Significant Accounting Policies	6 Months Ended
Significant Accounting Policies	Jun. 30, 2012
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 consolidated financial statements prepared in accordance with GAAP have been omitted. Therefore, these consolidated financial statements should be read along with the annual consolidated financial statements included in PHI’s annual report on Form 10-K for the year ended December 31, 2011, as amended to include the executive compensation and other information required by Part III of Form 10-K (which information originally had been omitted as permitted by that form). 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 June 30, 2012, in accordance with GAAP. The year-end December 31, 2011 consolidated balance sheet included herein was derived from audited consolidated financial statements, but does not include all disclosures required by GAAP. Interim results for the three and six months ended June 30, 2012 may not be indicative of PHI’s results that will be realized for the full year ending December 31, 2012. 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 contingencies, the calculation of future cash flows and fair value amounts for use in asset and goodwill impairment calculations, fair value calculations for derivative instruments, pension and other postretirement benefit assumptions, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of unbilled revenue, recognition of changes in network service transmission rates for prior service year costs, accrual of self-insurance reserves for general and auto liability claims, accrual of interest related to income taxes, 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, and income tax provisions and reserves. 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 Restoration Costs On June 29, 2012, the respective service territories of Pepco, DPL and ACE were affected by a rapidly moving thunderstorm with hurricane-force winds, known as a “derecho,” which resulted in widespread customer outages in each of the service territories. The derecho caused extensive damage to the electric transmission and distribution systems of Pepco, DPL and ACE. Storm restoration activity commenced immediately following the storm and continued into July 2012, with the majority of the incremental storm restoration costs occurring after the end of the second quarter of 2012. Total incremental storm restoration costs incurred by PHI through June 30, 2012 were $3.0 million, with $1.8 million incurred for repair work and $1.2 million incurred as capital expenditures. Costs incurred for repair work of $1.5 million were deferred as regulatory assets to reflect the probable recovery of these storm restoration costs in Maryland and New Jersey, and $0.3 million was charged to Other operation and maintenance expense. All of these total incremental storm restoration costs have been estimated for the cost of restoration services provided by outside contractors since the invoices for such services had not been received at June 30, 2012. Actual invoices may vary from these estimates. The total incremental storm restoration costs of PHI associated with the derecho are currently estimated to range between $70 million and $85 million. This range was developed using estimates of costs related to mutual assistance and contractor services, materials and supplies, and other expenses, and actual costs may vary from these estimates. A portion of the costs will be expensed with the balance being charged to capital. A portion of the costs expensed will be deferred as regulatory assets to reflect the probable recovery of these storm restoration costs in Maryland and New Jersey. PHI’s utility subsidiaries will be pursuing recovery of the incremental storm restoration costs in their respective jurisdictions during the next cycle of distribution base rate cases. 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 $4 million, based on obtaining an actuarial estimate of the unpaid losses attributed to general and auto liability claims for each of PHI’s utility subsidiaries at June 30, 2011. Consolidation of Variable Interest Entities PHI assesses its contractual arrangements with variable interest entities to determine whether it is the primary beneficiary and thereby has to consolidate the entities in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 810. The guidance addresses conditions under which an entity should be consolidated based upon variable interests rather than voting interests. Subsidiaries of PHI have the following contractual arrangements 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) totaling 459 megawatts. One of the agreements ends in 2016 and the other two end in 2024. PHI was unable to obtain sufficient information to determine whether these three entities were variable interest entities or if ACE was the primary beneficiary. As a result, PHI 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 June 30, 2012 and 2011 were approximately $49 million and $55 million, respectively, of which approximately $47 million and $51 million, respectively, consisted of power purchases under the PPAs. Net purchase activities with the NUGs for the six months ended June 30, 2012 and 2011 were approximately $100 million and $112 million, respectively, of which approximately $98 million and $104 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. As of June 30, 2012, PHI, through its DPL subsidiary, has entered into three land-based wind PPAs in the aggregate amount of 128 megawatts and one solar PPA with a 10 megawatt facility. All of the facilities associated with these PPAs are operational, and DPL is obligated to purchase energy and RECs in amounts generated and delivered by the wind facilities and solar renewable energy credits (SRECs) from the solar facility up to certain amounts (as set forth below) at rates that are primarily fixed under the PPAs. PHI has concluded that consolidation is not required for any of these PPAs under the FASB guidance on the consolidation of variable interest entities. DPL is obligated to purchase energy and RECs from one of the wind facilities through 2024 in amounts not to exceed 50 megawatts, from the second wind facility through 2031 in amounts not to exceed 40 megawatts, and from the third wind facility through 2031 in amounts not to exceed 38 megawatts. DPL’s purchases under the three wind PPAs totaled $6 million and $4 million for the three months ended June 30, 2012 and 2011, respectively, and $15 million and $9 million for the six months ended June 30, 2012 and 2011, respectively. The term of the agreement with the solar facility is 20 years and DPL is obligated to purchase SRECs in an amount up to 70 percent of the energy output at a fixed price. DPL’s purchases under the solar agreement were less than $1 million for the three and six months ended June 30, 2012. On October 18, 2011, the Delaware Public Service Commission (DPSC) approved a tariff submitted by DPL in accordance with the requirements of the RPS specific to fuel cell facilities totaling 30 megawatts to be constructed by a qualified fuel cell provider. 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 by the fuel cell facilities over 21 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 provides for a reduction in DPL’s REC requirements based upon the actual energy output of the facilities. In June 2012, a 3 megawatt fuel cell generation facility was placed into service under the tariff. DPL billed less than $1 million to distribution customers during the three and six months ended June 30, 2012. A 27 megawatt fuel cell generation facility is expected to be placed into service in 5 megawatt increments beginning in January 2013. DPL is accounting for this arrangement as an agency transaction. 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 In April 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 generation companies to receive payments from, or require them to 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 electric 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, which is currently estimated to be approximately 15 percent for ACE. The NJBPU has approved full recovery from distribution customers of payments made by ACE and the other EDCs, and distribution customers would be entitled to any payments received from the generation companies. In May 2012, all three generators under the SOCAs bid into the PJM 2015-2016 capacity auction and two of the generators cleared that capacity auction. ACE recorded a derivative asset (liability) for the estimated fair value of each SOCA and recorded an offsetting regulatory liability (asset) as described in more detail in Note (13), “Derivative Instruments and Hedging Activities”, and Note (14), “Fair Value Disclosures.” FASB guidance on derivative accounting and the accounting for regulated operations would apply to ACE’s obligations under the third SOCA once the related capacity has cleared a PJM auction. The next PJM capacity auction is scheduled for May 2013. PHI has concluded that consolidation is not required for the SOCAs under the FASB guidance on the consolidation of variable interest entities. 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 (now Conectiv, LLC (Conectiv)) in 2002 and is allocated entirely to Power Delivery for purposes of impairment testing based on the aggregation of its components because its utilities have similar characteristics. 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 the carrying amount of its net assets. 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 protracted decline in PHI’s stock price causing market capitalization to fall 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 six months ended June 30, 2012. Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions Taxes included in Pepco Holdings’ gross revenues were $93 million and $94 million for the three months ended June 30, 2012 and 2011, respectively, and $184 million and $190 million for the six months ended June 30, 2012 and 2011, respectively. Reclassifications and Adjustments Certain prior period amounts have been reclassified in order to conform to the current period presentation. The following reclassifications and adjustments have been recorded and are not considered material either individually or in the aggregate: Pepco Energy Services Derivative Accounting Adjustments In the second quarter of 2012, PHI recorded an adjustment to reclassify certain 2011 mark-to-market losses from Operating revenue to Fuel and purchased energy expenses for Pepco Energy Services. The reclassification resulted in an increase in Operating revenue and an increase in Fuel and purchased energy expenses of $3 million and $7 million for the three and six months ended June 30, 2011, respectively. This reclassification did not result in a change to net income. 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 six months ended June 30, 2011. DPL Operating Revenue Adjustment In the second quarter of 2012, DPL recorded an adjustment to correct an overstatement of unbilled revenue in its natural gas distribution business related to prior periods. The adjustment resulted in a decrease in Operating revenue of $1 million for the three and six months ended June 30, 2012. DPL Default Electricity Supply Revenue and Cost Adjustments During the second quarter of 2011, DPL recorded adjustments to correct certain errors associated with the accounting for Default Electricity Supply revenue and costs. These adjustments primarily arose from the under-recognition of allowed returns on the cost of working capital and resulted in a pre-tax decrease in Other operation and maintenance expense of $8 million for the three and six months ended June 30, 2011. Income Tax Expense Adjustments In the second quarter of 2012, Pepco recorded an adjustment to reduce Income tax expense as a result of the reversal of interest expense erroneously recorded on certain effectively settled income tax positions in the first quarter of 2012. This adjustment resulted in a decrease to Income tax expense of $1 million for the three months ended June 30, 2012. During the first quarter of 2011, Pepco recorded an adjustment to correct certain income tax errors related to prior periods associated with interest on uncertain tax positions. The adjustment resulted in an increase in Income tax expense of $1 million for the six months ended June 30, 2011.
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, 2011, as amended to include the executive compensation and other information required by Part III of Form 10-K (which information originally had been omitted as permitted by that form). 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 June 30, 2012, in accordance with GAAP. The year-end December 31, 2011 balance sheet included herein was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and six months ended June 30, 2012 may not be indicative of results that will be realized for the full year ending December 31, 2012. 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, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of unbilled revenue, 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 Restoration Costs On June 29, 2012, the respective service territories of Pepco were affected by a rapidly moving thunderstorm with hurricane-force winds, known as a “derecho,” which resulted in widespread customer outages in each of the service territories. The derecho caused extensive damage to Pepco’s electric transmission and distribution systems. Storm restoration activity commenced immediately following the storm and continued into July 2012, with the majority of the incremental storm restoration costs occurring after the end of the second quarter of 2012. Total incremental storm restoration costs incurred by Pepco through June 30, 2012 were $1.6 million, with $1.0 million incurred for repair work and $0.6 million incurred as capital expenditures. Costs incurred for repair work of $0.8 million were deferred as regulatory assets to reflect the probable recovery of these storm restoration costs in Maryland, and $0.2 million was charged to Other operation and maintenance expense. All of these total incremental storm restoration costs have been estimated for the cost of restoration services provided by outside contractors since the invoices for such services had not been received at June 30, 2012. Actual invoices may vary from these estimates. The total incremental storm restoration costs of Pepco associated with the derecho are currently estimated to range between $39 million and $47 million. This range was developed using estimates of costs related to mutual assistance and contractor services, materials and supplies, and other expenses, and actual costs may vary from these estimates. A portion of the costs will be expensed with the balance being charged to capital. A portion of the costs expensed will be deferred as regulatory assets to reflect the probable recovery of these storm restoration costs in Maryland. Pepco will be pursuing recovery of the incremental storm restoration costs during the next cycle of distribution base rate cases. 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 losses attributed 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 $86 million and $85 million for the three months ended June 30, 2012 and 2011, respectively, and $169 million and $171 million for the six months ended June 30, 2012 and 2011, 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: Income Tax Expense Adjustments In the second quarter of 2012, Pepco recorded an adjustment to reduce Income tax expense as a result of the reversal of interest expense erroneously recorded on certain effectively settled income tax positions in the first quarter of 2012. This adjustment resulted in a decrease to Income tax expense of $1 million for the three months ended June 30, 2012. During the first quarter of 2011, Pepco recorded an adjustment to correct certain income tax errors related to prior periods associated with interest on uncertain tax positions. The adjustment resulted in an increase in Income tax expense of $1 million for the six months ended June 30, 2011.
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, 2011, as amended to include the executive compensation and other information required by Part III of Form 10-K (which information originally had been omitted as permitted by that form). 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 June 30, 2012, in accordance with GAAP. The year-end December 31, 2011 balance sheet included herein was derived from audited financial statements, but does not include all disclosures required by GAAP. Interim results for the three and six months ended June 30, 2012 may not be indicative of DPL’s results that will be realized for the full year ending December 31, 2012. 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, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of unbilled revenue, 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 Restoration Costs On June 29, 2012, the respective service territories of DPL were affected by a rapidly moving thunderstorm with hurricane-force winds, known as a “derecho,” which resulted in widespread customer outages in each of the service territories. The derecho caused extensive damage to DPL’s electric transmission and distribution systems. Storm restoration activity commenced immediately following the storm and continued into July 2012, with the majority of the incremental storm restoration costs occurring after the end of the second quarter of 2012. Total incremental storm restoration costs incurred by DPL through June 30, 2012 were $0.5 million, with $0.3 million incurred for repair work and $0.2 million incurred as capital expenditures. Costs incurred for repair work of $0.2 million were deferred as regulatory assets to reflect the probable recovery of these storm restoration costs in Maryland, and $0.1 million was charged to Other operation and maintenance expense. All of these total incremental storm restoration costs have been estimated for the cost of restoration services provided by outside contractors since the invoices for such services had not been received at June 30, 2012. Actual invoices may vary from these estimates. The total incremental storm restoration costs of DPL associated with the derecho are currently estimated to range between $2 million and $3 million. This range was developed using estimates of costs related to mutual assistance and contractor services, materials and supplies, and other expenses, and actual costs may vary from these estimates. A portion of the costs will be expensed with the balance being charged to capital. A portion of the costs expensed will be deferred as regulatory assets to reflect the probable recovery of these storm restoration costs in Maryland. DPL will be pursuing recovery of the incremental storm restoration costs during the next cycle of distribution base rate cases. General and Auto Liability During the second quarter of 2011, DPL reduced its self-insurance reserves for general and auto liability claims by approximately $2 million, based on obtaining an actuarial estimate of the unpaid losses attributed to general and auto liability claims for DPL at June 30, 2011. Consolidation of Variable Interest Entities - DPL Renewable Energy Transactions DPL assesses its contractual arrangements with variable interest entities to determine whether it is the primary beneficiary and thereby has to consolidate the entities in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 810. The guidance addresses conditions under which an entity should be consolidated based upon variable interests rather than voting interests. 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. As of June 30, 2012, DPL has entered into three land-based wind power purchase agreements (PPAs) in the aggregate amount of 128 megawatts and one solar PPA with a 10 megawatt facility. All of the facilities associated with these PPAs are operational, and DPL is obligated to purchase energy and RECs in amounts generated and delivered by the wind facilities and solar renewable energy credits (SRECs) from the solar facility up to certain amounts (as set forth below) at rates that are primarily fixed under the PPAs. DPL has concluded that consolidation is not required for any of these PPAs under the FASB guidance on the consolidation of variable interest entities. DPL is obligated to purchase energy and RECs from one of the wind facilities through 2024 in amounts not to exceed 50 megawatts, from the second wind facility through 2031 in amounts not to exceed 40 megawatts, and from the third wind facility through 2031 in amounts not to exceed 38 megawatts. DPL’s purchases under the three wind PPAs totaled $6 million and $4 million for the three months ended June 30, 2012 and 2011, respectively, and $15 million and $9 million for the six months ended June 30, 2012 and 2011, respectively. The term of the agreement with the solar facility is 20 years and DPL is obligated to purchase SRECs in an amount up to 70 percent of the energy output at a fixed price. DPL’s purchases under the solar agreement were less than $1 million for the three and six months ended June 30, 2012. On October 18, 2011, the Delaware Public Service Commission (DPSC) approved a tariff submitted by DPL in accordance with the requirements of the RPS specific to fuel cell facilities totaling 30 megawatts to be constructed by a qualified fuel cell provider. 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 by the fuel cell facilities over 21 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 provides for a reduction in DPL’s REC requirements based upon the actual energy output of the facilities. In June 2012, a 3 megawatt fuel cell generation facility was placed into service under the tariff. DPL billed less than $1 million to distribution customers during the three and six months ended June 30, 2012. A 27 megawatt fuel cell generation facility is expected to be placed into service in 5 megawatt increments beginning in January 2013. DPL is accounting for this arrangement as an agency transaction. 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 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 DPL below the carrying amount of its net assets. 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 six months ended June 30, 2012. 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 June 30, 2012 and 2011, and $8 million and $9 million for the six months ended June 30, 2012 and 2011, 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: Natural Gas Operating Revenue Adjustment In the second quarter of 2012, DPL recorded an adjustment to correct an overstatement of unbilled revenue in its natural gas distribution business related to prior periods. The adjustment resulted in a decrease in Operating revenue of $1 million for the three and six months ended June 30, 2012. Default Electricity Supply Revenue and Cost Adjustments During the second quarter of 2011, DPL recorded adjustments to correct certain errors associated with the accounting for Default Electricity Supply revenue and costs. These adjustments primarily arose from the under-recognition of allowed returns on the cost of working capital and resulted in a pre-tax decrease in Other operation and maintenance expense of $8 million for the three and six months ended June 30, 2011.
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 consolidated financial statements prepared in accordance with GAAP have been omitted. Therefore, these consolidated financial statements should be read along with the annual consolidated financial statements included in ACE’s annual report on Form 10-K for the year ended December 31, 2011, as amended to include the executive compensation and other information required by Part III of Form 10-K (which information originally had been omitted as permitted by that form). 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 June 30, 2012, in accordance with GAAP. The year-end December 31, 2011 consolidated balance sheet included herein was derived from audited consolidated financial statements, but does not include all disclosures required by GAAP. Interim results for the three and six months ended June 30, 2012 may not be indicative of ACE’s results that will be realized for the full year ending December 31, 2012. 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, fair value calculations for derivative instruments, pension and other postretirement benefits assumptions, the assessment of the probability of recovery of regulatory assets, accrual of storm restoration costs, accrual of unbilled revenue, 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 Restoration Costs On June 29, 2012, ACE was affected by a rapidly moving thunderstorm with hurricane-force winds, known as a “derecho,” which resulted in widespread customer outages in its service territory. The derecho caused extensive damage to ACE’s electric transmission and distribution systems. Storm restoration activity commenced immediately following the storm and continued into July 2012, with the majority of the incremental storm restoration costs occurring after the end of the second quarter of 2012. Total incremental storm restoration costs incurred by ACE through June 30, 2012 were $0.9 million, with $0.5 million incurred for repair work and $0.4 million incurred as capital expenditures. All of the costs incurred for repair work of $0.5 million were deferred as regulatory assets to reflect the probable recovery of these storm restoration costs. All of these total incremental storm restoration costs have been estimated for the cost of restoration services provided by outside contractors since the invoices for such services had not been received at June 30, 2012. Actual invoices may vary from these estimates. The total incremental storm restoration costs of ACE associated with the derecho are currently estimated to range between $29 million and $35 million. This range was developed using estimates of costs related to mutual assistance and contractor services, materials and supplies, and other expenses, and actual costs may vary from these estimates. A portion of the costs will be expensed with the balance being charged to capital. The costs expensed will be deferred as regulatory assets to reflect the probable recovery of these storm restoration costs in New Jersey. ACE will be pursuing recovery of the incremental storm restoration costs in its next distribution base rate case. 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 losses attributed to general and auto liability claims for ACE at June 30, 2011. Consolidation of Variable Interest Entities ACE assesses its contractual arrangements with variable interest entities to determine whether it is the primary beneficiary and thereby has to consolidate the entities in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 810. The guidance addresses conditions under which an entity should be consolidated based upon variable interests rather than voting interests. ACE Power Purchase Agreements ACE is a party to three power purchase agreements (PPAs) with unaffiliated, non-utility generators (NUGs) totaling 459 megawatts. One of the agreements ends in 2016 and the other two end in 2024. ACE was unable to obtain sufficient information to determine whether these three entities were variable interest entities or if ACE was the primary beneficiary. As a result, ACE 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 June 30, 2012 and 2011 were approximately $49 million and $55 million, respectively, of which approximately $47 million and $51 million, respectively, consisted of power purchases under the PPAs. Net purchase activities with the NUGs for the six months ended June 30, 2012 and 2011 were approximately $100 million and $112 million, respectively, of which approximately $98 million and $104 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 In April 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 generation companies to receive payments from, or require them to 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 electric 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, which is currently estimated to be approximately 15 percent for ACE. The NJBPU has approved full recovery from distribution customers of payments made by ACE and the other EDCs, and distribution customers would be entitled to any payments received from the generation companies. In May 2012, all three generators under the SOCAs bid into the PJM 2015-2016 capacity auction and two of the generators cleared that capacity auction. ACE recorded a derivative asset (liability) for the estimated fair value of each SOCA and recorded an offsetting regulatory liability (asset) as described in more detail in Note (10), “Derivative Instruments and Hedging Activities”, and Note (11), “Fair Value Disclosures.” FASB guidance on derivative accounting and the accounting for regulated operations would apply to ACE’s obligations under the third SOCA once the related capacity has cleared a PJM auction. The next PJM capacity auction is scheduled for May 2013. ACE has concluded that consolidation is not required for the SOCAs under the FASB guidance on the consolidation of variable interest entities. Taxes Assessed by a Governmental Authority on Revenue-Producing Transactions Taxes included in ACE’s gross revenues were $3 million and $5 million for the three months ended June 30, 2012 and 2011, respectively, and $7 million and $10 million for the six months ended June 30, 2012 and 2011, respectively. Reclassifications and Adjustments Certain prior period amounts have been reclassified in order to conform to the current period presentation. The following adjustment has been recorded and is not considered material. Income Tax Expense Adjustment During the second quarter of 2011, ACE completed a reconciliation of its deferred taxes associated with certain regulatory assets and recorded adjustments that resulted in an increase to Income tax expense of $1 million for the three and six months ended June 30, 2011.

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