019, cannot be reasonably determined.

Environmental Matters

DPL’s and 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. The majority of solid waste created from the combustion of coal and fossil fuels consists of fly ash and other coal combustion by-products.

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

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Contractual Obligations, Commercial Commitments and Contingencies

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 March 31, 2019, DP&L could be responsible for the repayment of 4.9%, or $67.5 million, of $1,378.5 million OVEC debt obligations if they came due, comprised of both fixed and variable rate securities with maturities from 2019 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 March 31, 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.

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Business Segments

3 Months Ended

Mar. 31, 2019

Segment Reporting Information [Line Items]

Business Segments

Business Segments

DPL has presented the results of operations of Miami Fort Station, Zimmer Station, the Peaker Assets, Stuart Station, and Killen Station as discontinued operations as a group of components for all periods presented. For more information, see Note 14 – Discontinued Operations of Notes to DPL's Condensed Consolidated Financial Statements. As such, AES Ohio Generation only has operating activity coming from its undivided ownership interest in Conesville, which does not meet the thresholds to be a separate reportable operating segment. DPL manages its business through one reportable operating segment, the Utility segment. The primary segment performance measure is income / (loss) from continuing operations before income tax as management has concluded that this measure best reflects the underlying business performance of DPL and is the most relevant measure considered in DPL’s internal evaluation of the financial performance of its segment. The Utility segment is discussed further below.

Utility Segment

The Utility segment is comprised of DP&L’s electric transmission and distribution businesses, which distribute electricity to residential, commercial, industrial and governmental customers. DP&L distributes electricity to more than 526,000 retail customers located in a 6,000-square mile area of West Central Ohio. 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 recording 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. The Utility segment includes revenues and costs associated with our investment in OVEC and the historical results of DP&L’s Beckjord Facility, which was closed in 2014 and transferred to a third party in the first quarter of 2018, and Hutchings Coal generating facility, which was closed in 2013. These assets did not transfer to AES Ohio Generation as part of DP&L's Generation Separation on October 1, 2017. Thus, they are grouped within the Utility segment for segment reporting purposes. In addition, regulatory deferrals and collections, which include fuel deferrals in historical periods, are included in the Utility segment.

Included within the “Other” column are other businesses that do not meet the GAAP requirements for disclosure as reportable segments as well as certain corporate costs, which include interest expense on DPL’s long-term debt and adjustments related to purchase accounting from the Merger. DPL's undivided interest in Conesville is now included within the "Other" column as it no longer meets the requirement for disclosure as a reportable operating segment, since the results of operations of the other EGUs are now presented as discontinued operations. The accounting policies of the reportable segment are the same as those described in Note 1 – Overview and Summary of Significant Accounting Policies of our 10-K. Intersegment sales, costs of sales and expenses are eliminated in consolidation. Certain shared and corporate costs are allocated between "Other" and the Utility reporting segment.

The following tables present financial information for DPL’s Utility reportable business segment:

$ in millions	Utility		Other (a)			Adjustments and Eliminations			DPL Consolidated
Three months ended March 31, 2019
Revenues from external customers	$	201.1	$	7.9		$	—		$	209.0
Intersegment revenues	0.3		0.8			(1.1		)	—
Total revenues	$	201.4	$	8.7		$	(1.1	)	$	209.0
Depreciation and amortization	$	18.0	$	0.4		$	—		$	18.4
Interest expense	$	7.1	$	16.6		$	—		$	23.7
Income / (loss) from continuing operations before income tax	$	35.1	$	(15.9	)	$	—		$	19.2
Cash capital expenditures	$	33.7	$	0.6		$	—		$	34.3
At March 31, 2019
Total assets	$	1,792.9	$	607.9		$	(535.1	)	$	1,865.7
$ in millions	Utility		Other (a)			Adjustments and Eliminations			DPL Consolidated
Three months ended March 31, 2018
Revenues from external customers	$	195.8	$	11.6		$	—		$	207.4
Intersegment revenues	0.2		0.6			(0.8		)	—
Total revenues	$	196.0	$	12.2		$	(0.8	)	$	207.4
Depreciation and amortization	$	18.6	$	0.2		$	—		$	18.8
Interest expense	$	8.2	$	19.6		$	—		$	27.8
Income / (loss) from continuing operations before income tax	$	19.3	$	(16.8	)	$	—		$	2.5
Cash capital expenditures	$	24.6	$	2.7		$	—		$	27.3
At December 31, 2018
Total assets	$	1,819.6	$	545.9		$	(482.4	)	$	1,883.1

(a) "Other" includes Cash capital expenditures and Total assets related to the assets of discontinued operations and held-for-sale businesses for all periods presented.

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Revenue (Notes)

3 Months Ended

Mar. 31, 2019

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, and RTO Capacity revenues, see Note 14—Revenue in Item 8.—Financial Statements and Supplementary Data of our Form 10-K.

DPL's revenue from contracts with customers was $208.3 million and $198.2 million for the three months ended March 31, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue by segment for the three months ended March 31, 2019 and 2018:

$ in millions	Utility		Other		Adjustments and Eliminations			Total
	Three months ended March 31, 2019
Retail Revenue
Retail revenue from contracts with customers	$	182.7	$	—	$	(0.3	)	$	182.4
Other retail revenues (a)	0.7		—		—			0.7
Wholesale Revenue
Wholesale revenue from contracts with customers	5.0		3.4		—			8.4
RTO revenue	10.9		—		—			10.9
RTO capacity revenues	2.1		1.6		—			3.7
Other revenues from contracts with customers (b)	—		2.9		—			2.9
Other revenues	—		0.8		(0.8		)	—
Total revenues	$	201.4	$	8.7	$	(1.1	)	$	209.0
	Three months ended March 31, 2018
Retail Revenue
Retail revenue from contracts with customers	$	161.2	$	—	$	(0.2	)	$	161.0
Other retail revenues (a)	9.2		—		—			9.2
Wholesale Revenue
Wholesale revenue from contracts with customers	12.6		7.7		—			20.3
RTO revenue	11.1		0.1		—			11.2
RTO capacity revenues	1.9		1.4		—			3.3
Other revenues from contracts with customers (b)	—		2.4		—			2.4
Other revenues	—		0.6		(0.6		)	—
Total revenues	$	196.0	$	12.2	$	(0.8	)	$	207.4

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606. Accounts receivable balances associated with these revenues were $1.5 million at March 31, 2019, and there were no balances at December 31, 2018.

(b) Other revenues from contracts with customers primarily includes revenues for various services provided by Miami Valley Lighting.

The balances of receivables from contracts with customers were $74.8 million and $72.6 million as of March 31, 2019 and December 31, 2018, respectively. Payment terms for all receivables from contracts with customers are typically within 30 days.

Subsidiaries [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, and RTO 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 $200.7 million and $186.8 million for the three months ended March 31, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue for the three months ended March 31, 2019 and 2018:

	Three months ended
$ in millions	March 31, 2019		March 31, 2018
Retail Revenue
Retail revenue from contracts with customers	$	182.7	$	161.2
Other retail revenues (a)	0.7		9.2
Wholesale Revenue
Wholesale revenue from contracts with customers	5.0		12.6
RTO revenue	10.9		11.1
RTO capacity revenues	2.1		1.9
Total revenues	$	201.4	$	196.0

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606. Accounts receivable balances associated with these revenues were $1.5 million at March 31, 2019, and there were no balances at December 31, 2018.

The balances of receivables from contracts with customers were $72.4 million and $70.1 million as of March 31, 2019 and December 31, 2018, respectively. Payment terms for all receivables from contracts with customers are typically within 30 days.

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Dispositions (Notes)

3 Months Ended

Mar. 31, 2019

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, DPL recognized a loss on the transfer of $11.7 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 months ended March 31, 2018, excluding the loss on transfer noted above. Prior to the transfer, the Beckjord Facility was included in the Utility segment.

Discontinued Operations

On December 8, 2017, DPL and AES Ohio Generation completed the sale transaction of their entire undivided interest in the Miami Fort Station and the Zimmer Station. On March 27, 2018, DPL and AES Ohio Generation completed the sale transaction of the Peaker assets to Kimura Power, LLC, and this transaction resulted in a loss on sale of $1.9 million for the three months ended March 31, 2018. Further, on May 31, 2018, DPL and AES Ohio Generation retired the Stuart Station coal-fired and diesel-fired generating units and the Killen Station coal-fired generating unit and combustion turbine, as planned.

Consequently, DPL determined that the disposal of this group of components as a whole represents a strategic shift by us to exit generation, and, as such, qualifies to be presented as discontinued operations. Therefore, the results of operations and financial position for this group of components were reported as such in the Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets for all periods presented.

The following table summarizes the major categories of assets and liabilities at the dates indicated:

$ in millions	March 31, 2019			December 31, 2018
Accounts receivable, net	$	3.3		$	4.0
Taxes applicable to subsequent years	1.7			2.3
Other prepayments and current assets	1.5			2.4
Intangible assets, net	5.3			5.3
Total assets of the disposal group classified as assets of discontinued operations and held-for-sale businesses in the balance sheets	$	11.8		$	14.0
Accounts payable	$	2.9		$	3.9
Accrued taxes	2.4			3.1
Other current liabilities	3.7			5.2
Deferred taxes (a)	(33.8		)	(39.8		)
Taxes payable	1.1			2.3
Pension, retiree and other benefits	9.6			9.7
Asset retirement obligations	68.9			90.4
Other deferred credits	6.7			6.6
Total liabilities of the disposal group classified as liabilities of discontinued operations and held-for-sale businesses in the balance sheets	$	61.5		$	81.4

(a) Deferred taxes represent the tax asset position of the discontinued group of components, which were netted with liabilities on DPL prior to classification as discontinued operations.

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

	Three months ended
	March 31,
$ in millions	2019			2018
Revenues	$	16.3		$	85.8
Cost of revenues	(6.6		)	(41.1		)
Operating and other expenses	20.1			(24.7		)
Income from discontinued operations	29.8			20.0
Gain / (loss) from disposal of discontinued operations	0.1			(1.9		)
Income tax expense from discontinued operations	4.3			3.5
Net income from discontinued operations	$	25.6		$	14.6

Cash flows related to discontinued operations are included in our Condensed Consolidated Statements of Cash Flows. Cash flows from operating activities for discontinued operations were $8.1 million and $9.0 million for the three months ended March 31,2019 and 2018, respectively. Cash flows from investing activities for discontinued operations were $235.8 million for the three months ended March 31,2018. For the three months ended March 31,2019, there were no cash flows from investing activities.

AROs of Discontinued Operations

DPL's retired Stuart and Killen generating facilities continue to carry ARO liabilities consisting primarily of river intake and discharge structures, coal unloading facilities, landfills and ash disposal facilities. In the first quarter of 2019, DPL reduced the ARO liability related to the Stuart and Killen ash ponds and landfills by a combined $22.5 million based on updated internal analyses that reduced estimated closure costs associated with these ash ponds and landfills. The remaining ARO liability related to Stuart and Killen is included in the Asset retirement obligations balance in the total liabilities of the disposal group classified as liabilities of discontinued operations and held-for-sale businesses in the balance sheets as of March 31, 2019 above. As these plants are no longer in service, the reduction to the ARO liability was also recorded as a credit to depreciation and amortization expense in the same amount. The credit to depreciation and amortization expense is included in operating and other expenses of discontinued operations for the three months ended March 31, 2019 in the table above.

Subsidiaries [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 months ended March 31, 2018, excluding the loss on transfer noted above.

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Discontinued Operations

3 Months Ended

Mar. 31, 2019

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, DPL recognized a loss on the transfer of $11.7 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 months ended March 31, 2018, excluding the loss on transfer noted above. Prior to the transfer, the Beckjord Facility was included in the Utility segment.

Discontinued Operations

On December 8, 2017, DPL and AES Ohio Generation completed the sale transaction of their entire undivided interest in the Miami Fort Station and the Zimmer Station. On March 27, 2018, DPL and AES Ohio Generation completed the sale transaction of the Peaker assets to Kimura Power, LLC, and this transaction resulted in a loss on sale of $1.9 million for the three months ended March 31, 2018. Further, on May 31, 2018, DPL and AES Ohio Generation retired the Stuart Station coal-fired and diesel-fired generating units and the Killen Station coal-fired generating unit and combustion turbine, as planned.

Consequently, DPL determined that the disposal of this group of components as a whole represents a strategic shift by us to exit generation, and, as such, qualifies to be presented as discontinued operations. Therefore, the results of operations and financial position for this group of components were reported as such in the Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets for all periods presented.

The following table summarizes the major categories of assets and liabilities at the dates indicated:

$ in millions	March 31, 2019			December 31, 2018
Accounts receivable, net	$	3.3		$	4.0
Taxes applicable to subsequent years	1.7			2.3
Other prepayments and current assets	1.5			2.4
Intangible assets, net	5.3			5.3
Total assets of the disposal group classified as assets of discontinued operations and held-for-sale businesses in the balance sheets	$	11.8		$	14.0
Accounts payable	$	2.9		$	3.9
Accrued taxes	2.4			3.1
Other current liabilities	3.7			5.2
Deferred taxes (a)	(33.8		)	(39.8		)
Taxes payable	1.1			2.3
Pension, retiree and other benefits	9.6			9.7
Asset retirement obligations	68.9			90.4
Other deferred credits	6.7			6.6
Total liabilities of the disposal group classified as liabilities of discontinued operations and held-for-sale businesses in the balance sheets	$	61.5		$	81.4

(a) Deferred taxes represent the tax asset position of the discontinued group of components, which were netted with liabilities on DPL prior to classification as discontinued operations.

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

	Three months ended
	March 31,
$ in millions	2019			2018
Revenues	$	16.3		$	85.8
Cost of revenues	(6.6		)	(41.1		)
Operating and other expenses	20.1			(24.7		)
Income from discontinued operations	29.8			20.0
Gain / (loss) from disposal of discontinued operations	0.1			(1.9		)
Income tax expense from discontinued operations	4.3			3.5
Net income from discontinued operations	$	25.6		$	14.6

Cash flows related to discontinued operations are included in our Condensed Consolidated Statements of Cash Flows. Cash flows from operating activities for discontinued operations were $8.1 million and $9.0 million for the three months ended March 31,2019 and 2018, respectively. Cash flows from investing activities for discontinued operations were $235.8 million for the three months ended March 31,2018. For the three months ended March 31,2019, there were no cash flows from investing activities.

AROs of Discontinued Operations

DPL's retired Stuart and Killen generating facilities continue to carry ARO liabilities consisting primarily of river intake and discharge structures, coal unloading facilities, landfills and ash disposal facilities. In the first quarter of 2019, DPL reduced the ARO liability related to the Stuart and Killen ash ponds and landfills by a combined $22.5 million based on updated internal analyses that reduced estimated closure costs associated with these ash ponds and landfills. The remaining ARO liability related to Stuart and Killen is included in the Asset retirement obligations balance in the total liabilities of the disposal group classified as liabilities of discontinued operations and held-for-sale businesses in the balance sheets as of March 31, 2019 above. As these plants are no longer in service, the reduction to the ARO liability was also recorded as a credit to depreciation and amortization expense in the same amount. The credit to depreciation and amortization expense is included in operating and other expenses of discontinued operations for the three months ended March 31, 2019 in the table above.

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Summary of Significant Accounting Policies (Policy)

3 Months Ended

Mar. 31, 2019

Significant Accounting Policies [Line Items]

Description of Business

Description of Business

DPL is a diversified regional energy company organized in 1985 under the laws of Ohio. DPL has one reportable segment: the Utility segment. See Note 11 – Business Segments for more information relating to this reportable segment. The terms “we,” “us,” “our” and “ours” are used to refer to DPL and its subsidiaries.

DPL is an indirectly wholly-owned subsidiary of AES.

DP&L, a wholly-owned subsidiary of DPL, 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 526,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a6,000-square mile area of West Central Ohio. 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 will primarily be 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.

DPL’s other primary subsidiaries include MVIC and AES Ohio Generation. MVIC is our captive insurance company that provides insurance services to DPL and our other subsidiaries. AES Ohio Generation's only operating asset is an undivided interest in Conesville. AES Ohio Generation sells all of its energy and capacity into the wholesale market. DPL's subsidiaries are all wholly-owned.

DPL also has a wholly-owned business trust, DPL Capital Trust II, formed for the purpose of issuing trust capital securities to investors.

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.

DPL and its subsidiaries employed 629 people as of March 31, 2019, of which 617 were employed by DP&L. Approximately 58% of all DPLemployees are under a collective bargaining agreement, which expires October 31, 2020.

Financial Statement Presentation

Financial Statement Presentation

DPL’s Condensed Consolidated Financial Statements include the accounts of DPL and its wholly-owned subsidiaries except for DPL Capital Trust II, which is not consolidated, consistent with the provisions of GAAP. As of March 31, 2019, AES Ohio Generation has an undivided ownership interest in one coal-fired generating facility, which is included in the financial statements at a carrying value of zero as it has been fully impaired. Operating revenues and expenses of this facility are included on a pro rata basis in the corresponding lines in the Condensed Consolidated Statements of Operations.

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

All material intercompany accounts and transactions are eliminated in consolidation. We have evaluated subsequent events through the date this report is issued.

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 Consolidated Financial Statements presented in this report contain all adjustments necessary to fairly state our financial position as of March 31, 2019; our results of operations for the three months ended March 31, 2019 and 2018, our cash flows for the three months ended March 31, 2019 and 2018 and the changes in our equity for the three months ended March 31, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three months ended March 31, 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.

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 March 31, 2019 and 2018 were $13.9 million and $13.1 million, respectively.

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 consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 consolidated 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 consolidated 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 consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 condensed consolidated financial statements.

THE DAYTON POWER AND LIGHT COMPANY [Member]

Significant Accounting Policies [Line Items]

Description of Business

Description of Business

DP&Lis 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 526,000 customers located in West Central Ohio. Additionally, DP&L provides retail SSO electric service to residential, commercial, industrial and governmental customers in a6,000-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 will primarily be 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 617 people as of March 31, 2019. Approximately 59% of DP&Lemployees are under a collective bargaining agreement, which expires October 31, 2020.

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 March 31, 2019; our results of operations for the three months ended March 31, 2019 and 2018, our cash flows for the three months ended March 31, 2019 and 2018 and the changes in our equity for the three months ended March 31, 2019 and 2018. Unless otherwise noted, all adjustments are normal and recurring in nature. Due to various factors, interim results for the three months ended March 31, 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.

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 March 31, 2019 and 2018 were $13.9 million and $13.1 million, respectively.

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
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 consolidated 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, 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 condensed financial statements.

XML

Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2019

Related Party Transaction [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

New accounting pronouncements adopted in 2019 – The following table provides a brief description of recently adopted accounting pronouncements that had an impact on our consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 consolidated 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 consolidated 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 consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 condensed consolidated financial statements.

Schedule of Cash and Cash Equivalents [Table Text Block]

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

$ in millions	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	70.8	$	90.5
Restricted cash	42.0		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	112.8	$	111.7

Schedule of New Accounting Pronouncements

– The following table provides a brief description of recently adopted accounting pronouncements that had an impact on our consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 consolidated 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 consolidated 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 consolidated 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 consolidated financial statements.

ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
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 condensed consolidated financial statements.

THE DAYTON POWER AND LIGHT COMPANY [Member]

Related Party Transaction [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

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
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 consolidated 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, 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 condensed financial statements.

Schedule of Cash and Cash Equivalents [Table Text Block]

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	March 31, 2019		December 31, 2018
Cash and cash equivalents	$	18.8	$	45.0
Restricted cash	42.0		21.2
Cash, Cash Equivalents, and Restricted Cash, End of Period	$	60.8	$	66.2

XML

Supplemental Financial Information (Tables)

3 Months Ended

Mar. 31, 2019

Supplemental Financial Information [Line Items]

Schedule of Supplemental Financial Information

Accounts receivable and Inventories are as follows at March 31, 2019 and December 31, 2018:

	March 31,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	60.5		$	55.8
Unbilled revenue	15.7			16.8
Amounts due from affiliates	0.7			—
Due from PJM transmission enhancement settlement	9.8			16.5
Other	1.6			2.3
Provision for uncollectible accounts	(0.6		)	(0.9		)
Total accounts receivable, net	$	87.7		$	90.5
Inventories, at average cost:
Fuel and limestone	$	3.5		$	1.9
Materials and supplies	8.4			8.3
Other	—			0.5
Total inventories, at average cost	$	11.9		$	10.7

Reclassification out of Accumulated Other Comprehensive Income

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three months ended March 31, 2019 and 2018 are as follows:

Details about Accumulated Other Comprehensive Income / (Loss) components	Affected line item in the Condensed Consolidated Statements of Operations	Three months ended March 31,
$ in millions		2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	(0.3	)	$	(1.0	)
	Income tax expense	0.1			0.6
	Net of income taxes	(0.2		)	(0.4		)
	Loss from discontinued operations	—			4.1
	Income tax benefit from discontinued operations	—			(1.4		)
	Net of income taxes	—			2.7
Amortization of defined benefit pension items (Note 8):
	Other expense	0.1			0.2
	Income tax benefit	—			(0.1		)
	Net of income taxes	0.1			0.1
Total reclassifications for the period, net of income taxes		$	(0.1	)	$	2.4

Schedule of Accumulated Other Comprehensive Income (Loss)

Accumulated Other Comprehensive Income / (Loss) during the three months endedMarch 31, 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	$	17.0		$	(14.8	)	$	2.2
Other comprehensive loss before reclassifications	(0.3		)	—			(0.3		)
Amounts reclassified from AOCI to earnings	(0.2		)	0.1			(0.1		)
Net current period other comprehensive income / (loss)	(0.5		)	0.1			(0.4		)
Balance at March 31, 2019	$	16.5		$	(14.7	)	$	1.8

THE DAYTON POWER AND LIGHT COMPANY [Member]

Supplemental Financial Information [Line Items]

Schedule of Supplemental Financial Information

Accounts receivable and Inventories are as follows at March 31, 2019 and December 31, 2018:

	March 31,			December 31,
$ in millions	2019			2018
Accounts receivable, net:
Customer receivables	$	58.0		$	53.3
Unbilled revenue	15.7			16.8
Amounts due from affiliates	3.9			2.3
Due from PJM transmission enhancement settlement	9.8			16.5
Other	1.6			2.4
Provision for uncollectible accounts	(0.6		)	(0.9		)
Total accounts receivable, net	$	88.4		$	90.4
Inventories, at average cost:
Materials and supplies	$	8.1		$	7.1
Other	—			0.6
Total inventories, at average cost	$	8.1		$	7.7

Reclassification out of Accumulated Other Comprehensive Income

The amounts reclassified out of Accumulated Other Comprehensive Income / (Loss) by component during the three months ended March 31, 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 March 31,
$ in millions		2019			2018
Gains and losses on cash flow hedges (Note 5):
	Interest expense	$	(0.1	)	$	(0.8	)
	Income tax expense	—			0.5
	Net of income taxes	(0.1		)	(0.3		)
Amortization of defined benefit pension items (Note 8):
	Other expense	0.9			1.1
	Income tax benefit	(0.2		)	(0.2		)
	Net of income taxes	0.7			0.9
Total reclassifications for the period, net of income taxes		$	0.6		$	0.6

Schedule of Accumulated Other Comprehensive Income (Loss)

The changes in the components of Accumulated Other Comprehensive Income / (Loss) during the three months ended March 31, 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	(0.2		)	—			(0.2		)
Amounts reclassified from AOCI to earnings	(0.1		)	0.7			0.6
Net current period other comprehensive income / (loss)	(0.3		)	0.7			0.4
Balance at March 31, 2019	$	0.3		$	(35.2	)	$	(34.9	)

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Fair Value (Tables)

3 Months Ended

Mar. 31, 2019

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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 March 31, 2019 and December 31, 2018. Information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	March 31, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.1	$	0.1	$	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	$	6.7	$	8.3	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	1,475.7	$	1,544.9	$	1,475.9	$	1,519.6

Fair Value of Assets and Liabilities Measured on Recurring Basis

The fair value of assets and liabilities at March 31, 2019 and December 31, 2018 and the respective category within the fair value hierarchy for DPL is as follows:

$ in millions	Fair value at March 31, 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	$	0.1	$	—	$	—	$	0.1	$	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	0.1		8.2		—		8.3		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		1.1		—		1.1		—		1.5		—		1.5
Total Derivative assets	—		1.1		—		1.1		—		1.5		—		1.5
Total Assets	$	0.1	$	9.3	$	—	$	9.4	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	1,527.3	$	17.6	$	1,544.9	$	—	$	1,501.9	$	17.7	$	1,519.6
Total Liabilities	$	—	$	1,527.3	$	17.6	$	1,544.9	$	—	$	1,501.9	$	17.7	$	1,519.6

(a) Includes credit valuation adjustment

THE DAYTON POWER AND LIGHT COMPANY [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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 March 31, 2019 and December 31, 2018. Information about the fair value of our derivative instruments can be found in Note 5 – Derivative Instruments and Hedging Activities.

	March 31, 2019				December 31, 2018
$ in millions	Cost		Fair Value		Cost		Fair Value
Assets
Money market funds	$	0.1	$	0.1	$	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	$	6.7	$	8.3	$	7.1	$	8.1
	Carrying Value		Fair Value		Carrying Value		Fair Value
Liabilities
Long-term debt	$	585.5	$	592.6	$	586.1	$	593.8

Fair Value of Assets and Liabilities Measured on Recurring Basis

The fair value of assets and liabilities at March 31, 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 March 31, 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	$	0.1	$	—	$	—	$	0.1	$	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	0.1		8.2		—		8.3		0.4		7.7		—		8.1
Derivative assets
Interest rate hedges	—		1.1		—		1.1		—		1.5		—		1.5
Total derivative assets	—		1.1		—		1.1		—		1.5		—		1.5
Total assets	$	0.1	$	9.3	$	—	$	9.4	$	0.4	$	9.2	$	—	$	9.6
Liabilities
Long-term debt	$	—	$	575.0	$	17.6	592.6		$	—	$	576.1	$	17.7	$	593.8
Total liabilities	$	—	$	575.0	$	17.6	$	592.6	$	—	$	576.1	$	17.7	$	593.8

(a) Includes credit valuation adjustment

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Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosures [Line Items]

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 months ended March 31, 2019 and 2018:

	Three months ended					Three months ended
	March 31, 2019					March 31, 2018
			Interest						Interest
$ in millions (net of tax)	Power		Rate Hedge			Power			Rate Hedge
Beginning accumulated derivative gains / (losses) in AOCI	$	0.4	$	16.6		$	(2.8	)	$	17.5
Net gains / (losses) associated with current period hedging transactions	—		(0.3		)	—			0.9
Net gains / (losses) reclassified to earnings
Interest expense	—		(0.2		)	—			(0.4		)
Income / (loss) from discontinued operations	—		—			2.7			—
Ending accumulated derivative gains / (losses) in AOCI	$	0.4	$	16.1		$	(0.1	)	$	18.0
Portion expected to be reclassified to earnings in the next twelve months			$	(0.8	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)			17

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

Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location

DPL 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 DPL's interest rate swaps are as follows:

Fair Values of Derivative Instruments
at March 31, 2019
				Gross Amounts Not Offset in the Condensed Consolidated Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Consolidated Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Other prepayments and current assets)
Interest rate swap	Designated	$	0.8	$	—	$	—	$	0.8
Long-term derivative positions (presented in Other deferred assets)
Interest rate swap	Designated	0.3		—		—		0.3
Total assets		$	1.1	$	—	$	—	$	1.1

(a) Includes credit valuation adjustment.

Fair Values of Derivative Instruments
at December 31, 2018
				Gross Amounts Not Offset in the Condensed Consolidated Balance Sheets
$ in millions	Hedging Designation	Gross Fair Value as presented in the Condensed Consolidated Balance Sheets (a)		Financial Instruments with Same Counterparty in Offsetting Position		Cash Collateral		Net Fair Value
Assets
Short-term derivative positions (presented in Other prepayments and current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other deferred assets)
Interest rate swaps	Designated	0.6		—		—		0.6
Total assets		$	1.5	$	—	$	—	$	1.5

(a) Includes credit valuation adjustment.

THE DAYTON POWER AND LIGHT COMPANY [Member]

Derivative Instruments and Hedging Activities Disclosures [Line Items]

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 months ended March 31, 2019 and 2018:

	Three months ended
	March 31, 2019			March 31, 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	(0.2		)	0.5
Net losses reclassified to earnings
Interest expense	(0.1		)	(0.3		)
Ending accumulated derivative gains in AOCI	$	0.3		$	1.6
Portion expected to be reclassified to earnings in the next twelve months	$	(0.8	)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	17

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 March 31, 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 Other prepayments and current assets)
Interest rate swap	Designated	$	0.8	$	—	$	—	$	0.8
Long-term derivative positions (presented in Other deferred assets)
Interest rate swap	Designated	0.3		—		—		0.3
Total assets		$	1.1	$	—	$	—	$	1.1

(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 Other prepayments and current assets)
Interest rate swaps	Designated	$	0.9	$	—	$	—	$	0.9
Long-term derivative positions (presented in Other deferred assets)
Interest rate swaps	Designated	0.6		—		—		0.6
Total assets		$	1.5	$	—	$	—	$	1.5

(a) Includes credit valuation adjustment.

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Debt (Tables)

3 Months Ended

Mar. 31, 2019

Debt Instrument [Line Items]

Long-term Debt

The following table summarizes DPL's outstanding long-term debt.

	Interest		March 31,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	435.0		$	436.1
Tax-exempt First Mortgage Bonds - rates from 3.05% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.2%	2061	17.6			17.7
Unamortized deferred financing costs			(5.8		)	(6.3		)
Unamortized debt discounts and premiums, net			(1.3		)	(1.4		)
Total long-term debt at consolidated subsidiary			585.5			586.1
Senior unsecured notes	6.75%	2019	99.0			99.0
Senior unsecured notes	7.25%	2021	780.0			780.0
Note to DPL Capital Trust II (c)	8.125%	2031	15.6			15.6
Unamortized deferred financing costs			(3.9		)	(4.3		)
Unamortized debt discounts and premiums, net			(0.5		)	(0.5		)
Total long-term debt			1,475.7			1,475.9
Less: current portion			(103.6		)	(103.6		)
Long-term debt, net of current portion			$	1,372.1		$	1,372.3

(a) Range of interest rates for the three months endedMarch 31, 2019.

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

(c) Note payable to related party.

THE DAYTON POWER AND LIGHT COMPANY [Member]

Debt Instrument [Line Items]

Long-term Debt

The following table summarizes DP&L's outstanding long-term debt.

	Interest		March 31,			December 31,
$ in millions	Rate	Maturity	2019			2018
Term loan - rates from 4.50% - 4.53% (a) and 4.01% - 4.60% (b)		2022	$	435.0		$	436.1
Tax-exempt First Mortgage Bonds - rates from 3.05% - 3.07% (a) and 1.52% - 1.92% (b)		2020	140.0			140.0
U.S. Government note	4.2%	2061	17.6			17.7
Unamortized deferred financing costs			(5.8		)	(6.3		)
Unamortized debt discounts and premiums, net			(1.3		)	(1.4		)
Total long-term debt			585.5			586.1
Less: current portion			(4.6		)	(4.6		)
Long-term debt, net of current portion			$	580.9		$	581.5

(a) Range of interest rates for the three months ended March 31, 2019.

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

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2019

Entity Information [Line Items]

Schedule of Effective Income Tax Rates

The following table details the effective tax rates for the three months ended March 31, 2019 and 2018.

	Three months ended
	March 31,
	2019	2018
DPL	14.1%	8.0%

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Schedule of Effective Income Tax Rates

The following table details the effective tax rates for the three months ended March 31, 2019 and 2018.

	Three months ended
	March 31,
	2019	2018
DP&L	17.4%	18.7%

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Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2019

Entity Information [Line Items]

Schedule of Net Periodic Benefit Cost / (Income)

The net periodic benefit cost of the pension benefit plans for the three months ended March 31, 2019 and 2018 was:

	Three months ended
	March 31,
$ in millions	2019			2018
Service cost	$	0.9		$	1.5
Interest cost	3.7			3.4
Expected return on plan assets	(5.0		)	(5.2		)
Amortization of unrecognized:
Prior service cost	0.3			0.2
Actuarial loss	1.1			1.6
Net periodic benefit cost	$	1.0		$	1.5

THE DAYTON POWER AND LIGHT COMPANY [Member]

Entity Information [Line Items]

Schedule of Net Periodic Benefit Cost / (Income)

The net periodic benefit cost of the pension benefit plans for the three months ended March 31, 2019 and 2018 was:

	Three months ended
	March 31,
$ in millions	2019			2018
Service cost	$	0.9		$	1.5
Interest cost	3.7			3.4
Expected return on plan assets	(5.0		)	(5.2		)
Amortization of unrecognized:
Prior service cost	0.5			0.4
Actuarial loss	1.7			2.3
Net periodic benefit cost	$	1.8		$	2.4

XML

Business Segments (Tables)

3 Months Ended

Mar. 31, 2019

Segment Reporting Information [Line Items]

Financial Reporting for Reportable Business Segments

The following tables present financial information for DPL’s Utility reportable business segment:

$ in millions	Utility		Other (a)			Adjustments and Eliminations			DPL Consolidated
Three months ended March 31, 2019
Revenues from external customers	$	201.1	$	7.9		$	—		$	209.0
Intersegment revenues	0.3		0.8			(1.1		)	—
Total revenues	$	201.4	$	8.7		$	(1.1	)	$	209.0
Depreciation and amortization	$	18.0	$	0.4		$	—		$	18.4
Interest expense	$	7.1	$	16.6		$	—		$	23.7
Income / (loss) from continuing operations before income tax	$	35.1	$	(15.9	)	$	—		$	19.2
Cash capital expenditures	$	33.7	$	0.6		$	—		$	34.3
At March 31, 2019
Total assets	$	1,792.9	$	607.9		$	(535.1	)	$	1,865.7
$ in millions	Utility		Other (a)			Adjustments and Eliminations			DPL Consolidated
Three months ended March 31, 2018
Revenues from external customers	$	195.8	$	11.6		$	—		$	207.4
Intersegment revenues	0.2		0.6			(0.8		)	—
Total revenues	$	196.0	$	12.2		$	(0.8	)	$	207.4
Depreciation and amortization	$	18.6	$	0.2		$	—		$	18.8
Interest expense	$	8.2	$	19.6		$	—		$	27.8
Income / (loss) from continuing operations before income tax	$	19.3	$	(16.8	)	$	—		$	2.5
Cash capital expenditures	$	24.6	$	2.7		$	—		$	27.3
At December 31, 2018
Total assets	$	1,819.6	$	545.9		$	(482.4	)	$	1,883.1

(a) "Other" includes Cash capital expenditures and Total assets related to the assets of discontinued operations and held-for-sale businesses for all periods presented.

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Revenue (Tables)

3 Months Ended

Mar. 31, 2019

Disaggregation of Revenue [Table Text Block]

DPL's revenue from contracts with customers was $208.3 million and $198.2 million for the three months ended March 31, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue by segment for the three months ended March 31, 2019 and 2018:

$ in millions	Utility		Other		Adjustments and Eliminations			Total
	Three months ended March 31, 2019
Retail Revenue
Retail revenue from contracts with customers	$	182.7	$	—	$	(0.3	)	$	182.4
Other retail revenues (a)	0.7		—		—			0.7
Wholesale Revenue
Wholesale revenue from contracts with customers	5.0		3.4		—			8.4
RTO revenue	10.9		—		—			10.9
RTO capacity revenues	2.1		1.6		—			3.7
Other revenues from contracts with customers (b)	—		2.9		—			2.9
Other revenues	—		0.8		(0.8		)	—
Total revenues	$	201.4	$	8.7	$	(1.1	)	$	209.0
	Three months ended March 31, 2018
Retail Revenue
Retail revenue from contracts with customers	$	161.2	$	—	$	(0.2	)	$	161.0
Other retail revenues (a)	9.2		—		—			9.2
Wholesale Revenue
Wholesale revenue from contracts with customers	12.6		7.7		—			20.3
RTO revenue	11.1		0.1		—			11.2
RTO capacity revenues	1.9		1.4		—			3.3
Other revenues from contracts with customers (b)	—		2.4		—			2.4
Other revenues	—		0.6		(0.6		)	—
Total revenues	$	196.0	$	12.2	$	(0.8	)	$	207.4

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606. Accounts receivable balances associated with these revenues were $1.5 million at March 31, 2019, and there were no balances at December 31, 2018.

(b) Other revenues from contracts with customers primarily includes revenues for various services provided by Miami Valley Lighting.

Subsidiaries [Member]

Disaggregation of Revenue [Table Text Block]

DP&L's revenue from contracts with customers was $200.7 million and $186.8 million for the three months ended March 31, 2019 and 2018, respectively. The following table presents our revenue from contracts with customers and other revenue for the three months ended March 31, 2019 and 2018:

	Three months ended
$ in millions	March 31, 2019		March 31, 2018
Retail Revenue
Retail revenue from contracts with customers	$	182.7	$	161.2
Other retail revenues (a)	0.7		9.2
Wholesale Revenue
Wholesale revenue from contracts with customers	5.0		12.6
RTO revenue	10.9		11.1
RTO capacity revenues	2.1		1.9
Total revenues	$	201.4	$	196.0

(a) Other retail revenue primarily includes alternative revenue programs not accounted for under FASC 606. Accounts receivable balances associated with these revenues were $1.5 million at March 31, 2019, and there were no balances at December 31, 2018.

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Discontinued Operations (Tables)

3 Months Ended

Mar. 31, 2019

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Disposal Groups, Including Discontinued Operations [Table Text Block]

The following table summarizes the major categories of assets and liabilities at the dates indicated:

$ in millions	March 31, 2019			December 31, 2018
Accounts receivable, net	$	3.3		$	4.0
Taxes applicable to subsequent years	1.7			2.3
Other prepayments and current assets	1.5			2.4
Intangible assets, net	5.3			5.3
Total assets of the disposal group classified as assets of discontinued operations and held-for-sale businesses in the balance sheets	$	11.8		$	14.0
Accounts payable	$	2.9		$	3.9
Accrued taxes	2.4			3.1
Other current liabilities	3.7			5.2
Deferred taxes (a)	(33.8		)	(39.8		)
Taxes payable	1.1			2.3
Pension, retiree and other benefits	9.6			9.7
Asset retirement obligations	68.9			90.4
Other deferred credits	6.7			6.6
Total liabilities of the disposal group classified as liabilities of discontinued operations and held-for-sale businesses in the balance sheets	$	61.5		$	81.4

(a) Deferred taxes represent the tax asset position of the discontinued group of components, which were netted with liabilities on DPL prior to classification as discontinued operations.

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

	Three months ended
	March 31,
$ in millions	2019			2018
Revenues	$	16.3		$	85.8
Cost of revenues	(6.6		)	(41.1		)
Operating and other expenses	20.1			(24.7		)
Income from discontinued operations	29.8			20.0
Gain / (loss) from disposal of discontinued operations	0.1			(1.9		)
Income tax expense from discontinued operations	4.3			3.5
Net income from discontinued operations	$	25.6		$	14.6

XML

Summary of Significant Accounting Policies (Narrative) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) mi² employee segment generating_facility customer	Mar. 31, 2018 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)
Significant Accounting Policies [Line Items]
Number of reportable segments | segment	1
Cash and Cash Equivalents, at Carrying Value	$ 70.8		$ 90.5
Entity number of employees | employee	629
Employees under a collective bargaining agreement which expires in October-2011	58.00%
Excise taxes collected	$ 13.9	$ 13.1
Restricted Cash and Cash Equivalents, Current	42.0		21.2
Restricted Cash and Cash Equivalents	112.8	148.5	111.7	$ 24.9
Public Utilities, Property, Plant and Equipment, Generation or Processing	$ 0.0
THE DAYTON POWER AND LIGHT COMPANY [Member]
Significant Accounting Policies [Line Items]
Number of reportable segments | segment	1
Cash and Cash Equivalents, at Carrying Value	$ 18.8		45.0
Approximate number of retail customers | customer	526,000
Service area, square miles | mi²	6,000
Number of Operating Segments | segment	1
Entity number of employees | employee	617
Employees under a collective bargaining agreement which expires in October-2011	59.00%
Number Of Generating Facilities | generating_facility	1
Excise taxes collected	$ 13.9	13.1
Restricted Cash and Cash Equivalents, Current	42.0		21.2
Restricted Cash and Cash Equivalents	60.8	1.9	$ 66.2	$ 5.6
Adjustments for New Accounting Pronouncement [Member]
Significant Accounting Policies [Line Items]
AOCI reclassed to Retained Earnings before tax		1.6
AOCI reclassed to Retained Earnings, net of tax		1.0
Adjustments for New Accounting Pronouncement [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Significant Accounting Policies [Line Items]
AOCI reclassed to Retained Earnings before tax	1.7	1.7
AOCI reclassed to Retained Earnings, net of tax	$ 1.1	1.1
Non-service Pension Costs		1.2
Increase (Decrease) in Restricted Cash		$ 27.0

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Supplemental Financial Information (Supplemental Financial Information) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Supplemental Financial Information [Line Items]
Gain (Loss) on Disposition of Business	$ 0.0	$ (11.7)
Gain (Loss) on Sale of Assets and Asset Impairment Charges	0.9	0.6
Unbilled Revenue	15.7		$ 16.8
Customer receivables	60.5		55.8
Due from PJM transmission settlement	9.8		16.5
Amounts due from partners in jointly owned stations	0.7		0.0
Other	1.6		2.3
Provision for uncollectible accounts	(0.6)		(0.9)
Total accounts receivable, net	87.7		90.5
Fuel and limestone	3.5		1.9
Plant materials and supplies	8.4		8.3
Other	0.0		0.5
Total inventories, at average cost	11.9		10.7
THE DAYTON POWER AND LIGHT COMPANY [Member]
Supplemental Financial Information [Line Items]
Gain (Loss) on Disposition of Business	0.0	$ (12.4)
Unbilled Revenue	15.7		16.8
Customer receivables	58.0		53.3
Due from PJM transmission settlement	9.8		16.5
Amounts due from partners in jointly owned stations	3.9		2.3
Other	1.6		2.4
Provision for uncollectible accounts	(0.6)		(0.9)
Total accounts receivable, net	88.4		90.4
Plant materials and supplies	8.1		7.1
Other	0.0		0.6
Total inventories, at average cost	$ 8.1		$ 7.7

XML

Supplemental Financial Information (Reclassification out of ACOI) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income	$ (22.3)	$ (28.4)
Tax expense	(2.7)	(0.2)
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	29.8	20.0
Discontinued Operation, Tax Effect of Discontinued Operation	(4.3)	(3.5)
Net income / (loss)	42.1	16.9
Interest expense	(23.7)	(27.8)
Operating Expenses	(89.8)	(86.0)
THE DAYTON POWER AND LIGHT COMPANY [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income	(6.5)	(9.5)
Tax expense	(6.1)	(3.6)
Net income / (loss)	29.0	15.7
Interest expense	(7.1)	(8.2)
Operating Expenses	(85.6)	(82.5)
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Net income / (loss)	(0.1)	2.4
Reclassification out of Accumulated Other Comprehensive Income [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Net income / (loss)	0.6	0.6
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Tax expense	0.1	0.6
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	0.0	4.1
Discontinued Operation, Tax Effect of Discontinued Operation	0.0	(1.4)
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax	0.0	2.7
Net income / (loss)	(0.2)	(0.4)
Interest expense	(0.3)	(1.0)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Tax expense	0.0	0.5
Net income / (loss)	(0.1)	(0.3)
Interest expense	(0.1)	(0.8)
Amortization of defined benefit pension items [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income	0.1	0.2
Tax expense	0.0	(0.1)
Net income / (loss)	0.1	0.1
Amortization of defined benefit pension items [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income	0.9	1.1
Tax expense	(0.2)	(0.2)
Net income / (loss)	$ 0.7	$ 0.9

XML

Supplemental Financial Information (Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	$ 2.2
Other comprehensive income before reclassifications	(0.3)
Amounts reclassified from AOCI to earnings	(0.1)
Other comprehensive income / (loss)	(0.4)
Balance, end of period	1.8
THE DAYTON POWER AND LIGHT COMPANY [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	(35.3)
Other comprehensive income before reclassifications	(0.2)
Amounts reclassified from AOCI to earnings	0.6
Other comprehensive income / (loss)	0.4	$ 1.1
Balance, end of period	(34.9)
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	17.0
Other comprehensive income before reclassifications	(0.3)
Amounts reclassified from AOCI to earnings	(0.2)
Other comprehensive income / (loss)	(0.5)
Balance, end of period	16.5
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	0.6
Other comprehensive income before reclassifications	(0.2)
Amounts reclassified from AOCI to earnings	(0.1)
Other comprehensive income / (loss)	(0.3)
Balance, end of period	0.3
Change in unfunded pension obligation [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	(14.8)
Other comprehensive income before reclassifications	0.0
Amounts reclassified from AOCI to earnings	0.1
Other comprehensive income / (loss)	0.1
Balance, end of period	(14.7)
Change in unfunded pension obligation [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance, beginning of period	(35.9)
Other comprehensive income before reclassifications	0.0
Amounts reclassified from AOCI to earnings	0.7
Other comprehensive income / (loss)	0.7
Balance, end of period	$ (35.2)

XML

Regulatory Matters (Details) - USD ($) $ in Millions	Mar. 01, 2019	Jan. 22, 2019	Jan. 01, 2018	Mar. 31, 2019	Dec. 31, 2018
Requested Distribution Modernization Rider annual revenue through filing		$ 199.0
Regulatory Assets, Noncurrent				$ 151.2	$ 152.6
Unbilled Revenue				15.7	16.8
Period for refund of eligible excess ADIT and any related regulatory liability as required by PUCO			10 years
Due from PJM transmission settlement				9.8	16.5
Refund of eligible excess ADIT and any related regulatory liability as required by the PUCO	$ 65.1
Subsidiaries [Member]
Requested Distribution Modernization Rider annual revenue through filing		$ 199.0
Regulatory Assets, Noncurrent				151.2	152.6
Unbilled Revenue				15.7	16.8
Period for refund of eligible excess ADIT and any related regulatory liability as required by PUCO			10 years
Due from PJM transmission settlement				$ 9.8	$ 16.5
Refund of eligible excess ADIT and any related regulatory liability as required by the PUCO	$ 65.1

XML

Fair Value (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Long-term debt, earliest maturities	2019
Long-term debt, latest maturities	2061
THE DAYTON POWER AND LIGHT COMPANY [Member]
Long-term debt, earliest maturities	2020
Long-term debt, latest maturities	2061
Adjustments for New Accounting Pronouncement [Member]
AOCI reclassed to Retained Earnings before tax		$ 1.6
AOCI reclassed to Retained Earnings, net of tax		1.0
Adjustments for New Accounting Pronouncement [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
AOCI reclassed to Retained Earnings before tax	$ 1.7	1.7
AOCI reclassed to Retained Earnings, net of tax	$ 1.1	$ 1.1

XML

Fair Value (Fair Value and Cost of Non-Derivative Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Cost [Member]
Total Assets	$ 6.7	$ 7.1
Cost [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Assets	6.7	7.1
Fair Value [Member]
Total Master Trust Assets, Fair Value	8.3	8.1
Total Assets	8.3	8.1
Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	8.3	8.1
Total Assets	8.3	8.1
Money Market Funds [Member] | Cost [Member]
Total Master Trust Assets, Cost	0.1	0.4
Money Market Funds [Member] | Cost [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Cost	0.1	0.4
Money Market Funds [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	0.1	0.4
Money Market Funds [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.4
Equity Securities [Member] | Cost [Member]
Total Master Trust Assets, Cost	2.3	2.4
Equity Securities [Member] | Cost [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Cost	2.3	2.4
Equity Securities [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	3.9	3.5
Equity Securities [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	3.9	3.5
Debt Securities [Member] | Cost [Member]
Total Master Trust Assets, Cost	4.1	4.1
Debt Securities [Member] | Cost [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Cost	4.1	4.1
Debt Securities [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	4.1	4.0
Debt Securities [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	4.1	4.0
Hedge Funds [Member] | Cost [Member]
Total Master Trust Assets, Cost	0.1	0.1
Hedge Funds [Member] | Cost [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Cost	0.1	0.1
Hedge Funds [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Hedge Funds [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Tangible Assets [Member] | Cost [Member]
Total Master Trust Assets, Cost	0.1	0.1
Tangible Assets [Member] | Cost [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Cost	0.1	0.1
Tangible Assets [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Tangible Assets [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Debt [Member] | Cost [Member]
Debt, Cost	1,475.7	1,475.9
Debt [Member] | Cost [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt, Cost	585.5	586.1
Debt [Member] | Fair Value [Member]
Debt, Fair Value	1,544.9	1,519.6
Debt [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt, Fair Value	$ 592.6	$ 593.8

XML

Fair Value (Fair Value of Assets and Liabilities Measured on Recurring Basis) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Asset Retirement Obligations, Noncurrent	$ 9.4	$ 9.4
Level 1 [Member]
Total Master Trust Assets, Fair Value	0.1	0.4
Total Derivative Assets	0.0	0.0
Total Assets	0.1	0.4
Total Liabilities	0.0	0.0
Level 1 [Member] | Interest Rate Contract [Member]
Total Derivative Assets	0.0	0.0
Level 1 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.4
Total Derivative Assets	0.0	0.0
Total Assets	0.1	0.4
Total Liabilities	0.0	0.0
Level 1 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Contract [Member]
Total Derivative Assets	0.0	0.0
Level 2 [Member]
Total Master Trust Assets, Fair Value	8.2	7.7
Total Derivative Assets	1.1	1.5
Total Assets	9.3	9.2
Total Liabilities	1,527.3	1,501.9
Level 2 [Member] | Interest Rate Contract [Member]
Total Derivative Assets	1.1	1.5
Level 2 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	8.2	7.7
Total Derivative Assets	1.1	1.5
Total Assets	9.3	9.2
Total Liabilities	575.0	576.1
Level 2 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Contract [Member]
Total Derivative Assets	1.1	1.5
Level 3 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Total Derivative Assets	0.0	0.0
Total Assets	0.0	0.0
Total Liabilities	17.6	17.7
Level 3 [Member] | Interest Rate Contract [Member]
Total Derivative Assets	0.0	0.0
Level 3 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Total Derivative Assets	0.0	0.0
Total Assets	0.0	0.0
Total Liabilities	17.6	17.7
Level 3 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Contract [Member]
Total Derivative Assets	0.0	0.0
Fair Value [Member]
Total Master Trust Assets, Fair Value	8.3	8.1
Total Derivative Assets	1.1	1.5
Total Assets	9.4	9.6
Total Liabilities	1,544.9	1,519.6
Fair Value [Member] | Interest Rate Contract [Member]
Total Derivative Assets	1.1	1.5
Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	8.3	8.1
Total Derivative Assets	1.1	1.5
Total Assets	9.4	9.6
Total Liabilities	592.6	593.8
Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Contract [Member]
Total Derivative Assets	1.1	1.5
Money Market Funds [Member] | Level 1 [Member]
Total Master Trust Assets, Fair Value	0.1	0.4
Money Market Funds [Member] | Level 1 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.4
Money Market Funds [Member] | Level 2 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Money Market Funds [Member] | Level 2 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Money Market Funds [Member] | Level 3 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Money Market Funds [Member] | Level 3 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Money Market Funds [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	0.1	0.4
Money Market Funds [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.4
Equity Securities [Member] | Level 1 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Equity Securities [Member] | Level 1 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Equity Securities [Member] | Level 2 [Member]
Total Master Trust Assets, Fair Value	3.9	3.5
Equity Securities [Member] | Level 2 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	3.9	3.5
Equity Securities [Member] | Level 3 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Equity Securities [Member] | Level 3 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Equity Securities [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	3.9	3.5
Equity Securities [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	3.9	3.5
Debt Securities [Member] | Level 1 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Debt Securities [Member] | Level 1 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Debt Securities [Member] | Level 2 [Member]
Total Master Trust Assets, Fair Value	4.1	4.0
Debt Securities [Member] | Level 2 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	4.1	4.0
Debt Securities [Member] | Level 3 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Debt Securities [Member] | Level 3 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Debt Securities [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	4.1	4.0
Debt Securities [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	4.1	4.0
Hedge Funds [Member] | Level 1 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Hedge Funds [Member] | Level 1 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Hedge Funds [Member] | Level 2 [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Hedge Funds [Member] | Level 2 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Hedge Funds [Member] | Level 3 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Hedge Funds [Member] | Level 3 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Hedge Funds [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Hedge Funds [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Tangible Assets [Member] | Level 1 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Tangible Assets [Member] | Level 1 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Tangible Assets [Member] | Level 2 [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Tangible Assets [Member] | Level 2 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Tangible Assets [Member] | Level 3 [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Tangible Assets [Member] | Level 3 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.0	0.0
Tangible Assets [Member] | Fair Value [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Tangible Assets [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Total Master Trust Assets, Fair Value	0.1	0.1
Debt [Member] | Level 1 [Member]
Debt	0.0	0.0
Debt [Member] | Level 1 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt	0.0	0.0
Debt [Member] | Level 2 [Member]
Debt	1,527.3	1,501.9
Debt [Member] | Level 2 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt	575.0	576.1
Debt [Member] | Level 3 [Member]
Debt	17.6	17.7
Debt [Member] | Level 3 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt	17.6	17.7
Debt [Member] | Fair Value [Member]
Debt	1,544.9	1,519.6
Debt [Member] | Fair Value [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt	$ 592.6	$ 593.8

XML

Fair Value Fair Value Measurements (Fair Value of Assets and Liabilities Measured on a Non-recurring Basis) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Property, Plant and Equipment, Net	$ 1,348.9	$ 1,337.0
Asset Retirement Obligations, Noncurrent	9.4	9.4
THE DAYTON POWER AND LIGHT COMPANY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset Retirement Obligation	4.7	4.7
Property, Plant and Equipment, Net	$ 1,329.9	$ 1,318.1

XML

Derivative Instruments and Hedging Activities (Narrative) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($)	Mar. 31, 2019 USD ($) Number_of_interest_rate_swaps	Mar. 29, 2018 USD ($)
Sale of Derivative Instruments Interest Rate Swap			$ 60.0
Gain on sale of Derivative Instruments Interest Rate Swap	$ 0.8
THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument, Number of Financial Covenants | Number_of_interest_rate_swaps		2
Sale of Derivative Instruments Interest Rate Swap			$ 60.0
Gain on sale of Derivative Instruments Interest Rate Swap	$ 0.8
One Point One Three To One Point One Seven Bonds Maturing In August Two Thousand Twenty [Member]
Long-term Debt, Gross		$ 140.0
One Point One Three To One Point One Seven Bonds Maturing In August Two Thousand Twenty [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Long-term Debt, Gross		140.0
Interest Rate Swap [Member] | Designated as Hedging Instrument [Member]
Derivative, Notional Amount, Purchase (Sales), Net		140.0
Interest Rate Swap [Member] | Designated as Hedging Instrument [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Derivative, Notional Amount, Purchase (Sales), Net		$ 140.0

XML

Derivative Instruments and Hedging Activities (Outstanding Derivative Instruments) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2019	Dec. 31, 2018	Mar. 29, 2018
Sale of Derivative Instruments Interest Rate Swap				$ (60.0)
Gain on sale of Derivative Instruments Interest Rate Swap	$ 0.8
THE DAYTON POWER AND LIGHT COMPANY [Member]
Sale of Derivative Instruments Interest Rate Swap				$ (60.0)
Gain on sale of Derivative Instruments Interest Rate Swap	$ 0.8
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]
Derivative, Notional Amount, Purchase (Sales), Net		$ 140.0
Designated as Hedging Instrument [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Swap [Member]
Derivative, Notional Amount, Purchase (Sales), Net		140.0
Derivative Financial Instruments, Assets [Member]
Derivative Asset, Fair Value, Gross Asset		1.1	$ 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		1.1	1.5
Derivative Financial Instruments, Assets [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Derivative Asset, Fair Value, Gross Asset		1.1	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		1.1	1.5
Cash Flow Hedging [Member] | Other Prepayments and Current Assets [Member] | Short-term Derivative Positions [Member] | Forward Contract Power [Member]
Derivative Asset, Fair Value, Gross Asset			0.9
Derivative, Collateral, Obligation to Return Securities			0.0
Derivative, Collateral, Obligation to Return Cash			0.0
Derivative Asset, Fair Value, Amount Offset Against Collateral			0.9
Cash Flow Hedging [Member] | Other Prepayments and Current Assets [Member] | Short-term Derivative Positions [Member] | Interest Rate Swap [Member]
Derivative Asset, Fair Value, Gross Asset		0.8
Derivative, Collateral, Obligation to Return Securities		0.0
Derivative, Collateral, Obligation to Return Cash		0.0
Derivative Asset, Fair Value, Amount Offset Against Collateral		0.8
Cash Flow Hedging [Member] | Other Prepayments and Current Assets [Member] | Short-term Derivative Positions [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Swap [Member]
Derivative Asset, Fair Value, Gross Asset		0.8	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		0.8	0.9
Cash Flow Hedging [Member] | Other Deferred Asset [Member] | Long-term Derivative Positions [Member] | Interest Rate Swap [Member]
Derivative Asset, Fair Value, Gross Asset		0.3	0.6
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		0.3	0.6
Cash Flow Hedging [Member] | Other Deferred Asset [Member] | Long-term Derivative Positions [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Swap [Member]
Derivative Asset, Fair Value, Gross Asset		0.3	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		$ 0.3	$ 0.6

XML

Derivative Instruments and Hedging Activities (Gains or Losses Recognized in AOCI for the Cash Flow Hedges) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Forward Contract Power [Member]
Accumulated Derivative Gain/Loss in AOCI [Roll Forward]
Beginning accumulated derivative gain / (loss) in AOCI	$ 0.4	$ (2.8)
Net gains / (losses) associated with current period hedging transactions	0.0	0.0
Ending accumulated derivative gain / (loss) in AOCI	0.4	(0.1)
Portion expected to be reclassified to earnings in the next twelve months
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)
Interest Rate Contract [Member]
Accumulated Derivative Gain/Loss in AOCI [Roll Forward]
Beginning accumulated derivative gain / (loss) in AOCI	$ 16.6	17.5
Net gains / (losses) associated with current period hedging transactions	(0.3)	0.9
Ending accumulated derivative gain / (loss) in AOCI	16.1	18.0
Portion expected to be reclassified to earnings in the next twelve months	$ (0.8)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	17 months
THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Contract [Member]
Accumulated Derivative Gain/Loss in AOCI [Roll Forward]
Beginning accumulated derivative gain / (loss) in AOCI	$ 0.6	1.4
Net gains / (losses) associated with current period hedging transactions	(0.2)	0.5
Ending accumulated derivative gain / (loss) in AOCI	0.3	1.6
Portion expected to be reclassified to earnings in the next twelve months	$ (0.8)
Maximum length of time that we are hedging our exposure to variability in future cash flows related to forecasted transactions (in months)	17 months
Interest Expense [Member] | Forward Contract Power [Member]
Accumulated Derivative Gain/Loss in AOCI [Roll Forward]
Net gains losses reclassified to earnings	$ 0.0	0.0
Interest Expense [Member] | Interest Rate Contract [Member]
Accumulated Derivative Gain/Loss in AOCI [Roll Forward]
Net gains losses reclassified to earnings	(0.2)	(0.4)
Interest Expense [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member] | Interest Rate Contract [Member]
Accumulated Derivative Gain/Loss in AOCI [Roll Forward]
Net gains losses reclassified to earnings	(0.1)	(0.3)
Discontinued Operations, Disposed of by Means Other than Sale, Spinoff [Member] | Forward Contract Power [Member]
Accumulated Derivative Gain/Loss in AOCI [Roll Forward]
Net gains losses reclassified to earnings	0.0	2.7
Discontinued Operations, Disposed of by Means Other than Sale, Spinoff [Member] | Interest Rate Contract [Member]
Accumulated Derivative Gain/Loss in AOCI [Roll Forward]
Net gains losses reclassified to earnings	$ 0.0	$ 0.0

XML

Derivative Instruments and Hedging Activities (Fair Value and Balance Sheet Location (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Total Assets [Member]
Derivative Asset, Fair Value	$ 1.1	$ 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	1.1	1.5
Total Assets [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Derivative Asset, Fair Value	1.1	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	1.1	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	0.8
Derivative, Collateral, Obligation to Return Securities	0.0
Derivative, Collateral, Obligation to Return Cash	0.0
Derivative Asset, Fair Value, Amount Offset Against Collateral	0.8
Cash Flow Hedging [Member] | Interest Rate Swap [Member] | Short-term Derivative Positions [Member] | Other Prepayments and Current Assets [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Derivative Asset, Fair Value	0.8	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	0.8	0.9
Cash Flow Hedging [Member] | Interest Rate Swap [Member] | Long-term Derivative Positions [Member] | Other Deferred Asset [Member]
Derivative Asset, Fair Value	0.3	0.6
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	0.3	0.6
Cash Flow Hedging [Member] | Interest Rate Swap [Member] | Long-term Derivative Positions [Member] | Other Deferred Asset [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Derivative Asset, Fair Value	0.3	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	$ 0.3	$ 0.6

XML

Debt (Narrative) (Details) $ in Millions				3 Months Ended		6 Months Ended			12 Months Ended
	May 07, 2019 USD ($)	Apr. 17, 2019 USD ($)	Apr. 04, 2019 USD ($)	Mar. 31, 2019 USD ($) debt_covenant fiscal_quarter	Mar. 31, 2018 USD ($)	Dec. 31, 2019	Jun. 30, 2019	Jul. 03, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018 USD ($)	Sep. 30, 2018 USD ($)	Apr. 30, 2018 USD ($)	Mar. 30, 2018 USD ($)	Jan. 03, 2018	Aug. 03, 2015 USD ($)
Debt Instrument [Line Items]
Long-term Line of Credit				$ 0.0							$ 0.0
Retirement of long-term debt				$ 1.1	$ 131.1
Debt Covenant, Debt to EBITDA Ratio, Maximum											7.25
Debt to EBITDA Ratio				5.83
Long Term Indebtedness, Less than or Equal to												$ 750.0
Debt Covenant, Leverage Ratio, Maximum				0.67
Debt Covenant, Interest Coverage Ratio, Minimum				2.50							2.10
Leverage Ratio				1.40
Debt Covenant, Total Debt to Total Capitalization Ratio, Maximum				0.65								0.75
Interest Coverage Ratio				2.73
THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Line of Credit				$ 0.0							$ 0.0
Retirement of long-term debt				$ 1.1	$ 61.1
Long Term Indebtedness, Less than or Equal to												$ 750.0
Debt Covenant, Interest Coverage Ratio, Minimum				2.50
Debt Covenant, Total Debt to Total Capitalization Ratio, Maximum				0.65								0.75
Senior unsecured due in October 2019 - 6.75% [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount				$ 101.0
Long-term Debt, Gross				$ 99.0							99.0			$ 200.0
Make Whole Premium													$ 5.1
Debt instrument interest percentage				6.75%
Variable Rate Notes Backed by Term Loan and First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount				$ 60.0
Variable Rate Notes Backed by Term Loan and First Mortgage Bonds [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount				60.0
Long-term Debt, Gross				140.0							140.0
Debt Instrument, Face Amount																$ 200.0
Bank term loan due in July 2020 - rates from: 2.44% - 2.45% [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount				70.0
Term Loan Maturing 2022 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross				$ 435.0							436.1
Early prepayment rate								101.00%
Standard Repayment Rate				100.00%
Term Loan Maturing 2022 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross				$ 435.0							$ 436.1
Early prepayment rate								101.00%
Standard Repayment Rate				100.00%
Revolving Credit Agreement and Standby Letters of Credit [Member]
Debt Instrument [Line Items]
Number of financial covenants | debt_covenant				2
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
Number of prior quarters included in EBITDA to interest calculation | fiscal_quarter				4
Debt Covenant, Interest Coverage Ratio, Minimum				2.50
Interest Coverage Ratio				8.99
DPL Revolving Credit Agreement and Term Loan Maturing July 2020 [Member]
Debt Instrument [Line Items]
Number of financial covenants | debt_covenant				2
Number of prior quarters included in EBITDA to interest calculation | fiscal_quarter				4
Number of prior quarters included in debt to EBITDA ratio | fiscal_quarter				4
Base Rate Term Loan B [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage											2.25%				1.00%
Base Rate Term Loan B [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage											2.25%				1.00%
Eurodollar rate Term Loan B [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage											3.25%				2.00%
Eurodollar rate Term Loan B [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage											3.25%				2.00%
Ten Year Senior Unsecured Notes At725 Maturing At October152021 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross				$ 780.0							$ 780.0
Debt instrument interest percentage				7.25%
Subsequent Event [Member]
Debt Instrument [Line Items]
Debt Covenant, Debt to EBITDA Ratio, Maximum						6.75	7.00		6.50
Debt Covenant, Interest Coverage Ratio, Minimum										2.25
Scenario, Forecast [Member] | Senior unsecured due in October 2019 - 6.75% [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount			$ 99.0
Make Whole Premium			$ 1.5
Scenario, Forecast [Member] | Ten Year Senior Unsecured Bonds At435 Maturing At April152029 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt		$ 400.0
Debt instrument interest percentage		4.35%
Scenario, Forecast [Member] | Ten Year Senior Unsecured Notes At725 Maturing At October152021 [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount	$ 400.0
Long-term Debt, Gross	$ 380.0

XML

Debt (Long-term Debt) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Mar. 31, 2019	Jul. 03, 2018	May 07, 2019	Apr. 17, 2019	Dec. 31, 2018	Mar. 30, 2018
Debt Instrument [Line Items]
Unamortized deferred finance costs	$ (5.8)				$ (6.3)
Unamortized deferred finance costs	(3.9)				(4.3)
Unamortized long-term debt discounts and premiums, net	(0.5)				(0.5)
Total long-term debt at subsidiary	585.5				586.1
Total long-term debt	1,475.7				1,475.9
Less: current portion	(103.6)				(103.6)
Long-term debt	$ 1,372.1				1,372.3
Long-term debt, earliest maturities	2019
Long-term debt, latest maturities	2061
Long-term Line of Credit	$ 0.0				0.0
THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Unamortized deferred finance costs	(5.8)				(6.3)
Unamortized long-term debt discounts and premiums, net	(1.3)				(1.4)
Unamortized long-term debt discounts	(1.3)				(1.4)
Total long-term debt	585.5				586.1
Less: current portion	(4.6)				(4.6)
Long-term debt	$ 580.9				581.5
Long-term debt, earliest maturities	2020
Long-term debt, latest maturities	2061
Long-term Line of Credit	$ 0.0				0.0
Term Loan Maturing 2022 [Domain]
Debt Instrument [Line Items]
Debt instrument maturity year	Aug. 24, 2022
Term Loan Maturing 2022 [Domain] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument maturity year	Aug. 24, 2022
Term Loan Maturing 2022 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 435.0				436.1
Early prepayment rate		101.00%
Standard Repayment Rate	100.00%
Term Loan Maturing 2022 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 435.0				436.1
Early prepayment rate		101.00%
Standard Repayment Rate	100.00%
Pollution Control Series Maturing in August 2020 - 1.13% - 1.14% [Member]
Debt Instrument [Line Items]
Debt instrument maturity year	Aug. 01, 2020
Pollution Control Series Maturing in August 2020 - 1.13% - 1.14% [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 140.0				140.0
Debt instrument maturity year	Aug. 01, 2020
U.S. Government note maturing in February 2061 - 4.20% [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 17.6				17.7
Debt instrument maturity year	Feb. 01, 2061
Debt instrument interest percentage	4.20%
U.S. Government note maturing in February 2061 - 4.20% [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 17.6				17.7
Debt instrument maturity year	Feb. 01, 2061
Debt instrument interest percentage	4.20%
Senior unsecured due in October 2019 - 6.75% [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 99.0				99.0	$ 200.0
Debt instrument maturity year	Oct. 01, 2019
Debt instrument interest percentage	6.75%
Senior unsecured due in October 2021 - 7.25% [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 780.0				780.0
Debt instrument maturity year	Oct. 01, 2021
Debt instrument interest percentage	7.25%
Note to DPL Capital Trust II Maturing in September 2031 - 8.125% [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 15.6				$ 15.6
Debt instrument maturity year	Sep. 01, 2031
Debt instrument interest percentage	8.125%
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%
Maximum [Member] | Term Loan Maturing 2022 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage	4.53%
Debt Instrument, Interest Rate, Effective Percentage					4.60%
Maximum [Member] | Pollution Control Series Maturing in August 2020 - 1.13% - 1.14% [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage					1.92%
Maximum [Member] | Zero Point Two Three To Zero Point Two Nine And Zero Point One Six To Zero Point Three Six Percentage Of Bonds Maturing In November Two Thousand Forty [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage	3.07%
Maximum [Member] | Zero Point Two Three To Zero Point Two Nine And Zero Point One Six To Zero Point Three Six Percentage Of Bonds Maturing In November Two Thousand Forty [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage	3.07%				1.92%
Minimum [Member] | Term Loan Maturing 2022 [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage					4.01%
Debt Instrument, Interest Rate, Effective Percentage	4.50%
Minimum [Member] | Term Loan Maturing 2022 [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage					4.01%
Debt Instrument, Interest Rate, Effective Percentage	4.50%
Minimum [Member] | Pollution Control Series Maturing in August 2020 - 1.13% - 1.14% [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage					1.52%
Minimum [Member] | Zero Point Two Three To Zero Point Two Nine And Zero Point One Six To Zero Point Three Six Percentage Of Bonds Maturing In November Two Thousand Forty [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage	3.045%
Minimum [Member] | Zero Point Two Three To Zero Point Two Nine And Zero Point One Six To Zero Point Three Six Percentage Of Bonds Maturing In November Two Thousand Forty [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage	3.05%				1.52%
Scenario, Forecast [Member] | Ten Year Senior Unsecured Bonds At435 Maturing At April152029 [Member]
Debt Instrument [Line Items]
Debt instrument interest percentage				4.35%
Scenario, Forecast [Member] | Senior unsecured due in October 2021 - 7.25% [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 380.0

XML

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Entity Information [Line Items]
Effective income tax rates	14.10%	8.00%
Effective Income Tax Rate Reconciliation, at Combined Federal and State Statutory Income Tax Rate, Percent	21.60%
Estimated annual effective income tax rate	14.10%	19.20%
Non-cash capital contribution	$ 1.5	$ 44.6
THE DAYTON POWER AND LIGHT COMPANY [Member]
Entity Information [Line Items]
Effective income tax rates	17.40%	18.70%
Effective Income Tax Rate Reconciliation, at Combined Federal and State Statutory Income Tax Rate, Percent	21.60%
Estimated annual effective income tax rate	17.30%	19.80%

XML

Benefit Plans (Net Periodic Benefit Cost (Income)) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Pension [Member]
Contributions by employer	$ 7.5	$ 7.5
Service cost	0.9	1.5
Interest cost	3.7	3.4
Expected return on assets	(5.0)	(5.2)
Prior service cost	0.3	0.2
Actuarial loss / (gain)	1.1	1.6
Net periodic benefit cost	1.0	1.5
Postretirement [Member]
Defined Benefit Plan, Funded (Unfunded) Status of Plan	9.0		$ 9.2
THE DAYTON POWER AND LIGHT COMPANY [Member] | Pension [Member]
Contributions by employer	7.5	7.5
Service cost	0.9	1.5
Interest cost	3.7	3.4
Expected return on assets	(5.0)	(5.2)
Prior service cost	0.5	0.4
Actuarial loss / (gain)	1.7	2.3
Net periodic benefit cost	1.8	$ 2.4
THE DAYTON POWER AND LIGHT COMPANY [Member] | Postretirement [Member]
Defined Benefit Plan, Funded (Unfunded) Status of Plan	$ 9.0		$ 9.2

XML

Shareholder's Equity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Class of Stock [Line Items]
Non-cash capital contribution	$ 1.5	$ 44.6
Common Stock, Shares Authorized	1,500	1,500	1,500
Common stock, shares outstanding	1		1
THE DAYTON POWER AND LIGHT COMPANY [Member]
Class of Stock [Line Items]
Common Stock, Shares Authorized	50,000,000	50,000,000	50,000,000
Par value common shares (in USD per share)	$ 0.01	$ 0.01	$ 0.01
Common stock, shares outstanding	41,172,173		41,172,173
Proceeds from Contributions from Parent	$ 0.0	$ 80.0
Payments of Ordinary Dividends, Common Stock	$ 0.0	$ 23.8

XML

Contractual Obligations, Commercial Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Public Utility, Property, Plant and Equipment [Line Items]
Due to third parties, current	$ 0.0	$ 0.0
THE DAYTON POWER AND LIGHT COMPANY [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Debt maturity, earliest	2019
Debt maturity, latest	2040
AES Ohio Generation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Third party guarantees	$ 21.6
Debt Obligation on 4.9% Equity Ownership [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Equity ownership interest	4.90%
Equity ownership interest aggregate cost	$ 67.5
Electric Generation Company [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Debt obligation	$ 1,378.5
Other OVEC Member [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Equity ownership interest	4.90%
Other OVEC Member [Member] | THE DAYTON POWER AND LIGHT COMPANY [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Equity ownership interest	4.90%

XML

Business Segments (Narrative) (Details) - THE DAYTON POWER AND LIGHT COMPANY [Member]	3 Months Ended
	Mar. 31, 2019 mi² segment customer
Segment Reporting Information [Line Items]
Number of Operating Segments | segment	1
Approximate number of retail customers | customer	526,000
Service area, square miles | mi²	6,000

XML

Business Segments (Segment Financial Information) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Gain (Loss) on Disposition of Business	$ 0.0	$ (11.7)
External customer revenues	209.0	207.4
Intersegment revenues	0.0	0.0
Total revenues	209.0	207.4
Depreciation and amortization	18.4	18.8
Fuel Costs	3.5	4.5
Depreciation and amortization	(3.1)	20.1
Interest expense	23.7	27.8
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	19.2	2.5
Net income / (loss) from continuing operations	16.5	2.3
Discontinued operations, net of tax	25.6	14.6
Net income/ (loss)	42.1	16.9
Capital expenditures	34.3	27.3
Total assets	1,865.7		$ 1,883.1
Operating Segments [Member] | Utility [Member]
Segment Reporting Information [Line Items]
External customer revenues	201.1	195.8
Intersegment revenues	0.3	0.2
Total revenues	201.4	196.0
Depreciation and amortization	18.0	18.6
Interest expense	7.1	8.2
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	35.1	19.3
Capital expenditures	33.7	24.6
Total assets	1,792.9		1,819.6
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
External customer revenues	7.9	11.6
Intersegment revenues	0.8	0.6
Total revenues	8.7	12.2
Depreciation and amortization	0.4	0.2
Interest expense	16.6	19.6
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	(15.9)	(16.8)
Capital expenditures	0.6	2.7
Total assets	607.9		545.9
Adjustments and Eliminations [Member]
Segment Reporting Information [Line Items]
External customer revenues	0.0	0.0
Intersegment revenues	(1.1)	(0.8)
Total revenues	(1.1)	(0.8)
Depreciation and amortization	0.0	0.0
Interest expense	0.0	0.0
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	0.0	0.0
Capital expenditures	0.0	0.0
Total assets	(535.1)		(482.4)
Subsidiaries [Member]
Segment Reporting Information [Line Items]
Gain (Loss) on Disposition of Business	0.0	(12.4)
Depreciation and amortization	18.0	18.6
Fuel Costs	0.9	0.9
Depreciation and amortization	18.0	18.6
Interest expense	7.1	8.2
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	35.1	19.3
Net income/ (loss)	29.0	$ 15.7
Total assets	$ 1,792.9		$ 1,819.6

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Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Revenue from Contract with Customer, Excluding Assessed Tax	$ 208.3	$ 198.2
Alternative Revenue Programs Accounts Receivable, Gross	1.5		$ 0.0
RTO Revenue	10.9	11.2
RTO Capacity Revenue	3.7	3.3
Revenues	209.0	207.4
Contract with Customer, Asset, Gross	74.8		72.6
Corporate, Non-Segment [Member]
RTO Revenue	0.0	0.1
RTO Capacity Revenue	1.6	1.4
Revenues	8.7	12.2
Adjustments and Eliminations [Member]
RTO Revenue	0.0	0.0
RTO Capacity Revenue	0.0	0.0
Revenues	(1.1)	(0.8)
Utility [Member]
RTO Revenue	10.9	11.1
RTO Capacity Revenue	2.1	1.9
Revenues	201.4	196.0
Subsidiaries [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	200.7	186.8
Alternative Revenue Programs Accounts Receivable, Gross	1.5		0.0
RTO Revenue	10.9	11.1
RTO Capacity Revenue	2.1	1.9
Revenues	201.4	196.0
Contract with Customer, Asset, Gross	72.4		$ 70.1
Other Revenues [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2.9	2.4
Other non-606 revenue	0.0	0.0
Other Revenues [Member] | Corporate, Non-Segment [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2.9	2.4
Other non-606 revenue	0.8	0.6
Other Revenues [Member] | Adjustments and Eliminations [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0
Other non-606 revenue	(0.8)	(0.6)
Other Revenues [Member] | Utility [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0
Other non-606 revenue	0.0	0.0
Wholesale Revenue [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	8.4	20.3
Wholesale Revenue [Member] | Corporate, Non-Segment [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	3.4	7.7
Wholesale Revenue [Member] | Adjustments and Eliminations [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0
Wholesale Revenue [Member] | Utility [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5.0	12.6
Wholesale Revenue [Member] | Subsidiaries [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5.0	12.6
Retail Revenue [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	182.4	161.0
Other non-606 revenue	0.7	9.2
Retail Revenue [Member] | Corporate, Non-Segment [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0
Other non-606 revenue	0.0	0.0
Retail Revenue [Member] | Adjustments and Eliminations [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	(0.3)	(0.2)
Other non-606 revenue	0.0	0.0
Retail Revenue [Member] | Utility [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	182.7	161.2
Other non-606 revenue	0.7	9.2
Retail Revenue [Member] | Subsidiaries [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	182.7	161.2
Other non-606 revenue	$ 0.7	$ 9.2

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Dispositions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain (Loss) on Disposition of Business	$ 0.0	$ (11.7)
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	19.2	2.5
Property, Plant and Equipment, Additions	34.3	27.3
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		(11.7)
Property, Plant and Equipment, Additions		14.5
Subsidiaries [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain (Loss) on Disposition of Business	0.0	(12.4)
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest	$ 35.1	19.3
Subsidiaries [Member] | 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)
Property, Plant and Equipment, Additions		$ 14.5

XML

Discontinued Operations (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Sep. 30, 2018	Dec. 31, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax	$ 0.1	$ (1.9)
Long Term Indebtedness, Less than or Equal to			$ 750.0
Disposal Group, Including Discontinued Operation, Revenue	16.3	85.8
Disposal Group, Including Discontinued Operation, Accounts, Notes and Loans Receivable, Net	3.3			$ 4.0
Disposal Group, Including Discontinued Operations, Taxes Applicable to Subsequent Years	1.7			2.3
Disposal Group, Including Discontinued Operation, Other Assets, Current	1.5			2.4
Disposal Group, Including Discontinued Operation, Intangible Assets	5.3			5.3
Disposal Group, Including Discontinued Operation, Assets	11.8			14.0
Disposal Group, Including Discontinued Operation, Accounts Payable	2.9			3.9
Disposal Group, Including Discontinued Operation, Accrued Income Tax Payable	2.4			3.1
Disposal Group, Including Discontinued Operation, Other Liabilities, Current	3.7			5.2
Disposal Group, Including Discontinued Operation, Deferred Tax Liabilities	(33.8)			(39.8)
Disposal Group, Including Discontinued Operation, Taxes Payable	1.1			2.3
Disposal Group, Including Discontinued Operation, Pension Plan Benefit Obligation	9.6			9.7
Asset Retirement Obligation, Held for Sale	68.9			90.4
Disposal Group, Including Discontinued Operation, Other Liabilities, Noncurrent	6.7			6.6
Disposal Group, Including Discontinued Operation, Liabilities	61.5			$ 81.4
Disposal Group, Including Discontinued Operation, Costs of Goods Sold	(6.6)	(41.1)
Disposal Group, Including Discontinued Operation, Operating and Other Expenses	20.1	(24.7)
Disposal Group, Including Discontinued Operation, Asset Retirement Obligation, Revision of Estimate	22.5
Loss from discontinued operations before income taxes	29.8	20.0
Income tax expense / (benefit) from discontinued operations	4.3	3.5
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	25.6	14.6
Cash Provided by (Used in) Operating Activities, Discontinued Operations	8.1	9.0
Cash flows from investing activities for discontinued operations	$ 0.0	235.8
Subsidiaries [Member]
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
AES Ohio Generation peakers [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax		$ (1.9)