Regulatory Matters	6 Months Ended
Jun. 30, 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. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any 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. 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. Virginia Power purchases and, under its FERC market-based rate authority, sells electricity in the wholesale market. 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 year 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. In May 2012, FERC issued an order denying the rehearing requests. In July 2012, the North Carolina Commission filed an appeal of the FERC orders with the U.S. Court of Appeals for the Fourth Circuit. While 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, did 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 and Note 12 to the Consolidated Financial Statements in Dominion's and Virginia Power's Quarterly Report on Form 10-Q for the quarter ended March 31, 2013. Virginia Regulation Virginia Fuel Expenses In May 2013, Virginia Power submitted its annual fuel factor filing to the Virginia Commission, proposing an increase of approximately $162 million in fuel revenue for the rate year beginning July 1, 2013. In June 2013, the Virginia Commission issued an order approving the rate. Generation Rider S The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In June 2013, Virginia Power requested Virginia Commission approval of its annual update for Rider S for the twelve-month rate year beginning April 1, 2014, utilizing a 12.5% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE that Virginia Power has proposed, and which is pending a decision, in its 2013 biennial review case. Virginia Power proposed an approximately $287 million revenue requirement for the rate year. This case is pending. Generation Rider W The Virginia Commission previously approved Rider W in conjunction with Warren County. In May 2013, Virginia Power requested Virginia Commission approval of its annual update for Rider W for the twelve-month rate year beginning April 1, 2014, utilizing a 12.5% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE that Virginia Power has proposed, and which is pending a decision, in its 2013 biennial review case. Virginia Power proposed an approximately $122 million total revenue requirement (consisting of approximately $70 million for the eight months preceding the station's commercial operations period, and approximately $52 million for the four months of expected commercial operations in the rate year) for the rate year. This case is pending. Generation Rider B The Virginia Commission previously approved Rider B in conjunction with the conversion of the Altavista, Hopewell, and Southampton power stations to biomass. In June 2013, Virginia Power requested Virginia Commission approval of its annual update for Rider B for the twelve-month rate year beginning April 1, 2014, utilizing a 13.5% ROE (inclusive of a 200 basis point statutory enhancement) consistent with the base ROE that Virginia Power has proposed, and which is pending a decision, in its 2013 biennial review case. Virginia Power proposed an approximately $22 million revenue requirement for the rate year. This case is pending. The Altavista power station commenced commercial operations using biomass as its fuel in July 2013. Brunswick County Power Station and Generation Rider BW In November 2012, Virginia Power requested approval from the Virginia Commission to construct and operate Brunswick County. The application included a request for approval of associated transmission facilities and Rider BW. Virginia Power's proposed revenue requirement for Rider BW is approximately $45 million for the September 1, 2013 to August 31, 2014 rate year, reflecting an ROE of 11.4%, inclusive of a statutory enhancement of 100 basis points for Rider BW, consistent with the Biennial Review Order. Virginia Power requested an ROE enhancement of 100 basis points for Rider BW for a period of 15 years following commercial operations. In August 2013, the Virginia Commission approved Certificates of Public Convenience and Necessity for Brunswick County and related transmission interconnection facilities. The Virginia Commission also approved a revenue requirement of approximately $43 million for the September 1, 2013 to August 31, 2014 rate year, reflecting an ROE of 11.4%, inclusive of a statutory enhancement of 100 basis points for Rider BW, consistent with the Biennial Review Order. In addition, the Virginia Commission approved an ROE enhancement of 100 basis points for Rider BW for a period of 10 years following commercial operations. Virginia Power expects to commence construction of the facility during the third quarter of 2013, with commercial operations to begin in spring 2016. Transmission Rider T1 In May 2013, Virginia Power filed for an adjustment to its current Rider T1 with the Virginia Commission to recover costs of transmission service and demand response programs for the September 1, 2013 to August 31, 2014 rate year. The proposed Rider T1 revenue requirement is $81 million and reflects a total revenue requirement of approximately $404 million for costs of all transmission service and demand response programs. The transmission service and demand response program costs not recovered through Rider T1 are recovered as a component of base rates as previously approved by the Virginia Commission. In July 2013, the Virginia Commission issued an order approving the rate. Electric Transmission Projects In July 2010, the Virginia Commission authorized Virginia Power to construct the Radnor Heights Project. The Virginia Commission stated that these lines and substation must be constructed and in service by June 30, 2012, and that Virginia Power could apply to extend this date for good cause shown. In October 2012, the Virginia Commission issued an order extending this construction and the in-service date to July 31, 2013. In July 2013, Virginia Power filed and the Virginia Commission approved a motion to further extend this construction and in-service date to June 1, 2014. In January 2013, a notice of appeal was filed with the Supreme Court of Virginia by a private party regarding the Virginia Commission's December 2012 order authorizing construction of the Waxpool-Brambleton-BECO line. In May 2013, the Supreme Court of Virginia issued an order accepting the petition for appeal. Oral argument is scheduled for September 2013. Ohio Regulation PIR Program In 2008, East Ohio began PIR, aimed at replacing approximately 20% of its pipeline system. In May 2013, PIR cost recovery rates became effective as approved by the Ohio Commission in April 2013. The approval includes a revenue requirement of $67 million. PIPP Plus Program Under the Ohio PIPP Plus Program, eligible customers can receive energy assistance based on their ability to pay their bill. In July 2013, the Ohio Commission approved East Ohio's annual update of the PIPP Rider, which reflects the refund over the next year of an over-recovery of accumulated arrearages of approximately $91 million as of March 31, 2013, net of projected deferred program costs of approximately $54 million for the period from April 2013 through June 2014. UEX Rider East Ohio files an annual UEX Rider pursuant to which it seeks recovery of the bad debt expense of most customers not participating in the PIPP Plus Program. In July 2013, the Ohio Commission approved East Ohio's annual update of the UEX Rider, which reflects the elimination of accumulated unrecovered bad debt expense of approximately $3 million as of March 31, 2013, and recovery of prospective bad debt expense projected to total approximately $24 million for the twelve-month period from April 2013 to March 2014.

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. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any 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. 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. Virginia Power purchases and, under its FERC market-based rate authority, sells electricity in the wholesale market. 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 year 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. In May 2012, FERC issued an order denying the rehearing requests. In July 2012, the North Carolina Commission filed an appeal of the FERC orders with the U.S. Court of Appeals for the Fourth Circuit. While 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, did 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 and Note 12 to the Consolidated Financial Statements in Dominion's and Virginia Power's Quarterly Report on Form 10-Q for the quarter ended March 31, 2013.

Virginia Regulation

Virginia Fuel Expenses

In May 2013, Virginia Power submitted its annual fuel factor filing to the Virginia Commission, proposing an increase of approximately $162 million in fuel revenue for the rate year beginning July 1, 2013. In June 2013, the Virginia Commission issued an order approving the rate.

Generation Rider S

The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In June 2013, Virginia Power requested Virginia Commission approval of its annual update for Rider S for the twelve-month rate year beginning April 1, 2014, utilizing a 12.5% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE that Virginia Power has proposed, and which is pending a decision, in its 2013 biennial review case. Virginia Power proposed an approximately $287 million revenue requirement for the rate year. This case is pending.

Generation Rider W

The Virginia Commission previously approved Rider W in conjunction with Warren County. In May 2013, Virginia Power requested Virginia Commission approval of its annual update for Rider W for the twelve-month rate year beginning April 1, 2014, utilizing a 12.5% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE that Virginia Power has proposed, and which is pending a decision, in its 2013 biennial review case. Virginia Power proposed an approximately $122 million total revenue requirement (consisting of approximately $70 million for the eight months preceding the station's commercial operations period, and approximately $52 million for the four months of expected commercial operations in the rate year) for the rate year. This case is pending.

Generation Rider B

The Virginia Commission previously approved Rider B in conjunction with the conversion of the Altavista, Hopewell, and Southampton power stations to biomass. In June 2013, Virginia Power requested Virginia Commission approval of its annual update for Rider B for the twelve-month rate year beginning April 1, 2014, utilizing a 13.5% ROE (inclusive of a 200 basis point statutory enhancement) consistent with the base ROE that Virginia Power has proposed, and which is pending a decision, in its 2013 biennial review case. Virginia Power proposed an approximately $22 million revenue requirement for the rate year. This case is pending. The Altavista power station commenced commercial operations using biomass as its fuel in July 2013.

Brunswick County Power Station and Generation Rider BW

In November 2012, Virginia Power requested approval from the Virginia Commission to construct and operate Brunswick County. The application included a request for approval of associated transmission facilities and Rider BW. Virginia Power's proposed revenue requirement for Rider BW is approximately $45 million for the September 1, 2013 to August 31, 2014 rate year, reflecting an ROE of 11.4%, inclusive of a statutory enhancement of 100 basis points for Rider BW, consistent with the Biennial Review Order. Virginia Power requested an ROE enhancement of 100 basis points for Rider BW for a period of 15 years following commercial operations.

In August 2013, the Virginia Commission approved Certificates of Public Convenience and Necessity for Brunswick County and related transmission interconnection facilities. The Virginia Commission also approved a revenue requirement of approximately $43 million for the September 1, 2013 to August 31, 2014 rate year, reflecting an ROE of 11.4%, inclusive of a statutory enhancement of 100 basis points for Rider BW, consistent with the Biennial Review Order. In addition, the Virginia Commission approved an ROE enhancement of 100 basis points for Rider BW for a period of 10 years following commercial operations. Virginia Power expects to commence construction of the facility during the third quarter of 2013, with commercial operations to begin in spring 2016.

Transmission Rider T1

In May 2013, Virginia Power filed for an adjustment to its current Rider T1 with the Virginia Commission to recover costs of transmission service and demand response programs for the September 1, 2013 to August 31, 2014 rate year. The proposed Rider T1 revenue requirement is $81 million and reflects a total revenue requirement of approximately $404 million for costs of all transmission service and demand response programs. The transmission service and demand response program costs not recovered through Rider T1 are recovered as a component of base rates as previously approved by the Virginia Commission. In July 2013, the Virginia Commission issued an order approving the rate.

Electric Transmission Projects

In July 2010, the Virginia Commission authorized Virginia Power to construct the Radnor Heights Project. The Virginia Commission stated that these lines and substation must be constructed and in service by June 30, 2012, and that Virginia Power could apply to extend this date for good cause shown. In October 2012, the Virginia Commission issued an order extending this construction and the in-service date to July 31, 2013. In July 2013, Virginia Power filed and the Virginia Commission approved a motion to further extend this construction and in-service date to June 1, 2014.

In January 2013, a notice of appeal was filed with the Supreme Court of Virginia by a private party regarding the Virginia Commission's December 2012 order authorizing construction of the Waxpool-Brambleton-BECO line. In May 2013, the Supreme Court of Virginia issued an order accepting the petition for appeal. Oral argument is scheduled for September 2013.

Ohio Regulation

PIR Program

In 2008, East Ohio began PIR, aimed at replacing approximately 20% of its pipeline system. In May 2013, PIR cost recovery rates became effective as approved by the Ohio Commission in April 2013. The approval includes a revenue requirement of $67 million.

PIPP Plus Program

Under the Ohio PIPP Plus Program, eligible customers can receive energy assistance based on their ability to pay their bill. In July 2013, the Ohio Commission approved East Ohio's annual update of the PIPP Rider, which reflects the refund over the next year of an over-recovery of accumulated arrearages of approximately $91 million as of March 31, 2013, net of projected deferred program costs of approximately $54 million for the period from April 2013 through June 2014.

UEX Rider

East Ohio files an annual UEX Rider pursuant to which it seeks recovery of the bad debt expense of most customers not participating in the PIPP Plus Program. In July 2013, the Ohio Commission approved East Ohio's annual update of the UEX Rider, which reflects the elimination of accumulated unrecovered bad debt expense of approximately $3 million as of March 31, 2013, and recovery of prospective bad debt expense projected to total approximately $24 million for the twelve-month period from April 2013 to March 2014.