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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

12 Months Ended

Dec. 31, 2012

New Accounting Pronouncements, Policy [Policy Text Block]

New Accounting Matters

In 2012, the Company adopted accounting guidance that revised how comprehensive income is presented in its financial statements and conformed the presentation for 2011 and 2010. In the first quarter of 2013, the Company will adopt recent additional guidance requiring the disclosure of the effects of items reclassified out of accumulated other comprehensive income. The adoption of this guidance has not impacted, and is not expected to impact, the Company's results of operations, cash flows or financial position.

In 2012, the Company adopted accounting guidance that permits it to make a qualitative assessment about the likelihood of goodwill impairment each year. Such a qualitative (step zero) assessment was performed with respect to certain goodwill, and that assessment led the Company to determine that performing a two-step quantitative impairment test was unnecessary. For other goodwill, the two-step quantitative test was performed. The adoption of this guidance did not impact the Company's results of operations, cash flows or financial position.

In 2012, the Company adopted accounting guidance that amended existing requirements for measuring fair value and for disclosing information about fair value measurements. The adoption of this guidance did not impact the Company's results of operations, cash flows or financial position.

Jointly Owned Plant Policy [Policy Text Block]

Jointly Owned Utility Plant

SCE&G jointly owns and is the operator of Summer Station Unit 1. In addition, SCE&G will jointly own and will be the operator of the New Units being designed and constructed at the site of Summer Station. Each joint owner provides its own financing and shares the direct expenses and generation output in proportion to its ownership of a unit. SCE&G’s share of the direct expenses is included in the corresponding operating expenses on its income statement.



	Unit 1			New Units
As of December 31, 2012
Percent owned	66.7%			55.0%
Plant in service	$	1.1	billion	—
Accumulated depreciation	$	557.0	million	—
Construction work in progress	$	113.6	million	$	1.8	billion
As of December 31, 2011
Percent owned	66.7%			55.0%
Plant in service	$	1.0	billion	—
Accumulated depreciation	$	545.0	million	—
Construction work in progress	$	71.0	million	$	1.2	billion

SCE&G, on behalf of itself and as agent for Santee Cooper, has contracted the Consortium for the design and construction of the New Units at the site of Summer Station. SCE&G’s share of the estimated cash outlays (future value, excluding AFC) totals approximately $6.0 billion for plant costs and for related transmission infrastructure costs, and is projected based on historical one-year and five-year escalation rates as required by the SCPSC. The first New Unit is scheduled for substantial completion in 2017, and the second in 2018.

SCE&G’s latest IRP filed with the SCPSC continues to support SCE&G’s need for 55% of the output of the New Units. As previously reported, SCE&G has been advised by Santee Cooper that it is reviewing certain aspects of its capital improvement program and long-term power supply plan, including the level of its participation in the New Units. Santee Cooper has been engaged in discussions with several parties that may result in one or more of them executing a power purchase agreement or acquiring a portion of Santee Cooper’s ownership interest in the New Units. SCE&G is unable to predict whether any change in Santee Cooper’s ownership interest or the addition of new joint owners will increase project costs or delay the commercial operation dates of the New Units. Any such project cost increase or delay could be material.

Included within receivables on the balance sheet were amounts due to SCE&G from Santee Cooper for its share of direct expenses and construction costs for Summer Station Unit 1 and the New Units. These amounts totaled $92.9 million at December 31, 2012 and $63.6 million at December 31, 2011.

Consolidation, Policy [Policy Text Block]

Organization and Principles of Consolidation

SCANA, a South Carolina corporation, is a holding company. The Company engages predominantly in the generation and sale of electricity to wholesale and retail customers in South Carolina and in the purchase, sale and transportation of natural gas to wholesale and retail customers in South Carolina, North Carolina and Georgia. The Company also conducts other energy-related business and provides fiber optic communications in South Carolina.

The accompanying Consolidated Financial Statements reflect the accounts of SCANA and the following wholly-owned subsidiaries.



Regulated businesses		Nonregulated businesses
South Carolina Electric & Gas Company		SCANA Energy Marketing, Inc.
South Carolina Fuel Company, Inc.		SCANA Communications, Inc.
South Carolina Generating Company, Inc.		ServiceCare, Inc.
Public Service Company of North Carolina, Incorporated		SCANA Services, Inc.
Carolina Gas Transmission Corporation		SCANA Corporate Security Services, Inc.

The Company reports certain investments using the cost or equity method of accounting, as appropriate. Intercompany balances and transactions have been eliminated in consolidation, with the exception of profits on intercompany sales to regulated affiliates if the sales price is reasonable and the future recovery of the sales price through the rate-making process is probable, as permitted by accounting guidance.

Use of Estimates

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amount of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Asset Management and Supply Service Agreements

PSNC Energy utilizes asset management and supply service agreements with counterparties for certain natural gas storage facilities. Such counterparties held 44% and 45% of PSNC Energy’s natural gas inventory at December 31, 2012 and December 31, 2011, respectively, with a carrying value of $19.6 million and $28.7 million, respectively, through either capacity release or agency relationships. Under the terms of the asset management agreements, PSNC Energy receives storage asset management fees. No fees are received under supply service agreements. The agreements expire at various times through March 31, 2013

Earnings Per Share

The Company computes basic earnings per share by dividing net income by the weighted average number of common shares outstanding for the period. The Company computes diluted earnings per share using this same formula, after giving effect to securities considered to be dilutive potential common stock utilizing the treasury stock method. The Company has issued no securities that would have an antidilutive effect on earnings per share.

A reconciliation of the weighted average number of common shares for each of the three years ended December 31, 2012 for basic and diluted purposes is as follows:



In Millions	2012	2011	2010
Weighted Average Shares Outstanding—Basic	131.1	128.8	125.7
Net effect of equity forward contracts	2.2	1.4	0.6
Weighted Average Shares Outstanding—Diluted	133.3	130.2	126.3

Property, Plant and Equipment, Planned Major Maintenance Activities, Policy [Policy Text Block]

Major Maintenance

Planned major maintenance costs related to certain fossil fuel turbine equipment and nuclear refueling outages are accrued in periods other than when incurred in accordance with approval by the SCPSC for such accounting treatment and rate recovery of expenses accrued thereunder. The difference between such cumulative major maintenance costs and cumulative collections are classified as a regulatory asset or regulatory liability on the consolidated balance sheet (see Note 2). Other planned major maintenance is expensed when incurred.

Through 2017, SCE&G is authorized to collect $18.4 million annually through electric rates to offset certain turbine maintenance expenditures. For the years ended December 31, 2012 and 2011, SCE&G incurred $11.1 million and $11.5 million, respectively, for turbine maintenance.

Nuclear refueling outages are scheduled 18 months apart, and SCE&G begins accruing for each successive scheduled outage upon completion of the preceding scheduled outage. SCE&G accrued $1.2 million per month from January 2010 through December 2012 for its portion of the outages in the spring of 2011 and the fall of 2012. Total costs for the 2011 outage were $34.1 million, of which SCE&G was responsible for $22.7 million. Total costs for the 2012 outage were $32.3 million, of which SCE&G was responsible for $21.5 million. In connection with the SCPSC's December 2012 approval of SCE&G's retail electric rates (see Note 2), effective January 1, 2013, SCE&G began to accrue $1.4 million per month for its portion of the nuclear refueling outages that are scheduled to occur through the spring of 2020.

Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]

Goodwill

The Company considers amounts categorized by FERC as “acquisition adjustments” with carrying values of $210 million (net of writedown of $230 million) for PSNC Energy (Gas Distribution segment) and $20 million for CGT (All Other segment) to be goodwill. The Company tests these goodwill amounts for impairment annually as of January 1, unless indicators, events or circumstances require interim testing to be performed. The goodwill impairment testing is generally a two-step quantitative process which in step one requires estimation of the fair value of the respective reporting unit and the comparison of that amount to the carrying value of the reporting unit. If this step indicates an impairment (a carrying value in excess of fair value), then step two, measurement of the amount of the goodwill impairment (if any), is required. In the first quarter of 2012, the Company adopted guidance under which it has the option to first perform a qualitative assessment of impairment. Based on this qualitative ("step zero") assessment, if the Company determines that it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, the Company is not required to proceed with the two-step quantitative assessment.

In evaluations of PSNC Energy, fair value is estimated using the assistance of an independent appraisal. In evaluations of CGT, prior to adoption of the new guidance, estimated fair value was obtained from internal analyses. In all evaluations for the periods presented, step one or step zero, as applicable, has indicated no impairment. The fair values of the reporting units are substantially in excess of their carrying values, and no impairment charges have been recorded; however, should a write-down be required in the future, such a charge would be treated as an operating expense.

Nuclear Decommissiong [Policy Text Block]

Nuclear Decommissioning

SCE&G’s two-thirds share of estimated site-specific nuclear decommissioning costs for Summer Station Unit 1, including the cost of decommissioning plant components both subject to and not subject to radioactive contamination, totals $696.8 million, stated in 2012 dollars, pursuant to an updated decommissioning cost study performed in 2012. Santee Cooper is responsible for decommissioning costs related to its one-third ownership interest in Summer Station Unit 1. The cost estimate assumes that the site will be maintained over a period of approximately 60 years in such a manner as to allow for subsequent decontamination that would permit release for unrestricted use.

Under SCE&G’s method of funding decommissioning costs, amounts collected through rates ($3.2 million pre-tax in each of 2012, 2011 and 2010) are invested in insurance policies on the lives of certain Company personnel. SCE&G transfers to an external trust fund the amounts collected through electric rates, insurance proceeds and interest thereon, less expenses. The trusteed asset balance reflects the net cash surrender value of the insurance policies and cash held by the trust. Management intends for the fund, including earnings thereon, to provide for all eventual decommissioning expenditures for Summer Station Unit 1 on an after-tax basis.

Cash and Cash Equivalents, Policy [Policy Text Block]

Cash and Cash Equivalents

The Company considers temporary cash investments having original maturities of three months or less at time of purchase to be cash equivalents. These cash equivalents are generally in the form of commercial paper, certificates of deposit, repurchase agreements, treasury bills and notes.

Trade and Other Accounts Receivable, Unbilled Receivables, Policy [Policy Text Block]

Accounts Receivable

Accounts receivable reflect amounts due from customers arising from the delivery of energy or related services and include revenues earned pursuant to revenue recognition practices described below. These receivables include both billed and unbilled amounts. Receivables are generally due within one month of receipt of invoices which are presented on a monthly cycle basis.

Income Tax, Policy [Policy Text Block]

Income Taxes

The Company files a consolidated federal income tax return. Under a joint consolidated income tax allocation agreement, each subsidiary’s current and deferred tax expense is computed on a stand-alone basis. Deferred tax assets and liabilities are recorded for the tax effects of all significant temporary differences between the book basis and tax basis of assets and liabilities at currently enacted tax rates. Deferred tax assets and liabilities are adjusted for changes in such tax rates through charges or credits to regulatory assets or liabilities if they are expected to be recovered from, or passed through to, customers of the Company’s regulated subsidiaries; otherwise, they are charged or credited to income tax expense.

regulatory assets and regulatory liabilities [Policy Text Block]

Regulatory Assets and Regulatory Liabilities

The Company’s rate-regulated utilities record costs that have been or are expected to be allowed in the ratemaking process in a period different from the period in which the costs would be charged to expense by a nonregulated enterprise. These regulatory assets and liabilities represent expenses deferred for future recovery from customers or obligations to be refunded to customers and are primarily classified in the balance sheet as regulatory assets and regulatory liabilities (see Note 2). The regulatory assets and liabilities are amortized consistent with the treatment of the related costs in the ratemaking process.

Debt Premium, Discount, and Expense [Policy Text Block]

Debt Premium, Discount and Expense, Unamortized Loss on Reacquired Debt

The Company records long-term debt premium and discount within long-term debt and amortizes them as components of interest charges over the terms of the respective debt issues. For regulated subsidiaries, other issuance expense and gains or losses on reacquired debt that is refinanced are recorded in other deferred debits or credits and are amortized over the term of the replacement debt, also as interest charges.

Environmental Costs, Policy [Policy Text Block]

Environmental

The Company maintains an environmental assessment program to identify and evaluate current and former operations sites that could require environmental clean-up. As site assessments are initiated, estimates are made of the amount of expenditures, if any, deemed necessary to investigate and remediate each site. Environmental remediation liabilities are accrued when the criteria for loss contingencies are met. These estimates are refined as additional information becomes available; therefore, actual expenditures could differ significantly from the original estimates. Probable and estimable costs are accrued related to environmental sites on an undiscounted basis. Amounts estimated and accrued to date for site assessments and clean-up relate solely to regulated operations. Amounts expected to be recovered through rates are recorded in regulatory assets and, if applicable, amortized over approved amortization periods. Other environmental costs are recorded to expense.

Income Statement policy [Policy Text Block]

Income Statement Presentation

In its consolidated statements of income, the Company presents the activities of its regulated businesses (including those activities of segments described in Note 12) within operating income, and it presents all other activities within other income (expense).

Revenue Recognition, Policy [Policy Text Block]

Revenue Recognition

The Company records revenues during the accounting period in which it provides services to customers and includes estimated amounts for electricity and natural gas delivered but not billed. Unbilled revenues totaled $189.8 million at December 31, 2012 and $169.1 million at December 31, 2011.

Fuel costs, emission allowances and certain environmental reagent costs for electric generation are collected through the fuel cost component in retail electric rates. This component is established by the SCPSC during fuel cost hearings. Any difference between actual fuel costs and amounts contained in the fuel cost component is deferred and included when determining the fuel cost component during subsequent hearings.

SCE&G customers subject to a PGA are billed based on a cost of gas factor calculated in accordance with a gas cost recovery procedure approved by the SCPSC and subject to adjustment monthly. Any difference between actual gas costs, including the results of its hedging program, if any, and amounts contained in rates is deferred and included when making the next adjustment to the cost of gas factor. PSNC Energy’s PGA mechanism authorized by the NCUC allows the recovery of all prudently incurred gas costs, including the results of its hedging program, from customers. Any difference between actual gas costs and amounts contained in rates is deferred and included when establishing gas costs during subsequent PGA filings or in annual prudence reviews.

SCE&G’s gas rate schedules for residential, small commercial and small industrial customers include a WNA which minimizes fluctuations in gas revenues due to abnormal weather conditions. In August 2010, SCE&G implemented an eWNA on a pilot basis for its electric customers, and it will continue on a pilot basis unless modified or terminated by the SCPSC.

PSNC Energy is authorized by the NCUC to utilize a CUT which allows it to adjust base rates semi-annually for residential and commercial customers based on average per customer consumption, whether impacted by weather or other factors.

Taxes that are billed to and collected from customers are recorded as liabilities until they are remitted to the respective taxing authority. Such taxes are not included in revenues or expenses in the statements of income.

Property, Plant and Equipment, Policy [Policy Text Block]

Utility Plant

Utility plant is stated substantially at original cost. The costs of additions, replacements and betterments to utility plant, including direct labor, material and indirect charges for engineering, supervision and an allowance for funds used during construction, are added to utility plant accounts. The original cost of utility property retired or otherwise disposed of is removed from utility plant accounts and generally charged to accumulated depreciation. The costs of repairs and replacements of items of property determined to be less than a unit of property or that do not increase the asset’s life or functionality are charged to expense.

AFC is a noncash item that reflects the period cost of capital devoted to plant under construction. This accounting practice results in the inclusion of, as a component of construction cost, the costs of debt and equity capital dedicated to construction investment. AFC is included in rate base investment and depreciated as a component of plant cost in establishing rates for utility services. The Company’s regulated subsidiaries calculated AFC using average composite rates of 6.3% for 2012, 4.7% for 2011 and 7.4% for 2010. These rates do not exceed the maximum allowable rate as calculated under FERC Order No. 561. SCE&G capitalizes interest on nuclear fuel in process at the actual interest cost incurred.

The Company records provisions for depreciation and amortization using the straight-line method based on the estimated service lives of the various classes of property. The composite weighted average depreciation rates for utility plant assets were as follows:



	2012		2011		2010
SCE&G	2.93	%	2.92	%	2.83	%
GENCO	2.66	%	2.69	%	2.66	%
CGT	2.09	%	2.00	%	1.94	%
PSNC Energy	3.01	%	3.05	%	3.11	%
Aggregate of Above	2.90	%	2.90	%	2.85	%

SCE&G records nuclear fuel amortization using the units-of-production method. Nuclear fuel amortization is included in “Fuel used in electric generation” and recovered through the fuel cost component of retail electric rates. Provisions for amortization of nuclear fuel include amounts necessary to satisfy obligations to the DOE under a contract for disposal of spent nuclear fuel.

SCE&G

Significant Accounting Policies

New Accounting Pronouncements, Policy [Policy Text Block]

New Accounting Matters

In 2012, Consolidated SCE&G adopted accounting guidance that revised how comprehensive income is presented in its financial statements and conformed the presentation for 2011 and 2010. In the first quarter of 2013, Consolidated SCE&G will adopt recent additional guidance requiring the disclosure of the effects of items reclassified out of accumulated other comprehensive income. The adoption of this guidance did not impact Consolidated SCE&G's results of operations, cash flows or financial position.

In 2012, Consolidated SCE&G adopted accounting guidance that amended existing requirements for measuring fair value and for disclosing information about fair value measurements. The adoption of this guidance did not impact Consolidated SCE&G's results of operations, cash flows or financial position.

Jointly Owned Plant Policy [Policy Text Block]

Jointly Owned Utility Plant



	Unit 1			New Units
As of December 31, 2012
Percent owned	66.7%			55.0%
Plant in service	$	1.1	billion	—
Accumulated depreciation	$	557.0	million	—
Construction work in progress	$	113.6	million	$	1.8	billion
As of December 31, 2011
Percent owned	66.7%			55.0%
Plant in service	$	1.0	billion	—
Accumulated depreciation	$	545.0	million	—
Construction work in progress	$	71.0	million	$	1.2	billion

Consolidation, Policy [Policy Text Block]

Organization and Principles of Consolidation

SCE&G, a public utility, is a South Carolina corporation organized in 1924 and a wholly-owned subsidiary of SCANA, a South Carolina corporation. Consolidated SCE&G engages predominantly in the generation and sale of electricity to wholesale and retail customers in South Carolina and in the purchase, sale and transportation of natural gas to retail customers in South Carolina.

SCE&G has determined that it has a controlling financial interest in GENCO and Fuel Company (which are considered to be VIEs), and accordingly, the accompanying consolidated financial statements include the accounts of SCE&G, GENCO and Fuel Company. The equity interests in GENCO and Fuel Company are held solely by SCANA, SCE&G’s parent. Accordingly, GENCO’s and Fuel Company’s equity and results of operations are reflected as noncontrolling interest in Consolidated SCE&G’s consolidated financial statements. Intercompany balances and transactions between SCE&G, Fuel Company and GENCO have been eliminated in consolidation.

GENCO owns a coal-fired electric generating station with a 605 megawatt net generating capacity (summer rating). GENCO’s electricity is sold, pursuant to a FERC-approved tariff, solely to SCE&G under the terms of a power purchase agreement and related operating agreement. The effects of these transactions are eliminated in consolidation. Substantially all of GENCO’s property (carrying value of approximately $475 million) serves as collateral for its long-term borrowings. Fuel Company acquires, owns and provides financing for SCE&G’s nuclear fuel, certain fossil fuels and emission and other environmental allowances. See also Note 4.

Use of Estimates

Property, Plant and Equipment, Planned Major Maintenance Activities, Policy [Policy Text Block]

Utility Plant

AFC is a noncash item that reflects the period cost of capital devoted to plant under construction. This accounting practice results in the inclusion of, as a component of construction cost, the costs of debt and equity capital dedicated to construction investment. AFC is included in rate base investment and depreciated as a component of plant cost in establishing rates for utility services. Consolidated SCE&G calculated AFC using average composite rates of 6.3% for 2012, 4.6% for 2011 and 7.3% for 2010. These rates do not exceed the maximum allowable rate as calculated under FERC Order No. 561. SCE&G capitalizes interest on nuclear fuel in process at the actual interest cost incurred.

Consolidated SCE&G records provisions for depreciation and amortization using the straight-line method based on the estimated service lives of the various classes of property. The composite weighted average depreciation rates for utility plant assets were 2.91% in 2012, 2.90% in 2011 and 2.84% in 2010.

Major Maintenance

Planned major maintenance costs related to certain fossil fuel turbine equipment and nuclear refueling outages are accrued in periods other than when incurred in accordance with approval by the SCPSC for such accounting treatment and rate recovery of expenses accrued thereunder. The difference between such cumulative major maintenance costs and cumulative collections are classified as a regulatory asset or regulatory liability on the balance sheet (see Note 2). Other planned major maintenance is expensed when incurred.

Nuclear Decommissiong [Policy Text Block]

Nuclear Decommissioning

SCE&G’s two-thirds share of estimated site-specific nuclear decommissioning costs for Summer Station Unit 1, including the cost of decommissioning plant components both subject to and not subject to radioactive contamination, totals $696.8 million, stated in 2012 dollars, pursuant an updated decommissioning cost study performed in 2012. Santee Cooper is responsible for decommissioning costs related to its one-third ownership interest in Summer Station Unit 1. The cost estimate assumes that the site will be maintained over a period of approximately 60 years in such a manner as to allow for subsequent decontamination that would permit release for unrestricted use.

Under SCE&G’s method of funding decommissioning costs, amounts collected through rates ($3.2 million pre-tax in each of 2012, 2011 and 2010) are invested in insurance policies on the lives of certain SCE&G and affiliate personnel. SCE&G transfers to an external trust fund the amounts collected through electric rates, insurance proceeds and interest thereon, less expenses. The trusteed asset balance reflects the net cash surrender value of the insurance policies and cash held by the trust. Management intends for the fund, including earnings thereon, to provide for all eventual decommissioning expenditures for Summer Station Unit 1 on an after-tax basis.

Cash and Cash Equivalents, Policy [Policy Text Block]

Cash and Cash Equivalents

Consolidated SCE&G considers temporary cash investments having original maturities of three months or less at time of purchase to be cash equivalents. These cash equivalents are generally in the form of commercial paper, certificates of deposit, repurchase agreements, treasury bills and notes.

Trade and Other Accounts Receivable, Unbilled Receivables, Policy [Policy Text Block]

Accounts Receivable

Income tax presentation policy [Policy Text Block]

Income Taxes

Consolidated SCE&G is included in the consolidated federal income tax return of SCANA. Under a joint consolidated income tax allocation agreement, each SCANA subsidiary’s current and deferred tax expense is computed on a stand-alone basis. Deferred tax assets and liabilities are recorded for the tax effects of all significant temporary differences between the book basis and tax basis of assets and liabilities at currently enacted tax rates. Deferred tax assets and liabilities are adjusted for changes in such tax rates through charges or credits to regulatory assets or liabilities if they are expected to be recovered from, or passed through to, customers; otherwise, they are charged or credited to income tax expense. Also under provisions of the income tax allocation agreement, certain tax benefits of the parent holding company are distributed in cash to tax paying affiliates, including Consolidated SCE&G, in the form of capital contributions.

regulatory assets and regulatory liabilities [Policy Text Block]

Regulatory Assets and Regulatory Liabilities

Consolidated SCE&G records costs that have been or are expected to be allowed in the ratemaking process in a period different from the period in which the costs would be charged to expense by a nonregulated enterprise. These regulatory assets and liabilities represent expenses deferred for future recovery from customers or obligations to be refunded to customers and are primarily classified in the balance sheet as regulatory assets and regulatory liabilities (see Note 2). The regulatory assets and liabilities are amortized consistent with the treatment of the related costs in the ratemaking process.

Debt Premium, Discount, and Expense [Policy Text Block]

Debt Premium, Discount and Expense, Unamortized Loss on Reacquired Debt

Consolidated SCE&G records long-term debt premium and discount within long-term debt and amortizes them as components of interest charges over the terms of the respective debt issues. Other issuance expense and gains or losses on reacquired debt that is refinanced are recorded in other deferred debits or credits and are amortized over the term of the replacement debt, also as interest charges.

Environmental Costs, Policy [Policy Text Block]

Environmental

SCE&G maintains an environmental assessment program to identify and evaluate current and former operations sites that could require environmental clean-up. As site assessments are initiated, estimates are made of the amount of expenditures, if any, deemed necessary to investigate and remediate each site. Environmental remediation liabilities are accrued when the criteria for loss contingencies are met. These estimates are refined as additional information becomes available; therefore, actual expenditures could differ significantly from the original estimates. Probable and estimable costs are accrued related to environmental sites on an undiscounted basis. Amounts estimated and accrued to date for site assessments and clean-up relate solely to regulated operations. Amounts expected to be recovered through rates are recorded in regulatory assets and, if applicable, amortized over approved amortization periods. Other environmental costs are recorded to expense.

Income Statement policy [Policy Text Block]

Income Statement Presentation

In its consolidated statements of income, Consolidated SCE&G presents the activities of its regulated businesses (including those activities of segments described in Note 12) within operating income, and it presents all other activities within other income (expense).

Revenue Recognition, Policy [Policy Text Block]

Revenue Recognition

Consolidated SCE&G records revenues during the accounting period in which it provides services to customers and includes estimated amounts for electricity and natural gas delivered but not billed. Unbilled revenues totaled $129.0 million at December 31, 2012 and $117.8 million at December 31, 2011.

Customers subject to the PGA are billed based on a cost of gas factor calculated in accordance with a gas cost recovery procedure approved by the SCPSC and subject to adjustment monthly. Any difference between actual gas costs and amounts contained in rates is deferred and included when making the next adjustment to the cost of gas factor. In addition, included in these deferred amounts are realized gains and losses incurred in SCE&G’s natural gas hedging program, if any.