Regulatory Matters	3 Months Ended
Mar. 31, 2012
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 does 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 and an incentive of 1.25% for the other seven projects. In August 2008, FERC approved the proposal, effective September 1, 2008. All eleven projects are currently expected to be completed by the end of 2012. Numerous parties sought rehearing of the FERC order in August 2008, and rehearing is pending. Although Virginia Power cannot predict the outcome of the rehearing, 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. If accepted by FERC, the settlement 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 the incremental cost of certain underground transmission facilities, which will be set for briefing. While Virginia Power cannot predict the outcome of the briefing, it is not expected to have a material effect on results of operations. PJM In November 2011, PJM issued a formal notification that it would recalculate certain ancillary service revenues that had previously been paid during 2009, 2010 and 2011. Also in November 2011, PJM requested FERC permission to suspend its rebilling and repayment obligations associated with the recalculation of such revenues and petitioned FERC to establish a proceeding to determine the appropriate recalculations for the revenues during this period. In December 2011, FERC permitted the suspension of rebilling and repayment by PJM, subject to the outcome of FERC's proceedings to determine the appropriate revenue recalculation. In April 2012, FERC issued an Order Establishing Hearing and Settlement Judge Procedures to address the appropriate recalculation of the ancillary service credits PJM will be required to collect from Virginia Power. Virginia Power has accrued a liability of $36 million as of March 31, 2012 for estimated future billing adjustments from PJM related to the ancillary service revenues. Other Regulatory Matters Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 14 to the Consolidated Financial Statements in Dominion's and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2011. Virginia Regulation Biennial Review In November 2011, the Virginia Commission issued the Biennial Review Order, which included a determination that Virginia Power's new authorized ROE is 10.9%, inclusive of a performance incentive of 50 basis points for meeting certain RPS targets. In December 2011, Virginia Power filed a petition with the Virginia Commission seeking rehearing or reconsideration of the Biennial Review Order, to confirm the effective date of the newly authorized 10.9% base ROE. Virginia Power's petition requested the Virginia Commission to confirm that the 10.9% ROE authorized in the Biennial Review Order would apply prospectively, effective following the date of the Biennial Review Order on November 30, 2011, and that Virginia Power's previously-approved 11.9% base ROE authorized in the Virginia Settlement Approval Order would be used to measure base rate earnings for the period January 1, 2011 through November 30, 2011. In March 2012, the Virginia Commission issued an order denying Virginia Power's petition seeking rehearing or reconsideration. Contrary to Virginia Power's position, the Virginia Commission ruled that the new 10.9% ROE will be used to measure earnings for the entire 2011-2012 test period in the next biennial review in 2013. Also in March 2012, Virginia Power filed Petitions for Appeal with the Supreme Court of Virginia regarding the Biennial Review Order and the March 2012 order. In the Biennial Review Order, the Virginia Commission declined to award a performance incentive for generating plant performance, customer service or operating efficiency in connection with the 2009-2010 biennial review. Instead, in March 2012, the Virginia Commission issued an order initiating a rulemaking proceeding to develop specific performance metrics and nationally recognized standards for determining positive or negative performance incentives for electric utilities. Such incentive criteria would be applied in future biennial review proceedings. Virginia Power expects the Staff of the Virginia Commission to file proposed rules and regulations for performance incentives in September 2012. Generation Riders R and S In March 2012, the Virginia Commission approved annual updates for Riders R and S for the April 1, 2012 to March 31, 2013 rate year, utilizing an 11.4% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE authorized in the Biennial Review Order. The Virginia Commission's approvals authorized an approximately $74 million revenue requirement for Rider R, and an approximately $226 million revenue requirement for Rider S, comprised of approximately $52 million for the pre-commercial operation period and approximately $174 million for the commercial operation period. Generation Rider B In March 2012, the Virginia Commission approved the conversion of the Altavista, Hopewell, and Southampton power stations to biomass. The conversions will increase Dominion's renewable generation by more than 150 MW. The conversions are expected to be completed by the end of 2013. As part of its approval, the Virginia Commission also approved Rider B. The approved revenue requirement for Rider B is approximately $6 million for the April 1, 2012 to March 31, 2013 rate year, utilizing a 12.4% ROE (inclusive of a 200 basis point statutory enhancement) consistent with the base ROE authorized in the Biennial Review Order. The renewable generating unit statutory enhancement of 200 basis points will apply during construction and the first five years of the service lives of the converted facilities. North Carolina Regulation In March 2012, Virginia Power filed an application with the North Carolina Commission to increase base non-fuel revenues by approximately $64 million, with January 1, 2013 as the proposed effective date for the permanent rate revision. Virginia Power plans to file an application in August 2012 to decrease its fuel rates. The net effect of the proposed change in base rates and current estimate of fuel charges would be a net revenue increase of approximately $37 million. Virginia Power intends to implement rates on a temporary basis, subject to refund, on November 1, 2012, as permitted by North Carolina law. Virginia Power expects to receive an order from the North Carolina Commission in December 2012. Ohio Regulation In February 2012, East Ohio submitted an application with the Ohio Commission to adjust the cost recovery charge for costs associated with PIR investments for the six months ended December 31, 2011. The filing was made in accordance with changes to the PIR program approved by the Ohio Commission in August 2011 and effects a transition from a fiscal year ending June 30 to a calendar year for annual filings thereafter. The application includes total gross plant investment for the six-month July 1-December 31, 2011 transition period of $73 million, cumulative gross plant investment of $362 million, and a revenue requirement of $47 million. A stipulation was submitted by East Ohio, the Staff of the Ohio Commission and the Ohio Consumers' Counsel that supports the rates filed by East Ohio. The Ohio Commission issued an order approving the stipulation in April 2012. FERC Gas - Cove Point Rate Case In May 2011, Cove Point filed a general rate case for its FERC-jurisdictional services, with proposed rates to be effective July 1, 2011. In June 2011, FERC accepted a July 1, 2011 effective date for all proposed rates but two, for which the effective date was suspended from July 1 to December 1, 2011. In December 2011, Cove Point, FERC trial staff and the other active parties in the rate case reached a settlement in principle on all issues set for hearing by FERC, as well as on all outstanding proposed tariff changes filed in May 2011. In April 2012, Cove Point filed a stipulation and agreement resolving all outstanding issues in the rate case and establishing the mechanism for operational purchases of LNG. The settlement is subject to FERC approval. Settlement rates and tariff changes will be effective retroactive to April 1, 2012, once the FERC order approving the settlement is no longer subject to rehearing or appeal. Cove Point and settling customers will be subject to a rate moratorium through December 31, 2016. Cove Point is required to file its next rate case with rates to be effective January 1, 2017.

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 does 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 and an incentive of 1.25% for the other seven projects. In August 2008, FERC approved the proposal, effective September 1, 2008. All eleven projects are currently expected to be completed by the end of 2012. Numerous parties sought rehearing of the FERC order in August 2008, and rehearing is pending. Although Virginia Power cannot predict the outcome of the rehearing, 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. If accepted by FERC, the settlement 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 the incremental cost of certain underground transmission facilities, which will be set for briefing. While Virginia Power cannot predict the outcome of the briefing, it is not expected to have a material effect on results of operations.

PJM

In November 2011, PJM issued a formal notification that it would recalculate certain ancillary service revenues that had previously been paid during 2009, 2010 and 2011. Also in November 2011, PJM requested FERC permission to suspend its rebilling and repayment obligations associated with the recalculation of such revenues and petitioned FERC to establish a proceeding to determine the appropriate recalculations for the revenues during this period. In December 2011, FERC permitted the suspension of rebilling and repayment by PJM, subject to the outcome of FERC's proceedings to determine the appropriate revenue recalculation. In April 2012, FERC issued an Order Establishing Hearing and Settlement Judge Procedures to address the appropriate recalculation of the ancillary service credits PJM will be required to collect from Virginia Power. Virginia Power has accrued a liability of $36 million as of March 31, 2012 for estimated future billing adjustments from PJM related to the ancillary service revenues.

Other Regulatory Matters

Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 14 to the Consolidated Financial Statements in Dominion's and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2011.

Virginia Regulation

Biennial Review

In November 2011, the Virginia Commission issued the Biennial Review Order, which included a determination that Virginia Power's new authorized ROE is 10.9%, inclusive of a performance incentive of 50 basis points for meeting certain RPS targets. In December 2011, Virginia Power filed a petition with the Virginia Commission seeking rehearing or reconsideration of the Biennial Review Order, to confirm the effective date of the newly authorized 10.9% base ROE. Virginia Power's petition requested the Virginia Commission to confirm that the 10.9% ROE authorized in the Biennial Review Order would apply prospectively, effective following the date of the Biennial Review Order on November 30, 2011, and that Virginia Power's previously-approved 11.9% base ROE authorized in the Virginia Settlement Approval Order would be used to measure base rate earnings for the period January 1, 2011 through November 30, 2011. In March 2012, the Virginia Commission issued an order denying Virginia Power's petition seeking rehearing or reconsideration. Contrary to Virginia Power's position, the Virginia Commission ruled that the new 10.9% ROE will be used to measure earnings for the entire 2011-2012 test period in the next biennial review in 2013. Also in March 2012, Virginia Power filed Petitions for Appeal with the Supreme Court of Virginia regarding the Biennial Review Order and the March 2012 order.

In the Biennial Review Order, the Virginia Commission declined to award a performance incentive for generating plant performance, customer service or operating efficiency in connection with the 2009-2010 biennial review. Instead, in March 2012, the Virginia Commission issued an order initiating a rulemaking proceeding to develop specific performance metrics and nationally recognized standards for determining positive or negative performance incentives for electric utilities. Such incentive criteria would be applied in future biennial review proceedings. Virginia Power expects the Staff of the Virginia Commission to file proposed rules and regulations for performance incentives in September 2012.

Generation Riders R and S

In March 2012, the Virginia Commission approved annual updates for Riders R and S for the April 1, 2012 to March 31, 2013 rate year, utilizing an 11.4% ROE (inclusive of a 100 basis point statutory enhancement) consistent with the base ROE authorized in the Biennial Review Order. The Virginia Commission's approvals authorized an approximately $74 million revenue requirement for Rider R, and an approximately $226 million revenue requirement for Rider S, comprised of approximately $52 million for the pre-commercial operation period and approximately $174 million for the commercial operation period.

Generation Rider B

In March 2012, the Virginia Commission approved the conversion of the Altavista, Hopewell, and Southampton power stations to biomass. The conversions will increase Dominion's renewable generation by more than 150 MW. The conversions are expected to be completed by the end of 2013.

As part of its approval, the Virginia Commission also approved Rider B. The approved revenue requirement for Rider B is approximately $6 million for the April 1, 2012 to March 31, 2013 rate year, utilizing a 12.4% ROE (inclusive of a 200 basis point statutory enhancement) consistent with the base ROE authorized in the Biennial Review Order. The renewable generating unit statutory enhancement of 200 basis points will apply during construction and the first five years of the service lives of the converted facilities.

North Carolina Regulation

In March 2012, Virginia Power filed an application with the North Carolina Commission to increase base non-fuel revenues by approximately $64 million, with January 1, 2013 as the proposed effective date for the permanent rate revision. Virginia Power plans to file an application in August 2012 to decrease its fuel rates. The net effect of the proposed change in base rates and current estimate of fuel charges would be a net revenue increase of approximately $37 million. Virginia Power intends to implement rates on a temporary basis, subject to refund, on November 1, 2012, as permitted by North Carolina law. Virginia Power expects to receive an order from the North Carolina Commission in December 2012.

Ohio Regulation

In February 2012, East Ohio submitted an application with the Ohio Commission to adjust the cost recovery charge for costs associated with PIR investments for the six months ended December 31, 2011. The filing was made in accordance with changes to the PIR program approved by the Ohio Commission in August 2011 and effects a transition from a fiscal year ending June 30 to a calendar year for annual filings thereafter. The application includes total gross plant investment for the six-month July 1-December 31, 2011 transition period of $73 million, cumulative gross plant investment of $362 million, and a revenue requirement of $47 million. A stipulation was submitted by East Ohio, the Staff of the Ohio Commission and the Ohio Consumers' Counsel that supports the rates filed by East Ohio. The Ohio Commission issued an order approving the stipulation in April 2012.

FERC Gas - Cove Point Rate Case

In May 2011, Cove Point filed a general rate case for its FERC-jurisdictional services, with proposed rates to be effective July 1, 2011. In June 2011, FERC accepted a July 1, 2011 effective date for all proposed rates but two, for which the effective date was suspended from July 1 to December 1, 2011. In December 2011, Cove Point, FERC trial staff and the other active parties in the rate case reached a settlement in principle on all issues set for hearing by FERC, as well as on all outstanding proposed tariff changes filed in May 2011. In April 2012, Cove Point filed a stipulation and agreement resolving all outstanding issues in the rate case and establishing the mechanism for operational purchases of LNG. The settlement is subject to FERC approval. Settlement rates and tariff changes will be effective retroactive to April 1, 2012, once the FERC order approving the settlement is no longer subject to rehearing or appeal. Cove Point and settling customers will be subject to a rate moratorium through December 31, 2016. Cove Point is required to file its next rate case with rates to be effective January 1, 2017.