Significant Accounting Policies	9 Months Ended
Sep. 30, 2011
Significant Accounting Policies	(2) SIGNIFICANT ACCOUNTING POLICIES Financial Statement Presentation Pepco Holdings' unaudited Consolidated Financial Statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP). Pursuant to the rules and regulations of the Securities and Exchange Commission, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with the annual financial statements included in PHI's Annual Report on Form 10-K for the year ended December 31, 2010. In the opinion of PHI's management, the Consolidated Financial Statements contain all adjustments (which all are of a normal recurring nature) necessary to state fairly Pepco Holdings' financial condition as of September 30, 2011, in accordance with GAAP. The year-end December 31, 2010 Consolidated Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and nine months ended September 30, 2011 may not be indicative of PHI's results that will be realized for the full year ending December 31, 2011, since its Power Delivery business and the retail energy supply business of Pepco Energy Services are seasonal. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the Consolidated Financial Statements and accompanying notes. Although Pepco Holdings believes that its estimates and assumptions are reasonable, they are based upon information available to management at the time the estimates are made. Actual results may differ significantly from these estimates. Significant matters that involve the use of estimates include the assessment of goodwill and long-lived assets for impairment, fair value calculations for certain derivative instruments, the costs of providing pension and other postretirement benefits, evaluation of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of self-insurance reserves for general and auto liability claims, accrual of interest related to income taxes, accrual of restructuring charges, recognition of changes in network service transmission rates for prior service year costs, and the recognition of income tax benefits for investments in finance leases held in trust associated with PHI's portfolio of cross-border energy lease investments. Additionally, PHI is subject to legal, regulatory, and other proceedings and claims that arise in the ordinary course of its business. PHI records an estimated liability for these proceedings and claims, when it is probable that a loss has been incurred and the loss is reasonably estimable. Storm Costs During the third quarter of 2011, Pepco, DPL and ACE incurred significant costs associated with Hurricane Irene that affected their respective service territories. Total incremental storm costs associated with Hurricane Irene were $47 million, with $30 million incurred for repair work and $17 million incurred as capital expenditures. Costs incurred for repair work of $24 million were deferred as a regulatory asset to reflect the probable recovery of these storm costs in certain jurisdictions, and the remaining $6 million was charged to Other operation and maintenance expense. Approximately $31 million of these total incremental storm costs have been estimated for the cost of restoration services provided by outside contractors since a large portion of the invoices for such services had not been received at September 30, 2011. Actual invoices may vary from these estimates. PHI's utility subsidiaries currently plan to seek recovery of the incremental Hurricane Irene costs in each of their various jurisdictions in pending or planned distribution rate case filings. Network Service Transmission Rates In May 2011, PHI's utility subsidiaries filed their network service transmission rates with the Federal Energy Regulatory Commission effective for the service year beginning June 1, 2011. The new rates include an adjustment for costs incurred in the service year ended May 31, 2011 that were not reflected in the rates charged to customers for that service year. In the second quarter of 2011, PHI's utility subsidiaries recorded a $3 million decrease in transmission revenues as a change to the estimates recorded in previous periods primarily due to a decrease in the actual rate base versus the estimated rate base. For the nine months ended September 30, 2010, PHI's utilities recorded an $8 million increase in transmission revenues associated with a change to the estimates recorded in previous periods. General and Auto Liability During the second quarter of 2011, PHI's utility subsidiaries reduced their self-insurance reserves for general and auto liability claims by approximately $5 million, based on obtaining an actuarial estimate of the unpaid loss attributed to general and auto liability claims for each of PHI's utility subsidiaries at June 30, 2011. Consolidation of Variable Interest Entities In accordance with the provisions of the Financial Accounting Standards Board (FASB) guidance on the consolidation of variable interest entities (Accounting Standards Codification (ASC) 810), Pepco Holdings consolidates variable interest entities with respect to which Pepco Holdings or a subsidiary is the primary beneficiary. The guidance addresses conditions under which an entity should be consolidated based upon variable interests rather than voting interests. The subsidiaries of Pepco Holdings have contractual arrangements with several entities to which the guidance applies. ACE Power Purchase Agreements PHI, through its ACE subsidiary, is a party to three power purchase agreements (PPAs) with unaffiliated, non-utility generators (NUGs). PHI was unable to obtain sufficient information to determine whether these three entities were variable interest entities or if ACE was the primary beneficiary and as a result has applied the scope exemption from the consolidation guidance for enterprises that have not been able to obtain such information. Net purchase activities with the NUGs for the three months ended September 30, 2011 and 2010, were approximately $57 million and $82 million, respectively, of which approximately $55 million and $74 million, respectively, consisted of power purchases under the PPAs. Net purchase activities with the NUGs for the nine months ended September 30, 2011 and 2010, were approximately $169 million and $222 million, respectively, of which approximately $159 million and $203 million, respectively, consisted of power purchases under the PPAs. The power purchase costs are recoverable from ACE's customers through regulated rates. DPL Renewable Energy Transactions DPL is subject to Renewable Energy Portfolio Standards (RPS) in the state of Delaware that require it to obtain renewable energy credits (RECs) for energy delivered to its customers. DPL's costs associated with obtaining RECs to fulfill its RPS obligations are recoverable from its customers by law. PHI, through its DPL subsidiary, has entered into three land-based wind PPAs and one offshore wind PPA in the aggregate amount of 328 megawatts and one solar PPA with a 10 megawatt facility as of September 30, 2011. As the wind facilities become operational, DPL is obligated to purchase energy and RECs in amounts generated and delivered by the facilities at rates that are primarily fixed under these agreements. Under one of the PPAs, DPL is also obligated to purchase the capacity associated with the facility at rates that are generally fixed. If a wind facility does not become operational by a specified date, DPL has the right to terminate that PPA. DPL concluded that consolidation is not required for any of these agreements under FASB guidance on the consolidation of variable interest entities. Two of the land-based facilities are operational and DPL is obligated to purchase energy and RECs from one of these facilities through 2024 in amounts not to exceed 50.25 megawatts and the second of these facilities through 2031 in amounts not to exceed 40 megawatts. DPL's purchases under the operational wind PPAs totaled $3 million and $2 million for the three months ended September 30, 2011 and 2010, respectively, and $12 million and $8 million for the nine months ended September 30, 2011 and 2010, respectively. The other land-based wind agreement has a 20-year term and the facility is currently expected to become operational during 2011. In July 2011, the Delaware Public Service Commission (DPSC) approved amendments to this land-based wind PPA to change the location of the facility and to reduce the maximum generation capacity from 60 megawatts to 38 megawatts. The offshore wind facility is expected to become operational during 2016. If the offshore wind facility developer is unable to obtain all necessary permits and financing commitments, this could result in delays in the construction schedule and the operational start date of the offshore wind facility. The solar facility began operations in the third quarter of 2011. The term of the agreement with the solar facility is 20 years and DPL is obligated to purchase RECs in an amount up to 70 percent of the energy output at a fixed price. DPL's purchases under the agreement were $1 million during the third quarter of 2011. On October 18, 2011, the DPSC approved a tariff submitted by DPL specific to a 30 megawatt fuel cell facility to be constructed using fuel cells manufactured in the State of Delaware. The RPS require that the DPSC establish an irrevocable tariff under which DPL would be an agent that collects payments from its customers and disburses the amounts collected to a Qualified Fuel Cell Provider that deploys Delaware-manufactured fuel cells as part of a 30 megawatt generation facility. The tariff and the RPS establish that DPL would be an agent to collect payments in advance from its distribution customers and remit them to the Qualified Fuel Cell Provider for each megawatt hour of energy produced over 20 years. DPL would have no liability to the Qualified Fuel Cell Provider other than to remit payments collected from its distribution customers pursuant to the tariff. The RPS provide for a reduction in DPL's REC requirements based upon the actual energy output of the facility. PHI is currently assessing the appropriate accounting treatment for the transaction, including the applicability of FASB guidance on the consolidation of variable interest entities, leases, and derivative instruments. PHI's accounting review is expected to be completed in the fourth quarter of 2011. Atlantic City Electric Transition Funding LLC Atlantic City Electric Transition Funding LLC (ACE Funding) was established in 2001 by ACE solely for the purpose of securitizing authorized portions of ACE's recoverable stranded costs through the issuance and sale of bonds (Transition Bonds). The proceeds of the sale of each series of Transition Bonds have been transferred to ACE in exchange for the transfer by ACE to ACE Funding of the right to collect non-bypassable transition bond charges (the Transition Bond Charges) from ACE customers pursuant to bondable stranded costs rate orders issued by the New Jersey Board of Public Utilities (NJBPU) in an amount sufficient to fund the principal and interest payments on the Transition Bonds and related taxes, expenses and fees (Bondable Transition Property). ACE collects the Transition Bond Charges from its customers on behalf of ACE Funding and the holders of the Transition Bonds. The assets of ACE Funding, including the Bondable Transition Property, and the Transition Bond Charges collected from ACE's customers, are not available to creditors of ACE. The holders of the Transition Bonds have recourse only to the assets of ACE Funding. ACE owns 100 percent of the equity of ACE Funding and PHI consolidates ACE Funding in its financial statements as ACE is the primary beneficiary of ACE Funding under the variable interest entity consolidation guidance. ACE Standard Offer Capacity Agreements On April 28, 2011, ACE entered into three Standard Offer Capacity Agreements (SOCAs) by order of the NJBPU, each with a different generation company. The SOCAs were established under a New Jersey law enacted to promote the construction of qualified electric generation facilities in New Jersey. The SOCAs are 15-year, financially settled transactions approved by the NJBPU that allow generators to receive payments from, or make payments to, ACE based on the difference between the fixed price in the SOCAs and the price for capacity that clears PJM Interconnection, LLC (PJM). Each of the other electricity distribution companies (EDCs) in New Jersey has entered into SOCAs having the same terms with the same generation companies. The annual share of payments or receipts for ACE and the other EDCs is based upon each company's annual proportion of the total New Jersey load attributable to all EDCs. ACE and the other EDCs entered the SOCAs under protest based on concerns about the potential cost to distribution customers. In February 2011, ACE joined other plaintiffs in an action filed in the United States District Court for the District of New Jersey challenging the constitutionality of the New Jersey law. The proceeding is now in the discovery phase. In May 2011, the NJBPU denied a joint motion for reconsideration of its order requiring each of the EDCs to enter into the SOCAs. In June 2011, ACE and the other EDCs filed appeals related to the NJBPU orders with the Appellate Division of the New Jersey Superior Court. On October 17, 2011, one of the generation companies sent a notice of dispute under the SOCA to ACE. The notice of dispute alleges that certain actions taken by PJM have an adverse effect on the generation company's ability to clear the PJM auction as required by the SOCA and, under a provision of the SOCA, ACE and the generation supplier must attempt to amend the SOCA in order to permit transactions to continue thereunder, subject to NJBPU approval. ACE has agreed to meet with the generation supplier, but does not acknowledge that a "dispute" exists under the SOCA. Currently, PHI believes that FASB guidance on derivative accounting and the accounting for regulated operations would apply to a SOCA once capacity has cleared a PJM auction. Once cleared, the gain (loss) associated with the fair value of a derivative would be offset by the establishment of a regulatory liability (asset). Goodwill Goodwill represents the excess of the purchase price of an acquisition over the fair value of the net assets acquired at the acquisition date. Substantially all of Pepco Holdings' goodwill was generated by Pepco's acquisition of Conectiv in 2002 and is allocated entirely to Pepco Holdings' Power Delivery reporting unit for purposes of impairment testing based on the aggregation of its components. Pepco Holdings tests its goodwill for impairment annually as of November 1 and whenever an event occurs or circumstances change in the interim that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Factors that may result in an interim impairment test include, but are not limited to: a change in the identified reporting units; an adverse change in business conditions; a decline in PHI's stock price causing market capitalization to fall further below book value; an adverse regulatory action; or an impairment of long-lived assets in the reporting unit. PHI concluded that an interim impairment test was not required during the three months ended September 30, 2011. Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions Taxes included in Pepco Holdings' gross revenues were $111 million and $118 million for the three months ended September 30, 2011 and 2010, respectively, and $302 million and $280 million for the nine months ended September 30, 2011 and 2010, respectively. Reclassifications and Adjustments Certain prior period amounts have been reclassified in order to conform to the current period presentation. The following adjustments have been recorded and are not considered material either individually or in the aggregate: Default Electricity Supply Revenue and Costs Adjustments During 2011, DPL recorded adjustments associated with the accounting for Default Electricity Supply revenue and costs. These adjustments were primarily due to the under-recognition of allowed returns on working capital and under-recoveries of administrative costs and resulted in a pre-tax decrease in Other operation and maintenance expense of $1 million and $9 million for the three and nine months ended September 30, 2011, respectively. Pepco Energy Services Derivative Accounting Adjustments During the first quarter of 2011, PHI recorded an adjustment associated with an increase in the value of certain derivatives from October 1, 2010 to December 31, 2010, which had been erroneously recorded in other comprehensive income at December 31, 2010. This adjustment resulted in an increase in revenue and pre-tax earnings of $2 million for the nine months ended September 30, 2011. Other Taxes Adjustment In the third quarter of 2010, Pepco recorded an adjustment to correct certain errors related to other taxes which resulted in a decrease to Other taxes expense of $5 million (pre-tax) for the three and nine months ended September 30, 2010. Income Tax Adjustments During the first quarter of 2011, Pepco recorded an adjustment to correct certain income tax errors related to prior periods associated with the interest on uncertain tax positions. The adjustment resulted in an increase in income tax expense of $1 million for the nine months ended September 30, 2011. During the second quarter of 2010, PHI recorded an adjustment to correct certain income tax errors associated with casualty loss claims, which resulted in a decrease to income tax expense of $1 million for the nine months ended September 30, 2010. During the first quarter of 2010, ACE recorded an adjustment to correct certain income tax errors related to prior periods. The adjustment resulted in an increase in income tax expense of $6 million for the nine months ended September 30, 2010. The adjustment represents the reversal of erroneously recorded interest income for state income tax purposes related to uncertain and effectively settled tax positions, including $2 million, $3 million and $1 million recorded in 2009, 2008 and 2007, respectively. During 2010, PHI recorded various adjustments to income tax expense to reflect primarily the benefit from additional deductions related to executive compensation that had erroneously not been included in tax returns prior to 2008, a reduction in income tax expense associated with errors related to the deferred tax assets established in connection with the District of Columbia net operating losses, and an increase to income tax expense associated with the reversal of erroneously recorded interest income for state income tax purposes related to uncertain and effectively settled tax positions. These adjustments resulted in a decrease to income tax expense of $7 million related to continuing operations for the three months ended September 30, 2010 and a decrease to income tax expense of $1 million related to continuing operations for the nine months ended September 30, 2010. In the third quarter of 2010, Pepco recorded certain adjustments to correct errors in Income tax expense which resulted in an increase to Income tax expense of $4 million for the three and nine months ended September 30, 2010. Discontinued Operations In the third quarter of 2010, PHI recorded adjustments to reverse revenue erroneously recognized in the second quarter of 2010 associated with its discontinued operations. The adjustments resulted in an increase in net loss from discontinued operations of $7 million (pre-tax) for the three months ended September 30, 2010.
Potomac Electric Power Co [Member]
Significant Accounting Policies	(2) SIGNIFICANT ACCOUNTING POLICIES Financial Statement Presentation Pepco's unaudited financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP). Pursuant to the rules and regulations of the Securities and Exchange Commission, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with the annual financial statements included in Pepco's Annual Report on Form 10-K for the year ended December 31, 2010. In the opinion of Pepco's management, the financial statements contain all adjustments (which all are of a normal recurring nature) necessary to state fairly Pepco's financial condition as of September 30, 2011, in accordance with GAAP. The year-end December 31, 2010 Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and nine months ended September 30, 2011 may not be indicative of results that will be realized for the full year ending December 31, 2011 since the sales of electric energy are seasonal. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the financial statements and accompanying notes. Although Pepco believes that its estimates and assumptions are reasonable, they are based upon information available to management at the time the estimates are made. Actual results may differ significantly from these estimates. Significant matters that involve the use of estimates include the assessment of contingencies, the calculation of future cash flows and fair value amounts for use in asset impairment evaluations, pension and other postretirement benefits assumptions, unbilled revenue calculations, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of restructuring charges, recognition of changes in network service transmission rates for prior service year costs, accrual of self-insurance reserves for general and auto liability claims and income tax provisions and reserves. Additionally, Pepco is subject to legal, regulatory, and other proceedings and claims that arise in the ordinary course of its business. Pepco records an estimated liability for these proceedings and claims when it is probable that a loss has been incurred and the loss is reasonably estimable. Storm Costs During the third quarter of 2011, Pepco incurred significant costs associated with Hurricane Irene that affected its service territory. Total incremental storm costs associated with Hurricane Irene were $22 million, with $14 million incurred for repair work and $8 million incurred as capital expenditures. Costs incurred for repair work of $12 million were deferred as a regulatory asset to reflect the probable recovery of these storm costs in Pepco's jurisdictions, and the remaining $2 million was charged to Other operation and maintenance expense. Approximately $16 million of these total incremental storm costs have been estimated for the cost of restoration services provided by outside contractors since a large portion of the invoices for such services had not been received at September 30, 2011. Actual invoices may vary from these estimates. Pepco currently plans to seek recovery of the incremental Hurricane Irene costs in each of its jurisdictions in pending or planned distribution rate case filings. Network Service Transmission Rates In May 2011, Pepco filed its network service transmission rates with the Federal Energy Regulatory Commission effective for the service year beginning June 1, 2011. The new rates include an adjustment for costs incurred in the service year ended May 31, 2011 that were not reflected in the rates charged to customers for that service year. In the second quarter of 2011, Pepco recorded a $2 million decrease in transmission revenues as a change to the estimates recorded in previous periods primarily due to a decrease in the actual rate base versus the estimated rate base. For the nine months ended September 30, 2010, Pepco recorded a $3 million increase in transmission service revenue associated with a change to the estimates recorded in previous periods. General and Auto Liability During the second quarter of 2011, Pepco reduced its self-insurance reserves for general and auto liability claims by approximately $1 million, based on obtaining an actuarial estimate of the unpaid loss attributable to general and auto liability claims for Pepco at June 30, 2011. Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions Taxes included in Pepco's gross revenues were $100 million and $106 million for the three months ended September 30, 2011 and 2010, respectively, and $271 million and $249 million for the nine months ended September 30, 2011 and 2010, respectively. Reclassifications and Adjustments Certain prior period amounts have been reclassified in order to conform to the current period presentation. The following adjustments have been recorded which are not considered material individually or in the aggregate: Income Tax Adjustments During the first quarter of 2011, Pepco recorded an adjustment to correct certain income tax errors related to prior periods associated with the interest on uncertain tax positions. The adjustment resulted in an increase in income tax expense of $1 million for the nine months ended September 30, 2011. In the third quarter of 2010, Pepco recorded certain adjustments to correct errors in Income tax expense which resulted in an increase to Income tax expense of $4 million for the three and nine months ended September 30, 2010. Other Taxes Adjustment In the third quarter of 2010, Pepco recorded an adjustment to correct certain errors related to other taxes which resulted in a decrease to Other taxes expense of $5 million (pre-tax) for the three and nine months ended September 30, 2010.
Delmarva Power & Light Co/De [Member]
Significant Accounting Policies	(2) SIGNIFICANT ACCOUNTING POLICIES Financial Statement Presentation DPL's unaudited financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP). Pursuant to the rules and regulations of the Securities and Exchange Commission, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with the annual financial statements included in DPL's Annual Report on Form 10-K for the year ended December 31, 2010. In the opinion of DPL's management, the financial statements contain all adjustments (which all are of a normal recurring nature) necessary to state fairly DPL's financial condition as of September 30, 2011, in accordance with GAAP. The year-end December 31, 2010 Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and nine months ended September 30, 2011 may not be indicative of results that will be realized for the full year ending December 31, 2011 since the sales of electric energy and natural gas are seasonal. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the financial statements and accompanying notes. Although DPL believes that its estimates and assumptions are reasonable, they are based upon information available to management at the time the estimates are made. Actual results may differ significantly from these estimates. Significant matters that involve the use of estimates include the assessment of contingencies, the calculation of future cash flows and fair value amounts for use in asset and goodwill impairment evaluations, fair value calculations for derivative instruments, pension and other postretirement benefits assumptions, unbilled revenue calculations, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of restructuring charges, recognition of changes in network service transmission rates for prior service year costs, accrual of self-insurance reserves for general and auto liability claims and income tax provisions and reserves. Additionally, DPL is subject to legal, regulatory, and other proceedings and claims that arise in the ordinary course of its business. DPL records an estimated liability for these proceedings and claims when it is probable that a loss has been incurred and the loss is reasonably estimable. Storm Costs During the third quarter of 2011, DPL incurred significant costs associated with Hurricane Irene that affected its service territory. Total incremental storm costs associated with Hurricane Irene were $12 million, with $9 million incurred for repair work and $3 million incurred as capital expenditures. Costs incurred for repair work of $5 million were deferred as a regulatory asset to reflect the probable recovery of these storm costs in DPL's jurisdictions, and the remaining $4 million was charged to Other operation and maintenance expense. Approximately $7 million of these total incremental storm costs have been estimated for the cost of restoration services provided by outside contractors since a large portion of the invoices for such services had not been received at September 30, 2011. Actual invoices may vary from these estimates. DPL currently plans to seek recovery of the incremental Hurricane Irene costs in each of its jurisdictions in planned distribution rate case filings. Network Service Transmission Rates In May 2011, DPL filed its network service transmission rates with the Federal Energy Regulatory Commission effective for the service year beginning June 1, 2011. The new rates include an adjustment for costs incurred in the service year ended May 31, 2011 that were not reflected in the rates charged to customers for that service year. In the second quarter of 2011, DPL recorded a $2 million decrease in transmission revenues as a change to the estimates recorded in previous periods due to a decrease in the actual rate base versus the estimated rate base. For the nine months ended September 30, 2010, DPL recorded a $3 million increase in transmission service revenue associated with a change to the estimates recorded in previous periods. General and Auto Liability During the second quarter of 2011, DPL reduced its self-insurance reserves for general and auto liability claims by approximately $3 million, based on obtaining an actuarial estimate of the unpaid loss attributed to general and auto liability claims for DPL at June 30, 2011. Consolidation of Variable Interest Entities – DPL Renewable Energy Transactions DPL is subject to Renewable Energy Portfolio Standards (RPS) in the state of Delaware that require it to obtain renewable energy credits (RECs) for energy delivered to its customers. DPL's costs associated with obtaining RECs to fulfill its RPS obligations are recoverable from its customers by law. PHI, through its DPL subsidiary, has entered into three land-based wind power purchase agreements (PPAs) and one offshore wind PPA in the aggregate amount of 328 megawatts and one solar PPA with a 10 megawatt facility as of September 30, 2011. As the wind facilities become operational, DPL is obligated to purchase energy and RECs in amounts generated and delivered by the facilities at rates that are primarily fixed under these agreements. Under one of the PPAs, DPL is also obligated to purchase the capacity associated with the facility at rates that are generally fixed. If a wind facility does not become operational by a specified date, DPL has the right to terminate that PPA. DPL concluded that consolidation is not required for any of these agreements under FASB guidance on the consolidation of variable interest entities. Two of the land-based facilities are operational and DPL is obligated to purchase energy and RECs from one of these facilities through 2024 in amounts not to exceed 50.25 megawatts and the second of these facilities through 2031 in amounts not to exceed 40 megawatts. DPL's purchases under the operational wind PPAs totaled $3 million and $2 million for the three months ended September 30, 2011 and 2010, respectively, and $12 million and $8 million for the nine months ended September 30, 2011 and 2010, respectively. The other land-based wind agreement has a 20-year term and the facility is currently expected to become operational during 2011. In July 2011, the Delaware Public Service Commission (DPSC) approved amendments to this land-based wind PPA to change the location of the facility and to reduce the maximum generation capacity from 60 megawatts to 38 megawatts. The offshore wind facility is expected to become operational during 2016. If the offshore wind facility developer is unable to obtain all necessary permits and financing commitments, this could result in delays in the construction schedule and the operational start date of the offshore wind facility. The solar facility began operations in the third quarter of 2011. The term of the agreement with the solar facility is 20 years and DPL is obligated to purchase RECs in an amount up to 70 percent of the energy output at a fixed price. DPL's purchases under the agreement were $1 million during the third quarter of 2011. On October 18, 2011, the DPSC approved a tariff submitted by DPL specific to a 30 megawatt fuel cell facility to be constructed using fuel cells manufactured in the State of Delaware. The RPS require that the DPSC establish an irrevocable tariff under which DPL would be an agent that collects payments from its customers and disburses the amounts collected to a Qualified Fuel Cell Provider that deploys Delaware-manufactured fuel cells as part of a 30 megawatt generation facility. The tariff and the RPS establish that DPL would be an agent to collect payments in advance from its distribution customers and remit them to the Qualified Fuel Cell Provider for each megawatt hour of energy produced over 20 years. DPL would have no liability to the Qualified Fuel Cell Provider other than to remit payments collected from its distribution customers pursuant to the tariff. The RPS provide for a reduction in DPL's REC requirements based upon the actual energy output of the facility. PHI is currently assessing the appropriate accounting treatment for the transaction, including the applicability of FASB guidance on the consolidation of variable interest entities, leases, and derivative instruments. PHI's accounting review is expected to be completed in the fourth quarter of 2011. Goodwill Goodwill represents the excess of the purchase price of an acquisition over the fair value of the net assets acquired at the acquisition date. All of DPL's goodwill was generated by DPL's acquisition of Conowingo Power Company in 1995. DPL tests its goodwill for impairment annually and whenever an event occurs or circumstances change in the interim that would more likely than not reduce the fair value of DPL below its carrying amount. DPL performs its annual impairment test on November 1. Factors that may result in an interim impairment test include, but are not limited to: a change in the identified reporting units; an adverse change in business conditions; an adverse regulatory action; or an impairment of DPL's long-lived assets. DPL concluded that an interim impairment test was not required during the three months ended September 30, 2011. Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions Taxes included in DPL's gross revenues were $4 million for each of the three months ended September 30, 2011 and 2010 and $14 million and $13 million for the nine months ended September 30, 2011 and 2010, respectively. Reclassifications and adjustments Certain prior period amounts have been reclassified to conform to current period presentation. The following adjustment has been recorded and is not considered material. Default Electricity Supply Revenue and Costs Adjustments During 2011, DPL recorded adjustments associated with the accounting for Default Electricity Supply revenue and costs. These adjustments were primarily due to the under-recognition of allowed returns on working capital and administrative costs and resulted in a pre-tax decrease in Other operation and maintenance expense of $1 million and $9 million for the three and nine months ended September 30, 2011, respectively.
Atlantic City Electric Co [Member]
Significant Accounting Policies	(2) SIGNIFICANT ACCOUNTING POLICIES Financial Statement Presentation ACE's unaudited Consolidated Financial Statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP). Pursuant to the rules and regulations of the Securities and Exchange Commission, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with the annual financial statements included in ACE's Annual Report on Form 10-K for the year ended December 31, 2010. In the opinion of ACE's management, the Consolidated Financial Statements contain all adjustments (which all are of a normal recurring nature) necessary to state fairly ACE's financial condition as of September 30, 2011, in accordance with GAAP. The year-end December 31, 2010 Consolidated Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and nine months ended September 30, 2011 may not be indicative of results that will be realized for the full year ending December 31, 2011 since the sales of electric energy are seasonal. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the Consolidated Financial Statements and accompanying notes. Although ACE believes that its estimates and assumptions are reasonable, they are based upon information available to management at the time the estimates are made. Actual results may differ significantly from these estimates. Significant matters that involve the use of estimates include the assessment of contingencies, the calculation of future cash flows and fair value amounts for use in asset impairment evaluations, pension and other postretirement benefits assumptions, unbilled revenue calculations, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of restructuring charges, recognition of changes in network service transmission rates for prior service year costs, accrual of self-insurance reserves for general and auto liability claims and income tax provisions and reserves. Additionally, ACE is subject to legal, regulatory, and other proceedings and claims that arise in the ordinary course of its business. ACE records an estimated liability for these proceedings and claims when it is probable that a loss has been incurred and the loss is reasonably estimable. Storm Costs During the third quarter of 2011, ACE incurred significant costs associated with Hurricane Irene that affected its service territory. Total incremental storm costs associated with Hurricane Irene were $13 million, with $7 million incurred for repair work and $6 million incurred as capital expenditures. All costs incurred for repair work were deferred as a regulatory asset to reflect the probable recovery of these storm costs. Approximately $8 million of these total incremental storm costs have been estimated for the cost of restoration services provided by outside contractors since a large portion of the invoices for such services had not been received at September 30, 2011. Actual invoices may vary from these estimates. ACE currently plans to seek recovery of the incremental Hurricane Irene costs as discussed in Note (11), "Commitments and Contingencies—Rate Proceedings". Network Service Transmission Rates In May 2011, ACE filed its network service transmission rates with the Federal Energy Regulatory Commission effective for the service year beginning June 1, 2011. The new rates include an adjustment for costs incurred in the service year ended May 31, 2011 that were not reflected in the rates charged to customers for that service year. In the second quarter of 2011, ACE recorded a $1 million increase in transmission revenues as a change to the estimates recorded in previous periods primarily due to an increase in the actual rate base versus the estimated rate base. For the nine months ended September 30, 2010, ACE recorded a $2 million increase in transmission service revenue associated with a change to the estimates recorded in previous periods. General and Auto Liability During the second quarter of 2011, ACE reduced its self-insurance reserves for general and auto liability claims by approximately $1 million, based on obtaining an actuarial estimate of the unpaid loss attributed to general and auto liability claims for ACE at June 30, 2011. Consolidation of Variable Interest Entities ACE Power Purchase Agreements (PPAs) ACE is a party to three PPAs with unaffiliated, non-utility generators (NUGs). ACE was unable to obtain sufficient information to determine whether these three entities were variable interest entities or if ACE was the primary beneficiary and as a result has applied the scope exemption from the consolidation guidance for enterprises that have not been able to obtain such information. Net purchase activities with the NUGs for the three months ended September 30, 2011 and 2010 were approximately $57 million and $82 million, respectively, of which approximately $55 million and $74 million, respectively, consisted of power purchases under the PPAs. Net purchase activities with the NUGs for the nine months ended September 30, 2011 and 2010 were approximately $169 million and $222 million, respectively, of which approximately $159 million and $203 million, respectively, consisted of power purchases under the PPAs. The power purchase costs are recoverable from ACE's customers through regulated rates. Atlantic City Electric Transition Funding LLC Atlantic City Electric Transition Funding LLC (ACE Funding) was established in 2001 by ACE solely for the purpose of securitizing authorized portions of ACE's recoverable stranded costs through the issuance and sale of bonds (Transition Bonds). The proceeds of the sale of each series of Transition Bonds have been transferred to ACE in exchange for the transfer by ACE to ACE Funding of the right to collect non-bypassable transition bond charges (the Transition Bond Charges) from ACE customers pursuant to bondable stranded costs rate orders issued by the New Jersey Board of Public Utilities (NJBPU) in an amount sufficient to fund the principal and interest payments on the Transition Bonds and related taxes, expenses and fees (Bondable Transition Property). ACE collects the Transition Bond Charges from its customers on behalf of ACE Funding and the holders of the Transition Bonds. The assets of ACE Funding, including the Bondable Transition Property, and the Transition Bond Charges collected from ACE's customers, are not available to creditors of ACE. The holders of the Transition Bonds have recourse only to the assets of ACE Funding. ACE owns 100 percent of the equity of ACE Funding and consolidates ACE Funding in its financial statements as ACE is the primary beneficiary of ACE Funding under the variable interest entity consolidation guidance. ACE Standard Offer Capacity Agreements On April 28, 2011, ACE entered into three Standard Offer Capacity Agreements (SOCAs) by order of the NJBPU, each with a different generation company. The SOCAs were established under a New Jersey law enacted to promote the construction of qualified electric generation facilities in New Jersey. The SOCAs are 15-year, financially settled transactions approved by the NJBPU that allow generators to receive payments from, or make payments to, ACE based on the difference between the fixed price in the SOCAs and the price for capacity that clears PJM Interconnection, LLC (PJM). Each of the other electricity distribution companies (EDCs) in New Jersey has entered into SOCAs having the same terms with the same generation companies. The annual share of payments or receipts for ACE and the other EDCs is based upon each company's annual proportion of the total New Jersey load attributable to all EDCs. ACE and the other EDCs entered the SOCAs under protest based on concerns about the potential cost to distribution customers. In February 2011, ACE joined other plaintiffs in an action filed in the United States District Court for the District of New Jersey challenging the constitutionality of the New Jersey law. The proceeding is now in the discovery phase. In May 2011, the NJBPU denied a joint motion for reconsideration of its order requiring each of the EDCs to enter into the SOCAs. In June 2011, ACE and the other EDCs filed appeals related to the NJBPU orders with the Appellate Division of the New Jersey Superior Court. On October 17, 2011, one of the generation companies sent a notice of dispute under the SOCA to ACE. The notice of dispute alleges that certain actions taken by PJM have an adverse effect on the generation company's ability to clear the PJM auction as required by the SOCA and, under a provision of the SOCA, ACE and the generation supplier must attempt to amend the SOCA in order to permit transactions to continue thereunder, subject to NJBPU approval. ACE has agreed to meet with the generation supplier, but does not acknowledge that a "dispute" exists under the SOCA. Currently, PHI believes that Financial Accounting Standards Board (FASB) guidance on derivative accounting and the accounting for regulated operations would apply to a SOCA once capacity has cleared a PJM auction. Once cleared, the gain (loss) associated with the fair value of a derivative would be offset by the establishment of a regulatory liability (asset). Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions Taxes included in ACE's gross revenues were $7 million and $8 million for the three months ended September 30, 2011 and 2010, and $17 million and $18 million for the nine months ended September 30, 2011 and 2010. Reclassifications and Adjustments Certain prior period amounts have been reclassified in order to conform to the current period presentation. The following adjustments have been recorded and are not considered material either individually or in the aggregate: Income Tax Adjustments During the second quarter of 2011, ACE completed a reconciliation of its deferred taxes associated with certain regulatory assets and recorded adjustments which resulted in an increase to income tax expense of $1 million for the nine months ended September 30, 2011. During the first quarter of 2010, ACE recorded an adjustment to correct certain income tax errors related to prior periods. The adjustment resulted in an increase in income tax expense of $6 million for the nine months ended September 30, 2010. The adjustment represents the reversal of erroneously recorded interest income for state income tax purposes related to uncertain and effectively settled tax positions, including $2 million, $3 million and $1 million recorded in 2009, 2008 and 2007, respectively.

(2) SIGNIFICANT ACCOUNTING POLICIES

Financial Statement Presentation

Pepco Holdings' unaudited Consolidated Financial Statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP). Pursuant to the rules and regulations of the Securities and Exchange Commission, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with the annual financial statements included in PHI's Annual Report on Form 10-K for the year ended December 31, 2010. In the opinion of PHI's management, the Consolidated Financial Statements contain all adjustments (which all are of a normal recurring nature) necessary to state fairly Pepco Holdings' financial condition as of September 30, 2011, in accordance with GAAP. The year-end December 31, 2010 Consolidated Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and nine months ended September 30, 2011 may not be indicative of PHI's results that will be realized for the full year ending December 31, 2011, since its Power Delivery business and the retail energy supply business of Pepco Energy Services are seasonal.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the Consolidated Financial Statements and accompanying notes. Although Pepco Holdings believes that its estimates and assumptions are reasonable, they are based upon information available to management at the time the estimates are made. Actual results may differ significantly from these estimates.

Significant matters that involve the use of estimates include the assessment of goodwill and long-lived assets for impairment, fair value calculations for certain derivative instruments, the costs of providing pension and other postretirement benefits, evaluation of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of self-insurance reserves for general and auto liability claims, accrual of interest related to income taxes, accrual of restructuring charges, recognition of changes in network service transmission rates for prior service year costs, and the recognition of income tax benefits for investments in finance leases held in trust associated with PHI's portfolio of cross-border energy lease investments. Additionally, PHI is subject to legal, regulatory, and other proceedings and claims that arise in the ordinary course of its business. PHI records an estimated liability for these proceedings and claims, when it is probable that a loss has been incurred and the loss is reasonably estimable.

Storm Costs

During the third quarter of 2011, Pepco, DPL and ACE incurred significant costs associated with Hurricane Irene that affected their respective service territories. Total incremental storm costs associated with Hurricane Irene were $47 million, with $30 million incurred for repair work and $17 million incurred as capital expenditures. Costs incurred for repair work of $24 million were deferred as a regulatory asset to reflect the probable recovery of these storm costs in certain jurisdictions, and the remaining $6 million was charged to Other operation and maintenance expense. Approximately $31 million of these total incremental storm costs have been estimated for the cost of restoration services provided by outside contractors since a large portion of the invoices for such services had not been received at September 30, 2011. Actual invoices may vary from these estimates. PHI's utility subsidiaries currently plan to seek recovery of the incremental Hurricane Irene costs in each of their various jurisdictions in pending or planned distribution rate case filings.

Network Service Transmission Rates

In May 2011, PHI's utility subsidiaries filed their network service transmission rates with the Federal Energy Regulatory Commission effective for the service year beginning June 1, 2011. The new rates include an adjustment for costs incurred in the service year ended May 31, 2011 that were not reflected in the rates charged to customers for that service year. In the second quarter of 2011, PHI's utility subsidiaries recorded a $3 million decrease in transmission revenues as a change to the estimates recorded in previous periods primarily due to a decrease in the actual rate base versus the estimated rate base.

For the nine months ended September 30, 2010, PHI's utilities recorded an $8 million increase in transmission revenues associated with a change to the estimates recorded in previous periods.

General and Auto Liability

During the second quarter of 2011, PHI's utility subsidiaries reduced their self-insurance reserves for general and auto liability claims by approximately $5 million, based on obtaining an actuarial estimate of the unpaid loss attributed to general and auto liability claims for each of PHI's utility subsidiaries at June 30, 2011.

Consolidation of Variable Interest Entities

In accordance with the provisions of the Financial Accounting Standards Board (FASB) guidance on the consolidation of variable interest entities (Accounting Standards Codification (ASC) 810), Pepco Holdings consolidates variable interest entities with respect to which Pepco Holdings or a subsidiary is the primary beneficiary. The guidance addresses conditions under which an entity should be consolidated based upon variable interests rather than voting interests. The subsidiaries of Pepco Holdings have contractual arrangements with several entities to which the guidance applies.

ACE Power Purchase Agreements

PHI, through its ACE subsidiary, is a party to three power purchase agreements (PPAs) with unaffiliated, non-utility generators (NUGs). PHI was unable to obtain sufficient information to determine whether these three entities were variable interest entities or if ACE was the primary beneficiary and as a result has applied the scope exemption from the consolidation guidance for enterprises that have not been able to obtain such information.

Net purchase activities with the NUGs for the three months ended September 30, 2011 and 2010, were approximately $57 million and $82 million, respectively, of which approximately $55 million and $74 million, respectively, consisted of power purchases under the PPAs. Net purchase activities with the NUGs for the nine months ended September 30, 2011 and 2010, were approximately $169 million and $222 million, respectively, of which approximately $159 million and $203 million, respectively, consisted of power purchases under the PPAs. The power purchase costs are recoverable from ACE's customers through regulated rates.

DPL Renewable Energy Transactions

DPL is subject to Renewable Energy Portfolio Standards (RPS) in the state of Delaware that require it to obtain renewable energy credits (RECs) for energy delivered to its customers. DPL's costs associated with obtaining RECs to fulfill its RPS obligations are recoverable from its customers by law. PHI, through its DPL subsidiary, has entered into three land-based wind PPAs and one offshore wind PPA in the aggregate amount of 328 megawatts and one solar PPA with a 10 megawatt facility as of September 30, 2011. As the wind facilities become operational, DPL is obligated to purchase energy and RECs in amounts generated and delivered by the facilities at rates that are primarily fixed under these agreements. Under one of the PPAs, DPL is also obligated to purchase the capacity associated with the facility at rates that are generally fixed. If a wind facility does not become operational by a specified date, DPL has the right to terminate that PPA. DPL concluded that consolidation is not required for any of these agreements under FASB guidance on the consolidation of variable interest entities.

Two of the land-based facilities are operational and DPL is obligated to purchase energy and RECs from one of these facilities through 2024 in amounts not to exceed 50.25 megawatts and the second of these facilities through 2031 in amounts not to exceed 40 megawatts. DPL's purchases under the operational wind PPAs totaled $3 million and $2 million for the three months ended September 30, 2011 and 2010, respectively, and $12 million and $8 million for the nine months ended September 30, 2011 and 2010, respectively. The other land-based wind agreement has a 20-year term and the facility is currently expected to become operational during 2011. In July 2011, the Delaware Public Service Commission (DPSC) approved amendments to this land-based wind PPA to change the location of the facility and to reduce the maximum generation capacity from 60 megawatts to 38 megawatts.

The offshore wind facility is expected to become operational during 2016. If the offshore wind facility developer is unable to obtain all necessary permits and financing commitments, this could result in delays in the construction schedule and the operational start date of the offshore wind facility.

The solar facility began operations in the third quarter of 2011. The term of the agreement with the solar facility is 20 years and DPL is obligated to purchase RECs in an amount up to 70 percent of the energy output at a fixed price. DPL's purchases under the agreement were $1 million during the third quarter of 2011.

On October 18, 2011, the DPSC approved a tariff submitted by DPL specific to a 30 megawatt fuel cell facility to be constructed using fuel cells manufactured in the State of Delaware. The RPS require that the DPSC establish an irrevocable tariff under which DPL would be an agent that collects payments from its customers and disburses the amounts collected to a Qualified Fuel Cell Provider that deploys Delaware-manufactured fuel cells as part of a 30 megawatt generation facility. The tariff and the RPS establish that DPL would be an agent to collect payments in advance from its distribution customers and remit them to the Qualified Fuel Cell Provider for each megawatt hour of energy produced over 20 years. DPL would have no liability to the Qualified Fuel Cell Provider other than to remit payments collected from its distribution customers pursuant to the tariff. The RPS provide for a reduction in DPL's REC requirements based upon the actual energy output of the facility. PHI is currently assessing the appropriate accounting treatment for the transaction, including the applicability of FASB guidance on the consolidation of variable interest entities, leases, and derivative instruments. PHI's accounting review is expected to be completed in the fourth quarter of 2011.

Atlantic City Electric Transition Funding LLC

Atlantic City Electric Transition Funding LLC (ACE Funding) was established in 2001 by ACE solely for the purpose of securitizing authorized portions of ACE's recoverable stranded costs through the issuance and sale of bonds (Transition Bonds). The proceeds of the sale of each series of Transition Bonds have been transferred to ACE in exchange for the transfer by ACE to ACE Funding of the right to collect non-bypassable transition bond charges (the Transition Bond Charges) from ACE customers pursuant to bondable stranded costs rate orders issued by the New Jersey Board of Public Utilities (NJBPU) in an amount sufficient to fund the principal and interest payments on the Transition Bonds and related taxes, expenses and fees (Bondable Transition Property). ACE collects the Transition Bond Charges from its customers on behalf of ACE Funding and the holders of the Transition Bonds. The assets of ACE Funding, including the Bondable Transition Property, and the Transition Bond Charges collected from ACE's customers, are not available to creditors of ACE. The holders of the Transition Bonds have recourse only to the assets of ACE Funding. ACE owns 100 percent of the equity of ACE Funding and PHI consolidates ACE Funding in its financial statements as ACE is the primary beneficiary of ACE Funding under the variable interest entity consolidation guidance.

ACE Standard Offer Capacity Agreements

On April 28, 2011, ACE entered into three Standard Offer Capacity Agreements (SOCAs) by order of the NJBPU, each with a different generation company. The SOCAs were established under a New Jersey law enacted to promote the construction of qualified electric generation facilities in New Jersey. The SOCAs are 15-year, financially settled transactions approved by the NJBPU that allow generators to receive payments from, or make payments to, ACE based on the difference between the fixed price in the SOCAs and the price for capacity that clears PJM Interconnection, LLC (PJM). Each of the other electricity distribution companies (EDCs) in New Jersey has entered into SOCAs having the same terms with the same generation companies. The annual share of payments or receipts for ACE and the other EDCs is based upon each company's annual proportion of the total New Jersey load attributable to all EDCs. ACE and the other EDCs entered the SOCAs under protest based on concerns about the potential cost to distribution customers. In February 2011, ACE joined other plaintiffs in an action filed in the United States District Court for the District of New Jersey challenging the constitutionality of the New Jersey law. The proceeding is now in the discovery phase. In May 2011, the NJBPU denied a joint motion for reconsideration of its order requiring each of the EDCs to enter into the SOCAs. In June 2011, ACE and the other EDCs filed appeals related to the NJBPU orders with the Appellate Division of the New Jersey Superior Court.

On October 17, 2011, one of the generation companies sent a notice of dispute under the SOCA to ACE. The notice of dispute alleges that certain actions taken by PJM have an adverse effect on the generation company's ability to clear the PJM auction as required by the SOCA and, under a provision of the SOCA, ACE and the generation supplier must attempt to amend the SOCA in order to permit transactions to continue thereunder, subject to NJBPU approval. ACE has agreed to meet with the generation supplier, but does not acknowledge that a "dispute" exists under the SOCA.

Currently, PHI believes that FASB guidance on derivative accounting and the accounting for regulated operations would apply to a SOCA once capacity has cleared a PJM auction. Once cleared, the gain (loss) associated with the fair value of a derivative would be offset by the establishment of a regulatory liability (asset).

Goodwill

Goodwill represents the excess of the purchase price of an acquisition over the fair value of the net assets acquired at the acquisition date. Substantially all of Pepco Holdings' goodwill was generated by Pepco's acquisition of Conectiv in 2002 and is allocated entirely to Pepco Holdings' Power Delivery reporting unit for purposes of impairment testing based on the aggregation of its components. Pepco Holdings tests its goodwill for impairment annually as of November 1 and whenever an event occurs or circumstances change in the interim that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Factors that may result in an interim impairment test include, but are not limited to: a change in the identified reporting units; an adverse change in business conditions; a decline in PHI's stock price causing market capitalization to fall further below book value; an adverse regulatory action; or an impairment of long-lived assets in the reporting unit. PHI concluded that an interim impairment test was not required during the three months ended September 30, 2011.

Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions

Taxes included in Pepco Holdings' gross revenues were $111 million and $118 million for the three months ended September 30, 2011 and 2010, respectively, and $302 million and $280 million for the nine months ended September 30, 2011 and 2010, respectively.

Reclassifications and Adjustments

Certain prior period amounts have been reclassified in order to conform to the current period presentation. The following adjustments have been recorded and are not considered material either individually or in the aggregate:

Default Electricity Supply Revenue and Costs Adjustments

During 2011, DPL recorded adjustments associated with the accounting for Default Electricity Supply revenue and costs. These adjustments were primarily due to the under-recognition of allowed returns on working capital and under-recoveries of administrative costs and resulted in a pre-tax decrease in Other operation and maintenance expense of $1 million and $9 million for the three and nine months ended September 30, 2011, respectively.

Pepco Energy Services Derivative Accounting Adjustments

During the first quarter of 2011, PHI recorded an adjustment associated with an increase in the value of certain derivatives from October 1, 2010 to December 31, 2010, which had been erroneously recorded in other comprehensive income at December 31, 2010. This adjustment resulted in an increase in revenue and pre-tax earnings of $2 million for the nine months ended September 30, 2011.

Other Taxes Adjustment

In the third quarter of 2010, Pepco recorded an adjustment to correct certain errors related to other taxes which resulted in a decrease to Other taxes expense of $5 million (pre-tax) for the three and nine months ended September 30, 2010.

Income Tax Adjustments

During the first quarter of 2011, Pepco recorded an adjustment to correct certain income tax errors related to prior periods associated with the interest on uncertain tax positions. The adjustment resulted in an increase in income tax expense of $1 million for the nine months ended September 30, 2011.

During the second quarter of 2010, PHI recorded an adjustment to correct certain income tax errors associated with casualty loss claims, which resulted in a decrease to income tax expense of $1 million for the nine months ended September 30, 2010.

During the first quarter of 2010, ACE recorded an adjustment to correct certain income tax errors related to prior periods. The adjustment resulted in an increase in income tax expense of $6 million for the nine months ended September 30, 2010. The adjustment represents the reversal of erroneously recorded interest income for state income tax purposes related to uncertain and effectively settled tax positions, including $2 million, $3 million and $1 million recorded in 2009, 2008 and 2007, respectively.

During 2010, PHI recorded various adjustments to income tax expense to reflect primarily the benefit from additional deductions related to executive compensation that had erroneously not been included in tax returns prior to 2008, a reduction in income tax expense associated with errors related to the deferred tax assets established in connection with the District of Columbia net operating losses, and an increase to income tax expense associated with the reversal of erroneously recorded interest income for state income tax purposes related to uncertain and effectively settled tax positions. These adjustments resulted in a decrease to income tax expense of $7 million related to continuing operations for the three months ended September 30, 2010 and a decrease to income tax expense of $1 million related to continuing operations for the nine months ended September 30, 2010.

In the third quarter of 2010, Pepco recorded certain adjustments to correct errors in Income tax expense which resulted in an increase to Income tax expense of $4 million for the three and nine months ended September 30, 2010.

Discontinued Operations

In the third quarter of 2010, PHI recorded adjustments to reverse revenue erroneously recognized in the second quarter of 2010 associated with its discontinued operations. The adjustments resulted in an increase in net loss from discontinued operations of $7 million (pre-tax) for the three months ended September 30, 2010.

Significant Accounting Policies

(2) SIGNIFICANT ACCOUNTING POLICIES

Financial Statement Presentation

Pepco's unaudited financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP). Pursuant to the rules and regulations of the Securities and Exchange Commission, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with the annual financial statements included in Pepco's Annual Report on Form 10-K for the year ended December 31, 2010. In the opinion of Pepco's management, the financial statements contain all adjustments (which all are of a normal recurring nature) necessary to state fairly Pepco's financial condition as of September 30, 2011, in accordance with GAAP. The year-end December 31, 2010 Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and nine months ended September 30, 2011 may not be indicative of results that will be realized for the full year ending December 31, 2011 since the sales of electric energy are seasonal.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the financial statements and accompanying notes. Although Pepco believes that its estimates and assumptions are reasonable, they are based upon information available to management at the time the estimates are made. Actual results may differ significantly from these estimates.

Significant matters that involve the use of estimates include the assessment of contingencies, the calculation of future cash flows and fair value amounts for use in asset impairment evaluations, pension and other postretirement benefits assumptions, unbilled revenue calculations, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of restructuring charges, recognition of changes in network service transmission rates for prior service year costs, accrual of self-insurance reserves for general and auto liability claims and income tax provisions and reserves. Additionally, Pepco is subject to legal, regulatory, and other proceedings and claims that arise in the ordinary course of its business. Pepco records an estimated liability for these proceedings and claims when it is probable that a loss has been incurred and the loss is reasonably estimable.

Storm Costs

During the third quarter of 2011, Pepco incurred significant costs associated with Hurricane Irene that affected its service territory. Total incremental storm costs associated with Hurricane Irene were $22 million, with $14 million incurred for repair work and $8 million incurred as capital expenditures. Costs incurred for repair work of $12 million were deferred as a regulatory asset to reflect the probable recovery of these storm costs in Pepco's jurisdictions, and the remaining $2 million was charged to Other operation and maintenance expense. Approximately $16 million of these total incremental storm costs have been estimated for the cost of restoration services provided by outside contractors since a large portion of the invoices for such services had not been received at September 30, 2011. Actual invoices may vary from these estimates. Pepco currently plans to seek recovery of the incremental Hurricane Irene costs in each of its jurisdictions in pending or planned distribution rate case filings.

Network Service Transmission Rates

In May 2011, Pepco filed its network service transmission rates with the Federal Energy Regulatory Commission effective for the service year beginning June 1, 2011. The new rates include an adjustment for costs incurred in the service year ended May 31, 2011 that were not reflected in the rates charged to customers for that service year. In the second quarter of 2011, Pepco recorded a $2 million decrease in transmission revenues as a change to the estimates recorded in previous periods primarily due to a decrease in the actual rate base versus the estimated rate base.

For the nine months ended September 30, 2010, Pepco recorded a $3 million increase in transmission service revenue associated with a change to the estimates recorded in previous periods.

General and Auto Liability

During the second quarter of 2011, Pepco reduced its self-insurance reserves for general and auto liability claims by approximately $1 million, based on obtaining an actuarial estimate of the unpaid loss attributable to general and auto liability claims for Pepco at June 30, 2011.

Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions

Taxes included in Pepco's gross revenues were $100 million and $106 million for the three months ended September 30, 2011 and 2010, respectively, and $271 million and $249 million for the nine months ended September 30, 2011 and 2010, respectively.

Reclassifications and Adjustments

Certain prior period amounts have been reclassified in order to conform to the current period presentation. The following adjustments have been recorded which are not considered material individually or in the aggregate:

Income Tax Adjustments

During the first quarter of 2011, Pepco recorded an adjustment to correct certain income tax errors related to prior periods associated with the interest on uncertain tax positions. The adjustment resulted in an increase in income tax expense of $1 million for the nine months ended September 30, 2011.

In the third quarter of 2010, Pepco recorded certain adjustments to correct errors in Income tax expense which resulted in an increase to Income tax expense of $4 million for the three and nine months ended September 30, 2010.

Other Taxes Adjustment

In the third quarter of 2010, Pepco recorded an adjustment to correct certain errors related to other taxes which resulted in a decrease to Other taxes expense of $5 million (pre-tax) for the three and nine months ended September 30, 2010.

Significant Accounting Policies

(2) SIGNIFICANT ACCOUNTING POLICIES

Financial Statement Presentation

DPL's unaudited financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP). Pursuant to the rules and regulations of the Securities and Exchange Commission, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with the annual financial statements included in DPL's Annual Report on Form 10-K for the year ended December 31, 2010. In the opinion of DPL's management, the financial statements contain all adjustments (which all are of a normal recurring nature) necessary to state fairly DPL's financial condition as of September 30, 2011, in accordance with GAAP. The year-end December 31, 2010 Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and nine months ended September 30, 2011 may not be indicative of results that will be realized for the full year ending December 31, 2011 since the sales of electric energy and natural gas are seasonal.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the financial statements and accompanying notes. Although DPL believes that its estimates and assumptions are reasonable, they are based upon information available to management at the time the estimates are made. Actual results may differ significantly from these estimates.

Significant matters that involve the use of estimates include the assessment of contingencies, the calculation of future cash flows and fair value amounts for use in asset and goodwill impairment evaluations, fair value calculations for derivative instruments, pension and other postretirement benefits assumptions, unbilled revenue calculations, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of restructuring charges, recognition of changes in network service transmission rates for prior service year costs, accrual of self-insurance reserves for general and auto liability claims and income tax provisions and reserves. Additionally, DPL is subject to legal, regulatory, and other proceedings and claims that arise in the ordinary course of its business. DPL records an estimated liability for these proceedings and claims when it is probable that a loss has been incurred and the loss is reasonably estimable.

Storm Costs

During the third quarter of 2011, DPL incurred significant costs associated with Hurricane Irene that affected its service territory. Total incremental storm costs associated with Hurricane Irene were $12 million, with $9 million incurred for repair work and $3 million incurred as capital expenditures. Costs incurred for repair work of $5 million were deferred as a regulatory asset to reflect the probable recovery of these storm costs in DPL's jurisdictions, and the remaining $4 million was charged to Other operation and maintenance expense. Approximately $7 million of these total incremental storm costs have been estimated for the cost of restoration services provided by outside contractors since a large portion of the invoices for such services had not been received at September 30, 2011. Actual invoices may vary from these estimates. DPL currently plans to seek recovery of the incremental Hurricane Irene costs in each of its jurisdictions in planned distribution rate case filings.

Network Service Transmission Rates

In May 2011, DPL filed its network service transmission rates with the Federal Energy Regulatory Commission effective for the service year beginning June 1, 2011. The new rates include an adjustment for costs incurred in the service year ended May 31, 2011 that were not reflected in the rates charged to customers for that service year. In the second quarter of 2011, DPL recorded a $2 million decrease in transmission revenues as a change to the estimates recorded in previous periods due to a decrease in the actual rate base versus the estimated rate base.

For the nine months ended September 30, 2010, DPL recorded a $3 million increase in transmission service revenue associated with a change to the estimates recorded in previous periods.

General and Auto Liability

During the second quarter of 2011, DPL reduced its self-insurance reserves for general and auto liability claims by approximately $3 million, based on obtaining an actuarial estimate of the unpaid loss attributed to general and auto liability claims for DPL at June 30, 2011.

Consolidation of Variable Interest Entities – DPL Renewable Energy Transactions

DPL is subject to Renewable Energy Portfolio Standards (RPS) in the state of Delaware that require it to obtain renewable energy credits (RECs) for energy delivered to its customers. DPL's costs associated with obtaining RECs to fulfill its RPS obligations are recoverable from its customers by law. PHI, through its DPL subsidiary, has entered into three land-based wind power purchase agreements (PPAs) and one offshore wind PPA in the aggregate amount of 328 megawatts and one solar PPA with a 10 megawatt facility as of September 30, 2011. As the wind facilities become operational, DPL is obligated to purchase energy and RECs in amounts generated and delivered by the facilities at rates that are primarily fixed under these agreements. Under one of the PPAs, DPL is also obligated to purchase the capacity associated with the facility at rates that are generally fixed. If a wind facility does not become operational by a specified date, DPL has the right to terminate that PPA. DPL concluded that consolidation is not required for any of these agreements under FASB guidance on the consolidation of variable interest entities.

Two of the land-based facilities are operational and DPL is obligated to purchase energy and RECs from one of these facilities through 2024 in amounts not to exceed 50.25 megawatts and the second of these facilities through 2031 in amounts not to exceed 40 megawatts. DPL's purchases under the operational wind PPAs totaled $3 million and $2 million for the three months ended September 30, 2011 and 2010, respectively, and $12 million and $8 million for the nine months ended September 30, 2011 and 2010, respectively. The other land-based wind agreement has a 20-year term and the facility is currently expected to become operational during 2011. In July 2011, the Delaware Public Service Commission (DPSC) approved amendments to this land-based wind PPA to change the location of the facility and to reduce the maximum generation capacity from 60 megawatts to 38 megawatts.

The offshore wind facility is expected to become operational during 2016. If the offshore wind facility developer is unable to obtain all necessary permits and financing commitments, this could result in delays in the construction schedule and the operational start date of the offshore wind facility.

The solar facility began operations in the third quarter of 2011. The term of the agreement with the solar facility is 20 years and DPL is obligated to purchase RECs in an amount up to 70 percent of the energy output at a fixed price. DPL's purchases under the agreement were $1 million during the third quarter of 2011.

On October 18, 2011, the DPSC approved a tariff submitted by DPL specific to a 30 megawatt fuel cell facility to be constructed using fuel cells manufactured in the State of Delaware. The RPS require that the DPSC establish an irrevocable tariff under which DPL would be an agent that collects payments from its customers and disburses the amounts collected to a Qualified Fuel Cell Provider that deploys Delaware-manufactured fuel cells as part of a 30 megawatt generation facility. The tariff and the RPS establish that DPL would be an agent to collect payments in advance from its distribution customers and remit them to the Qualified Fuel Cell Provider for each megawatt hour of energy produced over 20 years. DPL would have no liability to the Qualified Fuel Cell Provider other than to remit payments collected from its distribution customers pursuant to the tariff. The RPS provide for a reduction in DPL's REC requirements based upon the actual energy output of the facility. PHI is currently assessing the appropriate accounting treatment for the transaction, including the applicability of FASB guidance on the consolidation of variable interest entities, leases, and derivative instruments. PHI's accounting review is expected to be completed in the fourth quarter of 2011.

Goodwill

Goodwill represents the excess of the purchase price of an acquisition over the fair value of the net assets acquired at the acquisition date. All of DPL's goodwill was generated by DPL's acquisition of Conowingo Power Company in 1995. DPL tests its goodwill for impairment annually and whenever an event occurs or circumstances change in the interim that would more likely than not reduce the fair value of DPL below its carrying amount. DPL performs its annual impairment test on November 1. Factors that may result in an interim impairment test include, but are not limited to: a change in the identified reporting units; an adverse change in business conditions; an adverse regulatory action; or an impairment of DPL's long-lived assets. DPL concluded that an interim impairment test was not required during the three months ended September 30, 2011.

Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions

Taxes included in DPL's gross revenues were $4 million for each of the three months ended September 30, 2011 and 2010 and $14 million and $13 million for the nine months ended September 30, 2011 and 2010, respectively.

Reclassifications and adjustments

Certain prior period amounts have been reclassified to conform to current period presentation. The following adjustment has been recorded and is not considered material.

Default Electricity Supply Revenue and Costs Adjustments

During 2011, DPL recorded adjustments associated with the accounting for Default Electricity Supply revenue and costs. These adjustments were primarily due to the under-recognition of allowed returns on working capital and administrative costs and resulted in a pre-tax decrease in Other operation and maintenance expense of $1 million and $9 million for the three and nine months ended September 30, 2011, respectively.

Significant Accounting Policies

(2) SIGNIFICANT ACCOUNTING POLICIES

Financial Statement Presentation

ACE's unaudited Consolidated Financial Statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP). Pursuant to the rules and regulations of the Securities and Exchange Commission, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with the annual financial statements included in ACE's Annual Report on Form 10-K for the year ended December 31, 2010. In the opinion of ACE's management, the Consolidated Financial Statements contain all adjustments (which all are of a normal recurring nature) necessary to state fairly ACE's financial condition as of September 30, 2011, in accordance with GAAP. The year-end December 31, 2010 Consolidated Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and nine months ended September 30, 2011 may not be indicative of results that will be realized for the full year ending December 31, 2011 since the sales of electric energy are seasonal.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the Consolidated Financial Statements and accompanying notes. Although ACE believes that its estimates and assumptions are reasonable, they are based upon information available to management at the time the estimates are made. Actual results may differ significantly from these estimates.

Significant matters that involve the use of estimates include the assessment of contingencies, the calculation of future cash flows and fair value amounts for use in asset impairment evaluations, pension and other postretirement benefits assumptions, unbilled revenue calculations, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of restructuring charges, recognition of changes in network service transmission rates for prior service year costs, accrual of self-insurance reserves for general and auto liability claims and income tax provisions and reserves. Additionally, ACE is subject to legal, regulatory, and other proceedings and claims that arise in the ordinary course of its business. ACE records an estimated liability for these proceedings and claims when it is probable that a loss has been incurred and the loss is reasonably estimable.

Storm Costs

During the third quarter of 2011, ACE incurred significant costs associated with Hurricane Irene that affected its service territory. Total incremental storm costs associated with Hurricane Irene were $13 million, with $7 million incurred for repair work and $6 million incurred as capital expenditures. All costs incurred for repair work were deferred as a regulatory asset to reflect the probable recovery of these storm costs. Approximately $8 million of these total incremental storm costs have been estimated for the cost of restoration services provided by outside contractors since a large portion of the invoices for such services had not been received at September 30, 2011. Actual invoices may vary from these estimates. ACE currently plans to seek recovery of the incremental Hurricane Irene costs as discussed in Note (11), "Commitments and Contingencies—Rate Proceedings".

Network Service Transmission Rates

In May 2011, ACE filed its network service transmission rates with the Federal Energy Regulatory Commission effective for the service year beginning June 1, 2011. The new rates include an adjustment for costs incurred in the service year ended May 31, 2011 that were not reflected in the rates charged to customers for that service year. In the second quarter of 2011, ACE recorded a $1 million increase in transmission revenues as a change to the estimates recorded in previous periods primarily due to an increase in the actual rate base versus the estimated rate base.

For the nine months ended September 30, 2010, ACE recorded a $2 million increase in transmission service revenue associated with a change to the estimates recorded in previous periods.

General and Auto Liability

During the second quarter of 2011, ACE reduced its self-insurance reserves for general and auto liability claims by approximately $1 million, based on obtaining an actuarial estimate of the unpaid loss attributed to general and auto liability claims for ACE at June 30, 2011.

Consolidation of Variable Interest Entities

ACE Power Purchase Agreements (PPAs)

ACE is a party to three PPAs with unaffiliated, non-utility generators (NUGs). ACE was unable to obtain sufficient information to determine whether these three entities were variable interest entities or if ACE was the primary beneficiary and as a result has applied the scope exemption from the consolidation guidance for enterprises that have not been able to obtain such information.

Net purchase activities with the NUGs for the three months ended September 30, 2011 and 2010 were approximately $57 million and $82 million, respectively, of which approximately $55 million and $74 million, respectively, consisted of power purchases under the PPAs. Net purchase activities with the NUGs for the nine months ended September 30, 2011 and 2010 were approximately $169 million and $222 million, respectively, of which approximately $159 million and $203 million, respectively, consisted of power purchases under the PPAs. The power purchase costs are recoverable from ACE's customers through regulated rates.

Atlantic City Electric Transition Funding LLC

Atlantic City Electric Transition Funding LLC (ACE Funding) was established in 2001 by ACE solely for the purpose of securitizing authorized portions of ACE's recoverable stranded costs through the issuance and sale of bonds (Transition Bonds). The proceeds of the sale of each series of Transition Bonds have been transferred to ACE in exchange for the transfer by ACE to ACE Funding of the right to collect non-bypassable transition bond charges (the Transition Bond Charges) from ACE customers pursuant to bondable stranded costs rate orders issued by the New Jersey Board of Public Utilities (NJBPU) in an amount sufficient to fund the principal and interest payments on the Transition Bonds and related taxes, expenses and fees (Bondable Transition Property). ACE collects the Transition Bond Charges from its customers on behalf of ACE Funding and the holders of the Transition Bonds. The assets of ACE Funding, including the Bondable Transition Property, and the Transition Bond Charges collected from ACE's customers, are not available to creditors of ACE. The holders of the Transition Bonds have recourse only to the assets of ACE Funding. ACE owns 100 percent of the equity of ACE Funding and consolidates ACE Funding in its financial statements as ACE is the primary beneficiary of ACE Funding under the variable interest entity consolidation guidance.

ACE Standard Offer Capacity Agreements

On April 28, 2011, ACE entered into three Standard Offer Capacity Agreements (SOCAs) by order of the NJBPU, each with a different generation company. The SOCAs were established under a New Jersey law enacted to promote the construction of qualified electric generation facilities in New Jersey. The SOCAs are 15-year, financially settled transactions approved by the NJBPU that allow generators to receive payments from, or make payments to, ACE based on the difference between the fixed price in the SOCAs and the price for capacity that clears PJM Interconnection, LLC (PJM). Each of the other electricity distribution companies (EDCs) in New Jersey has entered into SOCAs having the same terms with the same generation companies. The annual share of payments or receipts for ACE and the other EDCs is based upon each company's annual proportion of the total New Jersey load attributable to all EDCs. ACE and the other EDCs entered the SOCAs under protest based on concerns about the potential cost to distribution customers. In February 2011, ACE joined other plaintiffs in an action filed in the United States District Court for the District of New Jersey challenging the constitutionality of the New Jersey law. The proceeding is now in the discovery phase. In May 2011, the NJBPU denied a joint motion for reconsideration of its order requiring each of the EDCs to enter into the SOCAs. In June 2011, ACE and the other EDCs filed appeals related to the NJBPU orders with the Appellate Division of the New Jersey Superior Court.

On October 17, 2011, one of the generation companies sent a notice of dispute under the SOCA to ACE. The notice of dispute alleges that certain actions taken by PJM have an adverse effect on the generation company's ability to clear the PJM auction as required by the SOCA and, under a provision of the SOCA, ACE and the generation supplier must attempt to amend the SOCA in order to permit transactions to continue thereunder, subject to NJBPU approval. ACE has agreed to meet with the generation supplier, but does not acknowledge that a "dispute" exists under the SOCA.

Currently, PHI believes that Financial Accounting Standards Board (FASB) guidance on derivative accounting and the accounting for regulated operations would apply to a SOCA once capacity has cleared a PJM auction. Once cleared, the gain (loss) associated with the fair value of a derivative would be offset by the establishment of a regulatory liability (asset).

Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions

Taxes included in ACE's gross revenues were $7 million and $8 million for the three months ended September 30, 2011 and 2010, and $17 million and $18 million for the nine months ended September 30, 2011 and 2010.

Reclassifications and Adjustments

Certain prior period amounts have been reclassified in order to conform to the current period presentation. The following adjustments have been recorded and are not considered material either individually or in the aggregate:

Income Tax Adjustments

During the second quarter of 2011, ACE completed a reconciliation of its deferred taxes associated with certain regulatory assets and recorded adjustments which resulted in an increase to income tax expense of $1 million for the nine months ended September 30, 2011.

During the first quarter of 2010, ACE recorded an adjustment to correct certain income tax errors related to prior periods. The adjustment resulted in an increase in income tax expense of $6 million for the nine months ended September 30, 2010. The adjustment represents the reversal of erroneously recorded interest income for state income tax purposes related to uncertain and effectively settled tax positions, including $2 million, $3 million and $1 million recorded in 2009, 2008 and 2007, respectively.