Regulatory Matters	3 Months Ended
Mar. 31, 2013
Regulatory Matters [Abstract]
Regulatory Matters	Regulatory Matters Regulatory Matters Involving Potential Loss Contingencies As a result of issues generated in the ordinary course of business, Dominion and Virginia Power are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. This estimated range is based on currently available information and involves elements of judgment and significant uncertainties. This estimated range of possible loss may not represent the Companies' maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on Dominion's or Virginia Power's financial position, liquidity or results of operations. FERC - Electric Under the Federal Power Act, FERC regulates wholesale sales and transmission of electricity in interstate commerce by public utilities. Virginia Power purchases and sells electricity in the PJM wholesale market and Dominion's merchant generators sell electricity in the PJM, MISO and ISO-NE wholesale markets under Dominion's market-based sales tariffs authorized by FERC. In addition, Virginia Power has FERC approval of a tariff to sell wholesale power at capped rates based on its embedded cost of generation. This cost-based sales tariff could be used to sell to loads within or outside Virginia Power's service territory. Any such sales would be voluntary. Rates In April 2008, FERC granted an application for Virginia Power's electric transmission operations to establish a forward-looking formula rate mechanism that updates transmission rates on an annual basis and approved an ROE of 11.4%, effective as of January 1, 2008. The formula rate is designed to recover the expected revenue requirement for each calendar year and is updated based on actual costs. The FERC-approved formula method, which is based on projected costs, allows Virginia Power to earn a current return on its growing investment in electric transmission infrastructure. In July 2008, Virginia Power filed an application with FERC requesting a revision to its revenue requirement to reflect an additional ROE incentive adder for eleven electric transmission enhancement projects. Under the proposal, the cost of transmission service would increase to include an ROE incentive adder for each of the eleven projects, beginning the date each project enters commercial operation (but not before January 1, 2009). Virginia Power proposed an incentive of 1.5% for four of the projects (including the Meadow Brook-to-Loudoun and Carson-to-Suffolk lines, which were completed in 2011) and an incentive of 1.25% for the other seven projects. In August 2008, FERC approved the proposal, effective September 1, 2008, the incentives were included in the PJM Tariff, and billing for the incentives was made accordingly. In 2012, PJM canceled one of the eleven projects with an estimated cost of $7 million. The total cost for the other ten projects included in Virginia Power's formula rate for 2013 is $852 million and the remaining projects were completed in 2012. Numerous parties sought rehearing of the FERC order in August 2008, and in May 2012 FERC denied rehearing. In July 2012, the North Carolina Commission filed an appeal of the FERC orders granting the incentives with the U.S. Court of Appeals for the Fourth Circuit. Although Virginia Power cannot predict the outcome of the appeal, it is not expected to have a material effect on results of operations. In March 2010, ODEC and NCEMC filed a complaint with FERC against Virginia Power claiming that approximately $223 million in transmission costs related to specific projects were unjust, unreasonable and unduly discriminatory or preferential and should be excluded from Virginia Power's transmission formula rate. ODEC and NCEMC requested that FERC establish procedures to determine the amount of costs for each applicable project that should be excluded from Virginia Power's rates. In October 2010, FERC issued an order dismissing the complaint in part and established hearings and settlement procedures on the remaining part of the complaint. In February 2012, Virginia Power submitted to FERC a settlement agreement to resolve all issues set for hearing. All transmission customer parties to the proceeding joined the settlement. The Virginia Commission, North Carolina Commission and Public Staff of the North Carolina Commission, while not parties to the settlement, have agreed to not oppose the settlement. The settlement was accepted by FERC in May 2012 and provides for payment by Virginia Power to the transmission customer parties collectively of $250,000 per year for ten years and resolves all matters other than allocation of the incremental cost of certain underground transmission facilities, which has been briefed pursuant to FERC's May 2012 order and awaits FERC action. While Virginia Power cannot predict the outcome of the briefing, it is not expected to have a material effect on results of operations. Other Regulatory Matters Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 13 to the Consolidated Financial Statements in Dominion's and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2012. Virginia Regulation 2013 Biennial Review Pursuant to the Regulation Act, in March 2013, Virginia Power submitted its base rate filings and accompanying schedules in support of the 2013 biennial review of its rates, terms and conditions, as well as of its earnings for test years 2011 and 2012. In its filing, Virginia Power did not request an increase in base rates for generation and distribution services, and proposed that base rates remain at their existing level as set by the Virginia Settlement Approval Order. Virginia Power's earnings test analysis, as filed, demonstrates it earned an ROE of 10.11% on its generation and distribution services for the combined test period of 2011 and 2012. The Virginia Commission will determine whether Virginia Power's earnings for the 2011 and 2012 test years, considered as a whole, were within 50 basis points above or below the authorized ROE of 10.9% established in the 2011 biennial review. If Virginia Power's earnings for the test years are determined to be more than 50 basis points above the authorized ROE, the Virginia Commission will order a credit to customers of 60% of the earnings that exceeded an ROE of 11.4% for the biennial period. In such a scenario, the Virginia Commission can also order a reduction in Virginia Power's base rates, but only if the resulting rates will provide Virginia Power with the opportunity to fully recover the costs of providing its services and earn not less than a fair combined rate of return on its distribution and generation services. If Virginia Power's earnings for the test years are determined to be more than 50 basis points below the authorized ROE, the Virginia Commission can order an increase to Virginia Power's rates if such an increase is necessary to provide Virginia Power the opportunity to fully recover the costs of providing services and to earn not less than a fair combined rate of return on its generation and distribution services. The Virginia Commission will also authorize an ROE for Virginia Power that will be applied to Riders R, S, W, B, and C1A and C2A, and that will also be utilized to measure base rate earnings as of January 1, 2013. Virginia Power is requesting authorization of an ROE of 11.5% effective January 1, 2014 through December 31, 2014 based on Virginia Power's current cost of equity and performance. Pursuant to the Regulation Act, Virginia Power's authorized ROE can be no lower than the average of the returns reported for the three previous years by not less than a majority of comparable utilities in the Southeastern U.S., with certain limitations as described in the Regulation Act. A final order in the 2013 biennial review for base rates must be issued no later than November 28, 2013. DSM Riders C1A and C2A In April 2013, the Virginia Commission approved revenue requirements for Riders C1A and C2A of approximately $4 million and $23 million, respectively, for the May 1, 2013 to April 30, 2014 rate year. The Virginia Commission approved a two-year extension of the Residential Low Income Program subject to an approximately $14 million cost cap, as well as a three-year extension of the Residential Air Conditioner Cycling Program. The Virginia Commission rejected Virginia Power's request for approval of a process whereby the Virginia Commission Staff could administratively approve limited modifications to the designs of previously approved DSM programs. Virginia Power must file any application to continue Riders C1A and C2A by September 1, 2013. Generation Rider S The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In March 2013, the Virginia Commission approved a revised revenue requirement for Rider S of approximately $248 million for the rate year beginning April 1, 2013, and stated that Virginia Power should file its next Rider S case by June 30, 2013. Generation Rider B In 2012, the Virginia Commission approved the conversion of the Altavista, Hopewell, and Southampton power stations to biomass, and in conjunction approved Rider B. In March 2013, the Virginia Commission approved a revenue requirement for the pre-commercial operations date period and the post-commercial operations date period, resulting in an average recovery amount of approximately $12 million for the rate year commencing April 1, 2013. Solar Distributed Generation Demonstration Program In March 2013, the Virginia Commission approved Rate Schedule SP, under which Virginia Power will purchase 100% of the energy output from up to a combined 3 MW of customer-owned solar distributed generation facilities, including all environmental attributes and associated renewable energy credits, at a fixed price of $0.15 per kWh for five years. This fixed price has two components: an avoided cost component (including line losses) determined using Virginia Power's Rate Schedule 19 and recovered through Virginia Power's fuel factor, and a voluntary environmental contribution component provided by customers voluntarily participating in Virginia Power's Green Power Program. Ohio Regulation In 2008, East Ohio began PIR, aimed at replacing approximately 20% of its pipeline system. In February 2013, East Ohio filed an application with the Ohio Commission to adjust the cost recovery charge for costs associated with PIR investments for the calendar year 2012 and cumulatively. The application includes total gross plant investment for 2012 of $148 million, cumulative gross plant investment of $511 million, and a revenue requirement of $67 million. A stipulation was submitted by East Ohio and the Staff of the Ohio Commission that supports the rates filed by East Ohio. The Ohio Consumers' Counsel neither supports nor opposes the stipulation and has raised no issues regarding the rates filed. Approval of the application is anticipated in time to implement the resulting cost recovery charges in May 2013. FERC Gas Regulation Sabinsville-to-Morrisville Project In March 2013, FERC approved DTI's Sabinsville-to-Morrisville project and authorized commencement of construction in the second quarter of 2013. The project is expected to have capacity of approximately 92,000 Dths per day, which will be leased by TGP to move additional Marcellus supplies from a TGP pipeline in northeast Pennsylvania to a DTI line in upstate New York. The project is expected to be placed into service in November 2013. Tioga Area Expansion Project In March 2013, DTI received FERC approval of the Tioga Area Expansion Project. The project is expected to provide approximately 270,000 Dths per day of firm transportation service from supply interconnects in Tioga and Potter Counties in Pennsylvania to DTI's Crayne interconnect with Transcontinental Gas Pipe Line Company in Clinton County, Pennsylvania. Construction is expected to commence in April 2013 with an anticipated in-service date of November 2013.

Regulatory Matters

Regulatory Matters Involving Potential Loss Contingencies

As a result of issues generated in the ordinary course of business, Dominion and Virginia Power are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. This estimated range is based on currently available information and involves elements of judgment and significant uncertainties. This estimated range of possible loss may not represent the Companies' maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on Dominion's or Virginia Power's financial position, liquidity or results of operations.

FERC - Electric

Under the Federal Power Act, FERC regulates wholesale sales and transmission of electricity in interstate commerce by public utilities. Virginia Power purchases and sells electricity in the PJM wholesale market and Dominion's merchant generators sell electricity in the PJM, MISO and ISO-NE wholesale markets under Dominion's market-based sales tariffs authorized by FERC. In addition, Virginia Power has FERC approval of a tariff to sell wholesale power at capped rates based on its embedded cost of generation. This cost-based sales tariff could be used to sell to loads within or outside Virginia Power's service territory. Any such sales would be voluntary.

Rates

In April 2008, FERC granted an application for Virginia Power's electric transmission operations to establish a forward-looking formula rate mechanism that updates transmission rates on an annual basis and approved an ROE of 11.4%, effective as of January 1, 2008. The formula rate is designed to recover the expected revenue requirement for each calendar year and is updated based on actual costs. The FERC-approved formula method, which is based on projected costs, allows Virginia Power to earn a current return on its growing investment in electric transmission infrastructure.

In July 2008, Virginia Power filed an application with FERC requesting a revision to its revenue requirement to reflect an additional ROE incentive adder for eleven electric transmission enhancement projects. Under the proposal, the cost of transmission service would increase to include an ROE incentive adder for each of the eleven projects, beginning the date each project enters commercial operation (but not before January 1, 2009). Virginia Power proposed an incentive of 1.5% for four of the projects (including the Meadow Brook-to-Loudoun and Carson-to-Suffolk lines, which were completed in 2011) and an incentive of 1.25% for the other seven projects. In August 2008, FERC approved the proposal, effective September 1, 2008, the incentives were included in the PJM Tariff, and billing for the incentives was made accordingly. In 2012, PJM canceled one of the eleven projects with an estimated cost of $7 million. The total cost for the other ten projects included in Virginia Power's formula rate for 2013 is $852 million and the remaining projects were completed in 2012. Numerous parties sought rehearing of the FERC order in August 2008, and in May 2012 FERC denied rehearing. In July 2012, the North Carolina Commission filed an appeal of the FERC orders granting the incentives with the U.S. Court of Appeals for the Fourth Circuit. Although Virginia Power cannot predict the outcome of the appeal, it is not expected to have a material effect on results of operations.

In March 2010, ODEC and NCEMC filed a complaint with FERC against Virginia Power claiming that approximately $223 million in transmission costs related to specific projects were unjust, unreasonable and unduly discriminatory or preferential and should be excluded from Virginia Power's transmission formula rate. ODEC and NCEMC requested that FERC establish procedures to determine the amount of costs for each applicable project that should be excluded from Virginia Power's rates. In October 2010, FERC issued an order dismissing the complaint in part and established hearings and settlement procedures on the remaining part of the complaint. In February 2012, Virginia Power submitted to FERC a settlement agreement to resolve all issues set for hearing. All transmission customer parties to the proceeding joined the settlement. The Virginia Commission, North Carolina Commission and Public Staff of the North Carolina Commission, while not parties to the settlement, have agreed to not oppose the settlement. The settlement was accepted by FERC in May 2012 and provides for payment by Virginia Power to the transmission customer parties collectively of $250,000 per year for ten years and resolves all matters other than allocation of the incremental cost of certain underground transmission facilities, which has been briefed pursuant to FERC's May 2012 order and awaits FERC action. While Virginia Power cannot predict the outcome of the briefing, it is not expected to have a material effect on results of operations.

Other Regulatory Matters

Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 13 to the Consolidated Financial Statements in Dominion's and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2012.

Virginia Regulation

2013 Biennial Review

Pursuant to the Regulation Act, in March 2013, Virginia Power submitted its base rate filings and accompanying schedules in support of the 2013 biennial review of its rates, terms and conditions, as well as of its earnings for test years 2011 and 2012. In its filing, Virginia Power did not request an increase in base rates for generation and distribution services, and proposed that base rates remain at their existing level as set by the Virginia Settlement Approval Order. Virginia Power's earnings test analysis, as filed, demonstrates it earned an ROE of 10.11% on its generation and distribution services for the combined test period of 2011 and 2012. The Virginia Commission will determine whether Virginia Power's earnings for the 2011 and 2012 test years, considered as a whole, were within 50 basis points above or below the authorized ROE of 10.9% established in the 2011 biennial review. If Virginia Power's earnings for the test years are determined to be more than 50 basis points above the authorized ROE, the Virginia Commission will order a credit to customers of 60% of the earnings that exceeded an ROE of 11.4% for the biennial period. In such a scenario, the Virginia Commission can also order a reduction in Virginia Power's base rates, but only if the resulting rates will provide Virginia Power with the opportunity to fully recover the costs of providing its services and earn not less than a fair combined rate of return on its distribution and generation services. If Virginia Power's earnings for the test years are determined to be more than 50 basis points below the authorized ROE, the Virginia Commission can order an increase to Virginia Power's rates if such an increase is necessary to provide Virginia Power the opportunity to fully recover the costs of providing services and to earn not less than a fair combined rate of return on its generation and distribution services. The Virginia Commission will also authorize an ROE for Virginia Power that will be applied to Riders R, S, W, B, and C1A and C2A, and that will also be utilized to measure base rate earnings as of January 1, 2013. Virginia Power is requesting authorization of an ROE of 11.5% effective January 1, 2014 through December 31, 2014 based on Virginia Power's current cost of equity and performance. Pursuant to the Regulation Act, Virginia Power's authorized ROE can be no lower than the average of the returns reported for the three previous years by not less than a majority of comparable utilities in the Southeastern U.S., with certain limitations as described in the Regulation Act. A final order in the 2013 biennial review for base rates must be issued no later than November 28, 2013.

DSM Riders C1A and C2A

In April 2013, the Virginia Commission approved revenue requirements for Riders C1A and C2A of approximately $4 million and $23 million, respectively, for the May 1, 2013 to April 30, 2014 rate year. The Virginia Commission approved a two-year extension of the Residential Low Income Program subject to an approximately $14 million cost cap, as well as a three-year extension of the Residential Air Conditioner Cycling Program. The Virginia Commission rejected Virginia Power's request for approval of a process whereby the Virginia Commission Staff could administratively approve limited modifications to the designs of previously approved DSM programs. Virginia Power must file any application to continue Riders C1A and C2A by September 1, 2013.

Generation Rider S

The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In March 2013, the Virginia Commission approved a revised revenue requirement for Rider S of approximately $248 million for the rate year beginning April 1, 2013, and stated that Virginia Power should file its next Rider S case by June 30, 2013.

Generation Rider B

In 2012, the Virginia Commission approved the conversion of the Altavista, Hopewell, and Southampton power stations to biomass, and in conjunction approved Rider B. In March 2013, the Virginia Commission approved a revenue requirement for the pre-commercial operations date period and the post-commercial operations date period, resulting in an average recovery amount of approximately $12 million for the rate year commencing April 1, 2013.

Solar Distributed Generation Demonstration Program

In March 2013, the Virginia Commission approved Rate Schedule SP, under which Virginia Power will purchase 100% of the energy output from up to a combined 3 MW of customer-owned solar distributed generation facilities, including all environmental attributes and associated renewable energy credits, at a fixed price of $0.15 per kWh for five years. This fixed price has two components: an avoided cost component (including line losses) determined using Virginia Power's Rate Schedule 19 and recovered through Virginia Power's fuel factor, and a voluntary environmental contribution component provided by customers voluntarily participating in Virginia Power's Green Power Program.

Ohio Regulation

In 2008, East Ohio began PIR, aimed at replacing approximately 20% of its pipeline system. In February 2013, East Ohio filed an application with the Ohio Commission to adjust the cost recovery charge for costs associated with PIR investments for the calendar year 2012 and cumulatively. The application includes total gross plant investment for 2012 of $148 million, cumulative gross plant investment of $511 million, and a revenue requirement of $67 million. A stipulation was submitted by East Ohio and the Staff of the Ohio Commission that supports the rates filed by East Ohio. The Ohio Consumers' Counsel neither supports nor opposes the stipulation and has raised no issues regarding the rates filed. Approval of the application is anticipated in time to implement the resulting cost recovery charges in May 2013.

FERC Gas Regulation

Sabinsville-to-Morrisville Project

In March 2013, FERC approved DTI's Sabinsville-to-Morrisville project and authorized commencement of construction in the second quarter of 2013. The project is expected to have capacity of approximately 92,000 Dths per day, which will be leased by TGP to move additional Marcellus supplies from a TGP pipeline in northeast Pennsylvania to a DTI line in upstate New York. The project is expected to be placed into service in November 2013.

Tioga Area Expansion Project

In March 2013, DTI received FERC approval of the Tioga Area Expansion Project. The project is expected to provide approximately 270,000 Dths per day of firm transportation service from supply interconnects in Tioga and Potter Counties in Pennsylvania to DTI's Crayne interconnect with Transcontinental Gas Pipe Line Company in Clinton County, Pennsylvania. Construction is expected to commence in April 2013 with an anticipated in-service date of November 2013.