RATE AND OTHER REGULATORY MATTERS (Details) (SCE&G, USD $)	1 Months Ended								6 Months Ended
	Oct. 30, 2011	Jun. 30, 2011	Apr. 30, 2011	Oct. 31, 2010	Jul. 31, 2010	Jan. 31, 2010	Dec. 31, 2009	Sep. 30, 2009	Jun. 30, 2011	May 31, 2009	Dec. 31, 2007
SCE&G
Rate Matters
Recognized amount of fuel costs previously deferred as state income tax credits		$ 17,400,000							$ 17,400,000
Base fuel undercollected balance, recovery period (in years)			2
Increase in retail electric rates (as a percent)	2.70%			2.30%	4.88%			1.10%
Allowable return on common equity (as a percent)					10.70%				11.00%
Stipulations adopted pertaining to the order issued					1) included implementation of an eWNA for SCE&G's electric customers, which began in August 2010, (2) provided for a $25 million credit, over one year, to SCE&G's customers to be offset by amortization of weather related revenues which were deferred in the first quarter of 2010 pursuant to a stipulation between SCE&G and the ORS, (3) provided for a $48.7 million credit to SCE&G's customers over two years to be offset by accelerated recognition of previously deferred state income tax credits and (4) provided for the recovery of certain federally mandated capital expenditures that had been included in utility plant but were not being depreciated.
Credit to customers to be offset by amortization of weather-related revenues					25,000,000
Length of credit period (in years)					1Y
Credit to customers to be offset by accelerated recognition of previously deferred state income tax credits					48,700,000
Length of credit period (in years)					2Y
Estimated increase in revenue subject to change in the network and point to point transmission rates							5,600,000
Number of new nuclear generating units at summer station						2
Increase in retail electric rates	58,500,000			47,300,000				22,500,000
Number of intervenors who filed separate appeals to challenge the order passed by the regulatory authority										2
Amount of approved cost allowed as capital costs											4,500,000,000
Contingency cost associated with the project									438,000,000
Identifiable capital costs after approval of updated capital cost schedule									173,900,000
Increase (decrease) in natural gas retail rates				(10,400,000)
Increase (decrease) in natural gas retail rate requested		$ 8,640,000
Percentage increase (decrease) in natural gas retail rates (as a percent)				(2.10%)
Percentage increase (decrease) in natural gas retail rate requested (as a percent)		2.14%
Basis for rate calculation									12-month rolling average