10-K - SCANA Corporation
10-K - SCANA Corporation
10-K - SCANA Corporation
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Table of Contents<br />
costs for turbine maintenance in excess of cumulative collections are classified as a regulatory asset on the balance sheet. Nuclear<br />
refueling outages are scheduled 18 months apart, and SCE&G begins accruing for each successive scheduled outage upon completion<br />
of the preceding scheduled outage. SCE&G accrued $1.2 million per month from July 2008 through July 2011 for its portion of the<br />
outages in the fall of 2009 and the spring of 2011. Total costs for the 2009 outage were $32.7 million, of which SCE&G was<br />
responsible for $21.8 million. Total costs for the 2011 outage were $34.1 million, of which SCE&G was responsible for $22.7<br />
million. In July 2011, SCE&G began accruing $1.2 million per month for its portion of the refueling planned for the fall of 2012.<br />
SCE&G had an accrued balance of $7.2 million at December 31, 2011 and $14.3 million at December 31, 20<strong>10</strong>.<br />
Goodwill<br />
The Company considers amounts categorized by FERC as “acquisition adjustments” with carrying values of $2<strong>10</strong> million for<br />
PSNC Energy (Gas Distribution segment) and $20 million for CGT (All Other segment) to be goodwill. The Company tests these<br />
goodwill amounts for impairment annually as of January 1, unless indicators, events or circumstances require interim testing to be<br />
performed. The goodwill impairment testing is a two-step process which in step one requires estimation of the fair value of the<br />
respective reporting unit and the comparison of that amount to the carrying value of the reporting unit. If this step indicates an<br />
impairment (a carrying value in excess of fair value), then step two, measurement of the amount of the goodwill impairment (if any),<br />
is required. In the first quarter of 2012, the Company will adopt accounting guidance whereby it will have the option to first perform a<br />
qualitative assessment of impairment. Based on this assessment, if the Company determines that it is not more likely than not that the<br />
fair value of a reporting unit is less than its carrying amount, the Company will not be required to proceed with the two-step<br />
quantitative assessment.<br />
In evaluations of PSNC Energy, fair value is estimated using the assistance of an independent appraisal. In evaluations of<br />
CGT, estimated fair value has been obtained from internal analyses. In all evaluations for the periods presented, step one has indicated<br />
no impairment, and no impairment charges have been recorded; however, should a write-down be required in the future, such a charge<br />
would be treated as an operating expense.<br />
Nuclear Decommissioning<br />
SCE&G’s two-thirds share of estimated site-specific nuclear decommissioning costs for Summer Station Unit 1, including<br />
the cost of decommissioning plant components both subject to and not subject to radioactive contamination, totals $451.0 million,<br />
stated in 2006 dollars. Santee Cooper is responsible for decommissioning costs related to its one-third ownership interest in Summer<br />
Station Unit 1. The cost estimate assumes that the site would be maintained over a period of approximately 60 years in such a manner<br />
as to allow for subsequent decontamination that would permit release for unrestricted use.<br />
Under SCE&G’s method of funding decommissioning costs, amounts collected through rates ($3.2 million pre-tax in each of<br />
2011, 20<strong>10</strong> and 2009) are invested in insurance policies on the lives of certain Company personnel. SCE&G transfers to an external<br />
trust fund the amounts collected through electric rates, insurance proceeds and interest thereon, less expenses. The trusteed asset<br />
balance reflects the net cash surrender value of the insurance policies and cash held by the trust. Management intends for the fund,<br />
including earnings thereon, to provide for all eventual decommissioning expenditures for Summer Station Unit 1 on an after-tax basis.<br />
Cash and Cash Equivalents<br />
The Company considers temporary cash investments having original maturities of three months or less at time of purchase to<br />
be cash equivalents. These cash equivalents are generally in the form of commercial paper, certificates of deposit, repurchase<br />
agreements, treasury bills and notes.<br />
Account Receivable<br />
Accounts receivable reflect amounts due from customers arising from the delivery of energy or related services and include<br />
revenues earned pursuant to revenue recognition practices described below. These receivables include both billed and unbilled<br />
amounts. Receivables are generally due within one month of receipt of invoices which are presented on a monthly cycle basis.<br />
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