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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K10-K/A

(Amendment No. 1)

xANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 20092011

OR

oTRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from              to            

Each of the following classes or series of securities registered pursuant to Section 12 (b) of the Act is registered on the New York Stock Exchange:

Securities registered pursuant to Section 12(g) of the Act:  None

Indicate by check mark if each registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.

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.

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.

Indicate by check mark whether each registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).

Indicate by check mark whether each registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of each registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of each registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.

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

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

The aggregate market valueAll of the outstanding common stock of DPL Inc.’s common stock held is indirectly owned by non-affiliates of DPL Inc. as of June 30, 2009 was approximately $2.7 billion based on a closing sale price of $23.17 on that date as reported on the New York Stock Exchange.The AES Corporation.  All of the common stock of The Dayton Power and Light Company is owned by DPL Inc.

As of February 10, 2010,December 31, 2011, each registrant had the following shares of common stock outstanding:

Documents Incorporated by Reference:  None

This combined Form 10-K 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.

DOCUMENTS INCORPORATED BY REFERENCETHE REGISTRANTS MEET THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION I(1)(a) AND (b) OF FORM 10-K AND ARE THEREFORE FILING THIS FORM WITH THE REDUCED DISCLOSURE FORMAT.

Portions of DPL’s definitive proxy statement for its 2010 Annual Meeting of Shareholders are incorporated by reference in Part III of this Form 10-K.

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GLOSSARY OF TERMS

The following select abbreviations or acronyms are used in this Form 10-K:

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GLOSSARY OF TERMS (cont.)

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GLOSSARY OF TERMS (cont.)

Abbreviation or Acronym		Definition
RPM		Reliability Pricing Model
SB 221		Ohio Senate Bill 221, an Ohio electric energy bill that was signed by the Governor on May 1, 2008 and went into effect July 31, 2008. This law required all Ohio distribution utilities to file either an ESP or MRO to be in effect January 1, 2009. The law also contains, among other things, annual targets relating to advanced energy portfolio standards, renewable energy, demand reduction and energy efficiency standards.
SCR		Selective Catalytic Reduction
SEC		Securities and Exchange Commission
SECA		Seams Elimination Charge Adjustment
SERP		Supplemental Executive Retirement Plan
SFAS		Statement of Financial Accounting Standards
SO2		Sulfur Dioxide
SO3		Sulfur Trioxide
SSO		Standard Service Offer which represents the regulated rates, authorized by the PUCO, charged to retail customers within DP&L’s service territory.
Successor		DPL after its acquisition by AES.
TCRR		Transmission Cost Recovery Rider
USEPA		U.S. Environmental Protection Agency
USF		Universal Service Fund
VRDN		Variable Rate Demand Note

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PART I

Item 1 — Business

This report includes the combined filing of DPL and DP&L.  DP&Lis the principal.On November 28, 2011, DPL became a wholly-owned subsidiary of DPL providing approximately 98% of DPL’s total consolidated revenue and approximately 95% of DPL’s total consolidated asset base.AES, a global power company.  Throughout this report, the terms “we,” us,“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 clearly be noted in the section.

WEBSITE ACCESS TO REPORTSFORWARD LOOKING STATEMENTS

DPL and DP&L file current, annual and quarterly reports and other information required by the Securities Exchange Act of 1934, as amended, with the SEC.  You may read and copy any document we file at the SEC’s public reference room located at 100 F Street N.E., Washington, D.C. 20549, USA.  Please call the SEC at (800) SEC-0330 for further information on the public reference rooms.  Our SEC filings are also available to the public from the SEC’s website at http://www.sec.gov.

Our public internet site is http://www.dplinc.com.  We make available, free of charge, through our internet site, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and Forms 3, 4 and 5 filed on behalf of our directors and executive officers and amendments to those reports filed or furnished pursuant to the Securities Exchange Act of 1934, as amended, as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC.

In addition, our public internet site includes other items related to corporate governance matters, including, among other things, our governance guidelines, charters of various committees of the Board of Directors and our code of business conduct and ethics applicable to all employees, officers and directors.  You may obtain copies of these documents, free of charge, by sending a request, in writing, to DPL Investor Relations, 1065 Woodman Drive, Dayton, Ohio 45432.

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.  Please see page 38 for moreMatters 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, taking into account the information aboutcurrently 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 containedare 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: abnormal or severe weather and catastrophic weather-related damage; unusual maintenance or repair requirements; changes in fuel costs and purchased power, coal, environmental emissions, natural gas and other commodity prices; volatility and changes in markets for electricity and other energy-related commodities; performance of our suppliers; increased competition and deregulation in the electric utility industry; increased competition in the retail generation market; changes in interest rates; state, federal and foreign legislative and regulatory initiatives that affect cost and investment recovery, emission levels, rate structures or tax laws; changes in environmental laws and regulations to which DPL and its subsidiaries are subject; the development and operation of RTOs, including PJM to which DPL’s operating subsidiary (DP&L) has given control of its transmission functions; changes in our purchasing processes, pricing, delays, contractor and supplier performance and availability; significant delays associated with large construction projects; growth in our service territory and changes in demand and demographic patterns; changes in accounting rules and the effect of accounting pronouncements issued periodically by accounting standard-setting bodies; financial market conditions; the outcomes of litigation and regulatory investigations, proceedings or inquiries; general economic conditions; costs related to the Merger and the effects of any disruption from the Merger that may make it more difficult to maintain relationships with employees, customers, other business partners or government entities; 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.

COMPANY WEBSITES

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

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ORGANIZATION

DPL is a regional energy company organized in 1985 under the laws of Ohio.  Our executive offices are located at 1065 Woodman Drive, Dayton, Ohio 45432 –— telephone (937) 224-6000.DPL was acquired by The AES Corporation on November 28, 2011 and is a wholly-owned, indirect subsidiary of AES.

DPL’sDP&L principal subsidiary is DP&L.  DP&L is a public utility incorporated in 1911 under the laws of Ohio.  DP&L sells electricity to residential, commercial, industrial and governmental customers in a 6,000 square mile area of West Central Ohio.  Electricity for DP&L’s 24 county service area is primarily generated at eight coal-fired power plants and is distributed to more than 500,000 retail customers.  Principal industries served include automotive, food processing, paper, plastic, manufacturing and defense.  DP&L’s sales reflect the general economic conditions and seasonal weather patterns of the area.  DP&L sells any excess energy and capacity into the wholesale market.  DP&L also sells electricity to DPLER, an affiliate, to satisfy the electric requirements of its retail customers.

DPLER sells competitive retail electric service, under contract, to residential, commercial, industrial and governmental customers.  DPLER’s operations include those of its wholly-owned subsidiary, MC Squared, which was purchased on February 28, 2011.  DPLER has approximately 40,000 customers currently located throughout Ohio and Illinois.  DPLER does not have any transmission or generation assets and all of DPLER’s electric energy was purchased from DP&L or PJM to meet its sales obligations.

DPL’s other significant subsidiaries (all of which are wholly-owned) include: DPLE, which engages in the operation ofowns and operates peaking generating facilities and sells power infrom which it makes wholesale markets; DPLER, which sells retail electric energy under contract to major industrial and commercial customers in West Central Ohio;sales of electricity and MVIC, which is ourDPL’s captive insurance company that provides insurance services to us and ourDPL’s other subsidiaries.

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

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Transmission, AncillaryELECTRIC OPERATIONS AND FUEL SUPPLY

DPL’s present summer generating capacity, including peaking units, is approximately 3,818 MW.  Of this capacity, approximately 2,830 MW, or 74%, is derived from coal-fired steam generating stations and Other PJM-related Coststhe balance of approximately 988 MW, or 26%, consists of solar, combustion turbine and diesel peaking units.

DP&L’s present summer generating capacity, including peaking units, is approximately 3,262 MW.  Of this capacity, approximately 2,830 MW, or 87%, is derived from coal-fired steam generating stations and the balance of approximately 432 MW, or 13%, consists of solar, combustion turbine and diesel peaking units.

Our all-time net peak load was 3,270 MW, occurring August 8, 2007.

Approximately 87% of the existing steam generating capacity is provided by certain generating units owned as tenants in common with Duke Energy and CSP.  As tenants in common, each company owns a specified share of each of these units, is entitled to its share of capacity and energy output and has a capital and operating cost responsibility proportionate to its ownership share.  DP&L’s remaining steam generating capacity (approximately 365 MW) is derived from a generating station owned solely by DP&L.  Additionally, DP&L, Duke Energy and CSP own, as tenants in common, 880 circuit miles of 345,000-volt transmission lines.  DP&L has several interconnections with other companies for the purchase, sale and interchange of electricity.

In 2011, we generated 98.3% of our electric output from coal-fired units and 1.7% from solar, oil and natural gas-fired units.

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The following table sets forth DP&L’s and DPLE’s generating stations and, where indicated, those stations which DP&L owns as tenants in common.

*W = Wholly-Owned

C = Commonly-Owned

In addition to the above, DP&L also owns a 4.9% equity ownership interest in OVEC, an electric generating company.  OVEC has two plants located in Cheshire, Ohio and Madison, Indiana with a combined generation capacity of approximately 2,265 MW.  DP&L’s share of this generation capacity is approximately 111 MW.

We have substantially all of the total expected coal volume needed to meet our retail and firm wholesale sales requirements for 2012 under contract.  The majority of the contracted coal is purchased at fixed prices.  Some contracts provide for periodic adjustments and some are priced based on market indices.  Fuel costs are affected by changes in volume and price and are driven by a number of variables including weather, the wholesale market price of power, certain provisions in coal contracts related to government imposed costs, counterparty performance and credit, scheduled outages and generation plant mix.  Due to the installation of emission controls equipment at certain commonly owned units and barring any changes in the regulatory environment in which we operate, we expect to have a balanced SO2 and NOx position for 2012.

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The gross average cost of fuel consumed per kWh was as follows:

SEASONALITY

The power generation and delivery business is seasonal and weather patterns have a material effect on operating performance.  In the region we serve, demand for electricity is generally greater in the summer months associated with cooling and in the winter months associated with heating as compared to other times of the year.  Unusually mild summers and winters could have an adverse effect on our results of operations, financial condition and cash flows.

RATE REGULATION AND GOVERNMENT LEGISLATION

DP&L’s sales to SSO retail customers are subject to rate regulation by the PUCO.  DP&L’s transmission rates and wholesale electric rates to municipal corporations, rural electric co-operatives and other distributors of electric energy are subject to regulation by the FERC under the Federal Power Act.

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

Ohio legislation extends the jurisdiction of the PUCO to the records and accounts of certain public utility holding company systems, including DPL.  The legislation extends the PUCO’s supervisory powers to a holding company system’s general condition and capitalization, among other matters, to the extent that such matters relate to the costs associated with the provision of public utility service.  Based on existing PUCO and FERC authorization, regulatory assets and liabilities are recorded on the balance sheets.  See Note 4 of Notes to DPL’s Consolidated Financial Statements and Note 4 of Notes to DP&L’s Financial Statements.

COMPETITION AND REGULATION

Ohio Matters

Ohio Retail Rates

The PUCO maintains jurisdiction over DP&L’s delivery of electricity, SSO and other retail electric services.

On FebruaryMay 1, 2008, substitute SB 221, an Ohio electric energy bill, was signed by the Governor and went into effect July 31, 2008.  This law required that all Ohio distribution utilities file either an ESP or MRO to establish rates for SSO service.  Under the MRO, a periodic competitive bid process will set the retail generation price after the utility demonstrates that it can meet certain market criteria and bid requirements.  Also, under this option, utilities that still own generation in the state are required to phase-in the MRO over a period of not less than five years.  An ESP may allow for cost-based adjustments to the SSO for costs associated with environmental compliance; fuel and purchased power; construction of new or investment in specified generating facilities; and the provision of standby and default service, operating, maintenance, or other costs including taxes.  As part of its ESP, a utility is permitted to file an infrastructure improvement plan that will specify the initiatives the utility will take to rebuild, upgrade, or replace its electric distribution system, including cost recovery mechanisms.  Both the MRO and ESP option involve a “significantly excessive earnings test” based on the earnings of comparable companies with similar business and financial risks.  DP&L’s current SSO rates were established under an ESP that ends December 31, 2012.  DP&L is in the process of developing an SSO filing that will be the basis for rates effective January 1, 2013 using either an ESP or MRO case.  This case is scheduled to be filed on March 30, 2012.

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SB 221 and the implementation rules contain targets relating to advanced energy portfolio standards, renewable energy, demand reduction and energy efficiency standards.  If any targets are not met, compliance penalties will apply unless the PUCO makes certain findings that would excuse performance.  DP&L is currently meeting its renewable requirements and expects to remain in compliance.  The PUCO found that both DP&L and DPLER met the renewable targets in 2009, and the PUCO Staff recommended that the Commission find that they both met the renewable targets for 2010.

On May 19, 2010 the Commission approved in part and denied in part DP&L’s request that the PUCO find that it met the 2009 energy efficiency portfolio requirements and directed DP&L to file a measurement and verification plan as well as a market potential study.  We made this filing and settled the case through a stipulation that was approved in April 2011.  The next energy efficiency portfolio plan is due to be filed in April 2013.

We are unable to predict how the PUCO will respond to many of the filings discussed above, but believe that the outcome for the non-ESP/MRO filings will not be material to our financial condition or results of operations.  However, as the energy efficiency and alternative energy targets get increasingly larger over time, the costs of complying with SB 221 and the PUCO’s implementing rules or the results of our ESP/MRO filing on March 30, 2012 could have a material effect on our financial condition or results of operations.

The ESP Stipulation also provided for the establishment of a fuel and purchased power recovery rider beginning January 1, 2010.  The fuel rider fluctuates based on actual costs and recoveries and is modified at the start of each seasonal quarter: March 1, June 1, September 1 and December 1 each year.  As part of the PUCO approval process, an outside auditor was hired in 2011 to review fuel costs and the fuel procurement process for 2010.  DP&L and all of the active participants in this proceeding reached a Stipulation and Recommendation which was approved by the PUCO on November 9, 2011.  In November 2011, DP&L recorded a $25 million pretax ($16 million net of tax) adjustment as a result of the approval of the fuel settlement agreement by the PUCO.  The adjustment was due to the reversal of a provision recorded in accordance with the regulatory accounting rules.  An audit of 2011 fuel costs is currently ongoing.  The outcome of that audit is uncertain.

As a member of PJM, DP&L receives revenues from the RTO related to its transmission and generation assets and incurs costs associated with its load obligations for retail customers.  SB 221 included a provision that would allow Ohio electric utilities to seek and obtain a reconcilable rider to recover RTO-related costs and credits.  DP&L’s TCRR and PJM RPM riders were initially approved in November 2009 to recover these costs.  Both the TCRR and the RPM riders assign costs and revenues from PJM monthly bills to retail ratepayers based on the percentage of SSO retail customers’ load and sales volumes to total retail load and total retail and wholesale volumes.  Customer switching to CRES providers decreases DP&L’s SSO retail customers’ load and sales volumes.  Therefore, increases in customer switching cause more of the RPM capacity costs and revenues to be excluded from the RPM rider calculation.  RPM capacity costs and revenues are discussed further under “Regional Transmission Organizational Risks” in Item 1A — Risk Factors.  DP&L’s annual true-up of these two riders was approved by the PUCO by an order dated April 27, 2011 and its 2012 filing is still pending.

On September 9, 2009, the PUCO issued an order establishing a significantly excessive earnings test (SEET) proceeding pursuant to provisions contained in SB 221.  A question and answer session was held before the Commission on April 1, 2010 to allow the Commission to gain a better understanding of the issues.  The PUCO issued an order on June 30, 2010 to establish general rules for calculating the earnings and comparing them to a comparable group to determine whether there were significantly excessive earnings.  The other three Ohio utilities were required to make their SEET determinations in 2011 and 2010.  Pursuant to the ESP Stipulation, DP&L becomes subject to the SEET in 2013 based on 2012 earnings results and the SEET may have a material effect on operations.

On August 28, 2009, DP&L filed its application to establish reliability targets consistent with the most recent PUCO Electric Service and Safety Standards (ESSS).  On March 29, 2010, DP&L entered into a settlement establishing the new reliability targets.  This settlement was approved on July 29, 2010.  According to the ESSS rules, all Ohio utilities are subject to financial penalties if the established targets are not met for two consecutive years.

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Ohio Competitive Considerations and Proceedings

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

Market prices for power, as well as government aggregation initiatives within DP&L’s service territory, have led and may continue to lead to the entrance of additional competitors in our service territory.  At December 31, 2011, there were fourteen CRES providers in DP&L’s service territory.  DPLER, an affiliated company and one of the fourteen registered CRES providers, has been marketing supply services to DP&L customers.  During 2011, DPLER accounted for approximately 5,731 million kWh of the total 6,593 million kWh supplied by CRES providers within DP&L’s service territory.  Also during 2011, 27,812 customers with an annual energy usage of 862 million kWh were supplied by other CRES providers within DP&L’s service territory.  The volume supplied by DPLER represents approximately 41% of DP&L’s total distribution sales volume during 2011.  The reduction to gross margin in 2011 as a result of customers switching to DPLER and other CRES providers was approximately $58 million and $104 million, for DPL and DP&L, respectively.  We currently cannot determine the extent to which customer switching to CRES providers will occur in the future and the effect this will have on our operations, but any additional switching could have a significant adverse effect on our future results of operations, financial condition and cash flows.

Several communities in DP&L’s service area have passed ordinances allowing the communities to become government aggregators for the purpose of offering alternative electric generation supplies to their citizens.  To date, nine organizations have filed with the PUCO to initiate aggregation programs.  If these nine organizations move forward with aggregation, it could have a material effect on our earnings.  See Item 1A — Risk Factors for more information.

In 2010, DPLER began providing CRES services to business customers in Ohio who are not in DP&L’s service territory.  The incremental costs and revenues have not had a material effect on our results of operations, financial condition or cash flows.

DP&L entered into an economic development arrangement with its single largest electricity consumer.  This arrangement was approved by the PUCO on June 8, 2011 and became effective in July 2011.  Under Ohio law, DP&L is permitted to seek recovery of costs associated with economic development programs including foregone revenues from all customers.  On October 26, 2011, the PUCO approved our Economic Development Rider, as filed, which is designed to recover costs associated with this and other economic development contracts and programs.

Federal Matters

Like other electric utilities and energy marketers, DP&L and DPLE may sell or purchase electric products on the wholesale market.  DP&L and DPLE compete with other generators, power marketers, privately and municipally-owned electric utilities and rural electric cooperatives when selling electricity.  The ability of DP&L and DPLE to sell this electricity will depend not only on the performance of our generating units, but also on how DP&L’s and DPLE’s prices, terms and conditions compare to those of other suppliers.

As part of Ohio’s electric deregulation law, all of the state’s investor-owned utilities are required to join a RTO.  In October 2004, DP&L successfully integrated its high-voltage transmission lines into the PJM RTO.  The role of the RTO is to administer a competitive wholesale market for electricity and ensure reliability of the transmission grid.  PJM ensures the reliability of the high-voltage electric power system serving more than 50 million people in all or parts of Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia and the District of Columbia.  PJM coordinates and directs the operation of the region’s transmission grid, administers the world’s largest competitive wholesale electricity market and plans regional transmission expansion improvements to maintain grid reliability and relieve congestion.

The PJM RPM capacity base residual auction for the 2014/2015 period cleared at a per megawatt price of $126/day for our RTO area.  The per megawatt prices for the periods 2013/2014, 2012/2013 and 2011/2012 were $28/day, $16/day and $110/day, respectively, based on previous auctions.  Future RPM auction results will be dependent not only on the overall supply and demand of generation and load, but may also be impacted by congestion as well as PJM’s business rules relating to bidding for demand response and energy efficiency resources in the RPM capacity auctions.  Increases in customer switching causes more of the RPM capacity

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costs and revenues to be excluded from the RPM rider calculation.  We cannot predict the outcome of future auctions or customer switching but if the current auction price is not sustained, our future results of operations, financial condition and cash flows could be materially adversely impacted.

As a member of PJM, DP&L is also subject to charges and costs associated with PJM operations as approved by the FERC.  FERC orders issued in 2007 and thereafter regarding the allocation of costs of large transmission facilities within PJM which would result in additional costs being allocated to DP&L that, over time and depending on final costs and how quickly the facilities are constructed, could become material.  DP&L filed a notice of appeal to the U.S. Court of Appeals, D.C. Circuit, which was consolidated with other taken by other interested parties of the same FERC orders and the consolidated cases were assigned to the 7th Circuit.  On August 6, 2009, the 7th Circuit ruled that the FERC had failed to provide a reasoned basis for the allocation method it had approved.  Rehearings were filed by other interested litigants and denied by the Court, which then remanded the matter to the FERC for further proceedings.  On January 21, 2010, the FERC issued a procedural order on remand establishing a paper hearing process under which PJM will make an informational filing.  Subsequently, PJM and other parties, including DP&L, filed initial comments, testimony and recommendations and reply comments.  FERC did not establish a deadline for its issuance of a substantive order and the matter is still pending.  DP&L cannot predict the timing or the likely outcome of the proceeding.  Until such time as FERC may act to approve a change in methodology, PJM will continue to apply the allocation methodology that had been approved by FERC in 2007.  Although we continue to maintain that these costs should be borne by the beneficiaries of these projects and that DP&L is not one of these beneficiaries, any new credits or additional costs resulting from the ultimate outcome of this proceeding will be reflected in DP&L’s TCRR rider which already includes these costs.

NERC is a FERC-certified electric reliability organization responsible for developing and enforcing mandatory reliability standards, including Critical Infrastructure Protection (CIP) reliability standards, across eight reliability regions. In June 2009, Reliability First Corporation (RFC), with responsibilities assigned to it by NERC over the reliability region that includes DP&L, commenced a routine audit of DP&L’s operations.  The audit, which was for the period June 18, 2007 to June 25, 2009, evaluated DP&L’s compliance with 42 requirements in 18 NERC-reliability standards.  DP&L is currently subject to a compliance audit at a minimum of once every three years as provided by the NERC Rules of Procedure.  This audit was concluded in June 2009 and its findings revealed that DP&L had some Possible Alleged Violations (PAVs) associated with five NERC reliability requirements of various Standards.  In response to the report, DP&L filed mitigation plans with RFC/NERC to address the PAVs.  These mitigation plans were accepted by RFC/NERC.  In July 2010, DP&L negotiated a settlement with NERC under which DP&L agreed to pay an immaterial amount in exchange for a resolution of all issues and obligations relating to the aforementioned PAVs.  The settlement was approved on January 21, 2011 by the FERC.

ENVIRONMENTAL CONSIDERATIONS

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 effect 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 regarding whether modifications to or maintenance of certain coal-fired generating plants require additional permitting or pollution control technology, or whether emissions from coal-fired generating plants cause or contribute to global climate changes.

·Rules and future rules issued by the USEPA and Ohio EPA that require substantial reductions in SO2, particulates, mercury, acid gases, NOx, and other air emissions.  DP&L has installed emission control technology and is taking other measures to comply with required and anticipated reductions.

·Rules and future rules issued by the USEPA and Ohio EPA that require reporting and may require reductions of GHGs.

·Rules and future rules issued by the USEPA associated with the federal Clean Water Act, which prohibits the discharge of pollutants into waters of the United States except pursuant to appropriate permits.

·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 is fly ash and other coal combustion by-products.  The EPA has previously determined that fly ash and other coal

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combustion byproducts are not hazardous waste subject to the Resource Conservation and Recovery Act (RCRA), but the EPA is reconsidering that determination.  A change in determination or other additional regulation of fly ash or other coal combustion byproducts could significantly increase the costs of disposing of such ash byproducts.

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 to comply, or to determine compliance, with such regulations.  We record liabilities for loss contingencies related to transmission, capacity, ancillary serviceenvironmental matters when a loss is probable of occurring and other costs incurred since July 31, 2008 consistentcan be reasonably estimated in accordance with the provisions of SB 221.  Subsequently,GAAP.  Accordingly, we have estimated accruals for loss contingencies of approximately $3.4 million for environmental matters.  We also have a number of unrecognized loss contingencies related to environmental matters that are disclosed in the PUCO approved two separate ridersparagraphs below.  We evaluate the potential liability related to environmental matters quarterly and may revise our estimates.  Such revisions in November 2009, onethe estimates of the potential liabilities could have a material adverse effect on our results of operations, financial condition or cash flows.

We have several other pending environmental matters associated with our coal-fired generation units.  Together, these could result in significant capital and operations and maintenance expenditures for our coal-fired generation plants, and could result in the early retirement of our generation units that do not have SCR and FGD equipment installed.  Currently, our coal-fired generation units at Hutchings and Beckjord do not have this emission-control equipment installed.  DP&L owns 100% of the Hutchings plant and has a 50% interest in Beckjord Unit 6.  In addition to environmental matters, the operation of our coal-fired generation plants could be affected by a multitude of other factors, including forecasted power, capacity and commodity prices, competition and the levels of customer switching, current and forecasted customer demand, cost of capital and regulatory and legislative developments, any of which could pose a potential triggering event for an impairment of our investments in the Hutchings and Beckjord units.  On July 15, 2011, Duke Energy, a co-owner at the Beckjord Unit 6 facility, filed their Long-term Forecast Report with the PUCO.  The plan indicated that Duke Energy plans to cease production at the Beckjord Station, including our commonly owned Unit 6, in December 2014.  This was followed by a notification by Duke Energy to PJM, dated February 1, 2012, of a planned April 1, 2015 deactivation of this unit.  We are depreciating Unit 6 through December 2014 and do not believe that any additional accruals or impairment charges are needed as a result of this decision.  We are considering options for Hutchings Station, but have not yet made a final decision.  We do not believe that any accruals or impairment charges are needed related to the Hutchings Station.

Environmental Matters Related to Air Quality

Clean Air Act Compliance

In 1990, the federal government amended the CAA to further regulate air pollution.  Under the CAA, the USEPA sets limits on how much of a pollutant can be in the ambient air anywhere in the United States.  The CAA allows individual states to have stronger pollution controls than those set under the CAA, but states are not allowed to have weaker pollution controls than those set for the recovery of RPM capacity costswhole country.  The CAA has a material effect on our operations and another ridersuch effects are detailed below with respect to certain programs under the CAA.

Cross-State Air Pollution Rule

The Clean Air Interstate Rule (CAIR) final rules were published on May 12, 2005.  CAIR created an interstate trading program for the recovery of transmission, ancillaryannual NOx emission allowances and other PJM-related costs (TCRR)made modifications to an existing trading program for SO2.  Accordingly, during the period ended December 31, 2009,Litigation brought by entities not including DP&L deferred net RTO and other costs in the amount of $25.5 million.  Of this amount, approximately $9.8 million relates to the period August 1, 2008 through December 31, 2008, and $15.7 million relates to the twelve month period ended December 31, 2009.  The deferral of these costs resulted in a favorabledecision by the U.S. Court of Appeals for the District of Columbia Circuit on July 11, 2008 to vacate CAIR and its associated Federal Implementation Plan.  On December 23, 2008, the U.S. Court of Appeals issued an order on reconsideration that permits CAIR to remain in effect until the USEPA issues new regulations that would conform to the CAA requirements and the Court’s July 2008 decision.

In an attempt to conform to the Court’s decision, on July 6, 2010, the USEPA proposed the Clean Air Transport Rule (CATR).  These rules were finalized as the Cross-State Air Pollution Rule (CSAPR) on July 6, 2011, but subsequent litigation has resulted in their implementation being delayed indefinitely.  CSAPR creates four separate trading programs:  two SO2 areas (Group 1 and Group 2); and two NOx reduction requirements (annual and ozone season).  Group 1 states (16 states including Ohio) will have to meet a 2012 cap and additional reductions in 2014.  Group 2 states (7 states) will only have to meet the 2012 cap.  We do not believe the rule will have a material effect on our operations in 2012.  The Ohio EPA has a State Implementation Plan (SIP) that incorporates the CAIR program requirements, which remain in effect pending judicial review of CSAPR.  If CSAPR becomes effective, it is expected to institute a federal implementation plan (FIP) in lieu of state SIPs and allow for the states to develop SIPs for approval as early as 2013.  DP&L is

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unable to estimate the impact of the new requirements; however, CSAPR could have a material effect on our operations.

Mercury and Other Hazardous Air Pollutants

On May 3, 2011, the USEPA published proposed Maximum Achievable Control Technology (MACT) standards for coal- and oil-fired electric generating units.  The standards include new requirements for emissions of mercury and a number of other heavy metals.  The USEPA Administrator signed the final rule, now called MATS (Mercury and Air Toxics Standards), on December 16, 2011, and the rule was published in the Federal Register on February 16, 2012.  Affected electric generating units (EGUs) will have to come into compliance with the new requirements by April 16, 2015, but may be granted an additional year contingent on Ohio EPA approval.  DP&L is evaluating the costs that may be incurred to comply with the new requirement; however, MATS could have a material adverse effect on our results of operations and result in material compliance costs.

On April 29, 2010, the USEPA issued a proposed rule that would reduce emissions of toxic air pollutants from new and existing industrial, commercial and institutional boilers and process heaters at major and area source facilities.  The final rule was published in the Federal Register on March 21, 2011.  This regulation affects seven auxiliary boilers used for start-up purposes at DP&L’s generation facilities.  The regulations contain emissions limitations, operating limitations and other requirements.  In December 2011, the USEPA proposed additional changes to this rule and solicited comments.  Compliance costs are not expected to be material to DP&L’s operations.

On May 3, 2010, the National Emissions Standards for Hazardous Air Pollutants for compression ignition (CI) reciprocating internal combustion engines (RICE) became effective.  The units affected at DP&L are 18 diesel electric generating engines and eight emergency “black start” engines.  The existing CI RICE units must comply by May 3, 2013.  The regulations contain emissions limitations, operating limitations and other requirements.  Compliance costs for DP&L’s operations are not expected to be material.

National Ambient Air Quality Standards

On January 5, 2005, the USEPA published its final non-attainment designations for the National Ambient Air Quality Standard (NAAQS) for Fine Particulate Matter 2.5 (PM 2.5).  These designations included counties and partial counties in which DP&L operates and/or owns generating facilities.  As of December 31, 2011, DP&L’s Stuart, Killen and Hutchings Stations were located in non-attainment areas for the annual PM 2.5 standard.  There is a possibilitythat these areas will be re-designated as “attainment” for PM 2.5 within the next few calendar quarters and that the NAAQS for PM 2.5 will become more stringent.  We cannot predict the effect the revisions to the PM 2.5 standard will have on DP&L’s financial condition or results of operations.

On September 16, 2009, the USEPA announced that it would reconsider the 2008 national ground level ozone standard.  On September 2, 2011, the USEPA decided to postpone their revisiting of this standard until 2013.  DP&L cannot determine the effect of this potential change, if any, on its operations.

Effective April 12, 2010, the USEPA implemented revisions to its primary NAAQS for nitrogen dioxide.  This change may affect certain emission sources in heavy traffic areas like the I-75 corridor between Cincinnati and Dayton after 2016.  Several of our facilities or co-owned facilities are within this area.  DP&L cannot determine the effect of this potential change, if any, on its operations.

Effective August 23, 2010, the USEPA implemented revisions to its primary NAAQS for SO2 replacing the current 24-hour standard and annual standard with a one hour standard.  DP&L cannot determine the effect of this potential change, if any, on its operations.

On May 5, 2004, the USEPA issued its proposed regional haze rule, which addresses how states should determine the Best Available Retrofit Technology (BART) for sources covered under the regional haze rule.  Final rules were published July 6, 2005, providing states with several options for determining whether sources in the state should be subject to BART.  In the final rule, the USEPA made the determination that CAIR achieves greater progress than BART and may be used by states as a BART substitute and USEPA subsequently determined that if CSAPR becomes effective, it may be used to comply with BART requirements.  Numerous units owned and operated by us will be affected by BART.  We cannot determine the extent of the impact until Ohio determines how BART will be implemented.

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Carbon Emissions and Other Greenhouse Gases

In response to a U.S. Supreme Court decision that the USEPA has the authority to regulate CO2 emissions from motor vehicles, the USEPA made a finding that CO2 and certain other GHGs are pollutants under the CAA.  Subsequently, under the CAA, USEPA determined that CO2 and other GHGs from motor vehicles threaten the health and welfare of future generations by contributing to climate change.  This finding became effective in January 2010.  Numerous affected parties have petitioned the USEPA Administrator to reconsider this decision.  On April 1, 2010, USEPA signed the “Light-Duty Vehicle Greenhouse Gas Emission Standards and Corporate Average Fuel Economy Standards” rule.  Under USEPA’s view, this is the final action that renders carbon dioxide and other GHGs “regulated air pollutants” under the CAA.

Under USEPA regulations finalized in May 2010 (referred to as the “Tailoring Rule”), the USEPA began regulating GHG emissions from certain stationary sources in January 2011.  The Tailoring Rule sets forth criteria for determining which facilities are required to obtain permits for their GHG emissions pursuant to the CAA Prevention of Significant Deterioration and Title V operating permit programs.  Under the Tailoring Rule, permitting requirements are being phased in through successive steps that may expand the scope of covered sources over time.  The USEPA has issued guidance on what the Best Available Control Technology entails for the control of GHGs and individual states are required to determine what controls are required for facilities on a case-by-case basis.  The ultimate impact of the Tailoring Rule to DP&L cannot be determined at this time, but the cost of compliance could be material.

The USEPA plans to propose GHG standards for new and modified electric generating units (EGUs) under CAA subsection 111(b) — and propose and promulgate guidelines for states to address GHG standards for existing EGUs under CAA subsection 111(d) during 2012.  These rules may focus on energy efficiency improvements at power plants.  We cannot predict the effect of these standards, if any, on DP&L’s operations.

Approximately 99% of the energy we produce is generated by coal.  DP&L’s share of CO2 emissions at generating stations we own and co-own is approximately 16 million tons annually.  Further GHG legislation or regulation finalized at a future date could have a significant effect on DP&L’s operations and costs, which could adversely affect our net income, cash flows and financial condition.  However, due to the uncertainty associated with such legislation or regulation, we cannot predict the final outcome or the financial effect that such legislation or regulation may have on DP&L.

On September 22, 2009, the USEPA issued a final rule for mandatory reporting of GHGs from large sources that emit 25,000 metric tons per year or more of CO2, including electric generating units.  DP&L’s first report to the USEPA was submitted prior to the September 30, 2011 due date for 2010 emissions.  This reporting rule will guide development of policies and programs to reduce emissions.  DP&L does not anticipate that this reporting rule will result in any significant cost or other effect on current operations.

IncreaseLitigation, Notices of Violation and Other Matters Related to Air Quality

Litigation Involving Co-Owned Plants

On June 20, 2011, the U.S.Supreme Court ruled that the USEPA’s regulation of GHGs under the CAA displaced any right that plaintiffs may have had to seek similar regulation through federal common law litigation in Dividendsthe court system.  Although we are not named as a party to these lawsuits, DP&L is a co-owner of coal-fired plants with Duke Energy and AEP (or their subsidiaries) that could have been affected by the outcome of these lawsuits or similar suits that may have been filed against other electric power companies, including DP&L.  Because the issue was not squarely before it, the U.S. Supreme Court did not rule against the portion of plaintiffs’ original suits that sought relief under state law.

As a result of a 2008 consent decree entered into with the Sierra Club and approved by the U.S. District Court for the Southern District of Ohio, DP&L and the other owners of the J.M. Stuart generating station are subject to certain specified emission targets related to NOx, SO2 and particulate matter.  The consent decree also includes commitments for energy efficiency and renewable energy activities.  An amendment to the consent decree was entered into and approved in 2010 to clarify how emissions would be computed during malfunctions.  Continued compliance with the consent decree, as amended, is not expected to have a material effect on DPL’s Common StockDP&L’s results of operations, financial condition or cash flows in the future.

Notices of Violation Involving Co-Owned Plants

In November 1999, the USEPA filed civil complaints and NOVs against operators and owners of certain generation facilities for alleged violations of the CAA.  Generation units operated by Duke Energy (Beckjord Unit 6) and CSP (Conesville Unit 4) and co-owned by DP&L were referenced in these actions.  Although DP&L was not identified in the NOVs, civil complaints or state actions, the results of such proceedings could materially affect DP&L’s co-owned plants.

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

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In December 2007, the Ohio EPA issued a NOV to the DP&L-operated Killen generating station (co-owned by DP&L and Duke Energy) for alleged violations of the CAA.  The NOV alleged deficiencies in the continuous monitoring of opacity.  We submitted a compliance plan to the Ohio EPA on December 19, 2007.  To date, no further actions have been taken by the Ohio EPA.

On March 13, 2008, Duke Energy, the operator of the Zimmer generating station, received a NOV and a Finding of Violation (FOV) from the USEPA alleging violations of the CAA, the Ohio State Implementation Program (SIP) and permits for the Station in areas including SO2, opacity and increased heat input. A second NOV and FOV with similar allegations was issued on November 4, 2010.  Also in 2010, USEPA issued an NOV to Zimmer for excess emissions.  DP&L is a co-owner of the Zimmer generating station and could be affected by the eventual resolution of these matters.  Duke Energy is expected to act on behalf of itself and the co-owners with respect to these matters.  DP&L is unable to predict the outcome of these matters.

Notices of Violation Involving Wholly-Owned Plants

In 2007, the Ohio EPA and the USEPA issued NOVs to DP&L for alleged violations of the CAA at the O.H. Hutchings Station.  The NOVs’ alleged deficiencies relate to stack opacity and particulate emissions.  Discussions are under way with the USEPA, the U.S. Department of Justice and Ohio EPA.  On November 18, 2009, the USEPA issued an NOV to DP&L for alleged NSR violations of the CAA at the O.H. Hutchings Station relating to capital projects performed in 2001 involving Unit 3 and Unit 6.  DP&L does not believe that the two projects described in the NOV were modifications subject to NSR.  DP&L is engaged in discussions with the USEPA and Justice Department to resolve these matters, but DP&L is unable to determine the timing, costs or method by which these issues may be resolved.  The Ohio EPA is kept apprised of these discussions.

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

Clean Water Act — Regulation of Water Intake

On July 9, 2004, the USEPA issued final rules pursuant to the Clean Water Act governing existing facilities that have cooling water intake structures.  The rules require an assessment of impingement and/or entrainment of organisms as a result of cooling water withdrawal.  A number of parties appealed the rules.  In April 2009, the U.S. Supreme Court ruled that the USEPA did have the authority to compare costs with benefits in determining best technology available.  The USEPA released new proposed regulations on March 28, 2011, which were published in the Federal Register on April 20, 2011.  We submitted comments to the proposed regulations on August 17, 2011.  The final rules are expected to be in place by mid-2012.  We do not yet know the impact these proposed rules will have on our operations.

Clean Water Act — Regulation of Water Discharge

In December 2006, we submitted an application for the renewal of the Stuart Station NPDES Permit that was due to expire on June 30, 2007.  In July 2007, we received a draft permit proposing to continue our authority to discharge water from the station into the Ohio River.  On February 5, 2008, we received a letter from the Ohio EPA indicating that they intended to impose a compliance schedule as part of the final Permit, that requires us to implement one of two diffuser options for the discharge of water from the station into the Ohio River as identified in a thermal discharge study completed during the previous permit term.  Subsequently, DP&L and the Ohio EPA reached an agreement to allow DP&L to restrict public access to the water discharge area as an alternative to installing one of the diffuser options.  The Ohio EPA issued a revised draft permit that was received on November 12, 2008.  In December 2008, the USEPA requested that the Ohio EPA provide additional information regarding the thermal discharge in the draft permit.  In June 2009, DP&L provided information to the USEPA in response to their request to the Ohio EPA.  In September 2010, the USEPA formally objected to a revised permit provided by Ohio EPA due to questions regarding the basis for the alternate thermal limitation.  In December 2010, DP&L requested a public hearing on the objection, which was held on March 23, 2011.  We participated in and presented our position on the issue at the hearing and in written comments submitted on April 28, 2011.  In a letter to the Ohio EPA dated September 28, 2011, the USEPA reaffirmed its objection to the revised permit as previously drafted by the Ohio EPA.  This reaffirmation stipulated that if the Ohio EPA does not re-draft the permit to address the USEPA’s objection, then the authority for issuing the permit will pass to the USEPA.  The Ohio EPA issued another draft permit in December 2011 and a public hearing was held on February 2, 2012.  The draft permit would require DP&L, over the 54 months following issuance of a final permit, to take undefined actions to lower the temperature of its discharged water to a level unachievable by the station under its current design or alternatively make other significant modifications to the cooling water system.  DP&L submitted comments to the draft permit and is considering legal options.  Depending on the outcome of the process, the effects could be material on DP&L’s operation.

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coal combustion byproducts are regulated as hazardous waste, it is expected to have a material adverse effect on DP&L’s operations.

Notice of Violation Involving Co-Owned Plants

On DecemberSeptember 9, 2009,2011, DPL’sDP&L Boardreceived a notice of Directors authorizedviolation from the USEPA with respect to its co-owned J.M. Stuart generating station based on a quarterly dividend rate increasecompliance evaluation inspection conducted by the USEPA and Ohio EPA in 2009.  The notice alleged non-compliance by DP&L with certain provisions of approximately 6%, increasing the quarterly dividend perRCRA, the Clean Water Act National Pollutant Discharge Elimination System permit program and the station’s storm water pollution prevention plan.  The notice requested that DPL DP&Lcommon share from $.2850 respond with the actions it has subsequently taken or plans to $.3025.  If this dividend rate is maintained,take to remedy the annualized dividend would increase from $1.14 per share to $1.21 per share.USEPA’s findings and ensure that further violations will not occur.  Based on its review of the findings, although there can be no assurance, we believe that the notice will not result in any material effect on DP&L’s results of operations, financial condition or cash flow.

Legal and Other Matters

In February 2007, DP&L filed a lawsuit against a coal supplier seeking damages incurred due to the supplier’s failure to supply approximately 1.5 million tons of coal to two commonly owned plants under a coal supply agreement, of which approximately 570 thousand tons was DP&L’s share.  DP&L obtained replacement coal to meet its needs.  The supplier has denied liability, and is currently in federal bankruptcy proceedings in which DP&L is participating as an unsecured creditor.  DP&L is unable to determine the ultimate resolution of this matter.  DP&L has not recorded any assets relating to possible recovery of costs in this lawsuit.

In connection with DP&L and other utilities joining PJM, in 2006, the FERC ordered utilities to eliminate certain charges to implement transitional payments, known as SECA, effective December 1, 2004 through March 31, 2006, subject to refund. Through this proceeding, DP&L was obligated to pay SECA charges to other utilities, but received a net benefit from these transitional payments.  A hearing was held and an initial decision was issued in August 2006.  A final FERC order on this issue was issued on May 21, 2010 that substantially supports DP&L’s and other utilities’ position that SECA obligations should be paid by parties that used the transmission system during the timeframe stated above.  Prior to this final order being issued, DP&L entered into a significant number of bilateral settlement agreements with certain parties to resolve the matter, which by design will be unaffected by the final decision.  With respect to unsettled claims, DP&L management has deferred $17.8 million and $15.4 million as of December 31, 2011 and December 31, 2010, respectively, as Other deferred credits representing the amount of unearned income where the earnings process is not complete.  The amount at December 31, 2011 includes estimated earnings and interest of $5.2 million.  On September 30, 2011, the FERC issued two SECA-related orders that affirmed an earlier order issued in 2010 by denying the rehearing requests that a number of different parties, including DP&L, had filed.  These orders are now final, subject to possible appellate court review.  These orders do not affect prior settlements that had been reached with other parties that owed SECA revenues to DP&L or were recipients of amounts paid by DP&L.  For other parties that had not previously settled with DP&L, the exact timing and amounts of any payments that would be made or received by DP&L under these orders is still uncertain.

Also refer to Notes 2 and 18 of Notes to DPL’s Consolidated Financial Statements for additional information surrounding the merger and certain related legal matters.

Capital Expenditures for Environmental Matters

DP&L’s environmental capital expenditures are approximately $12 million, $12 million and $21 million in 2011, 2010 and 2009, respectively.  DP&L has budgeted $15 million in environmental related capital expenditures for 2012.

ELECTRIC SALESOPERATIONS AND REVENUESFUEL SUPPLY

(a)DPL’s present summer generating capacity, including peaking units, is approximately 3,818 MW.  Of this capacity, approximately 2,830 MW, or 74%, is derived from coal-fired steam generating stations and the balance of approximately 988 MW, or 26%, consists of solar, combustion turbine and diesel peaking units.

DP&L&L’s sells powerpresent summer generating capacity, including peaking units, is approximately 3,262 MW.  Of this capacity, approximately 2,830 MW, or 87%, is derived from coal-fired steam generating stations and the balance of approximately 432 MW, or 13%, consists of solar, combustion turbine and diesel peaking units.

Our all-time net peak load was 3,270 MW, occurring August 8, 2007.

Approximately 87% of the existing steam generating capacity is provided by certain generating units owned as tenants in common with Duke Energy and CSP.  As tenants in common, each company owns a specified share of each of these units, is entitled to DPLER (a subsidiaryits share of DPL).  The revenues associated with these sales are classified as wholesale sales oncapacity and energy output and has a capital and operating cost responsibility proportionate to its ownership share.  DP&L’s financial statements and retail sales for DPL.  The kWh volumes contain all volumes distributed on theremaining steam generating capacity (approximately 365 MW) is derived from a generating station owned solely by DP&L system which include.  Additionally, DP&L, Duke Energy and CSP own, as tenants in common, 880 circuit miles of 345,000-volt transmission lines.  DP&L has several interconnections with other companies for the retail sales by DPLER.  The sales for resale volumes are omittedpurchase, sale and interchange of electricity.

In 2011, we generated 98.3% of our electric output from DP&L to avoid duplicate reporting.coal-fired units and 1.7% from solar, oil and natural gas-fired units.

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The following table sets forth DP&L’s and DPLE’s generating stations and, where indicated, those stations which DP&L owns as tenants in common.

*W = Wholly-Owned

C = Commonly-Owned

In addition to the above, DP&L also owns a 4.9% equity ownership interest in OVEC, an electric generating company.  OVEC has two plants located in Cheshire, Ohio and Madison, Indiana with a combined generation capacity of approximately 2,265 MW.  DP&L’s share of this generation capacity is approximately 111 MW.

We have substantially all of the total expected coal volume needed to meet our retail and firm wholesale sales requirements for 2012 under contract.  The majority of the contracted coal is purchased at fixed prices.  Some contracts provide for periodic adjustments and some are priced based on market indices.  Fuel costs are affected by changes in volume and price and are driven by a number of variables including weather, the wholesale market price of power, certain provisions in coal contracts related to government imposed costs, counterparty performance and credit, scheduled outages and generation plant mix.  Due to the installation of emission controls equipment at certain commonly owned units and barring any changes in the regulatory environment in which we operate, we expect to have a balanced SO2 and NOx position for 2012.

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The gross average cost of fuel consumed per kWh was as follows: