DOCUMENT AND ENTITY INFORMATION |
3 Months Ended |
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Sep. 30, 2013
shares
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Document and Entity Information [Abstract] | |
Entity Registrant Name | Sempra Energy |
Document Type | 10-Q |
Document Period End Date | Sep. 30, 2013 |
Amendment Flag | false |
Document Fiscal Year Focus | 2013 |
Document Fiscal Period Focus | Q3 |
Current Fiscal Year End Date | --12-31 |
Entity Filer Category | Large Accelerated Filer |
Entity Common Shares Outstanding | 244,399,914 |
Entity Central Index Key | 0001032208 |
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- Definition If the value is true, then the document is an amendment to previously-filed/accepted document. No definition available.
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- Definition End date of current fiscal year in the format --MM-DD. No definition available.
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- Definition This is focus fiscal period of the document report. For a first quarter 2006 quarterly report, which may also provide financial information from prior periods, the first fiscal quarter should be given as the fiscal period focus. Values: FY, Q1, Q2, Q3, Q4, H1, H2, M9, T1, T2, T3, M8, CY. No definition available.
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- Definition This is focus fiscal year of the document report in CCYY format. For a 2006 annual report, which may also provide financial information from prior periods, fiscal 2006 should be given as the fiscal year focus. Example: 2006. No definition available.
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- Definition The end date of the period reflected on the cover page if a periodic report. For all other reports and registration statements containing historical data, it is the date up through which that historical data is presented. If there is no historical data in the report, use the filing date. The format of the date is CCYY-MM-DD. No definition available.
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- Definition The type of document being provided (such as 10-K, 10-Q, 485BPOS, etc). The document type is limited to the same value as the supporting SEC submission type, or the word "Other". No definition available.
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- Definition A unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Indicate number of shares or other units outstanding of each of registrant's classes of capital or common stock or other ownership interests, if and as stated on cover of related periodic report. Where multiple classes or units exist define each class/interest by adding class of stock items such as Common Class A [Member], Common Class B [Member] or Partnership Interest [Member] onto the Instrument [Domain] of the Entity Listings, Instrument. No definition available.
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- Definition Indicate whether the registrant is one of the following: (1) Large Accelerated Filer, (2) Accelerated Filer, (3) Non-accelerated Filer, (4) Smaller Reporting Company (Non-accelerated) or (5) Smaller Reporting Accelerated Filer. Definitions of these categories are stated in Rule 12b-2 of the Exchange Act. This information should be based on the registrant's current or most recent filing containing the related disclosure. No definition available.
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- Definition The exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- References No definition available.
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- References No definition available.
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- Definition Contingently Redeemable Preferred Stock of Subsidiary. No definition available.
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- Definition Deferred taxes refundable in rates, noncurrent asset. No definition available.
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- References No definition available.
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- Definition Preferred stock of subsidiaries. No definition available.
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- References No definition available.
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- Definition Regulatory assets arising from fixed-price contracts and other derivatives, current asset. No definition available.
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- Definition Regulatory assets arising from fixed-price contracts and other derivatives, noncurrent asset. No definition available.
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- Definition Regulatory assets arising from pension and other posretirement benefit obligations. No definition available.
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- Definition Regulatory assets arising from wildfire litigation costs. No definition available.
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- Definition Regulatory balancing accounts, overcollected. No definition available.
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- Definition Regulatory balancing amounts, undercollected. No definition available.
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- Definition Regulatory liabilities arising from removal obligations. No definition available.
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- Definition Regulatory balancing accounts, net asset No definition available.
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- Definition Regulatory balancing accounts, Net liability No definition available.
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- Definition Total deferred credits and other liabilities. No definition available.
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- Definition Total investments and other assets. No definition available.
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- Definition The aggregate of amounts due from customers or clients, within one year of the balance sheet date (or one operating cycle, if longer), for goods or services that have been delivered or sold in the normal course of business and an amount representing an agreement for an unconditional promise by the maker to pay the entity (holder) a definite sum of money at a future date within one year of the balance sheet, reduced to their estimated net realizable fair value by an allowance established by the entity of the amount it deems uncertain of collection and net of any write-downs taken for collection uncertainty on the part of the holder, respectively. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying value as of the balance sheet date of obligations incurred and payable, which are not elsewhere specified in the taxonomy. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying value as of the balance sheet date of obligations incurred (and for which invoices have typically been received) and payable to vendors for goods and services received that are used in an entity's business. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount due from customers or clients, within one year of the balance sheet date (or the normal operating cycle, whichever is longer), for goods or services (including trade receivables) that have been delivered or sold in the normal course of business, reduced to the estimated net realizable fair value by an allowance established by the entity of the amount it deems uncertain of collection. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying amount as of the balance sheet date of the unpaid sum of the known and estimated amounts payable to satisfy all currently due domestic and foreign income tax obligations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The noncurrent portion of the reserve for accumulated deferred investment tax credits as of the balance sheet date. This is the remaining investment credit, which will reduce the cost of services collected from ratepayers by a ratable portion over the investment's regulatory life. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The cumulative amount of depreciation, depletion and amortization (related to property, plant and equipment, but not including land) that has been recognized in the income statement. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Noncurrent portion of the carrying amount of a liability for an asset retirement obligation. An asset retirement obligation is a legal obligation associated with the disposal or retirement of a tangible long-lived asset that results from the acquisition, construction or development, or the normal operations of a long-lived asset, except for certain obligations of lessees. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Sum of the carrying amounts as of the balance sheet date of all assets that are recognized. Assets are probable future economic benefits obtained or controlled by an entity as a result of past transactions or events. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Sum of the carrying amounts as of the balance sheet date of all assets that are expected to be realized in cash, sold, or consumed within one year (or the normal operating cycle, if longer). Assets are probable future economic benefits obtained or controlled by an entity as a result of past transactions or events. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- References No definition available.
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- Definition Current assets (normally turning over within one year or one business cycle if longer) that are held for sale apart from normal operations and anticipated to be sold within one year. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of currency on hand as well as demand deposits with banks or financial institutions. Includes other kinds of accounts that have the general characteristics of demand deposits. Also includes short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. Excludes cash and cash equivalents within disposal group and discontinued operation. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Aggregate par or stated value of issued nonredeemable common stock (or common stock redeemable solely at the option of the issuer). This item includes treasury stock repurchased by the entity. Note: elements for number of nonredeemable common shares, par value and other disclosure concepts are in another section within stockholders' equity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition For utilities only, represents the carrying amount of the liability as of the balance sheet date for payments received by a utility from its customers in advance of performing its obligations under terms of its construction agreements. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The current portion of money or property received from customers which is either to be returned upon satisfactory contract completion or applied to customer receivables in accordance with the terms of the contract or the understandings. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Decommission fund to pay for the costs of decontaminating and decommissioning of facilities through collection of revenues derived from utility assessments and government appropriations. Decommission fund investment for the process whereby a power station, at the end of its economic life, is taken permanently out of service and its site made available for other purposes. In the case of a nuclear station this comprises three different states of clearance. Immediately after the final closure, radioactive material such as nuclear fuel and operational waste is removed and the buildings surrounding the reactor shield are dismantled and finally the reactor itself is dismantled. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- References No definition available.
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- Definition Amount after allocation of valuation allowances of deferred tax asset attributable to deductible temporary differences and carryforwards expected to be realized or consumed within one year or operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of deferred tax liability attributable to taxable temporary differences, net of deferred tax asset attributable to deductible temporary differences and carryforwards net of valuation allowances expected to be realized or consumed within one year or operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of deferred tax liability attributable to taxable temporary differences, net of deferred tax asset attributable to deductible temporary differences and carryforwards net of valuation allowances expected to be realized or consumed after one year (or the normal operating cycle, if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Fair values as of the balance sheet date for all assets resulting from contracts that meet the criteria of being accounted for as derivative instruments and which are expected to be converted into cash or otherwise disposed of within a year or the normal operating cycle, if longer, net of the effects of master netting arrangements. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Fair values as of the balance sheet date of all liabilities resulting from contracts that meet the criteria of being accounted for as derivative instruments, and which are expected to be extinguished or otherwise disposed of within a year or the normal operating cycle, if longer, net of the effects of master netting arrangements. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Fair values as of the balance sheet date of all liabilities resulting from contracts that meet the criteria of being accounted for as derivative instruments, and which are expected to be extinguished or otherwise disposed of after one year or beyond the normal operating cycle, if longer, net of the effects of master netting arrangements. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of receivables due from an entity that is affiliated with the reporting entity by means of direct or indirect ownership, due within 1 year (or 1 business cycle). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of payable due to an entity that is affiliated with the reporting entity by means of direct or indirect ownership. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Total of the carrying values as of the balance sheet date of obligations incurred through that date and payable for obligations related to services received from employees, such as accrued salaries and bonuses, payroll taxes and fringe benefits. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying amount as of the balance sheet date, which is the cumulative amount paid and (if applicable) the fair value of any noncontrolling interest in the acquiree, adjusted for any amortization recognized prior to the adoption of any changes in generally accepted accounting principles (as applicable) and for any impairment charges, in excess of the fair value of net assets acquired in one or more business combination transactions. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying amount as of the balance sheet date of amounts due under the terms of governmental, corporate, or foundation grants. For classified balance sheets, represents the current amount receivable, that is amounts expected to be collected within one year or the normal operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying amount due within one year of the balance sheet date (or one operating cycle, if longer) from tax authorities as of the balance sheet date representing refunds of overpayments or recoveries based on agreed-upon resolutions of disputes. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Sum of the carrying amounts of all intangible assets, excluding goodwill, as of the balance sheet date, net of accumulated amortization and impairment charges. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Sum of the carrying values as of the balance sheet date of (a) interest payable on all forms of debt, including trade payables, that has been incurred, and (b) dividends declared but unpaid on equity securities issued by the entity and outstanding (also includes dividends collected on behalf of another owner of securities that are being held by the entity). Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying amount (lower of cost or market) as of the balance sheet date of inventories less all valuation and other allowances. Excludes noncurrent inventory balances (expected to remain on hand past one year or one operating cycle, if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Total investments in (A) an entity in which the entity has significant influence, but does not have control, (B) subsidiaries that are not required to be consolidated and are accounted for using the equity and or cost method, and (C) an entity in which the reporting entity shares control of the entity with another party or group. Includes long-term advances receivable from a party that is affiliated with the reporting entity by means of direct or indirect ownership. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Total of all Liabilities and Stockholders' Equity items (or Partners' Capital, as applicable), including the portion of equity attributable to noncontrolling interests, if any. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Total obligations incurred as part of normal operations that are expected to be paid during the following twelve months or within one business cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- References No definition available.
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- Definition Carrying amount of reserve for known or estimated probable loss from litigation, which may include attorneys' fees and other litigation costs, which is expected to be paid within one year of the date of the statement of financial position. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Sum of the carrying values as of the balance sheet date of all long-term debt, which is debt initially having maturities due after one year from the balance sheet date or beyond the operating cycle, if longer, but excluding the portions thereof scheduled to be repaid within one year or the normal operating cycle, if longer plus capital lease obligations due to be paid more than one year after the balance sheet date. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Obligation related to long-term debt (excluding convertible debt) and capital leases, the portion which is due in one year or less in the future. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Total of all stockholders' equity (deficit) items, net of receivables from officers, directors, owners, and affiliates of the entity which is directly or indirectly attributable to that ownership interest in subsidiary equity which is not attributable to the parent (that is, noncontrolling interest, previously referred to as minority interest). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Aggregate carrying amount, as of the balance sheet date, of current assets not separately disclosed in the balance sheet. Current assets are expected to be realized or consumed within one year (or the normal operating cycle, if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Aggregate carrying amount, as of the balance sheet date, of noncurrent assets not separately disclosed in the balance sheet. Noncurrent assets are expected to be realized or consumed after one year (or the normal operating cycle, if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Aggregate carrying amount of current liabilities (due within one year or within the normal operating cycle if longer) not separately disclosed in the balance sheet. Includes costs that are statutory in nature, are incurred on contractual obligations, or accumulate over time and for which invoices have not yet been received or will not be rendered and of liabilities not separately disclosed. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Aggregate carrying amount, as of the balance sheet date, of noncurrent obligations not separately disclosed in the balance sheet. Noncurrent liabilities are expected to be paid after one year (or the normal operating cycle, if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition This represents the noncurrent liability for underfunded plans recognized in the balance sheet that is associated with the defined benefit pension plans and other postretirement defined benefit plans. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Aggregate par or stated value of issued nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer). This item includes treasury stock repurchased by the entity. Note: elements for number of nonredeemable preferred shares, par value and other disclosure concepts are in another section within stockholders' equity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Gross amount of long-lived physical assets used in the normal conduct of business and not intended for resale. Examples include, but are not limited to, land, buildings, machinery and equipment, office equipment, furniture and fixtures, and computer equipment. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount, net of accumulated depreciation, depletion and amortization, of long-lived physical assets used in the normal conduct of business and not intended for resale. Examples include, but are not limited to, land, buildings, machinery and equipment, office equipment, furniture and fixtures, and computer equipment. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- References No definition available.
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- Definition Carrying amount as of the balance sheet date of capitalized costs of regulated entities that are expected to be recovered through revenue sources within one year or the normal operating cycle, if longer. Such costs are capitalized if they meet both of the following criteria: a. It is probable that future revenue in an amount at least equal to the capitalized cost will result from inclusion of that cost in allowable costs for rate-making purposes. b. Based on available evidence, the future revenue will be provided to permit recovery of the previously incurred cost rather than to provide for expected levels of similar future costs. If the revenue will be provided through an automatic rate-adjustment clause, this criterion requires that the regulator's intent clearly be to permit recovery of the previously incurred cost. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying amount as of the balance sheet date of capitalized costs of regulated entities that are not expected to be recovered through revenue sources within one year or the normal operating cycle if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The carrying amounts of cash and cash equivalent items which are restricted as to withdrawal or usage. Restrictions may include legally restricted deposits held as compensating balances against short-term borrowing arrangements, contracts entered into with others, or entity statements of intention with regard to particular deposits; however, time deposits and short-term certificates of deposit are not generally included in legally restricted deposits. Excludes compensating balance arrangements that are not agreements which legally restrict the use of cash amounts shown on the balance sheet. For a classified balance sheet represents the current portion only (the noncurrent portion has a separate concept); there is a separate and distinct element for unclassified presentations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Cash and equivalents whose use in whole or in part is restricted for the long-term, generally by contractual agreements or regulatory requirements. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The cumulative amount of the reporting entity's undistributed earnings or deficit. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Reflects the total carrying amount as of the balance sheet date of debt having initial terms less than one year or the normal operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Total of all stockholders' equity (deficit) items, net of receivables from officers, directors, owners, and affiliates of the entity which are attributable to the parent. The amount of the economic entity's stockholders' equity attributable to the parent excludes the amount of stockholders' equity which is allocable to that ownership interest in subsidiary equity which is not attributable to the parent (noncontrolling interest, minority interest). This excludes temporary equity and is sometimes called permanent equity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of stockholders' equity (deficit), net of receivables from officers, directors, owners, and affiliates of the entity, attributable to both the parent and noncontrolling interests. Amount excludes temporary equity. Alternate caption for the concept is permanent equity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- References No definition available.
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- Definition Carrying amount, attributable to parent, of an entity's issued and outstanding stock which is not included within permanent equity. Temporary equity is a security with redemption features that are outside the control of the issuer, is not classified as an asset or liability in conformity with GAAP, and is not mandatorily redeemable. Includes any type of security that is redeemable at a fixed or determinable price or on a fixed or determinable date or dates, is redeemable at the option of the holder, or has conditions for redemption which are not solely within the control of the issuer. Includes stock with a put option held by an ESOP and stock redeemable by a holder only in the event of a change in control of the issuer. No definition available.
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CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) shares in Millions, $ in Millions |
Sep. 30, 2013 |
Dec. 31, 2012 |
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Property, plant and equipment related to VIE | $ 445 | $ 466 |
Long-term debt related to VIE | $ 327 | $ 335 |
Shareholders' equity: | ||
Preferred stock, shares authorized | 50 | 50 |
Preferred stock, shares issued | 0 | 0 |
Common stock, shares authorized | 750 | 750 |
Common stock, shares outstanding | 244 | 242 |
San Diego Gas and Electric Company and Subsidiary [Member] | ||
Property, plant and equipment related to VIE | $ 445 | $ 466 |
Long-term debt related to VIE | $ 327 | $ 335 |
Shareholders' equity: | ||
Common stock, shares authorized | 255 | 255 |
Common stock, shares outstanding | 117 | 117 |
Southern California Gas Company [Member] | ||
Shareholders' equity: | ||
Common stock, shares authorized | 100 | 100 |
Common stock, shares outstanding | 91 | 91 |
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- Definition Variable interest entities consolidated carrying amount long term debt. No definition available.
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- Definition Variable interest entities consolidated carrying amount net property plant and equipment. No definition available.
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- Definition The maximum number of common shares permitted to be issued by an entity's charter and bylaws. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Number of shares of common stock outstanding. Common stock represent the ownership interest in a corporation. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The maximum number of nonredeemable preferred shares (or preferred stock redeemable solely at the option of the issuer) permitted to be issued by an entity's charter and bylaws. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Total number of nonredeemable preferred shares (or preferred stock redeemable solely at the option of the issuer) issued to shareholders (includes related preferred shares that were issued, repurchased, and remain in the treasury). May be all or portion of the number of preferred shares authorized. Excludes preferred shares that are classified as debt. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- References No definition available.
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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions |
3 Months Ended | 9 Months Ended | ||
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Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
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REVENUES | ||||
Utilities | $ 2,223 | $ 2,170 | $ 6,889 | $ 6,099 |
Energy-related businesses | 328 | 337 | 963 | 880 |
Total revenues | 2,551 | 2,507 | 7,852 | 6,979 |
Utilities [Abstract] | ||||
Cost of natural gas | (261) | (212) | (1,182) | (864) |
Cost of electric fuel and purchased power | (537) | (515) | (1,461) | (1,252) |
Energy-related businesses [Abstract] | ||||
Cost of natural gas, electric fuel and purchased power | (120) | (136) | (325) | (346) |
Other cost of sales | (47) | (43) | (144) | (117) |
Operation and maintenance | (698) | (732) | (2,162) | (2,130) |
Depreciation and amortization | (286) | (280) | (828) | (803) |
Loss from plant closure | 0 | 0 | (200) | 0 |
Franchise fees and other taxes | (96) | (89) | (283) | (264) |
Gains on sale of assets | 39 | 0 | 113 | 7 |
Equity (losses) earnings before income tax | ||||
Equity (losses) earnings before income tax, other | 3 | (94) | 21 | (375) |
Other income (expense), net | 16 | 44 | 79 | 137 |
Interest income | 5 | 5 | 15 | 14 |
Interest expense | (137) | (126) | (413) | (352) |
Income before income taxes and equity earnings of certain unconsolidated subsidiaries | 432 | 329 | 1,082 | 634 |
Income tax (expense) benefit | (117) | (49) | (327) | (48) |
Equity earnings, net of income tax | 8 | 10 | 13 | 29 |
Net income | 323 | 290 | 768 | 615 |
Losses (earnings) attributable to noncontrolling interests | (22) | (20) | (41) | (44) |
Call premium on preferred stock of subsidiary | (3) | 0 | (3) | 0 |
Preferred dividends of subsidiaries | (2) | (2) | (5) | (5) |
Earnings | 296 | $ 268 | 719 | 566 |
Call premium on preferred stock | $ (3) | $ (3) | $ 0 | |
Basic earnings per common share: | ||||
Basic earnings per common share | $ 1.21 | $ 1.11 | $ 2.95 | $ 2.35 |
Basic earnings per common share, weighted-average number of shares outstanding (thousands) | 244,140 | 241,689 | 243,682 | 241,133 |
Diluted earnings per common share: | ||||
Diluted earnings per common share | $ 1.19 | $ 1.09 | $ 2.89 | $ 2.31 |
Diluted earnings per common share, weighted-average number of shares outstanding (thousands) | 249,259 | 245,802 | 248,723 | 245,013 |
Dividends declared per share of common stock | $ 0.63 | $ 0.60 | $ 1.89 | $ 1.80 |
San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Utility operating revenues | ||||
Electric | $ 970 | $ 998 | $ 2,685 | $ 2,349 |
Natural gas | 93 | 94 | 381 | 357 |
Total utility operating revenues | 1,063 | 1,092 | 3,066 | 2,706 |
Utility operating expenses | ||||
Utility cost of natural gas | 36 | 29 | 157 | 130 |
Utility cost of electric fuel and purchased power | 315 | 301 | 776 | 604 |
Utility operation and maintenance | 266 | 309 | 852 | 852 |
Utility depreciation and amortization | 126 | 128 | 367 | 359 |
Utility franchise fees and other taxes | 57 | 55 | 158 | 144 |
Utility loss from plant closure | 0 | 0 | 200 | 0 |
Total utility operating expenses | 800 | 822 | 2,510 | 2,089 |
Utility operating income | 263 | 270 | 556 | 617 |
Equity (losses) earnings before income tax | ||||
Other income (expense), net | 10 | 5 | 30 | 59 |
Interest income | 0 | 0 | 1 | 0 |
Interest expense | (50) | (49) | (147) | (124) |
Income before income taxes and equity earnings of certain unconsolidated subsidiaries | 223 | 226 | 440 | 552 |
Income tax (expense) benefit | (84) | (38) | (147) | (151) |
Net income | 139 | 188 | 293 | 401 |
Losses (earnings) attributable to noncontrolling interests | (5) | (12) | (1) | (23) |
Earnings | 134 | 176 | 292 | 378 |
Call premium on preferred stock | (3) | 0 | (3) | 0 |
Preferred dividend requirements | (2) | (2) | (4) | (4) |
Earnings attributable to common shares | 129 | 174 | 285 | 374 |
Southern California Gas Company [Member] | ||||
Utility operating revenues | ||||
Total utility operating revenues | 807 | 728 | 2,694 | 2,328 |
Utility operating expenses | ||||
Utility cost of natural gas | 209 | 175 | 966 | 703 |
Utility operation and maintenance | 314 | 316 | 936 | 933 |
Utility depreciation and amortization | 100 | 91 | 280 | 268 |
Utility franchise fees and other taxes | 29 | 27 | 95 | 91 |
Total utility operating expenses | 652 | 609 | 2,277 | 1,995 |
Utility operating income | 155 | 119 | 417 | 333 |
Equity (losses) earnings before income tax | ||||
Other income (expense), net | 2 | 6 | 9 | 14 |
Interest expense | (17) | (17) | (52) | (51) |
Income before income taxes and equity earnings of certain unconsolidated subsidiaries | 140 | 108 | 374 | 296 |
Income tax (expense) benefit | (38) | (37) | (107) | (105) |
Net income | 102 | 71 | 267 | 191 |
Earnings | 102 | 71 | 267 | 191 |
Preferred dividend requirements | 0 | 0 | (1) | (1) |
Earnings attributable to common shares | $ 102 | $ 71 | $ 266 | $ 190 |
X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition Utiltiies cost of electric fuel and purchased power recorded during the period. No definition available.
|
X | ||||||||||
- Definition Energy-related businesses cost of electric fuel and purchased power recorded during the period. No definition available.
|
X | ||||||||||
- Definition Energy-related revenues recognized during the period. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Equity (losses) earnings before income tax, other. No definition available.
|
X | ||||||||||
- Definition Equity earnings, net of income tax. No definition available.
|
X | ||||||||||
- Definition Loss from plant closure. No definition available.
|
X | ||||||||||
- Definition Preferred dividends of subsidiaries recorded during the period. No definition available.
|
X | ||||||||||
- Definition Utiltiies revenues recognized during the period. No definition available.
|
X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition Utilities cost of electric fuel and purchased power. No definition available.
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X | ||||||||||
- Definition Utiltiies cost of natural gas recorded during the period. No definition available.
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X | ||||||||||
- Definition Utility loss from plant closure. No definition available.
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X | ||||||||||
- Definition Aggregate dividends declared during the period for each share of common stock outstanding. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The current period expense charged against earnings on long-lived, physical assets not used in production, and which are not intended for resale, to allocate or recognize the cost of such assets over their useful lives; or to record the reduction in book value of an intangible asset over the benefit period of such asset; or to reflect consumption during the period of an asset that is not used in production. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Equity impact of aggregate cash, stock, and paid-in-kind dividends declared for preferred shareholders during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition The amount of net income (loss) for the period available to each share of common stock or common unit outstanding during the reporting period and to each share or unit that would have been outstanding assuming the issuance of common shares or units for all dilutive potential common shares or units outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition The aggregate revenue, whether regulated or unregulated, derived from the generation, transmission and distribution of electricity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The gains (losses) included in earnings resulting from the sale or disposal of tangible assets. This item does not include any gain (loss) recognized on the sale of oil and gas property or timber property. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Revenue derived from the regulated (by a federal, state, or local government or agency) generation, transmission and distribution of [natural] gas. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Cost incurred related to the gas activities, such as transportation, marketing and processing crude oil, natural gas and refined petroleum products. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Sum of operating profit and nonoperating income or expense before Income or Loss from equity method investments, income taxes, extraordinary items, and noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The sum of the current income tax expense or benefit and the deferred income tax expense or benefit pertaining to continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cost of borrowed funds accounted for as interest that was charged against earnings during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Income derived from investments in debt securities and on cash and cash equivalents the earnings of which reflect the time value of money or transactions in which the payments are for the use or forbearance of money. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The portion of profit or loss for the period, net of income taxes, which is attributable to the parent. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Amount of Net Income (Loss) attributable to noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Net income after adjustments for dividends on preferred stock (declared in the period) and/or cumulative preferred stock (accumulated for the period). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The aggregate amount of income or expense from ancillary business-related activities (that is to say, excluding major activities considered part of the normal operations of the business). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The net result for the period of deducting operating expenses from operating revenues. No definition available.
|
X | ||||||||||
- Definition The total amount of other operating cost and expense items that are associated with the entity's normal revenue producing operation. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The excess of (1) fair value of the consideration transferred to the holders of the preferred stock over (2) the carrying amount of the preferred stock in the registrant's balance sheet, during the accounting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The total amount of operating revenues recognized during the period. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Taxes, excluding payroll, income and excise taxes, if not included elsewhere, that could include production, real and personal property, and other selling and distribution-related taxes. No definition available.
|
X | ||||||||||
- Definition Discloses the total amount of all operating expenses for the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Discloses the amount of operating expense for the period related to depreciation and amortization. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The amount of purchased gas and petroleum charged against earnings for the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Discloses the amount of operating expense for the period for routine plant maintenance, repairs and operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Amount of operating expense for taxes other than income. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The aggregate amount of revenues for public and other utilities generated by the sale of electricity, water, gas, and other services. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The average number of shares or units issued and outstanding that are used in calculating diluted EPS or earnings per unit (EPU), determined based on the timing of issuance of shares or units in the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Number of [basic] shares or units, after adjustment for contingently issuable shares or units and other shares or units not deemed outstanding, determined by relating the portion of time within a reporting period that common shares or units have been outstanding to the total time in that period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Details
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- Details
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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Comprehensive income, net of income tax | ||||
Net income | $ 323 | $ 290 | $ 768 | $ 615 |
Foreign currency translation adjustments | 5 | 88 | 125 | 125 |
Financial instruments | (6) | (7) | 21 | (22) |
Net actuarial gain | 3 | (10) | 7 | (5) |
Total other comprehensive income (loss) | 2 | 71 | 153 | 98 |
Total Comprehensive Income Before Preferred Stock Dividend Requirements | 325 | 361 | 921 | 713 |
Preferred dividends of subsidiaries | (2) | (2) | (5) | (5) |
Comprehensive Income Net Of Tax | 323 | 359 | 916 | 708 |
San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Comprehensive income, net of income tax | ||||
Net income | 139 | 188 | 293 | 401 |
Financial instruments | (1) | (4) | 14 | (13) |
Net actuarial gain | 1 | 0 | 2 | 0 |
Total other comprehensive income (loss) | 0 | (4) | 16 | (13) |
Total Comprehensive Income Before Preferred Stock Dividend Requirements | 139 | 184 | 309 | 388 |
Southern California Gas Company [Member] | ||||
Comprehensive income, net of income tax | ||||
Net income | 102 | 71 | 267 | 191 |
Financial instruments | 1 | 1 | ||
Total other comprehensive income (loss) | 0 | 0 | 1 | 1 |
Total Comprehensive Income Before Preferred Stock Dividend Requirements | 102 | 71 | 268 | 192 |
Total Shareholders' Equity | ||||
Comprehensive income, net of income tax | ||||
Net income | 301 | 270 | 727 | 571 |
Foreign currency translation adjustments | 5 | 80 | 149 | 114 |
Financial instruments | (4) | (3) | 5 | (9) |
Net actuarial gain | 3 | (10) | 7 | (5) |
Total other comprehensive income (loss) | 4 | 67 | 161 | 100 |
Total Comprehensive Income Before Preferred Stock Dividend Requirements | 305 | 337 | 888 | 671 |
Preferred dividends of subsidiaries | (2) | (2) | (5) | (5) |
Comprehensive Income Net Of Tax | 303 | 335 | 883 | 666 |
Total Shareholders' Equity | San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Comprehensive income, net of income tax | ||||
Net income | 134 | 176 | 292 | 378 |
Financial instruments | 0 | 0 | 0 | 0 |
Net actuarial gain | 1 | 0 | 2 | 0 |
Total other comprehensive income (loss) | 1 | 0 | 2 | 0 |
Total Comprehensive Income Before Preferred Stock Dividend Requirements | 135 | 176 | 294 | 378 |
Noncontrolling Interests | ||||
Comprehensive income, net of income tax | ||||
Net income | 22 | 20 | 41 | 44 |
Foreign currency translation adjustments | 0 | 8 | (24) | 11 |
Financial instruments | (2) | (4) | 16 | (13) |
Net actuarial gain | 0 | 0 | 0 | 0 |
Total other comprehensive income (loss) | (2) | 4 | (8) | (2) |
Total Comprehensive Income Before Preferred Stock Dividend Requirements | 20 | 24 | 33 | 42 |
Preferred dividends of subsidiaries | 0 | 0 | 0 | |
Comprehensive Income Net Of Tax | 20 | 24 | 33 | 42 |
Noncontrolling Interests | San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Comprehensive income, net of income tax | ||||
Net income | 5 | 12 | 1 | 23 |
Financial instruments | (1) | (4) | 14 | (13) |
Net actuarial gain | 0 | 0 | 0 | 0 |
Total other comprehensive income (loss) | (1) | (4) | 14 | (13) |
Total Comprehensive Income Before Preferred Stock Dividend Requirements | $ 4 | $ 8 | $ 15 | $ 10 |
X | ||||||||||
- Definition Preferred dividends of subsidiaries recorded during the period. No definition available.
|
X | ||||||||||
- Definition Total comprehensive income before preferred stock dividend requirements. No definition available.
|
X | ||||||||||
- Definition The change in equity [net assets] of a business enterprise during a period from transactions and other events and circumstances from non-owner sources which are attributable to the reporting entity. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners, but excludes any and all transactions which are directly or indirectly attributable to that ownership interest in subsidiary equity which is not attributable to the parent. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition Amount after tax, before reclassification adjustments, resulting from the process of expressing in the reporting currency of the reporting entity those amounts that are denominated or measured in a different currency, and from transactions whose terms are denominated in a currency other than the entity's functional currency. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition Net of tax and reclassification adjustments amount of the change in accumulated gain (loss) from derivative instruments designated and qualifying as the effective portion of cash flow hedges. Also includes an entity's share of an equity investee's increase (decrease) in deferred hedging gain (loss). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition Net of tax amount of other comprehensive income (loss) attributable to both parent entity and noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Net of tax amount of the income statement impact of the reclassification adjustment for actuarial (gains) losses recognized as a component of net periodic benefit cost. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Details
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- Details
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- Details
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- Details
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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS $ in Millions, $ in Millions |
9 Months Ended | ||||
---|---|---|---|---|---|
Sep. 30, 2013
USD ($)
|
Sep. 30, 2012
USD ($)
|
||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||
Net income | $ 768 | $ 615 | |||
Adjustments to reconcile net income to net cash provided by operating activities: | |||||
Depreciation and amortization | 828 | 803 | |||
Deferred income taxes and investment tax credits | 327 | (45) | |||
Gains on sale of assets | (113) | (7) | |||
Loss from plant closure | 200 | 0 | |||
Equity earnings | (34) | 346 | |||
Fixed-price contracts and other derivatives | (25) | 1 | |||
Other | 23 | (1) | |||
Net change in other working capital components | (454) | (373) | |||
Changes in other assets | (203) | 202 | |||
Changes in other liabilities | 13 | 147 | |||
Net cash provided by operating activities | 1,330 | 1,688 | |||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||
Expenditures for property, plant and equipment | (1,785) | (2,241) | |||
Expenditures for investments | (21) | (359) | |||
Proceeds from sale of assets and investment | 566 | 9 | |||
Proceeds from U.S. Treasury grants | 238 | 0 | |||
Distributions from investments | 141 | 43 | |||
Purchases of nuclear decommissioning and other trust assets | (514) | (534) | |||
Proceeds from sales by nuclear decommissioning and other trusts | 510 | 534 | |||
Decrease in restricted cash | 285 | 89 | |||
Increase in restricted cash | (311) | (105) | |||
Other cash flows from investing activities | (10) | (12) | |||
Net cash used in investing activities | (901) | (2,576) | |||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||
Common dividends paid | (452) | (405) | |||
Preferred dividends paid by subsidiaries | (5) | (5) | |||
Proceeds from issuances of common stock | 57 | 50 | |||
Repurchases of common stock | (45) | (16) | |||
Issuances of debt (maturities greater than 90 days) | 1,404 | 2,294 | |||
Payments on debt (maturities greater than 90 days) | (1,444) | (563) | |||
Proceeds from sale of noncontrolling interests, net of $25 million in offering costs | 574 | 0 | |||
Increase (decrease) in short-term debt, net | 81 | (142) | |||
Distributions to noncontrolling interests | (28) | (36) | |||
Other cash flows from financing activities | 15 | (20) | |||
Net cash provided by (used in) financing activities | 157 | 1,157 | |||
Effect of exchange rate changes on cash and cash equivalents | 0 | 9 | |||
Increase (decrease) in cash and cash equivalents | 586 | 278 | |||
Cash and cash equivalents, beginning of period | 475 | [1] | 252 | ||
Cash and cash equivalents, end of period | 1,061 | 530 | |||
Sale of noncontrolling interests offering costs | 25 | ||||
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION | |||||
Interest payments, net of amounts capitalized | 359 | 278 | |||
Income tax payments, net of refunds | 106 | 99 | |||
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITIES | |||||
Nuclear facility plant reclassified to regulatory asset, net of depreciation and amortization | 512 | 0 | |||
Accrued capital expenditures | 285 | 315 | |||
Capital expenditures recoverable by U. S. Treasury grants receivable | 3 | 136 | |||
Sequestration of U.S. Treasury grants receivable | (23) | 0 | |||
Acquisition Of Business [Abstract] | |||||
Assets acquired | 13 | 29 | |||
Cash paid, net of cash acquired | (11) | (19) | |||
Liabilities Assumed | 2 | 10 | |||
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES | |||||
Call premium on preferred stock of subsidiary | 3 | 0 | |||
Call premium on preferred stock | 3 | 0 | |||
Dividends declared but not paid | 158 | 149 | |||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||
Net income | 293 | 401 | |||
Adjustments to reconcile net income to net cash provided by operating activities: | |||||
Utility depreciation and amortization | 367 | 359 | |||
Deferred income taxes and investment tax credits | 100 | 262 | |||
Utility loss from plant closure | 200 | 0 | |||
Fixed-price contracts and other derivatives | (7) | (9) | |||
Other | (9) | (55) | |||
Net change in other working capital components | (284) | (518) | |||
Changes in other assets | (164) | 201 | |||
Changes in other liabilities | 13 | 129 | |||
Net cash provided by operating activities | 509 | 770 | |||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||
Expenditures for property, plant and equipment | (679) | (998) | |||
Proceeds from sale of assets | 8 | 0 | |||
Purchases of nuclear decommissioning and other trust assets | (511) | (530) | |||
Proceeds from sales by nuclear decommissioning and other trusts | 507 | 524 | |||
Decrease in restricted cash | 54 | 74 | |||
Increase in restricted cash | (52) | (62) | |||
Other cash flows from investing activities | (5) | 0 | |||
Net cash used in investing activities | (678) | (992) | |||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||
Preferred dividends paid | (4) | (4) | |||
Issuances of long-term debt | 450 | 249 | |||
Payments on long-term debt | (183) | (7) | |||
Increase (decrease) in short-term debt, net | 0 | 2 | |||
Distributions to noncontrolling interests | (12) | (22) | |||
Other cash flows from financing activities | (2) | (3) | |||
Net cash provided by (used in) financing activities | 249 | 215 | |||
Increase (decrease) in cash and cash equivalents | 80 | (7) | |||
Cash and cash equivalents, beginning of period | 87 | [1] | 29 | ||
Cash and cash equivalents, end of period | 167 | 22 | |||
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION | |||||
Interest payments, net of amounts capitalized | 127 | 96 | |||
Income tax payments, net of refunds | 33 | (121) | |||
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITIES | |||||
Nuclear facility plant reclassified to regulatory asset, net of depreciation and amortization | 512 | 0 | |||
Accrued capital expenditures | 108 | 87 | |||
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES | |||||
Call premium on preferred stock | 3 | 0 | |||
Dividends declared but not paid | 1 | 1 | |||
Southern California Gas Company [Member] | |||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||
Net income | 267 | 191 | |||
Adjustments to reconcile net income to net cash provided by operating activities: | |||||
Utility depreciation and amortization | 280 | 268 | |||
Deferred income taxes and investment tax credits | 72 | 39 | |||
Other | (6) | (9) | |||
Net change in other working capital components | (56) | 240 | |||
Changes in other assets | (65) | 4 | |||
Changes in other liabilities | (5) | 13 | |||
Net cash provided by operating activities | 487 | 746 | |||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||
Expenditures for property, plant and equipment | (521) | (462) | |||
Increase (decrease) in loans to affiliates, net | 17 | (257) | |||
Net cash used in investing activities | (504) | (719) | |||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||
Common dividends paid | (50) | (150) | |||
Preferred dividends paid | (1) | (1) | |||
Issuances of long-term debt | 0 | 348 | |||
Debt issuances costs | 0 | (3) | |||
Net cash provided by (used in) financing activities | (51) | 194 | |||
Increase (decrease) in cash and cash equivalents | (68) | 221 | |||
Cash and cash equivalents, beginning of period | 83 | [1] | 36 | ||
Cash and cash equivalents, end of period | 15 | 257 | |||
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION | |||||
Interest payments, net of amounts capitalized | 44 | 36 | |||
Income tax payments, net of refunds | 66 | 46 | |||
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITIES | |||||
Accrued capital expenditures | $ 97 | $ 69 | |||
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Capital expenditures recoverable by U S Treasury grants receivable. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The cash inflow for the decrease in restricted cash. No definition available.
|
X | ||||||||||
- Definition The cash inflow from distributions from investments. No definition available.
|
X | ||||||||||
- Definition The cash outflow for the increase in restricted cash. No definition available.
|
X | ||||||||||
- Definition Loss from plant closure. No definition available.
|
X | ||||||||||
- Definition Nuclear facility plant reclassified to regulatory asset, net of depreciation and amortization. No definition available.
|
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- Definition Payments on debt (maturities greater than 90 days). No definition available.
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- Definition The cash outflow for preferred dividends paid by subsidiaries. No definition available.
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X | ||||||||||
- Definition The cash inflow from the sale of assets and investments. No definition available.
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X | ||||||||||
- Definition Proceeds from sale of noncontrolling interest, net of offering costs. No definition available.
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X | ||||||||||
- Definition The cash inflow for the sales of nuclear decommissioning and other trust assets. No definition available.
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X | ||||||||||
- Definition The cash inflow from U.S. Treasury grants proceeds. No definition available.
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X | ||||||||||
- Definition The cash outflow for the purchase of nuclear decommissioning and other trust assets. No definition available.
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- Definition Sale of noncontrolling interests offering costs. No definition available.
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X | ||||||||||
- Definition Sequestration of U.S. Treasury grants receivable. No definition available.
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X | ||||||||||
- Definition Utility loss from plant closure. No definition available.
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X | ||||||||||
- Definition The aggregate amount of adjustments to net income or loss necessary to remove the effects of all items whose cash effects are investing or financing cash flows. The aggregate amount also includes all noncash expenses and income items which reduce or increase net income and are thus added back or deducted when calculating cash provided by or used in operating activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition Future cash outflow to pay for purchases of fixed assets that have occurred. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Amount of currency on hand as well as demand deposits with banks or financial institutions. Includes other kinds of accounts that have the general characteristics of demand deposits. Also includes short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. Excludes cash and cash equivalents within disposal group and discontinued operation. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Amount of increase (decrease) in cash and cash equivalents. Cash and cash equivalents are the amount of currency on hand as well as demand deposits with banks or financial institutions. Includes other kinds of accounts that have the general characteristics of demand deposits. Also includes short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. Excludes cash and cash equivalents within disposal group and discontinued operation. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The net amount of deferred income taxes and income tax credits less the tax benefit from exercise of stock options. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The current period expense charged against earnings on long-lived, physical assets not used in production, and which are not intended for resale, to allocate or recognize the cost of such assets over their useful lives; or to record the reduction in book value of an intangible asset over the benefit period of such asset; or to reflect consumption during the period of an asset that is not used in production. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Net Increase or Decrease in the fair value of the derivative or group of derivatives included in earnings. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Carrying value as of the balance sheet date of dividends declared but unpaid on equity securities issued by the entity and outstanding. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The effect of exchange rate changes on cash balances held in foreign currencies. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The fair value of assets acquired in noncash investing or financing activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The gains (losses) included in earnings resulting from the sale or disposal of tangible assets. This item does not include any gain (loss) recognized on the sale of oil and gas property or timber property. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition This element represents the undistributed income (or loss) of equity method investments, net of dividends or other distributions received from unconsolidated subsidiaries, certain corporate joint ventures, and certain noncontrolled corporations; such investments are accounted for under the equity method of accounting. This element excludes distributions that constitute a return of investment, which are classified as investing activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The amount of cash paid during the current period to foreign, federal, state, and local authorities as taxes on income, net of any cash received during the current period as refunds for the overpayment of taxes. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The increase (decrease) during the reporting period of all assets and liabilities used in operating activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The increase (decrease) during the reporting period in other noncurrent operating assets not separately disclosed in the statement of cash flows. No definition available.
|
X | ||||||||||
- Definition The increase (decrease) during the reporting period in other noncurrent operating liabilities not separately disclosed in the statement of cash flows. No definition available.
|
X | ||||||||||
- Definition The amount of cash paid for interest during the period net of cash paid for interest that is capitalized. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The fair value of liabilities assumed in noncash investing or financing activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The net cash inflow or outflow from financing activity for the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The net cash inflow or outflow from investing activity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The net cash from (used in) all of the entity's operating activities, including those of discontinued operations, of the reporting entity. Operating activities generally involve producing and delivering goods and providing services. Operating activity cash flows include transactions, adjustments, and changes in value that are not defined as investing or financing activities. While for technical reasons this element has no balance attribute, the default assumption is a debit balance consistent with its label. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The net cash outflow or inflow from other investing activities. This element is used when there is not a more specific and appropriate element in the taxonomy. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash outflow to reacquire common stock during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash outflow paid to third parties in connection with debt origination, which will be amortized over the remaining maturity period of the associated long-term debt. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Cash outflow in the form of ordinary dividends to common shareholders, generally out of earnings. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Cash outflow in the form of ordinary dividends to preferred shareholders, generally out of earnings. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash outflow associated with the acquisition of a business, net of the cash acquired from the purchase. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash outflow associated with the purchase of all investments (debt, security, other) during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash outflow for purchases of and capital improvements on property, plant and equipment (capital expenditures), software, and other intangible assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash outflow to return capital to noncontrolled interest, which generally occurs when noncontrolling shareholders reduce their ownership stake (in a subsidiary of the entity). This element does not include dividends paid to noncontrolling shareholders. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The excess of (1) fair value of the consideration transferred to the holders of the preferred stock over (2) the carrying amount of the preferred stock in the registrant's balance sheet, during the accounting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash inflow from the additional capital contribution to the entity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash inflow during the period from additional borrowings in aggregate debt. Includes proceeds from short-term and long-term debt. No definition available.
|
X | ||||||||||
- Definition The cash inflow from a debt initially having maturity due after one year or beyond the operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash inflow or outflow associated with long-term loans for related parties where one party can exercise control or significant influence over another party, including affiliates, owners or officers and their immediate families, pension trusts, and so forth. Alternate caption: Proceeds from (Payments for) Advances to Affiliates. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The net cash inflow or outflow from other financing activities. This element is used when there is not a more specific and appropriate element in the taxonomy. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash inflow from a borrowing net of the cash outflow from repayment of a borrowing having initial term of repayment within three months. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition The cash inflow from the sale of property, plant and equipment (capital expenditures), software, and other intangible assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The cash outflow for debt initially having maturity due after one year or beyond the normal operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Discloses the amount of operating expense for the period related to depreciation and amortization. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Details
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- Details
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GENERAL |
3 Months Ended |
---|---|
Sep. 30, 2013 | |
Notes to Consolidated Financial Statements [Abstract] | |
General | NOTE 1. GENERAL PRINCIPLES OF CONSOLIDATION Sempra Energy Sempra Energy's Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based Fortune 500 energy-services holding company, and its consolidated subsidiaries and variable interest entities (VIEs). Sempra Energy's principal operating units are
We provide descriptions of each of our segments in Note 11. We refer to SDG&E and SoCalGas collectively as the California Utilities, which do not include the utilities in our Sempra International and Sempra U.S. Gas & Power operating units. Sempra Global is the holding company for most of our subsidiaries that are not subject to California utility regulation. All references in these Notes to “Sempra International,” “Sempra U.S. Gas & Power” and their respective reportable segments are not intended to refer to any legal entity with the same or similar name. In the first quarter of 2013, a Sempra Energy subsidiary, Infraestructura Energética Nova, S.A.B. de C.V. (IEnova), completed a private offering in the U.S. and outside of Mexico and a concurrent public offering in Mexico of common stock. The aggregate shares of common stock sold in the offerings represent approximately 18.9 percent of IEnova's outstanding ownership interest. IEnova is reported within the Sempra Mexico reportable segment. We discuss the offerings and IEnova further in Note 5. Sempra Energy uses the equity method to account for investments in companies over which we have the ability to exercise significant influence, but not control. We discuss our investments in unconsolidated entities in Note 4 herein and in Note 4 of the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2012. SDG&E SDG&E's Condensed Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, as we discuss in Note 5 under “Variable Interest Entities.” SDG&E's common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra Energy. SoCalGas SoCalGas' Condensed Consolidated Financial Statements include its subsidiaries, which comprise less than one percent of its consolidated financial position and results of operations. SoCalGas' common stock is wholly owned by Pacific Enterprises (PE), which is a wholly owned subsidiary of Sempra Energy. BASIS OF PRESENTATION This is a combined report of Sempra Energy, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. References in this report to “we,” “our” and “Sempra Energy Consolidated” are to Sempra Energy and its consolidated entities, unless otherwise indicated by the context. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity. We have prepared the Condensed Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States (U.S. GAAP) and in accordance with the interim-period-reporting requirements of Form 10-Q. Results of operations for interim periods are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after September 30, 2013 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. These adjustments are only of a normal, recurring nature. All December 31, 2012 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2012 consolidated financial statements. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim-period-reporting provisions of U.S. GAAP and the Securities and Exchange Commission. You should read the information in this Quarterly Report in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2012 (the Annual Report) and our Quarterly Reports on Form 10-Q for the quarters ended March 31 and June 30, 2013, which are combined reports for Sempra Energy, SDG&E and SoCalGas. Sempra South American Utilities has controlling interests in two electric distribution utilities in South America. Sempra Natural Gas owns Mobile Gas Service Corporation (Mobile Gas) in southwest Alabama and Willmut Gas Company (Willmut Gas) in Mississippi, and Sempra Mexico owns Ecogas Mexico, S. de R.L. de C.V. (Ecogas) in Northern Mexico, all natural gas distribution utilities. The California Utilities, Sempra Natural Gas' Mobile Gas and Willmut Gas, and Sempra Mexico's Ecogas prepare their financial statements in accordance with U.S. GAAP provisions governing regulated operations, as we discuss in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We follow the same accounting policies for interim reporting purposes, except for the adoption of new accounting standards as we discuss in Note 2. |
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The entire disclosure for organization, consolidation and basis of presentation of financial statements disclosure. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
NEW ACCOUNTING STANDARDS |
3 Months Ended |
---|---|
Sep. 30, 2013 | |
Notes to Consolidated Financial Statements [Abstract] | |
New Accounting Standards | NOTE 2. NEW ACCOUNTING STANDARDS We describe below recent pronouncements that have had or may have a significant effect on our financial statements. We do not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to our financial condition, results of operations, cash flows or disclosures. SEMPRA ENERGY, SDG&E AND SOCALGAS Accounting Standards Update (ASU) 2011-11, “Disclosures about Offsetting Assets and Liabilities” (ASU 2011-11) and ASU 2013-01, “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities” (ASU 2013-01): In order to allow for balance sheet comparison between U.S. GAAP and International Financial Reporting Standards (IFRS), ASU 2011-11 requires enhanced disclosures related to financial assets and liabilities eligible for offsetting in the statement of financial position. An entity must disclose both gross and net information about financial instruments and transactions subject to a master netting arrangement and eligible for offset, including cash collateral received and posted. ASU 2013-01 clarifies that the scope of ASU 2011-11 applies to derivatives, including bifurcated embedded derivatives, repurchase agreements and reverse repurchase agreements, and securities borrowing and securities lending transactions. We adopted ASU 2011-11 and ASU 2013-01 on January 1, 2013 as required and it did not affect our financial condition, results of operations or cash flows. We provide the additional disclosure in Note 7. ASU 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income” (ASU 2013-02): ASU 2013-02 requires an entity to present, either on the face of the statement of operations or in the notes to financial statements, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. We adopted ASU 2013-02 on January 1, 2013 as required and it did not affect our financial condition, results of operations or cash flows. We provide the additional disclosure in Note 5. ASU 2013-04, “Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date” (ASU 2013-04): ASU 2013-04 provides guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of the ASU is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. GAAP. The guidance requires an entity to measure those obligations as the sum of the amount the reporting entity agreed to pay on the basis of its arrangement among its co-obligors and any additional amount the reporting entity expects to pay on behalf of its co-obligors. The guidance in the ASU also requires an entity to disclose the nature and amount of the obligation as well as other information about those obligations. We will adopt ASU 2013-04 on January 1, 2014 as required and do not expect it to affect our financial condition, results of operations or cash flows. We will provide the additional disclosure in our 2014 interim financial statements. ASU 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists” (ASU 2013-11): ASU 2013-11 provides explicit guidance on the financial statement presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. ASU 2013-11 requires an entity to present an unrecognized tax benefit, or a portion of an unrecognized tax benefit, as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward. If a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position or the tax law of the applicable jurisdiction does not require the entity to use, and the entity does not intend to use, the deferred tax asset for such purposes, an entity is required to present the unrecognized tax benefit in the financial statements as a liability instead of combined with deferred tax assets. We will adopt ASU 2013-11 on January 1, 2014 as required and do not expect it to significantly affect our financial condition, results of operations or cash flows.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Tabular disclosure of changes in accounting principles, including adoption of new accounting pronouncements, that describes the new methods, amount and effects on financial statement line items. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
RECENT INVESTMENT ACTIVITY |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2013 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Notes to Consolidated Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Recent Investment Activity | NOTE 3. ACQUISITION AND DIVESTITURE ACTIVITY SEMPRA RENEWABLES In July 2013, Sempra Renewables formed a joint venture with Consolidated Edison Development (ConEdison Development), a non-related party, by selling a 50-percent interest in its 150-megawatt (MW) Copper Mountain Solar 2 solar power facility for $71 million in cash, subject to a final purchase price adjustment that we do not expect to be significant. Sempra Renewables recognized a pretax gain on the sale of $4 million ($2 million after-tax), included in Gain on Sale of Assets on our Condensed Consolidated Statements of Operations. Our remaining 50-percent interest in Copper Mountain Solar 2 is now accounted for under the equity method. In September 2013, Sempra Renewables formed another joint venture with ConEdison Development by selling a 50-percent interest in its 150-MW Mesquite Solar 1 solar power facility for $103 million in cash, subject to a final purchase price adjustment that we do not expect to be significant. Sempra Renewables recognized a pretax gain on the sale of $36 million ($22 million after-tax), included in Gain on Sale of Assets on our Condensed Consolidated Statements of Operations. Our remaining 50-percent interest in Mesquite Solar 1 is now accounted for under the equity method. Our equity method investments in Copper Mountain Solar 2 and Mesquite Solar 1 were measured at their historical cost and, therefore, no portion of the gains was attributable to a remeasurement of the retained investments to fair value. The following table summarizes the deconsolidation:
In September 2013, Sempra Renewables acquired the rights to develop the 75-MW Broken Bow 2 Wind project in Custer County, Nebraska. Sempra Renewables will develop the project, which is expected to be operational in late 2014. SEMPRA NATURAL GAS Mesquite Power Sale In February 2013, Sempra Natural Gas sold one 625-MW block of its 1,250-MW Mesquite Power natural gas-fired power plant in Arizona, including a portion related to common plant, for approximately $371 million in cash to the Salt River Project Agricultural Improvement and Power District (SRP). The asset was classified as held for sale at December 31, 2012 and we recognized a pretax gain on the sale of $74 million ($44 million after-tax) in 2013. In connection with the sale, we entered into a 20-year operations and maintenance agreement with SRP on February 28, 2013, whereby SRP assumed plant operations and maintenance of the facility, including our remaining 625-MW block. We provide additional information concerning the operations and maintenance agreement in Note 10. Willmut Gas Company In May 2012, Sempra Natural Gas acquired 100 percent of the outstanding common stock of Willmut Gas, a regulated natural gas distribution utility serving approximately 20,000 customers in Hattiesburg, Mississippi, for $19 million in cash and the assumption of $10 million of liabilities. Pro forma impacts on revenues and earnings for Sempra Energy had the acquisition occurred on January 1, 2011 were additional revenues of $7 million and negligible earnings for the nine months ended September 30, 2012. |
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The entire disclosure for the entity's recent investment activities. No definition available.
|
INVESTMENTS IN UNCONSOLIDATED ENTITIES |
3 Months Ended |
---|---|
Sep. 30, 2013 | |
Notes to Consolidated Financial Statements [Abstract] | |
Investments in Unconsolidated Entities | NOTE 4. INVESTMENTS IN UNCONSOLIDATED ENTITIES We provide additional information concerning all of our equity method investments in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.
SEMPRA SOUTH AMERICAN UTILITIES Sempra South American Utilities previously owned 43 percent of two Argentine natural gas utility holding companies, Sodigas Pampeana and Sodigas Sur. In December 2006, we decided to sell our Argentine investments and actively pursued their sale since that time. In the first quarter of 2013, we recorded a noncash impairment charge of $10 million ($7 million after-tax) to reduce the carrying value of our investments to estimated fair value. The net charge is reported in Equity Earnings, Net of Income Tax on the Condensed Consolidated Statement of Operations for the nine months ended September 30, 2013. In June 2013, we completed the sale of our Argentine investments for $13 million in cash. Our results for the nine months ended September 30, 2013 include an additional $7 million loss ($4 million after-tax) on the sale, which is also included in Equity Earnings, Net of Income Tax. We provide additional information concerning our investments in Sodigas Pampeana and Sodigas Sur in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report. As a result of the devaluation of the Argentine peso at the end of 2001 and subsequent changes in the value of the peso, Sempra South American Utilities had reduced the carrying value of its investments by a cumulative total of $270 million prior to the sale. These noncash adjustments, based on fluctuations in the value of the Argentine peso, did not affect earnings, but were recorded in Comprehensive Income and Accumulated Other Comprehensive Income (Loss). As a result of the sale of our investments, this cumulative foreign currency translation adjustment was reclassified to Equity Earnings, Net of Income Tax, where it was substantially offset by the elimination of a $250 million accrued liability established in 2006. Chilquinta Energía has entered into two 50-percent owned joint ventures, Eletrans S.A. and Eletrans II S.A. (collectively, Eletrans), with Sociedad Austral de Electricidad Sociedad Anónima (SAESA) to construct four transmission lines in Chile. In 2013, Eletrans entered into forward exchange contracts to manage the foreign currency exchange rate risk of the Chilean Unidad de Fomento (CLF) relative to the U.S. dollar, related to certain construction commitments that are denominated in CLF. The forward exchange contracts settle based on anticipated payments to vendors, generally monthly, ending in July 2018. We recorded a negligible amount of equity earnings in the three months ended September 30, 2013 and $3 million of equity losses in the nine months ended September 30, 2013 related to these forward contracts in Equity Earnings, Net of Income Tax on the Condensed Consolidated Statements of Operations. SEMPRA RENEWABLES Sempra Renewables invested $5 million and $296 million in its wind generation joint ventures in the nine months ended September 30, 2013 and 2012, respectively. SEMPRA NATURAL GAS Sempra Natural Gas owns a 25-percent interest in Rockies Express Pipeline LLC (Rockies Express), a partnership that operates a natural gas pipeline, the Rockies Express Pipeline (REX), that links the Rocky Mountains region to the upper Midwest and the eastern United States. In November 2012, Kinder Morgan Energy Partners L.P. (KMP) sold its 50-percent interest in Rockies Express, as part of a larger asset group, to Tallgrass Energy Partners, L.P. (Tallgrass). Phillips 66 owns the remaining interest of 25 percent. Our total investment in Rockies Express is accounted for as an equity method investment. The general partner of KMP is Kinder Morgan, Inc. (KMI). As a condition of KMI receiving antitrust approval from the Federal Trade Commission (FTC) for its acquisition of El Paso Corporation, KMI agreed to divest certain assets in its natural gas pipeline group. Included in the asset group, as noted above, was KMP's interest in Rockies Express. KMP recorded remeasurement losses during 2012 associated with these operations (classified as discontinued operations by KMP). We have recorded impairments of our partnership investment in Rockies Express of $300 million ($179 million after-tax) in the quarter ended June 30, 2012 and an additional $100 million ($60 million after-tax) in the quarter ended September 30, 2012, which are included in Equity Earnings (Losses), Before Income Tax on the Condensed Consolidated Statements of Operations. Our remaining carrying value in Rockies Express as of September 30, 2013 is $330 million. We discuss the fair value measurement of our investment in Rockies Express in Note 11 of the Notes to Consolidated Financial Statements in the Annual Report. RBS SEMPRA COMMODITIES RBS Sempra Commodities LLP (RBS Sempra Commodities) is a United Kingdom limited liability partnership that owned and operated commodities-marketing businesses previously owned by us. We and our partner in the joint venture, The Royal Bank of Scotland plc (RBS), sold substantially all of the partnership's businesses and assets in four separate transactions completed in 2010 and early 2011. We account for our investment in RBS Sempra Commodities under the equity method, and report our share of partnership earnings and other associated costs in Parent and Other. In April 2011, we and RBS entered into a letter agreement (Letter Agreement) which amended certain provisions of the agreements that formed RBS Sempra Commodities. The Letter Agreement addresses the wind-down of the partnership and the distribution of the partnership's remaining assets. In accordance with the Letter Agreement, we received a distribution of $50 million in May 2013. The investment balance of $76 million at September 30, 2013 reflects remaining distributions expected to be received from the partnership in accordance with the Letter Agreement. The timing and amount of distributions may be impacted by the matters we discuss related to RBS Sempra Commodities in Note 10 under “Other Litigation.” In addition, amounts may be retained by the partnership for an extended period of time to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership. In connection with the Letter Agreement described above, we also released RBS from its indemnification obligations with respect to the items for which J.P. Morgan Chase & Co. (JP Morgan), one of the buyers of the partnership's businesses, has agreed to indemnify us. We recorded no equity earnings or losses related to the partnership for either the three months or nine months ended September 30, 2013 and 2012. We discuss the RBS Sempra Commodities sales transactions, the Letter Agreement and other matters concerning the partnership in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report. |
X | ||||||||||
- References No definition available.
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- Definition The entire disclosure for equity method investments and joint ventures. Equity method investments are investments that give the investor the ability to exercise significant influence over the operating and financial policies of an investee. Joint ventures are entities owned and operated by a small group of businesses as a separate and specific business or project for the mutual benefit of the members of the group. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA |
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Notes to Consolidated Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Financial Data | NOTE 5. OTHER FINANCIAL DATA U.S. TREASURY GRANTS RECEIVABLE At December 31, 2012, we had recognized receivables for U.S. Treasury grants based on eligible costs at our Mesquite Solar 1 and Copper Mountain Solar 2 generating facilities when the projects, or portions of projects, were placed into service. During the first quarter of 2013, the federal government imposed automatic federal budget cuts, known as “sequestration,” as required by The Budget Control Act of 2011. As a result, cash grant payments to eligible taxpayers for renewable energy projects were reduced, and we recorded a reduction to our grants receivable of $23 million and a reversal of income tax benefit of $5 million during the first quarter of 2013. In June 2013, we received $74 million in cash related to the Copper Mountain Solar 2 grant. We received $164 million in cash for the remaining grant receivable for Mesquite Solar 1 in August 2013. INVENTORIES The components of inventories by segment are as follows:
VARIABLE INTEREST ENTITIES (VIE) We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based upon qualitative and quantitative analyses, which assess
SDG&E Tolling Agreements SDG&E has agreements under which it purchases power generated by facilities for which it supplies all of the natural gas to fuel the power plant (i.e., tolling agreements). SDG&E's obligation to absorb natural gas costs may be a significant variable interest. In addition, SDG&E has the power to direct the dispatch of electricity generated by these facilities. Based upon our analysis, the ability to direct the dispatch of electricity may have the most significant impact on the economic performance of the entity owning the generating facility because of the associated exposure to the cost of natural gas, which fuels the plants, and the value of electricity produced. To the extent that SDG&E (1) is obligated to purchase and provide fuel to operate the facility, (2) has the power to direct the dispatch, and (3) purchases all of the output from the facility for a substantial portion of the facility's useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on the operational characteristics of the facility, including its expected power generation output relative to its capacity to generate and the financial structure of the entity, among other factors. If we determine that SDG&E is the primary beneficiary, SDG&E and Sempra Energy consolidate the entity that owns the facility as a VIE, as we discuss below. Otay Mesa VIE SDG&E has an agreement to purchase power generated at the Otay Mesa Energy Center (OMEC), a 605-MW generating facility. In addition to tolling, the agreement provides SDG&E with the option to purchase the power plant at the end of the contract term in 2019, or upon earlier termination of the purchased-power agreement, at a predetermined price subject to adjustments based on performance of the facility. If SDG&E does not exercise its option, under certain circumstances, it may be required to purchase the power plant at a predetermined price, which we refer to as the put option. The facility owner, Otay Mesa Energy Center LLC (OMEC LLC), is a VIE (Otay Mesa VIE), of which SDG&E is the primary beneficiary. SDG&E has no OMEC LLC voting rights and does not operate OMEC. In addition to the risks absorbed under the tolling agreement, SDG&E absorbs separately through the put option a significant portion of the risk that the value of Otay Mesa VIE could decline. SDG&E and Sempra Energy have consolidated Otay Mesa VIE since the second quarter of 2007. Otay Mesa VIE's equity of $79 million at September 30, 2013 and $76 million at December 31, 2012 is included on the Condensed Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E. OMEC LLC has a loan outstanding of $337 million at September 30, 2013, the proceeds of which were used for the construction of OMEC. The loan is with third party lenders and is secured by OMEC's property, plant and equipment. SDG&E is not a party to the loan agreement and does not have any additional implicit or explicit financial responsibility to OMEC LLC. The loan fully matures in April 2019 and bears interest at rates varying with market rates. In addition, OMEC LLC has entered into interest rate swap agreements to moderate its exposure to interest rate changes. We provide additional information concerning the interest rate swaps in Note 7. Other Variable Interest Entities SDG&E's power procurement is subject to reliability requirements that may require SDG&E to enter into various power purchase arrangements which include variable interests. SDG&E evaluates the respective entities to determine if variable interests exist and, based on the qualitative and quantitative analyses described above, if SDG&E, and thereby Sempra Energy, is the primary beneficiary. SDG&E has determined that no contracts, other than the one relating to Otay Mesa VIE mentioned above, result in SDG&E being the primary beneficiary as of September 30, 2013. In addition to the tolling agreements described above, other variable interests involve various elements of fuel and power costs, including certain construction costs, tax credits, and other components of cash flow expected to be paid to or received by our counterparties. In most of these cases, the expectation of variability is not substantial, and SDG&E generally does not have the power to direct activities that most significantly impact the economic performance of the other VIEs. If our ongoing evaluation of these VIEs were to conclude that SDG&E becomes the primary beneficiary and consolidation by SDG&E becomes necessary, the effects are not expected to significantly affect the financial position, results of operations, or liquidity of SDG&E. In addition, SDG&E is not exposed to losses or gains as a result of these other VIEs, because all such variability would be recovered in rates. Sempra Energy's other operating units also enter into arrangements which could include variable interests. We evaluate these arrangements and applicable entities based upon the qualitative and quantitative analyses described above. Certain of these entities are service companies that are VIEs. As the primary beneficiary of these service companies, we consolidate them. In all other cases, we have determined that these contracts are not variable interests in a VIE and therefore are not subject to the U.S. GAAP requirements concerning the consolidation of VIEs. The Condensed Consolidated Statements of Operations of Sempra Energy and SDG&E include the following amounts associated with Otay Mesa VIE. The amounts are net of eliminations of transactions between SDG&E and Otay Mesa VIE. The financial statements of other consolidated VIEs are not material to the financial statements of Sempra Energy. The captions on the table below generally correspond to SDG&E's Condensed Consolidated Statements of Operations.
We provide additional information regarding Otay Mesa VIE in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. ASSET RETIREMENT OBLIGATIONS We discuss asset retirement obligations in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. The changes in asset retirement obligations are as follows:
PENSION AND OTHER POSTRETIREMENT BENEFITS Net Periodic Benefit Cost The following three tables provide the components of net periodic benefit cost:
Benefit Plan Contributions The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts we expect to contribute in 2013:
RABBI TRUST In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra Energy maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $486 million and $510 million at September 30, 2013 and December 31, 2012, respectively. EARNINGS PER SHARE The following table provides the per share computations for our earnings for the three months and nine months ended September 30, 2013 and 2012. Basic earnings per common share (EPS) is calculated by dividing earnings attributable to common shares by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.
The dilution from common stock options is based on the treasury stock method. Under this method, proceeds based on the exercise price plus unearned compensation and windfall tax benefits recognized, minus tax shortfalls recognized, are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits are tax deductions we would receive upon the assumed exercise of stock options in excess of the deferred income taxes we recorded related to the compensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options). We had no such antidilutive stock options outstanding during either the three months or nine months ended September 30, 2013. We had no such antidilutive stock options outstanding during the three months ended September 30, 2012 and 40,000 such options outstanding during the nine months ended September 30, 2012. During the three months and nine months ended September 30, 2013 and 2012, we had no stock options outstanding that were antidilutive because of the unearned compensation and windfall tax benefits included in the assumed proceeds under the treasury stock method. The dilution from unvested restricted stock awards (RSAs) and restricted stock units (RSUs) is also based on the treasury stock method. Proceeds equal to the unearned compensation and windfall tax benefits recognized, minus tax shortfalls recognized, related to the awards and units are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits recognized or tax shortfalls recognized are the difference between tax deductions we would receive upon the assumed vesting of RSAs or RSUs and the deferred income taxes we recorded related to the compensation expense on such awards and units. There were no antidilutive RSUs from the application of unearned compensation in the treasury stock method for either the three months or nine months ended September 30, 2013. There were 3,387 such antidilutive RSUs for the three months ended September 30, 2012 and 1,881 such antidilutive RSUs for the nine months ended September 30, 2012. There were no such antidilutive RSAs for either the three months or nine months ended September 30, 2013. There were no such antidilutive RSAs for the three months ended September 30, 2012 and 14,319 such antidilutive RSAs for the nine months ended September 30, 2012. Each performance-based RSU represents the right to receive between zero and 1.5 shares of Sempra Energy common stock based on Sempra Energy's four-year cumulative total shareholder return compared to the Standard & Poor's (S&P) 500 Utilities Index, as follows:
RSAs and those RSUs which are solely service-based have a maximum potential of 100 percent vesting and have the same dividend equivalent rights as performance-based RSUs. We include our performance-based RSUs in potential dilutive shares at zero to 150 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method. Due to market fluctuations of both Sempra Energy stock and the comparative index, dilutive performance-based RSUs may vary widely from period-to-period. We include our RSAs, which are solely service-based, and those RSUs that are solely service-based in potential dilutive shares at 100 percent. RSUs and RSAs may be excluded from potential dilutive shares by the application of unearned compensation in the treasury stock method, as we discuss above, or because performance goals are currently not met. The maximum excluded RSAs and RSUs, assuming performance goals were met at maximum levels, were 712,941 and 889,420 for the three months and nine months ended September 30, 2013, respectively, and 2,349,338 and 2,523,343 for the three months and nine months ended September 30, 2012, respectively. SDG&E PREFERRED STOCK In September 2013, SDG&E announced that it would redeem all six series of its outstanding shares of contingently redeemable preferred stock at prices ranging from $20.25 to $26.00 per share plus accrued dividends of $1 million. The redemption was completed in October 2013, and accordingly, we recorded the redemption value of $82 million, including a $3 million early call premium, as a current liability at September 30, 2013, included in Other Current Liabilities and Preferred Stock Pending Redemption on Sempra Energy's and SDG&E's Condensed Consolidated Balance Sheets, respectively. The early call premium is presented as Call Premium on Preferred Stock of Subsidiary on Sempra Energy's and Call Premium on Preferred Stock on SDG&E's Condensed Consolidated Statements of Operations. We provide more detail concerning SDG&E's preferred stock in Note 12 of the Notes to Consolidated Financial Statements in the Annual Report. SHARE-BASED COMPENSATION We discuss our share-based compensation plans in Note 9 of the Notes to Consolidated Financial Statements in the Annual Report. We recorded share-based compensation expense, net of income taxes, of $6 million and $5 million for the three months ended September 30, 2013 and 2012, respectively, and $17 million and $18 million for the nine months ended September 30, 2013 and 2012, respectively. Pursuant to our share-based compensation plans, we granted 651,193 performance-based RSUs, 105,680 service-based RSUs and 4,617 RSAs during the nine months ended September 30, 2013, primarily in January. In April 2013, the IEnova board of directors approved the IEnova 2013 Long-Term Incentive Plan. The purpose of this plan is to align the interests of employees and directors of IEnova with its shareholders. All awards issued from this plan and any related dividend equivalents will settle in cash based on the fair market value of the awards, based on IEnova's common stock value, upon vesting. In 2013, 1,014,899 RSUs have been issued from this plan. CAPITALIZED FINANCING COSTS Capitalized financing costs include capitalized interest costs and, primarily at the California Utilities, an allowance for funds used during construction (AFUDC) related to both debt and equity financing of construction projects. The following table shows capitalized financing costs for the three months and nine months ended September 30, 2013 and 2012.
COMPREHENSIVE INCOME The following tables present the changes in Accumulated Other Comprehensive Income by component and amounts reclassified out of Accumulated Other Comprehensive Income (Loss) to net income, excluding amounts attributable to noncontrolling interests:
For the three months ended September 30, 2013, Other Comprehensive Income, excluding amounts attributable to noncontrolling interests, at SoCalGas was negligible and reclassifications out of Accumulated Other Comprehensive Income (Loss) to Net Income were also negligible for SoCalGas. The amounts for comprehensive income in the Condensed Consolidated Statements of Comprehensive Income are net of income tax expense (benefit) as follows:
SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS The following two tables provide a reconciliation of Sempra Energy's and SDG&E's shareholders' equity and noncontrolling interests for the nine months ended September 30, 2013 and 2012.
Ownership interests that are held by owners other than Sempra Energy and SDG&E in subsidiaries or entities consolidated by them are accounted for and reported as noncontrolling interests. As a result, noncontrolling interests are reported as a separate component of equity on the Condensed Consolidated Balance Sheets. Earnings or losses attributable to noncontrolling interests are separately identified on the Condensed Consolidated Statements of Operations, and comprehensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income. Sale of Noncontrolling Interests On March 21, 2013, Sempra Energy's subsidiary, Infraestructura Energética Nova, S.A.B. de C.V. (IEnova) priced a private offering in the U.S. and outside of Mexico and a concurrent initial public offering in Mexico of new shares of Class II, Single Series common stock at $2.75 per share in U.S. dollars or 34.00 Mexican pesos. The initial purchasers in the private offering and the underwriters in the Mexican public offering were granted a 30-day option to purchase additional common shares at the initial offering price, less the underwriting discount, to cover overallotments. These options were exercised before the settlement date of the offerings, which was March 27, 2013. After the initial offerings and the exercise of the overallotment options, the aggregate shares of common stock sold in the offerings totaled 218,110,500, representing approximately 18.9 percent of IEnova's outstanding ownership interest. The net proceeds of the offerings, including the additional option shares, were approximately $574 million in U.S. dollars or 7.1 billion Mexican pesos. IEnova expects to use the net proceeds of the offerings primarily for general corporate purposes, and for the funding of its current investments and ongoing expansion plans. All U.S. dollar equivalents presented here were based on an exchange rate of 12.3841 Mexican pesos to 1.00 U.S. dollar as of March 21, 2013, the pricing date for the offerings. Net proceeds are after reduction for underwriting discounts and commissions and offering expenses. Following completion of the initial offerings and overallotment options, we beneficially owned 81.1 percent of IEnova and its subsidiaries. Consistent with applicable accounting guidance, changes in noncontrolling interests that do not result in a change of control are accounted for as equity transactions. When there are changes in noncontrolling interests of a subsidiary that do not result in a change of control, any difference between carrying value and fair value related to the change in ownership is recorded as an adjustment to shareholders' equity. As a result of the offerings and overallotment options, we recorded an increase in Sempra Energy's shareholders' equity of $135 million for the sale of IEnova shares to noncontrolling interests. IEnova is a separate legal entity, formerly known as Sempra México, S.A. de C.V., comprised primarily of Sempra Energy's operations in Mexico. IEnova is included within our Sempra Mexico reportable segment, but is not the same in its entirety as the reportable segment. In addition to the IEnova operating companies, the Sempra Mexico segment includes, among other things, certain holding companies and risk management activity. Also, IEnova's financial results are reported in Mexico under IFRS, as required by the Mexican Stock Exchange (the Bolsa Mexicana de Valores, S.A.B. de C.V.) where the new shares are now traded under the symbol IENOVA. The private offering was exempt from registration under the U.S. Securities Act of 1933, as amended (the Securities Act), and shares in the private offering were offered and sold only to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside of the United States, in accordance with Regulation S under the Securities Act. The shares were not registered under the Securities Act or any state securities laws, and may not be offered or sold in the United States absent registration or an applicable exemption from the registration requirements of the Securities Act and applicable securities laws. Preferred Stock The preferred stock of SoCalGas is presented at Sempra Energy as a noncontrolling interest at September 30, 2013 and December 31, 2012. The preferred stock of SDG&E was contingently redeemable preferred stock and was fully redeemed in October 2013, as we discuss in “SDG&E Preferred Stock” above. At Sempra Energy, the preferred stock dividends of both SDG&E and SoCalGas are charges against income related to noncontrolling interests. We provide additional information concerning preferred stock in Note 12 of the Notes to Consolidated Financial Statements in the Annual Report. At September 30, 2013 and December 31, 2012, we reported the following other noncontrolling ownership interests held by others (not including preferred shareholders) recorded in Other Noncontrolling Interests in Total Equity on Sempra Energy's Condensed Consolidated Balance Sheets:
TRANSACTIONS WITH AFFILIATES
Sempra Energy, SDG&E and SoCalGas provide certain services to each other and are charged an allocable share of the cost of such services. Amounts due to/from affiliates are as follows:
Revenues from unconsolidated affiliates at SDG&E and SoCalGas are as follows:
OTHER INCOME, NET Other Income, Net on the Condensed Consolidated Statements of Operations consists of the following:
INCOME TAXES
Changes in Income Tax Expense and Effective Income Tax Rates Sempra Energy Consolidated The increase in income tax expense in the three months ended September 30, 2013 was due to higher pretax income and a higher effective tax rate. The change in the effective income tax rate was primarily due to:
On September 13, 2013, the IRS and U.S. Department of the Treasury released final tangible property regulations on the capitalization and expensing rules applicable to expenditures for the acquisition and production of tangible property. A company must conform its tax accounting methods and elect any safe harbors under the final regulations no later than January 1, 2014, however, if a change in the company's tax accounting methods is required to conform to the final regulations, the company must adjust its deferred tax balances in the current period for any tax adjustments required to bring all prior periods into compliance with the final regulations. We have evaluated our capitalization and expensing policies under the final tangible property regulations and believe that these final regulations will not have a material impact on our financial statements. Accordingly, we have not made any adjustment to our deferred tax balances at September 30, 2013 resulting from the IRS' issuance of final tangible property regulations during the period.
The California Public Utilities Commission (CPUC) requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income taxes are not recorded to deferred income tax expense, but rather to a regulatory asset or liability. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the effective income tax rate. The following items are subject to flow-through treatment:
We provide additional information about our accounting for income taxes in Notes 1 and 7 of the Notes to Consolidated Financial Statements in the Annual Report. |
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DEBT AND CREDIT FACILITIES |
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Debt and Credit Facilities | NOTE 6. DEBT AND CREDIT FACILITIES Committed Lines of Credit At September 30, 2013, Sempra Energy Consolidated had an aggregate of $4.1 billion in committed lines of credit to provide liquidity and to support commercial paper, the major components of which we detail below. Available unused credit on these lines at September 30, 2013 was $3.6 billion. Sempra Energy Sempra Energy has a $1.067 billion, five-year syndicated revolving credit agreement expiring in March 2017. Citibank, N.A. serves as administrative agent for the syndicate of 24 lenders. No single lender has greater than a 7-percent share. Borrowings bear interest at benchmark rates plus a margin that varies with market index rates and Sempra Energy's credit ratings. The facility requires Sempra Energy to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At September 30, 2013 and December 31, 2012, Sempra Energy was in compliance with this and all other financial covenants under the credit facility. The facility also provides for issuance of up to $635 million of letters of credit on behalf of Sempra Energy with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. At September 30, 2013, Sempra Energy had $12 million of letters of credit outstanding supported by the facility. Sempra Global Sempra Global has a $2.189 billion, five-year syndicated revolving credit agreement expiring in March 2017. Citibank, N.A. serves as administrative agent for the syndicate of 25 lenders. No single lender has greater than a 7-percent share. Sempra Energy guarantees Sempra Global's obligations under the credit facility. Borrowings bear interest at benchmark rates plus a margin that varies with market index rates and Sempra Energy's credit ratings. The facility requires Sempra Energy to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At September 30, 2013 and December 31, 2012, Sempra Global was in compliance with this and all of the financial covenants under the credit facility. At September 30, 2013, Sempra Global had $445 million of commercial paper outstanding supported by the facility. At December 31, 2012, $300 million of commercial paper outstanding was classified as long-term debt based on management's intent and ability to maintain this level of borrowing on a long-term basis either supported by this credit facility or by issuing long-term debt. This classification has no impact on cash flows. As a result of issuances of long-term debt in the nine months ended September 30, 2013, as we discuss below, none of the commercial paper outstanding at September 30, 2013 is classified as long-term debt. California Utilities SDG&E and SoCalGas have a combined $877 million, five-year syndicated revolving credit agreement expiring in March 2017. JPMorgan Chase Bank, N.A. serves as administrative agent for the syndicate of 24 lenders. No single lender has greater than a 7-percent share. The agreement permits each utility to individually borrow up to $658 million, subject to a combined limit of $877 million for both utilities. It also provides for the issuance of letters of credit on behalf of each utility subject to a combined letter of credit commitment of $200 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit. Borrowings under the facility bear interest at benchmark rates plus a margin that varies with market index rates and the borrowing utility's credit ratings. The agreement requires each utility to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At September 30, 2013 and December 31, 2012, the California Utilities were in compliance with this and all other financial covenants under the credit facility. Each utility's obligations under the agreement are individual obligations, and a default by one utility would not constitute a default by the other utility or preclude borrowings by, or the issuance of letters of credit on behalf of, the other utility. At September 30, 2013, SDG&E and SoCalGas had no outstanding borrowings supported by the facility. Available unused credit on the line at September 30, 2013 was $658 million at both SDG&E and SoCalGas, subject to the combined limit on the facility of $877 million. GUARANTEES RBS Sempra Commodities As we discuss in Note 4, in 2010 and early 2011, Sempra Energy, RBS and RBS Sempra Commodities sold substantially all of the businesses and assets within the partnership in four separate transactions. In connection with each of these transactions, the buyers were, subject to certain qualifications, obligated to replace any guarantees that we had issued in connection with the applicable businesses sold with guarantees of their own. The buyers have substantially completed this process with regard to all existing, open positions, except for one remaining position expected to terminate by January 2014. For those guarantees which have not been replaced, the buyers are obligated to indemnify us in accordance with the applicable transaction documents for any claims or losses in connection with the guarantees that we issued associated with the businesses sold. We discuss additional matters related to our investment in RBS Sempra Commodities in Note 10. Other Guarantees Sempra Renewables and BP Wind Energy each currently hold 50-percent interests in the Flat Ridge 2 Wind Farm. The project obtained construction financing in December 2012, and proceeds from the loans were used to return $148 million of each owner's joint venture investment in 2012. After completion of the project in March 2013, the construction financing was converted into permanent financing consisting of a term loan and a fixed-rate note. The term loan of $242 million expires in June 2023 and the fixed-rate note of $110 million expires in June 2035. The financing agreement requires Sempra Renewables and BP Wind Energy, severally for each partner's 50-percent interest, to return cash to the project in the event that the project does not meet certain cash flow criteria or in the event that the project's debt service, operation and maintenance and firm transmission and production tax credits reserve accounts are not maintained at specific thresholds. Sempra Renewables recorded a liability of $3 million in the first quarter of 2013 for the fair value of its obligations associated with the cash flow requirements, which constitutes a guarantee. The liability is being amortized over its expected life. The outstanding loans are not guaranteed by the partners. Sempra Renewables and BP Wind Energy each currently hold 50-percent interests in the Mehoopany Wind Farm. The project obtained construction financing in June 2012, and proceeds from the loans were used to return $17 million and $13 million of each owner's joint venture investment in 2012 and 2013, respectively. After completion of the project in May 2013, the construction financing was converted into permanent financing consisting of a term loan. The term loan of $162 million expires in May 2031. The financing agreement requires Sempra Renewables and BP Wind Energy, severally for each partner's 50-percent interest, to return cash to the project in the event that the project does not meet certain cash flow criteria or in the event that the project's debt service, operation and maintenance and production tax credits reserve accounts are not maintained at specific thresholds. Additionally, in conjunction with the term loan conversion, Sempra Renewables and BP Wind Energy have provided guarantees to the lenders in lieu of Mehoopany Wind Farm funding a reserve account requirement. Sempra Renewables recorded liabilities of $11 million in the second quarter of 2013 for the fair value of its obligations associated with the cash flow and reserve account requirements, which constitute guarantees. The liabilities are being amortized over their expected lives. The outstanding loans are not guaranteed by the partners. WEIGHTED AVERAGE INTEREST RATES The weighted average interest rates on the total short-term debt outstanding at Sempra Energy were 1.02 percent and 0.72 percent at September 30, 2013 and December 31, 2012, respectively. The weighted average interest rate at Sempra Energy at December 31, 2012 includes interest rates for commercial paper borrowings classified as long-term, as we discuss above. LONG-TERM DEBT SDG&E In September 2013, SDG&E publicly offered and sold $450 million of 3.60-percent first mortgage bonds maturing in 2023. SDG&E used a portion of the proceeds from this offering to redeem all $60 million of its outstanding 5.85-percent Pollution Control Revenue Bonds (PCRB) due in 2021 and $115 million of its outstanding 5.90-percent PCRBs due in 2014. Sempra Mexico On February 14, 2013, IEnova publicly offered and sold in Mexico $306 million (U.S. dollar equivalent) of 6.3-percent notes maturing in 2023 with a U.S. dollar equivalent rate of 4.12 percent after entering into a cross-currency swap for U.S. dollars at the time of issuance. IEnova also publicly offered and sold in Mexico $102 million (U.S. dollar equivalent) of variable rate notes, maturing in 2018, which after a floating-to-fixed cross-currency swap for U.S. dollars at the time of issuance, carry a U.S. dollar equivalent rate of 2.66 percent. The notes and related interest are denominated in Mexican pesos, and the interest rate for the variable rate notes is based on the 28-day Interbank Equilibrium Interest Rate plus 30 basis points. IEnova used $357 million of the proceeds of the notes for the repayment of intercompany debt, including accrued interest, primarily to other Sempra Energy consolidated foreign entities. Sempra Renewables In May 2013, Copper Mountain Solar 2 entered into a loan agreement with a syndicate of banks to borrow up to $286 million and took a draw of $146 million in May 2013, the proceeds of which were distributed to Sempra Renewables to reimburse it for the first phase of construction costs of the project. The loan, which is secured by the project, is payable semi-annually and fully matures in May 2023. To partially moderate its exposure to interest rate changes, Copper Mountain Solar 2 entered into floating-to-fixed interest rate swaps for 75 percent of the loan amount, resulting in an effective fixed rate of 5.33 percent. The remaining 25 percent bears interest at rates varying with market rates (2.81 percent at September 30, 2013). In connection with the loan agreement, Copper Mountain Solar 2 may also utilize up to $60 million under a letter of credit facility, which may be used to meet project collateral requirements and debt service reserve requirements. In the third quarter of 2013, Sempra Renewables sold 50-percent interests in Copper Mountain Solar 2 and Mesquite Solar 1 to ConEdison Development. Sempra Renewables' interests are now accounted for under the equity method and their long-term debt of $146 million at Copper Mountain 2 and $297 million at Mesquite Solar 1 was deconsolidated upon the sales. We provide further discussion of the sales in Note 3. Sempra South American Utilities In May 2013, Chilquinta Energía retired $86 million of outstanding Series A Chilean public bonds maturing in 2014 with a stated interest rate of 2.75 percent. INTEREST RATE SWAPS We discuss our fair value interest rate swaps and interest rate swaps to hedge cash flows in Note 7. |
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Derivative Financial Instruments | NOTE 7. DERIVATIVE FINANCIAL INSTRUMENTS We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk and benchmark interest rate risk. We may also manage foreign exchange rate exposures using derivatives. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines in anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not presented below. We record all derivatives at fair value on the Condensed Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) undesignated. Depending on the applicability of hedge accounting and, for the California Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Condensed Consolidated Statements of Cash Flows. In certain cases, we apply the normal purchase or sale exception to derivative accounting and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk that a given future revenue or expense item may vary, and other criteria. We may designate an interest rate derivative as a fair value hedging instrument if it effectively converts our own debt from a fixed interest rate to a variable rate. The combination of the derivative and debt instruments results in fixing that portion of the fair value of the debt that is related to benchmark interest rates. Designating fair value hedges is dependent on the instrument being used, the effectiveness of the instrument in offsetting changes in the fair value of our debt instruments, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business.
We summarize net energy derivative volumes as of September 30, 2013 and December 31, 2012 as follows:
In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the physical locations of our assets and other contractual obligations, such as natural gas and electric power purchases and sales.
INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We utilize interest rate swaps typically designated as fair value hedges, as a means to achieve our targeted level of variable rate debt as a percent of total debt. In addition, we may utilize interest rate swaps, which are typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings. Interest rate derivatives are utilized by the California Utilities as well as by other Sempra Energy subsidiaries. Although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate derivatives may not be recovered from customers as timely as described above with regard to natural gas derivatives. Accordingly, interest rate derivatives are generally accounted for as hedges at the California Utilities, as well as at the rest of Sempra Energy's subsidiaries. Separately, Otay Mesa VIE has entered into interest rate swap agreements to moderate its exposure to interest rate changes. This activity was designated as a cash flow hedge as of April 1, 2011. The net notional amounts of our interest rate derivatives, excluding the cross-currency swaps discussed below, as of September 30, 2013 and December 31, 2012 were:
FOREIGN CURRENCY DERIVATIVES We are exposed to exchange rate movements at our Mexican subsidiaries, which have U.S. dollar denominated cash balances, receivables and payables (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. These subsidiaries also have deferred income tax assets and liabilities that are denominated in the Mexican peso, which must be translated into U.S. dollars for financial reporting purposes. From time to time, we may utilize short-term foreign currency derivatives at our subsidiaries and at the consolidated level as a means to manage the risk of exposure to significant fluctuations in our income tax expense from these impacts. We may also utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries. On February 14, 2013, Sempra Mexico entered into cross-currency swap agreements, which were designated as cash flow hedges. We discuss the notional amount of the cross-currency swaps in Note 6. In addition, Sempra South American Utilities may utilize foreign currency derivatives at its subsidiaries and joint ventures as a means to manage foreign currency rate risk. We discuss such swaps at Chilquinta Energía's Eletrans joint venture investment in Note 4. FINANCIAL STATEMENT PRESENTATION Each Condensed Consolidated Balance Sheet reflects the offsetting of net derivative positions and cash collateral with the same counterparty when management believes a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Condensed Consolidated Balance Sheets as of September 30, 2013 and December 31, 2012, including the amount of cash collateral receivables that were not offset, as the cash collateral is in excess of liability positions.
The effects of derivative instruments designated as hedges on the Condensed Consolidated Statements of Operations and on Other Comprehensive Income (OCI) and Accumulated Other Comprehensive Income (AOCI) for the three months and nine months ended September 30 were:
Sempra Energy Consolidated expects that losses of $22 million, which are net of income tax benefit, that are currently recorded in AOCI (including losses of $11 million in noncontrolling interests) related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates and certain commodity prices in effect when derivative contracts that are currently outstanding mature. The Sempra Energy Consolidated amount includes losses of $10 million at SDG&E in noncontrolling interest related to Otay Mesa VIE. SoCalGas expects that losses of $1 million, which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings. For all forecasted transactions, the maximum term over which we are hedging exposure to the variability of cash flows at September 30, 2013 is approximately 15 years and 6 years for Sempra Energy and SDG&E, respectively. The maximum term of hedged interest rate variability related to debt at Sempra Renewables' equity method investees is 22 years. We recorded negligible hedge ineffectiveness in the three-month period ended September 30, 2013 and $1 million of hedge ineffectiveness in the nine-month period ended September 30, 2013 and $1 million of hedge ineffectiveness in both the three-month and nine-month periods ended September 30, 2012. The effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations for the three months and nine months ended September 30 were:
CONTINGENT FEATURES For Sempra Energy and SDG&E, certain of our derivative instruments contain credit limits which vary depending upon our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. For Sempra Energy, the total fair value of this group of derivative instruments in a net liability position at September 30, 2013 and December 31, 2012 is $3 million and $8 million, respectively. As of September 30, 2013, if the credit ratings of Sempra Energy were reduced below investment grade, $3 million of additional assets could be required to be posted as collateral for these derivative contracts. For SDG&E, the total fair value of this group of derivative instruments in a net liability position at September 30, 2013 and December 31, 2012 is $2 million and $6 million, respectively. As of September 30, 2013, if the credit ratings of SDG&E were reduced below investment grade, $2 million of additional assets could be required to be posted as collateral for these derivative contracts. For Sempra Energy, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.
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- Definition The entire disclosure for the entity's entire derivative instruments and hedging activities. Describes an entity's risk management strategies, derivatives in hedging activities and non-hedging derivative instruments, the assets, obligations, liabilities, revenues and expenses arising therefrom, and the amounts of and methodologies and assumptions used in determining the amounts of such items. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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Notes to Consolidated Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Measurements | NOTE 8. FAIR VALUE MEASUREMENTS We discuss the valuation techniques and inputs we use to measure fair value and the definition of the three levels of the fair value hierarchy in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We have not changed the valuation techniques or inputs we use to measure fair value during the nine months ended September 30, 2013. Recurring Fair Value Measures The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2013 and December 31, 2012. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities, and their placement within the fair value hierarchy levels. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 under “Financial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2013 and December 31, 2012 in the tables below include the following:
There were no transfers into or out of Level 1, Level 2 or Level 3 for Sempra Energy Consolidated, SDG&E or SoCalGas during the periods presented, nor any changes in valuation techniques used in recurring fair value measurements.
Level 3 Information The following table sets forth reconciliations of changes in the fair value of congestion revenue rights (CRRs) classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated and SDG&E:
SDG&E's Energy and Fuel Procurement department, in conjunction with SDG&E's finance group, is responsible for determining the appropriate fair value methodologies used to value and classify CRRs on an ongoing basis. Inputs used to determine the fair value of CRRs are reviewed and compared with market conditions to determine reasonableness. All costs related to CRRs are expected to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments. CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California Independent System Operator (ISO), an objective source. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instruments are classified as Level 3. As of September 30, 2013 the auction prices range from $(8) per MWh to $8 per MWh at a given location, and the fair value of these instruments is derived from auction price differences between two locations. As of September 30, 2012 the auction prices ranged from $(3) per MWh to $5 per MWh. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement. We summarize CRR volumes in Note 7. Realized gains and losses associated with CRRs are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Condensed Consolidated Statements of Operations. Unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. Fair Value of Financial Instruments The fair values of certain of our financial instruments (cash, temporary investments, accounts and notes receivable, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. The following table provides the carrying amounts and fair values of certain other financial instruments at September 30, 2013 and December 31, 2012:
We base the fair value of certain of our long-term debt and preferred stock on a market approach using quoted market prices for identical or similar securities in thinly-traded markets (Level 2). We value other long-term debt using an income approach based on the present value of estimated future cash flows discounted at rates available for similar securities (Level 3). We calculated the fair value of our investments in affordable housing partnerships using an income approach based on the present value of estimated future cash flows discounted at rates available for similar investments (Level 3). Nuclear Decommissioning Trusts We discuss SDG&E's investments in nuclear decommissioning trust funds in Note 9 below and in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report. The following table shows the fair values and gross unrealized gains and losses for the securities held in the trust funds:
The following table shows the proceeds from sales of securities in the trusts and gross realized gains and losses on those sales:
Net unrealized gains (losses) are included in Regulatory Liabilities Arising from Removal Obligations on the Condensed Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification. |
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- References No definition available.
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- Definition The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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CALIFORNIA UTILITIES' REGULATORY MATTERS |
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Sep. 30, 2013 | |
Notes to Consolidated Financial Statements [Abstract] | |
Sempra Utilities' Regulatory Matters | NOTE 9. CALIFORNIA UTILITIES' REGULATORY MATTERS We discuss matters affecting our California Utilities in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report, and provide updates to those discussions and details of any new matters below. JOINT MATTERS CPUC General Rate Case (GRC) The CPUC uses a general rate case proceeding to prospectively set rates sufficient to allow the California Utilities to recover their reasonable cost of operations and maintenance and to provide the opportunity to realize their authorized rates of return on their investment. In December 2010, the California Utilities filed their 2012 General Rate Case (2012 GRC) applications to establish their authorized 2012 revenue requirements and the ratemaking mechanisms by which those requirements would change on an annual basis over the subsequent three-year (2013-2015) period. In May 2013, the CPUC approved a final decision (Final GRC Decision) in the California Utilities' 2012 GRC. The Final GRC Decision establishes a 2012 revenue requirement of $1.733 billion for SDG&E and $1.959 billion for SoCalGas. This represents an increase of $119 million (7.4 percent) and $115 million (6.2 percent) over SDG&E's and SoCalGas' authorized 2011 revenue requirements, respectively. The Final GRC Decision is effective retroactive to January 1, 2012, and SDG&E and SoCalGas recorded the cumulative earnings effect of the retroactive application of the Final GRC Decision of $69 million and $37 million, respectively, in the second quarter of 2013. For SDG&E and SoCalGas, respectively, these amounts include an incremental earnings impact of $52 million and $25 million related to 2012 and $17 million and $12 million related to the first quarter of 2013. The amount of revenue associated with the retroactive period is expected to be recovered in SDG&E's rates over a 28-month period beginning in September 2013, and in SoCalGas' rates over a 31-month period beginning in June 2013. At September 30, 2013, SDG&E reported on its Condensed Consolidated Balance Sheet $366 million as a regulatory asset, with $203 million classified as noncurrent, representing the retroactive revenue from the Final GRC Decision to be recovered by SDG&E in rates during the period September 2013 through December 2015. At September 30, 2013, SoCalGas reported on its Condensed Consolidated Balance Sheet a regulatory asset of $117 million, with $65 million as noncurrent, representing the retroactive revenue from the Final GRC Decision to be recovered in rates through December 2015. The Final GRC Decision also establishes a four-year GRC period (through 2015) with a revenue attrition mechanism for the escalation of the adopted revenue requirements for years 2013, 2014, and 2015 based on fixed annual factors of 2.65 percent, 2.75 percent and 2.75 percent, respectively. For SDG&E, the Final GRC Decision also provides the revenue requirement for cost recovery of wildfire insurance premiums beginning January 1, 2012, as we discuss in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report. We provide additional information regarding the 2012 GRC in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report. CPUC Cost of Capital A cost of capital proceeding determines a utility's authorized capital structure and authorized rate of return on rate base (ROR), which is a weighted average of the authorized returns on debt, preferred stock, and common equity (return on equity or ROE), weighted on a basis consistent with the authorized capital structure. The authorized ROR is the rate that the California Utilities are authorized to use in establishing rates to recover the cost of debt and equity used to finance their investment in electric and natural gas distribution, natural gas transmission and electric generation assets. In addition, a cost of capital proceeding also addresses the automatic ROR adjustment mechanism which applies market-based benchmarks to determine whether an adjustment to the authorized ROR is required during the interim years between cost of capital proceedings. SDG&E and SoCalGas filed separate applications with the CPUC in April 2012 to update their cost of capital effective January 1, 2013. The CPUC issued a ruling in June 2012 bifurcating the proceeding. Phase 1 addressed each utility's cost of capital for 2013, with a final decision issued in December 2012, which granted SDG&E and SoCalGas an authorized ROR of 7.79 percent and 8.02 percent, respectively. The CPUC-authorized ROR in effect prior to the effective date of this decision was 8.40 percent for SDG&E and 8.68 percent for SoCalGas. We provide additional details regarding the cost of capital proceeding in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report. Phase 2 addressed the cost of capital adjustment mechanisms for SDG&E, SoCalGas, Southern California Edison (Edison) and Pacific Gas and Electric Company (PG&E). SDG&E, SoCalGas, PG&E, Edison and the Office of Ratepayer Advocates (ORA) (formerly the Division of Ratepayer Advocates) sponsored a joint stipulation in Phase 2 of the proceeding. In March 2013, the CPUC's final decision adopted the joint stipulation, as proposed. SDG&E retains its current cost of capital adjustment mechanism, and SoCalGas has implemented this same adjustment mechanism, which we describe in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report. Both utilities are forgoing their proposed off-ramp provision. Natural Gas Pipeline Operations Safety Assessments Various regulatory agencies, including the CPUC, are evaluating natural gas pipeline safety regulations, practices and procedures. In February 2011, the CPUC opened a forward-looking rulemaking proceeding to examine what changes should be made to existing pipeline safety regulations for California natural gas pipelines. The California Utilities are parties to this proceeding. In June 2011, the CPUC directed SoCalGas, SDG&E, PG&E and Southwest Gas to file comprehensive implementation plans to test or replace all natural gas transmission pipelines that have not been pressure tested. The California Utilities filed their Pipeline Safety Enhancement Plan (PSEP) with the CPUC in August 2011. The proposed safety measures, investments and estimated costs are not included in the California Utilities' 2012 GRC process discussed above. In December 2011, the assigned Commissioner to the rulemaking proceeding for the pipeline safety regulations ruled that SDG&E's and SoCalGas' Triennial Cost Allocation Proceeding (TCAP) would be the most logical proceeding to conduct the reasonableness and ratemaking review of the companies' PSEP. In January 2012, the CPUC Consumer Protection and Safety Division (CPSD) issued a Technical Report of the California Utilities' PSEP. The report, along with testimony and evidentiary hearings, will be used to evaluate the PSEP in the regulatory process. Generally, the report found that the PSEP approach to pipeline replacement and pressure testing and other proposed enhancements is reasonable. In February 2012, the assigned Commissioner in the TCAP issued a ruling setting a schedule for the review of the SDG&E and SoCalGas PSEP with evidentiary hearings held in August 2012. SDG&E and SoCalGas now expect the Administrative Law Judge to issue a proposed decision in Phase 1A of this proceeding in the fourth quarter of 2013. We anticipate that the proposed decision, if adopted, would require SoCalGas and SDG&E to update the costs included in their previous filings, as well as to reflect additional records that have been recovered resulting in a reduction of the number of pipeline miles without records. In April 2012, the CPUC issued an interim decision in the rulemaking proceeding formally transferring the PSEP to the TCAP and authorizing SDG&E and SoCalGas to establish regulatory accounts to record the incremental costs of initiating the PSEP prior to a final decision on the PSEP. The TCAP proceeding will address the recovery of the costs recorded in the regulatory account. In April 2012, the CPUC issued a decision expanding the scope of the rulemaking proceeding to incorporate the provisions of California Senate Bill (SB) 705, which requires gas utilities to develop and implement a plan for the safe and reliable operation of their gas pipeline facilities. SDG&E and SoCalGas submitted their pipeline safety plans in June 2012. The CPUC decision also orders the utilities to undergo independent management and financial audits to assure that the utilities are fully meeting their safety responsibilities. CPSD will select the independent auditors and will oversee the audits. A schedule for the audits has not been established. In December 2012, the CPUC issued a final decision accepting the utility safety plans filed pursuant to SB 705. We provide additional information regarding these rulemaking proceedings and the California Utilities' PSEP in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report. Utility Incentive Mechanisms The CPUC applies performance-based measures and incentive mechanisms to all California investor-owned utilities, under which the California Utilities have earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. We provide additional information regarding these incentive mechanisms in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report, and below. Natural Gas Procurement In the first quarter of 2012, SoCalGas recorded its Gas Cost Incentive Mechanism (GCIM) award of $6.2 million for natural gas procured for its core customers during the 12-month period ending March 31, 2011. In July 2013, the CPUC approved SoCalGas' application requesting a GCIM award of $5.4 million for the 12-month period ending March 31, 2012, which SoCalGas recorded in the third quarter of 2013. In June 2013, SoCalGas applied to the CPUC for approval of a GCIM award of $5.8 million for natural gas procured for its core customers during the 12-month period ending March 31, 2013. SoCalGas expects a CPUC decision on this application in the first half of 2014. Energy Efficiency In September 2013, SoCalGas and SDG&E filed their incentive award claims of $3.1 million and $3.9 million, respectively, for their energy efficiency performance in program year 2011. We expect CPUC approval of the awards by the end of 2013. Both SoCalGas and SDG&E plan to file incentive award claims for the 2012 program year in the third quarter of 2014. We currently expect the award amounts to be approximately equal to the amounts claimed for the 2011 program year. In September 2013, the CPUC approved a new Efficiency Savings and Performance Incentive mechanism that would apply for the 2013–2014 program period. The mechanism will be applied on an annual basis and remain in effect for future program cycles unless modified by the CPUC. We currently expect the annual amount of the energy efficiency awards for both SoCalGas and SDG&E under this new mechanism to approximate the amount of awards claimed for the 2011 program year. SDG&E MATTERS San Onofre Nuclear Generating Station (SONGS) SONGS Outage and Retirement SDG&E has a 20-percent ownership interest in San Onofre Nuclear Generating Station (SONGS), a 2,150-MW nuclear generating facility near San Clemente, California. SONGS is operated by Southern California Edison (Edison), the majority owner, and is subject to the jurisdiction of the Nuclear Regulatory Commission (NRC) and the CPUC. On June 6, 2013, Edison notified SDG&E that it had reached a decision to permanently retire SONGS Units 2 and 3 and seek approval to start the decommissioning activities for the entire facility. Edison advised SDG&E that its management had made the unilateral decision to retire the Units once Edison concluded that the considerable uncertainty about when, or if, the NRC would allow a restart of Unit 2 could not be resolved. Given this uncertainty, Edison decided to retire both Units and seek the authority from the NRC to commence the decommissioning of SONGS. By way of background, the steam generators were replaced in Units 2 and 3, and the Units returned to service in 2010 and 2011, respectively. Both Units have been shut down since early 2012 after a water leak occurred in the Unit 3 steam generator. Edison concluded that the leak was due to unexpected wear from tube-to-tube contact. At the time the leak was identified, Edison also inspected and tested Unit 2 and subsequently found unexpected tube wear in Unit 2's steam generators, as well. In March 2012, in response to the shutdown of SONGS, the NRC issued a Confirmatory Action Letter (CAL) which, among other things, outlined the requirements Edison would be required to meet before the NRC would approve a restart of either of the Units. In October 2012, Edison submitted a restart plan to the NRC proposing to operate Unit 2 at a reduced power level for a period of five months, at which time the Unit would be brought down for further inspection. Edison did not file a restart plan for Unit 3, pending further inspection and analysis of what the required repairs or modifications would need to be to return the Unit back to service in a safe manner. The NRC had been reviewing the restart plan for Unit 2 proposed by Edison since that time, and in May 2013, the Atomic Safety and Licensing Board (ASLB), an adjudicatory arm of the NRC, concluded that the CAL process constituted a de facto license amendment proceeding that was subject to a public hearing. This conclusion by the ASLB resulted in further uncertainty regarding when a final decision might be made on restarting Unit 2. CPUC SONGS Order Instituting Investigation (OII) In response to the prolonged outage, the CPUC issued the OII, pursuant to California Public Utilities' Code Section 455.5. The OII consolidates all SONGS issues in various related proceedings into a single proceeding. The OII, among other things, ruled that all revenues associated with the investment in, and operation of, SONGS since January 1, 2012 are subject to refund to customers, pending the outcome of the proceeding. The OII proceeding will also determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of this outage, including purchased replacement power costs that are typically recovered through the Energy Resource Recovery Account (ERRA) balancing account subject only to a reasonableness review by the CPUC. The first phase of the OII addresses 2012 costs. Two hearings were held in 2013 on this first phase, in May to address the 2012 capital and operation and maintenance costs, and in August to address the appropriate determination of the cost of purchased replacement power. We expect a CPUC decision on the first phase of the OII in the fourth quarter of 2013. The second phase of the OII addresses the appropriate rate recovery treatment of the investment in SONGS assets. Hearings on this second phase were held in October 2013, and we expect a CPUC decision on this phase of the OII in the first half of 2014. The third and fourth phases of the OII will address the reasonableness of the steam generator replacement project costs. No hearing dates for these two phases have been scheduled. Since the unscheduled outage started, SDG&E has procured power to meet its customers' needs to replace the power that would have been supplied to SDG&E from SONGS, had SONGS been in operation. The estimated cost of the purchased replacement power, determined consistent with the methodology used in the CPUC's OII into the SONGS outage, incurred from January 2012 through June 6, 2013, the date Edison notified SDG&E of the early closure of SONGS, was approximately $166 million. Of this total, $93 million was incurred in 2012 and has been approved for collection in rates pursuant to prior ERRA proceedings. The remaining $74 million, discussed below, represents replacement power costs incurred in 2013 through June 6 that have not been approved for recovery in rates. In addition to the estimated cost of the purchased replacement power mentioned above, SDG&E's share of SONGS' operating costs, including depreciation, and the return on its investment in SONGS from January 1, 2012 through June 30, 2013, was approximately $300 million. We provide additional information regarding the OII in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report. Accounting for the Early Retirement of SONGS Given the decision by Edison to close SONGS, SDG&E management assessed the appropriate accounting for an early-retired plant. In conducting this assessment, management took into consideration, among other things, the interrelationship of any recovery of SDG&E's investment in SONGS, the cost of operations, the cost of purchased replacement power and the probability of having to refund to customers a portion or all of the revenue subject to refund. Management's assessment took into account that the CPUC is considering all of these elements on a combined basis in the OII. After considering the regulatory precedent regarding rate recovery of investments in and costs incurred related to early-retired plants, management considered a number of possible regulatory outcomes from the OII proceeding, none of which management considered certain, and given SDG&E's non-operator and minority interest position and the regulatory precedent on such matters, management believes that it is probable that SDG&E will recover in rates a substantial portion of its investment in SONGS, the associated costs incurred to date and the cost of the purchased replacement power. The amount that management has deemed to be probable of recovery was determined based on management's assessment of the likelihood of the potential regulatory outcomes identified. As a result of Edison's decision to permanently retire SONGS Units 2 and 3, and as a result of our assessment described above, SDG&E established a new regulatory asset included in Other Assets–Other Regulatory Assets on the Condensed Consolidated Balance Sheet. As of September 30, 2013, the balance in this new regulatory asset was $431 million and was comprised of the following:
The amount that SDG&E will eventually recover will require a regulatory decision from the CPUC that could result in recovery of an amount that is significantly different than management's estimate. In addition to recoveries through the regulatory process, SDG&E intends to pursue various avenues for recovery from other potentially responsible parties and insurance carriers. However, these anticipated recoveries, if any, cannot be included in our current estimates. SDG&E will continue to assess the probability of recovery in rates of this new regulatory asset, as well as: 1) the cost of the purchased replacement power of $93 million approved in prior ERRA proceedings for collection in rates, and 2) the operations and maintenance expenses incurred by SDG&E since the start of the forced outages, which amounted to approximately $220 million through September 30, 2013. Should SDG&E conclude that recovery in rates is less than the amount anticipated or no longer probable, SDG&E will record an additional charge against earnings at the time such a conclusion is reached. Nuclear Regulatory Commission (NRC) Proceedings In September 2013, Edison received an NRC Inspection Report which identified a preliminary finding with low to moderate safety significance and an apparent violation regarding Unit 3's steam generators. In addition, the report identified a preliminary finding with very low safety significance for Unit 2's steam generators for failing to ensure that MHI's modeling and analysis were adequate. Simultaneously, the NRC issued an Inspection Report to MHI containing a Notice of Nonconformance for its flawed computer modeling in the design of the replacement steam generators. Nuclear Decommissioning and Funding As a result of Edison's decision to permanently retire SONGS Units 2 and 3, Edison has begun the decommissioning phase of the plant. The process of decommissioning a nuclear power plant is governed by NRC regulations. The regulations categorize the decommissioning activities into three phases: initial activities, major decommissioning and storage activities, and license termination. Initial activities include providing notice of permanent cessation of operations (accomplished on June 12, 2013) and notice of permanent removal of fuel from the reactor vessels (provided by Edison to the NRC on June 28 and July 22, 2013 for Units 3 and 2, respectively). Within two years after the announcement of retirement, the licensee (Edison) must submit a post-shutdown decommissioning activities report, an irradiated fuel management plan and a site-specific decommissioning cost estimate. Edison currently estimates that it will provide the other initial activity phase plans and cost estimates to the NRC by the end of 2014. In accordance with state and federal requirements and regulations, SDG&E has assets held in trusts, referred to as the Nuclear Decommissioning Trust (NDT), to fund decommissioning costs for SONGS Units 1, 2 and 3. As of September 30, 2013, the fair value of SDG&E's NDT assets was $981 million. Except for the use of funds for the planning of decommissioning activities, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs. SDG&E currently plans to file a request with the CPUC for such authorization by the end of 2013. Until CPUC approval is received, SDG&E will use working capital to pay for any SONGS decommissioning costs incurred, and such expenditures will be reimbursed from the NDT upon that approval. SDG&E and Edison have a joint application pending with the CPUC requesting continued rate recovery of the estimated cost for decommissioning of SONGS. SDG&E is currently authorized to recover $8 million annually to fund additional investments in the NDT to pay for the cost of decommissioning SONGS. In its pending application with the CPUC, SDG&E is requesting to recover $16 million on an annual basis to fund additional investments in the NDT. We expect a decision on this application in the first half of 2014. We provide additional information regarding the NDT and the SONGS decommissioning in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report. Power Procurement and Resource Planning
South Bay Substation SDG&E filed an application in 2010 with the CPUC for a permit to construct a new substation to replace the aging and obsolete South Bay substation and accommodate the retirement of the South Bay Power Plant. The existing substation will be demolished when the new substation has been constructed, energized and all transmission lines have been transferred. On October 17, 2013, the CPUC approved SDG&E's permit to construct the South Bay Substation Relocation Project at SDG&E's proposed site, which will be located south of the existing site. The project, estimated at $145 million to $175 million, will replace the existing 138/69-kilovolt (kV) substation with the new 230/69/12-kV Bay Boulevard Substation. SDG&E is in the process of obtaining the additional permits required to begin construction, including the coastal development permit from the California Coastal Commission. SDG&E currently expects the project to be in service by 2017. East County Substation In June 2012, the CPUC approved SDG&E's application for authorization to proceed with the East County Substation project, estimated to cost $435 million. The Bureau of Land Management (BLM) issued its record of decision in August 2012. SDG&E began construction in the second quarter of 2013 and expects the substation to be placed in service in the second half of 2014. FERC Formulaic Rate Matters SDG&E submitted its Electric Transmission Formula Rate (TO4) filing with the Federal Energy Regulatory Commission (FERC) in February 2013 to be effective September 1, 2013. This proceeding will set the rate making methodology and rate of return for SDG&E's FERC-regulated electric transmission operations and assets. SDG&E's TO4 filing is requesting a rate making formula that is essentially the same as the TO3 Formula. SDG&E's TO4 filing is requesting: 1) rates to be determined by a base period of historical costs and a forecast of capital investments and 2) a true-up period similar to balancing account treatment that is designed to provide SDG&E earnings of no more and no less than its actual cost of service including its authorized return on investment. This TO4 proceeding will also set SDG&E's authorized return on equity (ROE) on FERC rate base. SDG&E's TO4 filing proposes a FERC ROE of 11.3 percent. Parties have protested SDG&E's proposed ROE and have requested an ROE in the high 8 percent to low 10 percent range. They have also protested other aspects of the TO4 filing. Although the FERC issued orders conditionally adopting the rates proposed by SDG&E based on the 11.3 percent ROE, effective September 1, 2013, such revenues are subject to refund. Settlement negotiations are currently ongoing. If no settlement is reached, hearings at the FERC will begin in May 2014. Based upon recent decisions, and the fact that SDG&E does not currently have any incentive adders in relation to existing projects, the outcome of this proceeding likely may result in an ROE closer to 10 percent. With respect to SDG&E's TO3 Formula, a hearing has been scheduled for early 2014 to address SDG&E's proposed recovery of $23.2 million of costs related to excess wildfire claims in transmission rates for the period September 1, 2012 through August 31, 2013. Excess Wildfire Claims Cost Recovery at the CPUC SDG&E and SoCalGas filed an application, along with other related filings, with the CPUC in August 2009 proposing a new framework and mechanism for the future recovery of all wildfire-related expenses for claims, litigation expenses and insurance premiums that are in excess of amounts authorized by the CPUC for recovery in distribution rates. In December 2012, the CPUC issued a final decision that ultimately did not approve the proposed framework for the utilities but allowed SDG&E to maintain its authorized memorandum account, so that SDG&E may file applications with the CPUC requesting recovery of amounts properly recorded in the memorandum account at a later time, subject to reasonableness review. SDG&E intends to pursue recovery of such costs in a future application. SDG&E will continue to assess the potential for recovery of these costs in rates. Should SDG&E conclude that recovery in rates is no longer probable, SDG&E will record a charge against earnings at the time such conclusion is reached. If SDG&E had concluded that the recovery of regulatory assets related to CPUC-regulated operations was no longer probable or was less than currently estimated at September 30, 2013, the resulting after-tax charge against earnings would have been up to $186 million. In addition, in periods following any such conclusion, SDG&E's earnings will be adversely impacted by increases in the estimated cost to litigate or settle pending wildfire claims. We discuss how we assess the probability of recovery of our regulatory assets in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We provide additional information about 2007 wildfire litigation costs and their recovery in Note 10. SOCALGAS MATTER Aliso Canyon Natural Gas Storage Compressor Replacement In September 2009, SoCalGas filed an application with the CPUC requesting approval to replace certain obsolete natural gas turbine compressors used in the operations of SoCalGas' Aliso Canyon natural gas storage reservoir with a new electric compressor station. In April 2012, the CPUC issued a draft environmental impact report (EIR) for the project concluding that no significant or unavoidable adverse environmental impacts have been identified from the construction or operation of the proposed project. In July 2013, the CPUC issued a final EIR confirming the conclusions and findings in the draft EIR. On October 29, 2013, the CPUC issued a proposed decision that adopts the EIR and approves the estimated $200 million project. We expect the CPUC to issue a final decision in November 2013. |
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- Definition The entire disclosure for public utilities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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COMMITMENTS AND CONTINGENCIES |
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Notes to Consolidated Financial Statements [Abstract] | |
Commitments and Contingencies | NOTE 10. COMMITMENTS AND CONTINGENCIES LEGAL PROCEEDINGS We accrue losses for legal proceedings when it is probable that a loss has been incurred and the amounts of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverage and could materially adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued. At September 30, 2013, Sempra Energy's accrued liabilities for material legal proceedings, on a consolidated basis, were $177 million. At September 30, 2013, accrued liabilities for material legal proceedings for SDG&E and SoCalGas were $164 million and $5 million, respectively. At September 30, 2013, accrued liabilities of $164 million at Sempra Energy and SDG&E were related to wildfire litigation discussed below. SDG&E 2007 Wildfire Litigation In October 2007, San Diego County experienced several catastrophic wildfires. Reports issued by the California Department of Forestry and Fire Protection (Cal Fire) concluded that two of these fires (the Witch and Rice fires) were SDG&E “power line caused” and that a third fire (the Guejito fire) occurred when a wire securing a Cox Communications' (Cox) fiber optic cable came into contact with an SDG&E power line “causing an arc and starting the fire.” Cal Fire reported that the Rice fire burned approximately 9,500 acres and damaged 206 homes and two commercial properties, and the Witch and Guejito fires merged and eventually burned approximately 198,000 acres, resulting in two fatalities, approximately 40 firefighters injured and an estimated 1,141 homes destroyed. A September 2008 staff report issued by the CPUC's CPSD reached substantially the same conclusions as the Cal Fire reports, but also contended that the power lines involved in the Witch and Rice fires and the lashing wire involved in the Guejito fire were not properly designed, constructed and maintained. In April 2010, proceedings initiated by the CPUC to determine if any of its rules were violated were settled with SDG&E's payment of $14.75 million. Numerous parties have sued SDG&E and Sempra Energy in San Diego County Superior Court seeking recovery of unspecified amounts of damages, including punitive damages, from the three fires. These include owners and insurers of properties that were destroyed or damaged in the fires and government entities seeking recovery of firefighting, emergency response, and environmental costs. They assert various bases for recovery, including inverse condemnation based upon a California Court of Appeal decision finding that another California investor-owned utility was subject to strict liability, without regard to foreseeability or negligence, for property damages resulting from a wildfire ignited by power lines. In October 2010, the Court of Appeal affirmed the trial court's ruling that these claims must be pursued in individual lawsuits, rather than as class actions on behalf of all persons who incurred wildfire damages. In February 2011, the California Supreme Court denied a petition for review of the affirmance. A trial has been set for September 26, 2014. SDG&E filed cross-complaints against Cox seeking indemnification for any liability that SDG&E might incur in connection with the Guejito fire, two SDG&E contractors seeking indemnification in connection with the Witch fire, and one SDG&E contractor seeking indemnification in connection with the Rice fire. SDG&E settled its claims against Cox and the three contractors for a total of approximately $824 million. Among other things, the settlement agreements provide that SDG&E will defend and indemnify Cox and the three contractors against all compensatory damage claims and related costs arising out of the wildfires. SDG&E has settled all of the approximately 19,000 claims brought by homeowner insurers for damage to insured property relating to the three fires. Under the settlement agreements, SDG&E has paid or will pay 57.5 percent of the approximately $1.6 billion paid or reserved for payment by the insurers to their policyholders and received an assignment of the insurers' claims against other parties potentially responsible for the fires. The wildfire litigation also includes claims of non-insurer plaintiffs for damage to uninsured and underinsured structures, business interruption, evacuation expenses, agricultural damage, emotional harm, personal injuries and other losses. SDG&E has settled the claims of approximately 5,950 of these plaintiffs, including all of the government entities. There are now less than 100 cases left to be resolved and substantially all of those remaining individual and business plaintiffs have submitted settlement demands and damage estimates totaling approximately $550 million. SDG&E does not expect a significant number of additional plaintiffs to file lawsuits given the applicable statutes of limitation, but does expect to receive additional settlement demands and damage estimates from existing plaintiffs as settlement negotiations continue. SDG&E has established reserves for the wildfire litigation as we discuss below. SDG&E's settled claims and defense costs have exceeded its $1.1 billion of liability insurance coverage for the covered period and the $824 million recovered from third parties. It expects that its wildfire reserves and amounts paid to resolve wildfire claims will continue to increase as it obtains additional information. As we discuss in Note 9, SDG&E has concluded that it is probable that it will be permitted to recover in rates a substantial portion of its reasonably incurred costs of resolving wildfire claims in excess of its liability insurance coverage and the amounts recovered from third parties. Accordingly, although such recovery will require future regulatory approval, at September 30, 2013, Sempra Energy and SDG&E have recorded assets of $339 million in Regulatory Assets Arising From Wildfire Litigation Costs on their Condensed Consolidated Balance Sheets, including $315 million related to CPUC-regulated operations, which represents the amount substantially equal to the aggregate amount it has paid or reserved for payment for the resolution of wildfire claims and related costs in excess of its liability insurance coverage and amounts recovered from third parties. SDG&E will increase the regulatory assets if the estimate of amounts to settle remaining claims increases. SDG&E will continue to assess the probability of recovery of these excess wildfire costs in rates. Should SDG&E conclude that recovery in rates is no longer probable, SDG&E will record a charge against earnings at the time such conclusion is reached. If SDG&E had concluded that the recovery of regulatory assets related to CPUC-regulated operations was no longer probable or was less than currently estimated at September 30, 2013, the resulting after-tax charge against earnings would have been up to $186 million. In addition, in periods following any such conclusion, SDG&E's earnings will be adversely impacted by increases in the estimated cost to litigate or settle pending wildfire claims. We provide additional information about excess wildfire claims cost recovery and related CPUC actions in Note 9 and discuss how we assess the probability of recovery of our regulatory assets in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. SDG&E's cash flow may be materially adversely affected due to the timing differences between the resolution of claims and the recoveries in rates, which may extend over a number of years. Also, recovery from customers will require future regulatory actions, and a failure to obtain substantial or full recovery, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy's and SDG&E's businesses, financial condition, cash flows, results of operations and prospects. SDG&E will continue to gather information to evaluate and assess the remaining wildfire claims and the likelihood, amount and timing of related recoveries in rates and will make appropriate adjustments to wildfire reserves and the related regulatory assets as additional information becomes available. Since 2010, as liabilities for wildfire litigation have become reasonably estimable in the form of settlement demands, damage estimates, and other damage information, SDG&E has recorded related reserves as a liability. The impact of this liability at September 30, 2013 is offset by the recognition of regulatory assets, as discussed above, for reserves in excess of the insurance coverage and recoveries from third parties. The impact of the change in the reserves on SDG&E's and Sempra Energy's after-tax earnings was an increase of $0.5 million and $0.8 million for the three months ended September 30, 2013 and 2012, respectively, and an increase of $0.2 million and a decrease of $4.1 million for the nine months ended September 30, 2013 and 2012, respectively. At September 30, 2013, wildfire litigation reserves were $164 million ($127 million current and $37 million long-term). Additionally, through September 30, 2013, SDG&E has expended $285 million (cumulative, excluding amounts covered by insurance and amounts recovered from third parties) to pay for the settlement of wildfire claims and related costs. Sunrise Powerlink Electric Transmission Line The Sunrise Powerlink is a 117-mile, 500-kV electric transmission line between the Imperial Valley and the San Diego region that was energized and placed in service in June 2012. The Sunrise Powerlink project was approved by the CPUC in December 2008, the BLM in January 2009, and the U.S. Forest Service (USFS) in July 2010. Numerous administrative appeals and legal challenges have been resolved in favor of the project. Three legal challenges are pending. In February 2010, project opponents filed a lawsuit in Federal District Court in San Diego alleging that the BLM failed to properly address the environmental impacts of the approved Sunrise Powerlink route and the related potential development of renewable resources in east San Diego County and Imperial County. In July 2012, the U.S. Court of Appeals for the Ninth Circuit affirmed the District Court's grant of the defendants' motion for summary judgment. In January 2011, project opponents filed a lawsuit in Federal District Court in San Diego alleging that the federal approvals for construction of the project on USFS land and BLM land violated the National Environmental Policy Act and other federal environmental laws. In June 2012, the U.S. Court of Appeals for the Ninth Circuit affirmed the District Court's denial of plaintiffs' motion for a preliminary injunction. In February 2011, opponents of the Sunrise Powerlink filed a lawsuit in Sacramento County Superior Court against the State Water Resources Control Board and SDG&E alleging that the water quality certification issued by the Board under the Federal Clean Water Act violated the California Environmental Quality Act. The Superior Court denied the plaintiffs' petition in July 2012, and the plaintiffs have appealed. A claim for additional compensation has been submitted by one of SDG&E's contractors on the Sunrise Powerlink project. The contractor was awarded the transmission line overhead and underground construction contract on a fixed-fee basis of $456 million after agreed-upon amendments. The contractor has asserted that it is owed additional compensation above the fixed-fee portion of the contract. In May 2013, the contractor filed two civil complaints, one in San Diego County and the other in Imperial County, seeking Foreclosure of Mechanics Liens previously filed in the sum of $99.2 million and $81.1 million, respectively. SDG&E has not been formally served with the complaints, although the parties had previously agreed to stay those proceedings. In October 2013, the contractor served a Demand for Arbitration pursuant to contractual provisions. At this time, based on the documentation submitted by the contractor and the terms of the fixed-fee agreement, SDG&E has concluded that the contractor has not supported its claim for additional compensation in the amount it has requested. September 2011 Power Outage In September 2011, a power outage lasting approximately 12 hours affected millions of people from Mexico to southern Orange County, California. Within several days of the outage, several SDG&E customers filed a class action lawsuit in Federal District Court in San Diego against Arizona Public Service Company, Pinnacle West, and SDG&E alleging that the companies failed to prevent the outage. The lawsuit seeks recovery of unspecified amounts of damages, including punitive damages. In July 2012, the court granted SDG&E's motion to dismiss the punitive damages request and dismissed Arizona Public Service Company and Pinnacle West from the lawsuit. In September 2013, the court granted SDG&E's motion for summary judgment and dismissed the lawsuit. In October 2013, the plaintiffs appealed the court's dismissal of their action. The FERC and North American Electric Reliability Corporation (NERC) conducted a joint inquiry to determine the cause of the power failure and issued a report in May 2012 regarding their findings. The report does not make any findings of failure on SDG&E's part that led to the power failure. However, this report is not dispositive on any potential liability of SDG&E related to the events of that power outage. More than 7,000 customers' claims, primarily related to food spoilage, have been submitted directly to SDG&E. Smart Meters Patent Infringement Lawsuit In October 2011, SDG&E was sued by a Texas design and manufacturing company in Federal District Court, Southern District of California, and later transferred to the Federal District Court, Western District of Oklahoma, alleging that SDG&E's recently installed smart meters infringed certain patents. The meters were purchased from a third party vendor that has agreed to defend and indemnify SDG&E. The lawsuit seeks injunctive relief and recovery of unspecified amounts of damages. Lawsuit Against Mitsubishi Heavy Industries, Ltd. On July 18, 2013, SDG&E filed a lawsuit in the Superior Court of California in the County of San Diego against Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsubishi Heavy Industries America, Inc. (collectively MHI). The lawsuit seeks to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators MHI provided to the SONGS nuclear power plant. The lawsuit asserts a number of causes of action, including fraud, based on the representations MHI made about its qualifications and ability to design generators free from defects of the kind that resulted in the permanent shutdown of the plant and further seeks to set aside the contractual limitation of damages that MHI has asserted. On July 24, 2013, MHI removed the lawsuit to the United States District Court for the Southern District of California, and on August 8, 2013, MHI moved to stay the proceeding pending resolution of the dispute resolution process involving MHI and Edison arising from their contract for the purchase and sale of the steam generators. On October 16, 2013, Edison initiated an arbitration proceeding against MHI seeking damages stemming from the failure of the replacement steam generators. SoCalGas SoCalGas, along with Monsanto Co., Solutia, Inc., Pharmacia Corp., and Pfizer, Inc., are defendants in seven Los Angeles County Superior Court lawsuits filed beginning in April 2011 seeking recovery of unspecified amounts of damages, including punitive damages, as a result of plaintiffs' exposure to PCBs (polychlorinated biphenyls). The lawsuits allege plaintiffs were exposed to PCBs not only through the food chain and other various sources but from PCB-contaminated natural gas pipelines owned and operated by SoCalGas. This contamination allegedly caused plaintiffs to develop cancer and other serious illnesses. Plaintiffs assert various bases for recovery, including negligence and products liability. SoCalGas has settled two of the seven lawsuits for an amount that is not significant and has been recorded. Sempra Mexico Permit Challenges and Property Disputes Sempra Mexico has been engaged in a long-running land dispute relating to property adjacent to its Energía Costa Azul LNG terminal near Ensenada, Mexico. The adjacent property is not required by environmental or other regulatory permits for the operation of the terminal. A claimant to the adjacent property has nonetheless asserted that his health and safety are endangered by the operation of the facility. In February 2011, based on a complaint by the claimant, the then new Ensenada Mayor attempted to temporarily close the terminal based on claims of irregularities in municipal permits issued six years earlier. This attempt was promptly countermanded by Mexican federal and Baja California state authorities. No terminal permits or operations were affected as a result of these proceedings or events and the terminal has continued to operate normally. Sempra Mexico expects additional Mexican court proceedings and governmental actions regarding the claimant's assertions as to whether the terminal's permits should be modified or revoked in any manner. The property claimant also filed a lawsuit in July 2010 against Sempra Energy in Federal District Court in San Diego seeking compensatory and punitive damages as well as the earnings from the Energía Costa Azul LNG terminal based on his allegations that he was wrongfully evicted from the adjacent property and that he has been harmed by other allegedly improper actions. Additionally, several administrative challenges are pending in Mexico before the Mexican environmental protection agency (SEMARNAT) and/or the Federal Tax and Administrative Courts seeking revocation of the environmental impact authorization (EIA) issued to Energía Costa Azul in 2003. These cases generally allege that the conditions and mitigation measures in the EIA are inadequate and challenge findings that the activities of the terminal are consistent with regional development guidelines. A similar administrative challenge seeking to revoke the port concession for our marine operations at our Energía Costa Azul LNG terminal, which was filed with and rejected by the Mexican Communications and Transportation Ministry, remains on appeal in Mexican federal court as well. Also, there are two real property cases pending against Energía Costa Azul in which the plaintiffs seek to annul the recorded property titles for parcels on which the Energía Costa Azul LNG terminal is situated and to obtain possession of different parcels that allegedly sit in the same place; one of these cases was dismissed in September 2013 at the direction of the state appellate court. A third complaint was served in April 2013 seeking to invalidate the contract by which Energía Costa Azul, S. de R.L. de C.V. purchased another of the terminal parcels, on the grounds the purchase price was unfair. Sempra Mexico expects further proceedings on each of these matters, except for the real property case that was dismissed. In July 2012, a Mexicali state court issued a ruling declaring the purchase contract by which Termoeléctrica de Mexicali (TDM) acquired the property on which the facility is located to be invalid, on the grounds that the proceeding in which the seller acquired title was invalid. In June 2013, an appellate court overturned the lower court ruling, and the case was subsequently dismissed. Competitor Claims (Dismissed) In October 2012, a competitor for one of the two contracts awarded by the Mexican Federal Electricity Commission (Comisión Federal de Electricidad, or CFE) for the construction and operation of a natural gas pipeline in Sonora filed an amparo in the Mexican federal district court in Mexico City, challenging the tender process and the award to us. The competitor, a subsidiary of Fermaca, Sásabe Pipeline, S. de R.L. de C.V., filed suit against 11 different governmental authorities, including the CFE, the President of Mexico, and the Mexican Energy Ministry. Sásabe Pipeline, which was the second-place bidder, alleges CFE discriminated against it in the bidding process, including by failing to accept its comments on the bid guidelines. In February 2013, we were notified that Guaymas Pipeline S. de R. L. de C.V., another subsidiary of Fermaca, filed another, similar amparo challenging the process by which the second of the two contracts was awarded, although it did not submit a bid for the project. Both cases were dismissed in April 2013. Sempra Natural Gas Liberty Gas Storage, LLC (Liberty) received a demand for arbitration from Williams Midstream Natural Gas Liquids, Inc. (Williams) in February 2011 related to a sublease agreement. Williams alleges that Liberty was negligent in its attempt to convert certain salt caverns to natural gas storage and seeks damages of $56.7 million. Liberty filed a counterclaim alleging breach of contract in the inducement and seeks damages of more than $215 million. Other Litigation As described in Note 4, we hold a noncontrolling interest in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. In March 2012, RBS received a letter from the United Kingdom's Revenue and Customs Department (HMRC) regarding a value-added-tax (VAT) matter related to RBS Sempra Energy Europe (RBS SEE), a former indirect subsidiary of RBS Sempra Commodities that was sold to JP Morgan. The letter states that HMRC is conducting a number of investigations into VAT tax refund claims made by various businesses related to the purchase and sale of carbon credit allowances. The letter also states that HMRC believes it has grounds to deny RBS the ability to reduce its VAT liability by VAT paid during 2009 because it knew or should have known that certain vendors in the trading chain did not remit their own VAT to HMRC. In September 2012, HMRC issued an assessment of £86 million for the VAT paid in connection with these transactions and identified several options for responding, including requesting a review by HMRC and appealing to an independent tribunal. HMRC indicated that the assessment was issued on a protective basis as discussion about the issues is continuing. In August 2007, the U.S. Court of Appeals for the Ninth Circuit issued a decision reversing and remanding certain FERC orders declining to provide refunds regarding short-term bilateral sales up to one month in the Pacific Northwest for the January 2000 to June 2001 time period. In December 2010, the FERC approved a comprehensive settlement previously reached by Sempra Energy and RBS Sempra Commodities with the State of California. The settlement resolves all issues with regard to sales between the California Department of Water Resources (DWR) and Sempra Commodities in the Pacific Northwest, but potential claims may exist regarding sales in the Pacific Northwest between Sempra Commodities and other parties. The FERC is in the process of addressing these potential claims on remand. Pursuant to the agreements related to the formation of RBS Sempra Commodities, we have indemnified RBS should the liability from the final resolution of these matters be greater than the reserves related to Sempra Commodities. Pursuant to our agreement with the Noble Group Ltd., one of the buyers of RBS Sempra Commodities' businesses, we have also indemnified Noble Americas Gas & Power Corp. and its affiliates for all losses incurred by such parties resulting from these proceedings as related to Sempra Commodities. We are also defendants in ordinary routine litigation incidental to our businesses, including personal injury, product liability, property damage and other claims. California juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases. NUCLEAR INSURANCE SDG&E and the two other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. This insurance provides $375 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides for up to $13.2 billion of secondary financial protection (SFP). If a nuclear liability loss occurring at any U.S. licensed/commercial reactor exceeds the $375 million insurance limit, all nuclear reactor owners could be required to contribute to the SFP. SDG&E's contribution would be up to $50.93 million. This amount is subject to an annual maximum of $7.6 million, unless a default occurs by any other SONGS owner. If the SFP is insufficient to cover the liability loss, SDG&E could be subject to an additional assessment. The SONGS owners, including SDG&E, also have $2.75 billion of nuclear property, decontamination, and debris removal insurance, subject to a $2.5 million deductible for “each and every loss.” In addition, the SONGS owners have insurance coverage for outage expenses and replacement power costs due to accidental property damage. These insurance coverages are provided through Nuclear Electric Insurance Limited (NEIL), a mutual insurance company. The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated coverage. Insured members are subject to retrospective premium assessments. SDG&E could be assessed up to $9.7 million. Edison, on behalf of itself and the minority owners of SONGS (including SDG&E), has placed NEIL on notice of claims under both the property damage and outage insurance policies as a result of SONGS' Units 2 and 3 being shut down since early 2012. The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act). The industry aggregate loss limit for property claims arising from non-certified acts of terrorism is $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts. We provide additional information about SONGS in Note 9. CONTRACTUAL COMMITMENTS We discuss below significant changes in the first nine months of 2013 to contractual commitments discussed in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report. Natural Gas Contracts SoCalGas' natural gas purchase and pipeline capacity commitments have increased by $156 million since December 31, 2012. The increase, primarily due to new natural gas purchase and pipeline capacity contracts in the first nine months of 2013 of $710 million, is partially offset by a decrease of $554 million from fulfillment of commitments. Net future payments are expected to decrease by $357 million in 2013 and to increase by $245 million in 2014, $41 million in 2015, $67 million in 2016, $70 million in 2017 and $90 million thereafter compared to December 31, 2012. Sempra Natural Gas' natural gas purchase and storage capacity commitments have increased by $22 million since December 31, 2012, primarily due to additional storage capacity under existing contracts in the first nine months of 2013. Net future payments are expected to decrease by $36 million in 2013, and increase by $10 million in 2014, $7 million in 2015, $7 million in 2016, $7 million in 2017 and $27 million thereafter compared to December 31, 2012. Sempra Rockies Marketing, a subsidiary of Sempra Natural Gas, has an agreement for capacity on the Rockies Express Pipeline through November 2019, as we discuss in Note 4. Historically, the capacity costs have been more than offset by revenues from releases of the capacity. However, certain capacity release commitments will conclude during 2013 and new contracting activity related to that capacity may not be sufficient to offset all of our capacity commitments. Including capacity released to others, Sempra Rockies Marketing's obligation to Rockies Express Pipeline LLC for future capacity payments are expected to be $3 million in 2013, $14 million each year in 2014 through 2017 and $83 million thereafter. LNG Purchase Agreements At September 30, 2013, Sempra Natural Gas has various purchase agreements with major international companies for the supply of LNG to the Energía Costa Azul and Cameron terminals. We discuss these agreements further in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report. Sempra Natural Gas' commitments under all LNG purchase agreements, reflecting changes in forward prices since December 31, 2012 and actual transactions for the first nine months of 2013, are expected to decrease by $424 million in 2013, $37 million in 2014, $42 million in 2015, $59 million in 2016, $66 million in 2017 and $731 million thereafter compared to December 31, 2012. The LNG commitment amounts above are based on Sempra Natural Gas' commitment to accept the maximum possible delivery of cargoes under the agreements. Actual LNG purchases for the nine months ended September 30, 2013 have been significantly lower than the maximum amounts possible. Purchased-Power Contracts SDG&E's commitments under purchased-power contract commitments have increased by $3.1 billion since December 31, 2012. The increase is primarily due to new contracts associated with renewable energy development projects. Net future payments are therefore expected to decrease by $1 million in 2013 and increase by $77 million in 2014, $140 million in 2015, $141 million in 2016, $141 million in 2017 and $2.6 billion thereafter compared to December 31, 2012. Operating Leases SDG&E occupies a six-building office complex in San Diego pursuant to two separate operating leases. In 2013, SDG&E amended these lease agreements to extend their expiration from 2017 to 2024. One lease has four five-year renewal options and the other lease has three five-year renewal options, now exercisable beginning in 2024. Significant net changes to future payments on all noncancelable operating leases at SDG&E, including the San Diego office complex, are a decrease of $18 million in 2013 and increases of $3 million each year in 2014 through 2016, $1 million in 2017, and $84 million thereafter compared to December 31, 2012.
Sempra Renewables entered into a land lease in 2013 for the Copper Mountain Solar 3 project, which lease expires in 2050. Future payments on the lease are $2 million each year in 2014 through 2017 and $76 million thereafter. Headquarters Lease In August 2013, Sempra Energy entered into a 25-year, build-to-suit lease for its future San Diego, California, headquarters. We expect to occupy the building in the second half of 2015. Future payments on the lease will be $4 million in 2015, $10 million in 2016, $10 million in 2017 and $287 million thereafter. Construction and Development Projects In the first nine months of 2013, significant net increases to contractual commitments at SoCalGas were $372 million primarily for the Pipeline Safety Enhancement Program. Net future payments under these contractual commitments are expected to increase by $91 million in 2013, $71 million in 2014, and $70 million each year in 2015 through 2017 compared to December 31, 2012. In the first nine months of 2013, significant net increases to contractual commitments at Sempra Mexico were $197 million for contracts related to the construction of an approximately 500-mile natural gas transport pipeline network and $215 million for the Energía Sierra Juárez wind project. Net future payments under these contractual commitments are expected to increase by $12 million in 2013, $219 million in 2014, $179 million in 2015 and $2 million in 2016 compared to December 31, 2012. In the first nine months of 2013, significant net increases to contractual commitments at Sempra Renewables were $515 million for the construction of Copper Mountain Solar 3 facilities and $82 million for the construction of Broken Bow 2 facilities. The future payments under these contractual commitments are expected to be $106 million in 2013, $453 million in 2014, and $38 million in 2015. Guarantees In the first nine months of 2013, Sempra Renewables provided additional guarantees to certain solar and wind farm joint ventures aggregating a maximum of $250 million with an associated aggregated carrying value of $11 million for debt service and operation of the solar and wind farms, as we discuss in Note 6. Other In February 2013, Sempra Natural Gas entered into a long-term operations and maintenance agreement for its remaining block of the Mesquite Power natural gas-fired power plant, which expires in 2033. The total cost associated with this agreement is estimated to be approximately $36 million. The future payments for this contractual commitment are expected to be $1 million in 2013, $2 million each year in 2014 through 2017 and $27 million thereafter. We provide additional information about Mesquite Power in Note 3. |
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- References No definition available.
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- Definition The entire disclosure for commitments and contingencies. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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SEGMENT INFORMATION |
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Notes to Consolidated Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Segment Information | NOTE 11. SEGMENT INFORMATION We have six separately managed reportable segments, as follows:
Sempra South American Utilities and Sempra Mexico comprise our Sempra International operating unit. Sempra Renewables and Sempra Natural Gas comprise our Sempra U.S. Gas & Power operating unit. We evaluate each segment's performance based on its contribution to Sempra Energy's reported earnings. The California Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC. The California Utilities' operations are based on rates set by the CPUC and the FERC. We describe the accounting policies of all of our segments in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. During the fourth quarter of 2012, Sempra Mexico initiated a public debt offering process through one of its subsidiaries. We discuss this debt issuance, which occurred on February 14, 2013, in Note 6. The subsidiary issuing the debt, now IEnova, was previously included in Parent and Other. In anticipation of the debt issuance, we revised the manner in which we make resource allocation decisions to our Sempra Mexico segment and assess its performance. As a result, we reclassified certain amounts from Parent and Other, which contains interest and other corporate costs and certain holding company activities, to our Sempra Mexico segment. Losses reclassified as a result of the restatement were $12 million for both the three months and nine months ended September 30, 2012. In accordance with U.S. GAAP, the historical segment disclosures have been restated to be consistent with the current presentation. The following tables show selected information by segment from our Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets. Amounts labeled as “All other” in the following tables consist primarily of parent organizations.
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- References No definition available.
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- Definition The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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SIGNIFICANT ACCOUNTING POLICIES (Policies) |
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Significant Accounting Policies | |
New Accounting Standards Policy [Text Block] | NOTE 2. NEW ACCOUNTING STANDARDS We describe below recent pronouncements that have had or may have a significant effect on our financial statements. We do not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to our financial condition, results of operations, cash flows or disclosures. SEMPRA ENERGY, SDG&E AND SOCALGAS Accounting Standards Update (ASU) 2011-11, “Disclosures about Offsetting Assets and Liabilities” (ASU 2011-11) and ASU 2013-01, “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities” (ASU 2013-01): In order to allow for balance sheet comparison between U.S. GAAP and International Financial Reporting Standards (IFRS), ASU 2011-11 requires enhanced disclosures related to financial assets and liabilities eligible for offsetting in the statement of financial position. An entity must disclose both gross and net information about financial instruments and transactions subject to a master netting arrangement and eligible for offset, including cash collateral received and posted. ASU 2013-01 clarifies that the scope of ASU 2011-11 applies to derivatives, including bifurcated embedded derivatives, repurchase agreements and reverse repurchase agreements, and securities borrowing and securities lending transactions. We adopted ASU 2011-11 and ASU 2013-01 on January 1, 2013 as required and it did not affect our financial condition, results of operations or cash flows. We provide the additional disclosure in Note 7. ASU 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income” (ASU 2013-02): ASU 2013-02 requires an entity to present, either on the face of the statement of operations or in the notes to financial statements, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. We adopted ASU 2013-02 on January 1, 2013 as required and it did not affect our financial condition, results of operations or cash flows. We provide the additional disclosure in Note 5. ASU 2013-04, “Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date” (ASU 2013-04): ASU 2013-04 provides guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of the ASU is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. GAAP. The guidance requires an entity to measure those obligations as the sum of the amount the reporting entity agreed to pay on the basis of its arrangement among its co-obligors and any additional amount the reporting entity expects to pay on behalf of its co-obligors. The guidance in the ASU also requires an entity to disclose the nature and amount of the obligation as well as other information about those obligations. We will adopt ASU 2013-04 on January 1, 2014 as required and do not expect it to affect our financial condition, results of operations or cash flows. We will provide the additional disclosure in our 2014 interim financial statements. ASU 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists” (ASU 2013-11): ASU 2013-11 provides explicit guidance on the financial statement presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. ASU 2013-11 requires an entity to present an unrecognized tax benefit, or a portion of an unrecognized tax benefit, as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward. If a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position or the tax law of the applicable jurisdiction does not require the entity to use, and the entity does not intend to use, the deferred tax asset for such purposes, an entity is required to present the unrecognized tax benefit in the financial statements as a liability instead of combined with deferred tax assets. We will adopt ASU 2013-11 on January 1, 2014 as required and do not expect it to significantly affect our financial condition, results of operations or cash flows.
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Consolidation Variable Interest Entity Policy | VARIABLE INTEREST ENTITIES (VIE) We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based upon qualitative and quantitative analyses, which assess
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Earnings Per Share Policy Text Block | EARNINGS PER SHARE The following table provides the per share computations for our earnings for the three months and nine months ended September 30, 2013 and 2012. Basic earnings per common share (EPS) is calculated by dividing earnings attributable to common shares by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. The dilution from common stock options is based on the treasury stock method. Under this method, proceeds based on the exercise price plus unearned compensation and windfall tax benefits recognized, minus tax shortfalls recognized, are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits are tax deductions we would receive upon the assumed exercise of stock options in excess of the deferred income taxes we recorded related to the compensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options). The dilution from unvested restricted stock awards (RSAs) and restricted stock units (RSUs) is also based on the treasury stock method. |
Derivatives Policy Text Block | We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk and benchmark interest rate risk. We may also manage foreign exchange rate exposures using derivatives. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines in anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not presented below. We record all derivatives at fair value on the Condensed Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) undesignated. Depending on the applicability of hedge accounting and, for the California Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Condensed Consolidated Statements of Cash Flows. In certain cases, we apply the normal purchase or sale exception to derivative accounting and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk that a given future revenue or expense item may vary, and other criteria. We may designate an interest rate derivative as a fair value hedging instrument if it effectively converts our own debt from a fixed interest rate to a variable rate. The combination of the derivative and debt instruments results in fixing that portion of the fair value of the debt that is related to benchmark interest rates. Designating fair value hedges is dependent on the instrument being used, the effectiveness of the instrument in offsetting changes in the fair value of our debt instruments, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We utilize interest rate swaps typically designated as fair value hedges, as a means to achieve our targeted level of variable rate debt as a percent of total debt. In addition, we may utilize interest rate swaps, which are typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings. Interest rate derivatives are utilized by the California Utilities as well as by other Sempra Energy subsidiaries. Although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate derivatives may not be recovered from customers as timely as described above with regard to natural gas derivatives. Accordingly, interest rate derivatives are generally accounted for as hedges at the California Utilities, as well as at the rest of Sempra Energy's subsidiaries. Separately, Otay Mesa VIE has entered into interest rate swap agreements to moderate its exposure to interest rate changes. This activity was designated as a cash flow hedge as of April 1, 2011 FOREIGN CURRENCY DERIVATIVES We are exposed to exchange rate movements at our Mexican subsidiaries, which have U.S. dollar denominated cash balances, receivables and payables (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. These subsidiaries also have deferred income tax assets and liabilities that are denominated in the Mexican peso, which must be translated into U.S. dollars for financial reporting purposes. From time to time, we may utilize short-term foreign currency derivatives at our subsidiaries and at the consolidated level as a means to manage the risk of exposure to significant fluctuations in our income tax expense from these impacts. We may also utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries. |
Legal Costs Policy Text Block | LEGAL PROCEEDINGS We accrue losses for legal proceedings when it is probable that a loss has been incurred and the amounts of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverage and could materially adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued. At September 30, 2013, Sempra Energy's accrued liabilities for material legal proceedings, on a consolidated basis, were $177 million. At September 30, 2013, accrued liabilities for material legal proceedings for SDG&E and SoCalGas were $164 million and $5 million, respectively. At September 30, 2013, accrued liabilities of $164 million at Sempra Energy and SDG&E were related to wildfire litigation discussed below. |
Noncontrolling Interest Policy [Text Block] | Ownership interests that are held by owners other than Sempra Energy and SDG&E in subsidiaries or entities consolidated by them are accounted for and reported as noncontrolling interests. As a result, noncontrolling interests are reported as a separate component of equity on the Condensed Consolidated Balance Sheets. Earnings or losses attributable to noncontrolling interests are separately identified on the Condensed Consolidated Statements of Operations, and comprehensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income.
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- Definition Disclosure of accounting policy for new accounting standards. No definition available.
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- Definition Disclosure of accounting policy for noncontrolling interests. No definition available.
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- Definition Disclosure of accounting policy for consolidation to describe the significant judgments and assumptions made in determining whether a variable interest held by the entity requires the variable interest entity to be consolidated and (or) disclose information about its involvement with the variable interest entity; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; and the significant factors considered and judgments made in determining that the power to direct the activities that significantly impact the economic performance of the variable interest entity are shared (as defined). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Disclosure of accounting policy for its derivative instruments and hedging activities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Disclosure of accounting policy for computing basic and diluted earnings or loss per share for each class of common stock and participating security. Addresses all significant policy factors, including any antidilutive items that have been excluded from the computation and takes into account stock dividends, splits and reverse splits that occur after the balance sheet date of the latest reporting period but before the issuance of the financial statements. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Disclosure of accounting policy for legal costs incurred to protect or defend the entity's assets and rights, or to obtain assets, including monetary damages, or to obtain rights. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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RECENT INVESTMENT ACTIVITY (Tables) |
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Schedule of Business Deconsolidation Table |
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OTHER FINANCIAL DATA (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Financial Data (Tables) [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Net Periodic Benefit Cost Table |
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Contributions to Benefit Plans Table |
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Earnings Per Share Computations Table |
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Total Shareholder Return Ranking Table |
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Capitalized Financing Costs Table |
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Changes in Components of Accumulated Comprehensive Income Table |
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Reclassifications out of AOCI Table |
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Income Tax Expense (Benefit) Associated with Other Comprehensive Income Table |
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Shareholders' Equity and Noncontrolling Interests Table |
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Amounts Due To and From Affiliates at SDG&E and SoCalGas Table |
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Revenues From Unconsolidated Affiliates at SDG&E and SoCalGas Table |
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Other Income and Expense Table |
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Income Tax Expense and Effective Income Tax Rates Table |
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Variable Interest Entity Table |
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Ownership Interests Held By Others Table |
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Inventory Table |
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Asset Retirement Obligations Table |
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X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition Tabular disclosure of capitalized financing costs. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of asset retirement obligations. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of comprehensive income. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of contributions to benefit plans. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of due to and from affiliates. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of income tax expense and effective income tax rate. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of reclassification out of AOCI. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of revenues from affiliates. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of shareholders and noncontrolling interests. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of tax expense benefit on comprehensive income. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of total shareholder return. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of an entity's basic and diluted earnings per share calculations. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of the carrying amount as of the balance sheet date of merchandise, goods, commodities, or supplies held for future sale or to be used in manufacturing, servicing or production process. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Tabular disclosure of the components of net benefit costs for pension plans and/or other employee benefit plans including service cost, interest cost, expected return on plan assets, gain (loss), prior service cost or credit, transition asset or obligation, and gain (loss) recognized due to settlements or curtailments. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Tabular disclosure of the components of non-operating income or non-operating expense that may include amounts earned from dividends, interest on securities, gains (losses) on securities sold, equity earnings of unconsolidated affiliates, net gain (loss) on sales of business, interest expense and other miscellaneous income or expense items. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of other units or shares or classes of ownership in a partnership. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Tabular disclosure of the significant judgments and assumptions made in determining whether a variable interest (as defined) held by the entity requires the variable interest entity (VIE) (as defined) to be consolidated and (or) disclose information about its involvement with the VIE, individually or in aggregate (as applicable); the nature of restrictions, if any, on the consolidated VIE's assets and on the settlement of its liabilities reported by an entity in its statement of financial position, including the carrying amounts of such assets and liabilities; the nature of, and changes in, the risks associated with involvement in the VIE; how involvement with the VIE affects the entity's financial position, financial performance, and cash flows; the lack of recourse if creditors (or beneficial interest holders) of the consolidated VIE have no recourse to the general credit of the primary beneficiary (if applicable); the terms of arrangements, giving consideration to both explicit arrangements and implicit variable interests, if any, that could require the entity to provide financial support to the VIE, including events or circumstances that could expose the entity to a loss; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; the significant factors considered and judgments made in determining that the power to direct the activities of a VIE that most significantly impact the VIE's economic performance are shared (as defined); the carrying amounts and classification of assets and liabilities of the VIE included in the statement of financial position; the entity's maximum exposure to loss, if any, as a result of its involvement with the VIE, including how the maximum exposure is determined and significant sources of the entity's exposure to the VIE; a comparison of the carrying amounts of the assets and liabilities and the entity's maximum exposure to loss; information about any liquidity arrangements, guarantees, and (or) other commitments by third parties that may affect the fair value or risk of the entity's variable interest in the VIE; whether or not the entity has provided financial support or other support (explicitly or implicitly) to the VIE that it was not previously contractually required to provide or whether the entity intends to provide that support, including the type and amount of the support and the primary reasons for providing the support; and supplemental information the entity determines necessary to provide. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DERIVATIVE FINANCIAL INSTRUMENTS (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2013 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Financial Instruments (Tables) [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Commodity Derivative Volumes Table |
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Notional Amounts of Interest Rate Derivatives Table |
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Derivative Instruments on the Condensed Consolidated Balance Sheets Table |
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Fair Value Hedge Impact on the Condensed Consolidated Statements of Operations Table |
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Cash Flow Hedge Impact on the Condensed Consolidated Statements of Operations Table |
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Undesignated Derivative Impact on the Condensed Consolidated Statements of Operations Table |
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X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition Tabular disclosure of cash flow hedges impact on statement of operations. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of commodity derivative volumes. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of notional amounts of interest rate derivatives. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of undesignated derivative instruments impact on statement of operations. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of the location and amount of gains and losses reported in the statement of financial performance, or when applicable, the statement of financial position. For example, (a) gains and losses recognized in the income statement on derivative instruments designated and qualifying as hedging instruments in fair value hedges and related hedged items designated and qualifying in fair value hedges and (b) gains and losses initially recognized in other comprehensive income on derivative instruments designated and qualifying as cash flow hedges. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Tabular disclosure of the location and fair value amounts of derivative instruments (and nonderivative instruments that are designated and qualify as hedging instruments) reported in the statement of financial position. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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FAIR VALUE MEASUREMENTS (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2013 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Measurements (Tables) [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value of Financial Instruments Table |
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Nuclear Decommissioning Trusts Table |
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Sales of Securities Table |
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Recurring Fair Value Measures Table |
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Recurring Fair Value Measures Level 3 Rollforward Table |
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X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition Tabular disclosure of Nuclear Decommissioning trusts. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of fair value of financial instruments. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of recurring fair value assets and liabilties. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of recurring fair value assets and liabilties unobservable inputs reconciliation. No definition available.
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X | ||||||||||
- Definition Tabular disclosure of sales of securities from Nuclear Decommissioning trusts. No definition available.
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SEGMENT INFORMATION (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Segment Information (Tables) [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Segment Information Table |
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X | ||||||||||
- References No definition available.
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X | ||||||||||
- Definition Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
RECENT INVESTMENT ACTIVITY (DETAILS) - USD ($) $ in Millions |
1 Months Ended | 9 Months Ended | |
---|---|---|---|
Feb. 28, 2013 |
Sep. 30, 2012 |
May 20, 2012 |
|
Property, plant and equipment | |||
Proceeds from sale of Mesquite Power plant | $ 371 | ||
Gain on sale of Mesquite Power plant | 74 | ||
Gain on sale of Mesquite Power plant, after tax | $ 44 | ||
Willmut Gas [Member] | |||
Property, plant and equipment | |||
Total liabilities | $ (10) | ||
Pro forma revenues | $ 7 | ||
Cash consideration (fair value of total consideration) | $ 19 | ||
Acquired percentage interest in joint venture | 100.00% |
X | ||||||||||
- Definition The amount of total liabilities recognized as of the acquisition date. No definition available.
|
X | ||||||||||
- Definition Gain on sale of Mesquite Power plant, after tax. No definition available.
|
X | ||||||||||
- Definition Amount of cash paid to acquire the entity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Percentage of voting equity interests acquired in the business combination. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The pro forma revenue for a period as if the business combination or combinations had been completed at the beginning of the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The difference between the sale price or salvage price and the book value of a property, plant, and equipment asset that was sold or retired during the reporting period. This element refers to the gain (loss). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The cash inflow from the sale of long-lived, physical assets that are used in the normal conduct of business to produce goods and services and not intended for resale. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Details
|
RECENT INVESTMENT ACTIVITY 2 (DETAILS) $ in Millions |
3 Months Ended | |||
---|---|---|---|---|
Sep. 30, 2013
USD ($)
| ||||
Mesquite Solar 1 [Member] | ||||
Deconsolidation of business [Line Items] | ||||
Proceeds from sale, net of transaction costs | $ 100 | [1] | ||
Other assets | (72) | |||
Property, plant and equipment, net | (461) | |||
Long-term debt including current portion | 297 | |||
Other liabilities | 31 | |||
Gain on sale of assets | (36) | |||
Equity method investments upon deconsolidation | (141) | |||
Transaction costs | $ 3 | |||
Ownership percentage in equity method investee | 50.00% | |||
Gain on sale of assets, after tax | $ 22 | |||
Proceeds From Divestiture Of Businesses | 103 | |||
Copper Mountain Solar 2 [Member] | ||||
Deconsolidation of business [Line Items] | ||||
Proceeds from sale, net of transaction costs | 68 | [1] | ||
Other assets | (30) | |||
Property, plant and equipment, net | (266) | |||
Long-term debt including current portion | 146 | |||
Other liabilities | 19 | |||
Gain on sale of assets | (4) | |||
Equity method investments upon deconsolidation | (67) | |||
Transaction costs | $ 3 | |||
Ownership percentage in equity method investee | 50.00% | |||
Gain on sale of assets, after tax | $ 2 | |||
Proceeds From Divestiture Of Businesses | $ 71 | |||
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Deconsolidation business line items. No definition available.
|
X | ||||||||||
- Definition Equity method investments recorded upon deconsolidation. No definition available.
|
X | ||||||||||
- Definition Reduction in Long Term Debt Including Current Portion due to deconsolidation. No definition available.
|
X | ||||||||||
- Definition Reduction in other assets due to deconsolidation. No definition available.
|
X | ||||||||||
- Definition Reduction in other liabilities due to deconsolidation. No definition available.
|
X | ||||||||||
- Definition Proceeds from sale of assets, net of transactions costs No definition available.
|
X | ||||||||||
- Definition Reduction in Property Plant And Equipment due to deconsolidation. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The amount of the gain (loss) recognized by the parent and included in its attributable portion of net income for the period due to deconsolidation of a subsidiary or derecognition of a group of assets. The gain (loss) recognized and included in the net income attributable to the parent for the period is generally computed as the difference between: (a) the aggregate of: (1) the fair value of any consideration received; (2) the fair value of any retained noncontrolling investment in the former subsidiary at the date the subsidiary was deconsolidated; and (3) the carrying amount of any noncontrolling interest in the former subsidiary (including any accumulated other comprehensive income attributable to the noncontrolling interest) at the date the subsidiary was deconsolidated and (b) the carrying amount of the former subsidiary's assets and liabilities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The percentage of ownership of common stock or equity participation in the investee accounted for under the equity method of accounting. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The cash inflow associated with the amount received from the sale of a portion of the company's business, for example a segment, division, branch or other business, during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Details
|
X | ||||||||||
- Details
|
INVESTMENTS IN UNCONSOLIDATED ENTITIES (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||
---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Jun. 30, 2013 |
Mar. 31, 2013 |
Sep. 30, 2012 |
Jun. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Investment In Joint Venture Disclosure [Abstract] | |||||||
Distributions from RBS Sempra Commodities LLP | $ 50 | ||||||
Investment in RBS Sempra Commodities LLP | $ 76 | $ 76 | |||||
Loss on impairment of investment in Rockies Express | $ 100 | ||||||
Loss on impairment of investment in Rockies Express, after tax | 60 | ||||||
Schedule of Equity Method Investments [Line Items] | |||||||
Sempra Renewables' Equity Method Investments In Joint Ventures | 5 | 296 | 5 | $ 296 | |||
Equity Method Investment, Cumulative Foreign Currency Translation Adjustments | 270 | 270 | |||||
Equity earnings, net of income tax | 8 | $ 10 | 13 | $ 29 | |||
Pretax loss on sale of Argentina | (7) | ||||||
Aftertax loss on sale of Argentina | (4) | ||||||
Proceeds from sale of Argentina | $ 13 | ||||||
Accrued Liabilities, Argentina | $ 250 | $ 250 | |||||
Rockies Express [Member] | |||||||
Schedule of Equity Method Investments [Line Items] | |||||||
Ownership percentage in equity method investee | 25.00% | 25.00% | |||||
Ownership percentage of minority partner in equity method investee | 25.00% | 25.00% | |||||
Ownership percentage of operating partner in equity method investee | 50.00% | 50.00% | |||||
Equity Method Investment, Other than Temporary Impairment | $ 300 | ||||||
Equity Method Investment Other Than Temporary Impairment After Tax | $ 179 | ||||||
Equity Method Investment, Remaining Carrying Value | $ 330 | $ 330 | |||||
Sodigas [Member] | |||||||
Schedule of Equity Method Investments [Line Items] | |||||||
Ownership percentage in equity method investee | 43.00% | 43.00% | |||||
Equity Method Investment, Other than Temporary Impairment | $ 10 | ||||||
Equity Method Investment Other Than Temporary Impairment After Tax | $ 7 | ||||||
Eletrans [Member] | |||||||
Schedule of Equity Method Investments [Line Items] | |||||||
Ownership percentage in equity method investee | 50.00% | 50.00% | |||||
Equity earnings, net of income tax | $ 0 | $ (3) |
X | ||||||||||
- Definition Distributions from RBS Sempra Commodities LLP No definition available.
|
X | ||||||||||
- Definition Equity method investment, cumulative foreign currency translation adjustments No definition available.
|
X | ||||||||||
- Definition Equity method investment other than temporary impairment, after tax. No definition available.
|
X | ||||||||||
- Definition Ownership percentage of minority partner in equity method investee. No definition available.
|
X | ||||||||||
- Definition Ownership percentage of operating partner in equity method investee. No definition available.
|
X | ||||||||||
- Definition Aftertax loss on sale of Argentina. No definition available.
|
X | ||||||||||
- Definition Equity method investment, remaining carrying value. No definition available.
|
X | ||||||||||
- Definition Equity earnings, net of income tax. No definition available.
|
X | ||||||||||
- Definition Investment in RBS Sempra Commodities LLP. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Loss on impairment of investment in Rockies Express. No definition available.
|
X | ||||||||||
- Definition Loss on impairment of investment in Rockies Express, after tax. No definition available.
|
X | ||||||||||
- Definition Carrying value as of the balance sheet date of obligations incurred and payable, pertaining to costs that are statutory in nature, are incurred on contractual obligations, or accumulate over time and for which invoices have not yet been received or will not be rendered. Examples include taxes, interest, rent and utilities. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition This item represents an other than temporary decline in value that has been recognized against an investment accounted for under the equity method of accounting. The excess of the carrying amount over the fair value of the investment represents the amount of the write down which is or was reflected in earnings. The written down value is a new cost basis with the adjusted value of the investment becoming its new carrying value subject to the equity accounting method. Evidence of a loss in value might include, but would not necessarily be limited to, absence of an ability to recover the carrying amount of the investment or inability of the investee to sustain an earnings capacity which would justify the carrying amount of the investment. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The percentage of ownership of common stock or equity participation in the investee accounted for under the equity method of accounting. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition This item represents the amount of gain (loss) arising from the disposal of an equity method investment. No definition available.
|
X | ||||||||||
- Definition This item represents the carrying amount on the entity's balance sheet of its investment in common stock of an equity method investee. This is not an indicator of the fair value of the investment, rather it is the initial cost adjusted for the entity's share of earnings and losses of the investee, adjusted for any distributions (dividends) and other than temporary impairment (OTTI) losses recognized. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The cash inflow associated with the sale of equity method investments, which are investments in joint ventures and entities in which the entity has an equity ownership interest normally of 20 to 50 percent and exercises significant influence. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
|
X | ||||||||||
- Details
|
X | ||||||||||
- Details
|
X | ||||||||||
- Details
|
OTHER FINANCIAL DATA - U.S. TREASURY GRANTS RECEIVABLE (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||||
---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Jun. 30, 2013 |
Mar. 31, 2013 |
Sep. 30, 2013 |
Sep. 30, 2012 |
Dec. 31, 2012 |
[1] | |||
U.S. Treasury Grants Receivable [Line Items] | |||||||||
U.S. Treasury grants receivable | $ 0 | $ 0 | $ 258 | ||||||
Proceeds From U.S. Treasury Grants | 238 | $ 0 | |||||||
Reduction in tax benefit due to sequestration | $ 5 | ||||||||
Sequestration of U.S. Treasury grants receivable | $ 23 | $ 0 | |||||||
Mesquite Solar 1 [Member] | |||||||||
U.S. Treasury Grants Receivable [Line Items] | |||||||||
Proceeds From U.S. Treasury Grants | $ 164 | ||||||||
Copper Mountain Solar 2 [Member] | |||||||||
U.S. Treasury Grants Receivable [Line Items] | |||||||||
Proceeds From U.S. Treasury Grants | $ 74 | ||||||||
|
X | ||||||||||
- Definition The cash inflow from U.S. Treasury grants proceeds. No definition available.
|
X | ||||||||||
- Definition Reduction in tax benefit due to sequestration. No definition available.
|
X | ||||||||||
- Definition Sequestration of U.S. Treasury grants receivable. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Carrying amount as of the balance sheet date of amounts due under the terms of governmental, corporate, or foundation grants. For classified balance sheets, represents the current amount receivable, that is amounts expected to be collected within one year or the normal operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Details
|
X | ||||||||||
- Details
|
OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||
---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
Dec. 31, 2012 |
|
Variable Interest Entities Disclosure [Abstract] | |||||
Equity of variable interest entity | $ 79 | $ 79 | $ 76 | ||
Secured debt of variable interest entity | 337 | 337 | |||
Amounts Associated With Variable Interest Entities, Operating Revenues, Electric | (4) | $ 0 | 0 | $ 0 | |
Amounts Associated With Variable Interest Entities, Operating Revenues, Gas | 0 | 0 | 0 | 0 | |
Amounts Associated With Variable Interest Entities, Total Operating Revenues | (4) | 0 | 0 | 0 | |
Amounts Associated With Variable Interest Entities, Cost of Electric Fuel And Purchased Power | (27) | (26) | (65) | (66) | |
Amounts Associated With Variable Interest Entities, Operation And Maintenance | 7 | 4 | 33 | 15 | |
Amounts Associated With Variable Interest Entities, Depreciation And Amortization | 7 | 7 | 20 | 19 | |
Amounts Associated With Variable Interest Entities, Total Operating Expenses | (13) | (15) | (12) | (32) | |
Amounts Associated With Variable Interest Entities, Operating Income (Loss) | 9 | 15 | 12 | 32 | |
Amounts Associated With Variable Interest Entities, Other Income (Expense), Net | 0 | 0 | 0 | (1) | |
Amounts Associated With Variable Interest Entities, Interest Expense | (4) | (3) | (11) | (8) | |
Amounts Associated With Variable Interest Entities, Net Income (Loss) | 5 | 12 | 1 | 23 | |
Amounts Associated With Variable Interest Entities, (Earnings) Losses Attributable Noncontrolling Interests | (5) | (12) | (1) | (23) | |
Amounts Associated With Variable Interest Entities, Earnings | $ 0 | $ 0 | $ 0 | $ 0 |
X | ||||||||||
- Definition Amounts associated with variable interest entities, cost of electric fuel and purchased power. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, depreciation and amortization. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, earnings. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, (earnings) losses attributable noncontrolling interests. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, interest expense. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, net income. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, operating income. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, operating revenues, electric. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, operating revenues, gas. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, operation and maintenance. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, other income (expense), net. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, total operating expenses. No definition available.
|
X | ||||||||||
- Definition Amounts associated with variable interest entities, total operating revenues. No definition available.
|
X | ||||||||||
- Definition Secured debt of variable interest entity. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The net carrying amount of the consolidated Variable Interest Entity's assets and liabilities included in the reporting entity's statement of financial position. No definition available.
|
OTHER FINANCIAL DATA - GOODWILL (Details) $ in Millions |
Sep. 30, 2013
USD ($)
|
|||
---|---|---|---|---|
Goodwill [Line Items] | ||||
Goodwill, Beginning Balance | $ 1,111 | [1] | ||
Goodwill, Ending Balance | $ 1,045 | |||
|
X | ||||||||||
- Definition Carrying amount as of the balance sheet date, which is the cumulative amount paid and (if applicable) the fair value of any noncontrolling interest in the acquiree, adjusted for any amortization recognized prior to the adoption of any changes in generally accepted accounting principles (as applicable) and for any impairment charges, in excess of the fair value of net assets acquired in one or more business combination transactions. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
|
OTHER FINANCIAL DATA - ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Millions |
9 Months Ended | ||||||||
---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Asset Retirement Obligations, Balance as of January 1 | [1] | $ 2,056 | $ 1,925 | ||||||
Asset Retirement Obligation, Accretion Expense | 74 | 69 | |||||||
Asset Retirement Obligation, Liabilities Incurred | 4 | 15 | |||||||
Asset Retirement Obligation, Payments | (1) | (1) | |||||||
Asset Retirement Obligation, Revisions, GRC- related | [2] | (135) | (8) | ||||||
Asset Retirement Obligation, Revisions, Other | [3] | 181 | 0 | ||||||
Asset Retirement Obligations, Balance as of September 30 | [1] | 2,179 | 2,000 | ||||||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Asset Retirement Obligations, Balance as of January 1 | [1] | 741 | 698 | ||||||
Asset Retirement Obligation, Accretion Expense | 35 | 31 | |||||||
Asset Retirement Obligation, Liabilities Incurred | 0 | 0 | |||||||
Asset Retirement Obligation, Payments | 0 | 0 | |||||||
Asset Retirement Obligation, Revisions, GRC- related | [2] | (30) | 0 | ||||||
Asset Retirement Obligation, Revisions, Other | [3] | 207 | 0 | ||||||
Asset Retirement Obligations, Balance as of September 30 | [1] | $ 953 | 729 | ||||||
Asset Retirement Obligations, Increase in Asset Service Lives, Beginning Rate | 2.00% | ||||||||
Asset Retirement Obligations, Increase in Asset Service Lives, Ending Rate | 7.00% | ||||||||
Southern California Gas Company [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Asset Retirement Obligations, Balance as of January 1 | [1] | $ 1,253 | 1,175 | ||||||
Asset Retirement Obligation, Accretion Expense | 37 | 36 | |||||||
Asset Retirement Obligation, Liabilities Incurred | 0 | 0 | |||||||
Asset Retirement Obligation, Payments | 0 | 0 | |||||||
Asset Retirement Obligation, Revisions, GRC- related | [2] | (105) | 0 | ||||||
Asset Retirement Obligation, Revisions, Other | [3] | 0 | 0 | ||||||
Asset Retirement Obligations, Balance as of September 30 | [1] | $ 1,185 | $ 1,211 | ||||||
Asset Retirement Obligations, Increase in Asset Service Lives, Beginning Rate | 4.00% | ||||||||
Asset Retirement Obligations, Increase in Asset Service Lives, Ending Rate | 6.00% | ||||||||
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Asset retirement obligations, increase in asset service lives, beginning rate. No definition available.
|
X | ||||||||||
- Definition Asset retirement obligations, increase in asset service lives, ending rate. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The carrying amount of a liability for an asset retirement obligation. An asset retirement obligation is a legal obligation associated with the disposal or retirement of a tangible long-lived asset that results from the acquisition, construction or development, or the normal operations of a long-lived asset, except for certain obligations of lessees. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Amount of accretion expense recognized during the period that is associated with an asset retirement obligation. Accretion expense measures and incorporates changes due to the passage of time into the carrying amount of the liability. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Amount of asset retirement obligations incurred during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Amount of the Increase or Decrease in the amount of the asset retirement obligation during the current period for changes in the amount or timing of the estimated cash flows associated with the settlement of the obligation. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Details
|
X | ||||||||||
- Details
|
OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Pension Benefits | ||||
Net Periodic Benefit Cost | ||||
Service cost | $ 28 | $ 23 | $ 82 | $ 68 |
Interest cost | 35 | 40 | 111 | 122 |
Expected return on assets | (39) | (38) | (121) | (116) |
Amortization of prior service cost | 1 | 0 | 3 | 2 |
Amortization of actuarial loss | 11 | 12 | 41 | 35 |
Settlement | 1 | 1 | 1 | 8 |
Regulatory adjustment | (14) | 9 | (65) | (9) |
Total net periodic benefit cost | 23 | 47 | 52 | 110 |
Pension and Other Postretirement Benefit Contributions [Abstract] | ||||
Contributions to pension plans | 48 | |||
Expected contributions to pension and other postretirement benefit plans | 132 | 132 | ||
Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Net Periodic Benefit Cost | ||||
Service cost | 8 | 7 | 24 | 21 |
Interest cost | 9 | 11 | 30 | 34 |
Expected return on assets | (13) | (11) | (39) | (35) |
Amortization of prior service cost | 0 | 0 | 1 | 1 |
Amortization of actuarial loss | 3 | 4 | 10 | 11 |
Settlement | 1 | (1) | 1 | 1 |
Regulatory adjustment | 3 | 7 | (3) | 7 |
Total net periodic benefit cost | 11 | 17 | 24 | 40 |
Pension and Other Postretirement Benefit Contributions [Abstract] | ||||
Contributions to pension plans | 26 | |||
Expected contributions to pension and other postretirement benefit plans | 53 | 53 | ||
Pension Benefits | Southern California Gas Company [Member] | ||||
Net Periodic Benefit Cost | ||||
Service cost | 17 | 13 | 50 | 40 |
Interest cost | 22 | 24 | 68 | 74 |
Expected return on assets | (24) | (23) | (73) | (72) |
Amortization of prior service cost | 0 | 0 | 1 | 1 |
Amortization of actuarial loss | 6 | 6 | 23 | 17 |
Settlement | 0 | 1 | ||
Regulatory adjustment | (17) | 2 | (62) | (16) |
Total net periodic benefit cost | 4 | 22 | 7 | 45 |
Pension and Other Postretirement Benefit Contributions [Abstract] | ||||
Contributions to pension plans | 8 | |||
Expected contributions to pension and other postretirement benefit plans | 59 | 59 | ||
Other Postretirement Benefits | ||||
Net Periodic Benefit Cost | ||||
Service cost | 8 | 4 | 21 | 19 |
Interest cost | 10 | 11 | 33 | 39 |
Expected return on assets | (15) | (13) | (44) | (40) |
Amortization of prior service cost | (1) | 0 | (3) | (2) |
Amortization of actuarial loss | 0 | 2 | 5 | 9 |
Settlement | 0 | 0 | 0 | 0 |
Regulatory adjustment | 3 | 3 | 7 | 8 |
Total net periodic benefit cost | 5 | 7 | 19 | 33 |
Pension and Other Postretirement Benefit Contributions [Abstract] | ||||
Contributions to other postretirement benefit plans | 19 | |||
Expected contributions to pension and other postretirement benefit plans | 23 | 23 | ||
Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Net Periodic Benefit Cost | ||||
Service cost | 2 | 1 | 6 | 5 |
Interest cost | 2 | 2 | 6 | 6 |
Expected return on assets | (3) | (1) | (7) | (5) |
Amortization of prior service cost | 1 | 1 | 3 | 3 |
Amortization of actuarial loss | 0 | 0 | 0 | 0 |
Settlement | 0 | 0 | 0 | 0 |
Regulatory adjustment | 1 | 1 | 1 | 2 |
Total net periodic benefit cost | 3 | 4 | 9 | 11 |
Pension and Other Postretirement Benefit Contributions [Abstract] | ||||
Contributions to other postretirement benefit plans | 9 | |||
Expected contributions to pension and other postretirement benefit plans | 12 | 12 | ||
Other Postretirement Benefits | Southern California Gas Company [Member] | ||||
Net Periodic Benefit Cost | ||||
Service cost | 5 | 2 | 13 | 12 |
Interest cost | 8 | 9 | 26 | 31 |
Expected return on assets | (12) | (10) | (36) | (33) |
Amortization of prior service cost | (2) | (1) | (6) | (5) |
Amortization of actuarial loss | 0 | 1 | 4 | 8 |
Settlement | 0 | 0 | ||
Regulatory adjustment | 2 | 2 | 6 | 6 |
Total net periodic benefit cost | 1 | $ 3 | 7 | $ 19 |
Pension and Other Postretirement Benefit Contributions [Abstract] | ||||
Contributions to other postretirement benefit plans | 7 | |||
Expected contributions to pension and other postretirement benefit plans | $ 7 | $ 7 |
X | ||||||||||
- Definition Defined benefit plan regulatory adjustment. No definition available.
|
X | ||||||||||
- Definition Defined benefit plan settlements cost. No definition available.
|
X | ||||||||||
- Definition The amount of gains or losses recognized in net periodic benefit cost. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The amount of the prior service cost or credit recognized in net periodic benefit cost relating to benefit changes attributable to plan participants' prior service pursuant to a plan amendment or a plan initiation. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The employer's best estimate, as soon as it can be reasonably determined, of contributions expected to be paid to the plan during the next fiscal year beginning after the date of the latest statement of financial position. Estimated contributions may be presented in the aggregate combining (1) contributions required by funding regulations or laws, (2) discretionary contributions, and (3) noncash contributions. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition An amount calculated as a basis for determining the extent of delayed recognition of the effects of changes in the fair value of assets. The expected return on plan assets is determined based on the expected long-term rate of return on plan assets and the market-related value of plan assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The increase in a defined benefit pension plan's projected benefit obligation or a defined benefit postretirement plan's accumulated postretirement benefit obligation due to the passage of time. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The total amount of net periodic benefit cost for defined benefit plans for the period. Periodic benefit costs include the following components: service cost, interest cost, expected return on plan assets, gain (loss), prior service cost or credit, transition asset or obligation, and gain (loss) due to settlements or curtailments. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The actuarial present value of benefits attributed by the pension benefit formula to services rendered by employees during the period. The portion of the expected postretirement benefit obligation attributed to employee service during the period. The service cost component is a portion of the benefit obligation and is unaffected by the funded status of the plan. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The amount of cash or cash equivalents contributed during the reporting period by the entity to fund non-pension postretirement benefits. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The amount of cash or cash equivalents contributed by the entity to fund its pension plans. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Details
|
X | ||||||||||
- Details
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OTHER FINANCIAL DATA - RABBI TRUST (Details) - USD ($) $ in Millions |
Sep. 30, 2013 |
Dec. 31, 2012 |
---|---|---|
Rabbi Trust Disclosure [Abstract] | ||
Rabbi Trust | $ 486 | $ 510 |
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The amount of cash, securities, or other assets held by a third-party trustee pursuant to the terms of an agreement which assets are available to be used by beneficiaries to that agreement only within the specific terms thereof and which agreement is expected to terminate more than one year from the balance sheet date (or operating cycle, if longer) at which time the assets held-in-trust will be released or forfeited. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA - EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Millions |
3 Months Ended | 9 Months Ended | |||||
---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
||||
Earnings Per Share Numerator [Abstract] | |||||||
Earnings | $ 296 | $ 268 | $ 719 | $ 566 | |||
Earnings Per Share Denominator [Abstract] | |||||||
Weighted-average common shares outstanding for basic EPS | 244,140,000 | 241,689,000 | 243,682,000 | 241,133,000 | |||
Dilutive effect of stock options, restricted stock awards and restricted stock units | 5,119,000 | 4,113,000 | 5,041,000 | 3,880,000 | |||
Weighted-average common shares outstanding for diluted EPS | 249,259,000 | 245,802,000 | 248,723,000 | 245,013,000 | |||
Earnings Per Share [Abstract] | |||||||
Basic earnings per common share | $ 1.21 | $ 1.11 | $ 2.95 | $ 2.35 | |||
Diluted earnings per common share | $ 1.19 | $ 1.09 | $ 2.89 | $ 2.31 | |||
Seventy Fifth Percentile Or Above [Member] | |||||||
Total Shareholder Return Ranking [Line Items] | |||||||
Common Shares Received For Each Restricted Stock Unit | [1] | 1.5 | |||||
Fiftieth Percentile [Member] | |||||||
Total Shareholder Return Ranking [Line Items] | |||||||
Common Shares Received For Each Restricted Stock Unit | [1] | 1 | |||||
Thirty Fifth Percentile Or Below [Member] | |||||||
Total Shareholder Return Ranking [Line Items] | |||||||
Common Shares Received For Each Restricted Stock Unit | [1] | 0 | |||||
Restricted Stock Units [Member] | |||||||
Schedule Of Performance Based Restricted Shares [Line Items] | |||||||
Contractual vesting percentage minimum | 0.00% | ||||||
Contractual vesting percentage maximum | 150.00% | ||||||
Restricted Stock Awards [Member] | |||||||
Schedule Of Performance Based Restricted Shares [Line Items] | |||||||
Contractual vesting percentage minimum | 0.00% | ||||||
Contractual vesting percentage maximum | 100.00% | ||||||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||||
Earnings Per Share Numerator [Abstract] | |||||||
Earnings | $ 134 | $ 176 | $ 292 | $ 378 | |||
Southern California Gas Company [Member] | |||||||
Earnings Per Share Numerator [Abstract] | |||||||
Earnings | $ 102 | $ 71 | $ 267 | $ 191 | |||
Out Of The Money Stock Options [Member] | |||||||
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items] | |||||||
Antidilutive securities excluded from computation of earnings per share | 0 | 0 | 0 | 40,000 | |||
Restricted Stock | |||||||
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items] | |||||||
Antidilutive securities excluded from computation of earnings per share | 712,941 | 2,349,338 | 889,420 | 2,523,343 | |||
Restricted Stock Units | |||||||
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items] | |||||||
Antidilutive securities excluded from computation of earnings per share | 0 | 3,387 | 0 | 1,881 | |||
Restricted Stock Awards [Member] | |||||||
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items] | |||||||
Antidilutive securities excluded from computation of earnings per share | 0 | 0 | 0 | 14,319 | |||
|
X | ||||||||||
- Definition Common shares received for each restricted stock unit. No definition available.
|
X | ||||||||||
- Definition Contractual vesting percentage maximum. No definition available.
|
X | ||||||||||
- Definition Contractual vesting percentage minimum. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Securities (including those issuable pursuant to contingent stock agreements) that could potentially dilute basic earnings per share (EPS) or earnings per unit (EPU) in the future that were not included in the computation of diluted EPS or EPU because to do so would increase EPS or EPU amounts or decrease loss per share or unit amounts for the period presented. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The amount of net income (loss) for the period available to each share of common stock or common unit outstanding during the reporting period and to each share or unit that would have been outstanding assuming the issuance of common shares or units for all dilutive potential common shares or units outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Additional shares included in the calculation of diluted EPS as a result of the potentially dilutive effect of share based payment arrangements using the treasury stock method. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The portion of profit or loss for the period, net of income taxes, which is attributable to the parent. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition The average number of shares or units issued and outstanding that are used in calculating diluted EPS or earnings per unit (EPU), determined based on the timing of issuance of shares or units in the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Number of [basic] shares or units, after adjustment for contingently issuable shares or units and other shares or units not deemed outstanding, determined by relating the portion of time within a reporting period that common shares or units have been outstanding to the total time in that period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA - PREFERRED STOCK (Details) - USD ($) |
3 Months Ended | 9 Months Ended | |
---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Preferred Stock (Details) [Abstract] | |||
Preferred stock redeemed | $ 82,000,000 | $ 82,000,000 | |
Preferred stock redemption price per share, minimum | 20.25 | 20.25 | |
Preferred stock redemption price per share, maximum | 26.00 | 26.00 | |
Accrued preferred stock dividends at redemption date | 1,000,000 | 1,000,000 | |
Call premium on preferred stock | $ 3,000,000 | $ 3,000,000 | $ 0 |
X | ||||||||||
- Definition Accrued preferred stock dividends at redemption date. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Preferred stock redeemed. No definition available.
|
X | ||||||||||
- Definition Preferred stock redemption price per share, maximum. No definition available.
|
X | ||||||||||
- Definition Preferred stock redemption price per share, minimum. No definition available.
|
X | ||||||||||
- Definition The excess of (1) fair value of the consideration transferred to the holders of the preferred stock over (2) the carrying amount of the preferred stock in the registrant's balance sheet, during the accounting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
OTHER FINANCIAL DATA - SHARE-BASED COMPENSATION (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Share Based Compensation Arrangement By Share Based Payment Award [Line Items] | ||||
Share-based compensation expense, net of income taxes | $ 6 | $ 5 | $ 17 | $ 18 |
Restricted Stock Awards Granted | 4,617 | |||
Restricted stock units issued by IEnova | 1,014,899 | |||
Performance-Based [Member] | ||||
Share Based Compensation Arrangement By Share Based Payment Award [Line Items] | ||||
Restricted stock units granted | 651,193 | |||
Service-Based [Member] | ||||
Share Based Compensation Arrangement By Share Based Payment Award [Line Items] | ||||
Restricted stock units granted | 105,680 |
X | ||||||||||
- Definition Restricted stock awards granted. No definition available.
|
X | ||||||||||
- Definition Restricted stock units issued by IEnova. No definition available.
|
X | ||||||||||
- Definition Represents the expense recognized during the period arising from equity-based compensation arrangements (for example, shares of stock, unit, stock options or other equity instruments) with employees, directors and certain consultants qualifying for treatment as employees. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The number of grants made during the period on other than stock (or unit) option plans (for example, phantom stock or unit plan, stock or unit appreciation rights plan, performance target plan). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
|
X | ||||||||||
- Details
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OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Capitalized Financing Costs Disclosure [Line Items] | ||||
AFUDC related to debt | $ 6 | $ 5 | $ 17 | $ 32 |
AFUDC related to equiity | 14 | 13 | 44 | 80 |
Other capitalized financing costs | 9 | 13 | 22 | 40 |
Total capitalized financing costs | 29 | 31 | 83 | 152 |
San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Capitalized Financing Costs Disclosure [Line Items] | ||||
AFUDC related to debt | 4 | 3 | 12 | 26 |
AFUDC related to equiity | 10 | 6 | 30 | 61 |
Total capitalized financing costs | 14 | 9 | 42 | 87 |
Southern California Gas Company [Member] | ||||
Capitalized Financing Costs Disclosure [Line Items] | ||||
AFUDC related to debt | 2 | 2 | 5 | 6 |
AFUDC related to equiity | 4 | 7 | 14 | 19 |
Total capitalized financing costs | $ 6 | $ 9 | $ 19 | $ 25 |
X | ||||||||||
- Definition Total capitalized financing costs. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Amount of interest capitalized during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The component of the allowance for funds used during construction during the period based on an assumed rate of return on equity funds used in financing the construction of regulated assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Amount capitalized of allowance for funds used during construction. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA - COMPREHENSIVE INCOME AND EQUITY (Details) $ / shares in Units, $ / shares in Units, $ in Millions, $ in Millions |
3 Months Ended | 9 Months Ended | ||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2013
USD ($)
$ / shares
shares
|
Mar. 31, 2013
MXN ($)
|
Sep. 30, 2013
USD ($)
|
Sep. 30, 2012
USD ($)
|
Sep. 30, 2013
USD ($)
|
Sep. 30, 2012
USD ($)
|
Mar. 31, 2013
$ / shares
shares
|
Dec. 31, 2012
USD ($)
|
|||||||||
Comprehensive Income And Equity Disclosure [Line Items] | ||||||||||||||||
Equity, beginning of period | $ 10,683 | [1] | $ 10,178 | |||||||||||||
Comprehensive income | $ 325 | $ 361 | 921 | 713 | ||||||||||||
Share-based compensation expense | 30 | 33 | ||||||||||||||
Call premium on preferred stock of subsidiary | (3) | 0 | (3) | 0 | ||||||||||||
Call premium on preferred stock | (3) | (3) | 0 | |||||||||||||
Common stock dividends declared | (460) | (435) | ||||||||||||||
Preferred dividends of subsidiaries | (2) | (2) | (5) | (5) | ||||||||||||
Issuance of common stock | 57 | 50 | ||||||||||||||
Tax benefit related to share-based compensation | 30 | |||||||||||||||
Repurchases of common stock | (45) | (16) | ||||||||||||||
Common stock released from ESOP | [2] | 9 | ||||||||||||||
Sale of noncontrolling interests, net of offering costs | 574 | |||||||||||||||
Equity contributed by noncontrolling interests | 5 | |||||||||||||||
Distributions to noncontrolling interests | (28) | (36) | ||||||||||||||
Equity, end of period | 11,754 | 10,496 | 11,754 | 10,496 | ||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Amount of ownership interests held by others | 825 | 825 | $ 381 | |||||||||||||
Sale Of Noncontrolling Interests [Abstract] | ||||||||||||||||
Proceeds From Sale Of Noncontrolling Interests Net | $ 574 | $ 7,100 | 574 | 0 | ||||||||||||
Common stock shares issued | shares | 218,110,500 | 218,110,500 | ||||||||||||||
Share price | (per share) | $ 2.75 | $ 34 | ||||||||||||||
Minority interest ownership percentage by parent | 81.10% | 81.10% | ||||||||||||||
Foreign currency exchange rate pesos to US dollars | 12.3841 | 12.3841 | ||||||||||||||
San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||||||||||
Comprehensive Income And Equity Disclosure [Line Items] | ||||||||||||||||
Equity, beginning of period | 4,298 | [1] | 3,841 | |||||||||||||
Comprehensive income | 139 | 184 | 309 | 388 | ||||||||||||
Call premium on preferred stock | (3) | 0 | (3) | 0 | ||||||||||||
Preferred dividend requirements | (2) | (2) | (4) | (4) | ||||||||||||
Distributions to noncontrolling interests | (12) | (22) | ||||||||||||||
Equity, end of period | 4,588 | 4,203 | 4,588 | 4,203 | ||||||||||||
Southern California Gas Company [Member] | ||||||||||||||||
Comprehensive Income And Equity Disclosure [Line Items] | ||||||||||||||||
Equity, beginning of period | [1] | 2,235 | ||||||||||||||
Comprehensive income | 102 | 71 | 268 | 192 | ||||||||||||
Preferred dividend requirements | 0 | 0 | (1) | (1) | ||||||||||||
Equity, end of period | 2,452 | 2,452 | ||||||||||||||
Total Shareholders' Equity | ||||||||||||||||
Comprehensive Income And Equity Disclosure [Line Items] | ||||||||||||||||
Equity, beginning of period | 10,282 | 9,775 | ||||||||||||||
Comprehensive income | 305 | 337 | 888 | 671 | ||||||||||||
Share-based compensation expense | 30 | 33 | ||||||||||||||
Call premium on preferred stock of subsidiary | (3) | |||||||||||||||
Common stock dividends declared | (460) | (435) | ||||||||||||||
Preferred dividends of subsidiaries | (2) | (2) | (5) | (5) | ||||||||||||
Issuance of common stock | 57 | 50 | ||||||||||||||
Tax benefit related to share-based compensation | 30 | |||||||||||||||
Repurchases of common stock | (45) | (16) | ||||||||||||||
Common stock released from ESOP | [2] | 9 | ||||||||||||||
Sale of noncontrolling interests, net of offering costs | 135 | |||||||||||||||
Equity contributed by noncontrolling interests | 0 | |||||||||||||||
Distributions to noncontrolling interests | 0 | 0 | ||||||||||||||
Equity, end of period | 10,909 | 10,082 | 10,909 | 10,082 | ||||||||||||
Total Shareholders' Equity | San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||||||||||
Comprehensive Income And Equity Disclosure [Line Items] | ||||||||||||||||
Equity, beginning of period | 4,222 | 3,739 | ||||||||||||||
Comprehensive income | 135 | 176 | 294 | 378 | ||||||||||||
Call premium on preferred stock | (3) | |||||||||||||||
Preferred dividend requirements | (4) | (4) | ||||||||||||||
Distributions to noncontrolling interests | 0 | 0 | ||||||||||||||
Equity, end of period | 4,509 | 4,113 | 4,509 | 4,113 | ||||||||||||
Noncontrolling Interests | ||||||||||||||||
Comprehensive Income And Equity Disclosure [Line Items] | ||||||||||||||||
Equity, beginning of period | 401 | 403 | ||||||||||||||
Comprehensive income | 20 | 24 | 33 | 42 | ||||||||||||
Share-based compensation expense | 0 | 0 | ||||||||||||||
Call premium on preferred stock of subsidiary | 0 | |||||||||||||||
Common stock dividends declared | 0 | 0 | ||||||||||||||
Preferred dividends of subsidiaries | 0 | 0 | 0 | |||||||||||||
Issuance of common stock | 0 | 0 | ||||||||||||||
Tax benefit related to share-based compensation | 0 | |||||||||||||||
Repurchases of common stock | 0 | 0 | ||||||||||||||
Common stock released from ESOP | [2] | 0 | ||||||||||||||
Sale of noncontrolling interests, net of offering costs | 439 | |||||||||||||||
Equity contributed by noncontrolling interests | 5 | |||||||||||||||
Distributions to noncontrolling interests | (28) | (36) | ||||||||||||||
Equity, end of period | 845 | 414 | 845 | 414 | ||||||||||||
Noncontrolling Interests | San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||||||||||
Comprehensive Income And Equity Disclosure [Line Items] | ||||||||||||||||
Equity, beginning of period | 76 | 102 | ||||||||||||||
Comprehensive income | 4 | 8 | 15 | 10 | ||||||||||||
Call premium on preferred stock | 0 | |||||||||||||||
Preferred dividend requirements | 0 | 0 | ||||||||||||||
Distributions to noncontrolling interests | (12) | (22) | ||||||||||||||
Equity, end of period | $ 79 | $ 90 | $ 79 | $ 90 | ||||||||||||
Ownership Interests Held By Others, Bay Gas Storage Company [Member] | ||||||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Percent of ownership held by others | 9.10% | 9.10% | ||||||||||||||
Amount of ownership interests held by others | $ 21 | $ 21 | 20 | |||||||||||||
Ownership Interests Held By Others, Southern Gas Transmission [Member] | ||||||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Percent of ownership held by others | 49.00% | 49.00% | ||||||||||||||
Amount of ownership interests held by others | $ 1 | $ 1 | 1 | |||||||||||||
Ownership Interests Held By Others, Liberty Gas Storage [Member] | ||||||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Percent of ownership held by others | 25.00% | 25.00% | ||||||||||||||
Amount of ownership interests held by others | $ 15 | $ 15 | 15 | |||||||||||||
Ownership Interests Held By Others, Tecsur [Member] | ||||||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Percent of ownership held by others | 9.80% | 9.80% | ||||||||||||||
Amount of ownership interests held by others | $ 3 | $ 3 | 4 | |||||||||||||
Ownership Interests Held By Others, Luz Del Sur [Member] | ||||||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Percent of ownership held by others | 20.20% | 20.20% | ||||||||||||||
Amount of ownership interests held by others | $ 222 | $ 222 | 236 | |||||||||||||
Ownership Interests Held By Others, Chilquinta Energia [Member] | ||||||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Percent of ownership held by others, minimum | [3] | 24.40% | 24.40% | |||||||||||||
Percent of ownership held by others, maximum | [3] | 43.40% | 43.40% | |||||||||||||
Amount of ownership interests held by others | [3] | $ 27 | $ 27 | 29 | ||||||||||||
Ownership Interests Held By Others, Otay Mesa VIE [Member] | ||||||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Percent of ownership held by others | 100.00% | 100.00% | ||||||||||||||
Amount of ownership interests held by others | $ 79 | $ 79 | 76 | |||||||||||||
Ownership Interests Held By Others IEnova [Member] | ||||||||||||||||
Ownership Interests Held By Others [Line Items] | ||||||||||||||||
Percent of ownership held by others | 18.90% | 18.90% | ||||||||||||||
Amount of ownership interests held by others | $ 457 | $ 457 | $ 0 | |||||||||||||
|
X | ||||||||||
- Definition Amount of ownership interests held by others. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Sale of noncontrolling interests, net of offering costs. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Percent of ownership held by others. No definition available.
|
X | ||||||||||
- Definition Percent of ownership held by others, maximum. No definition available.
|
X | ||||||||||
- Definition Percent of ownership held by others, minimum. No definition available.
|
X | ||||||||||
- Definition Preferred dividends of subsidiaries recorded during the period. No definition available.
|
X | ||||||||||
- Definition Proceeds from sale of noncontrolling interest, net of offering costs. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Total comprehensive income before preferred stock dividend requirements. No definition available.
|
X | ||||||||||
- Definition This element represents the amount of recognized equity-based compensation during the period, that is, the amount recognized as expense in the income statement (or as asset if compensation is capitalized). Alternate captions include the words "stock-based compensation". Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Tax benefit associated with any equity-based compensation plan other than an employee stock ownership plan (ESOP). The tax benefit results from the deduction by the entity on its tax return for an award of stock that exceeds the cumulative compensation cost for common stock or preferred stock recognized for financial reporting. Includes any resulting tax benefit that exceeds the previously recognized deferred tax asset (excess tax benefits). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Total number of common shares of an entity that have been sold or granted to shareholders (includes common shares that were issued, repurchased and remain in the treasury). These shares represent capital invested by the firm's shareholders and owners, and may be all or only a portion of the number of shares authorized. Shares issued include shares outstanding and shares held in the treasury. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Equity impact of aggregate cash, stock, and paid-in-kind dividends declared for common shareholders during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Equity impact of aggregate cash, stock, and paid-in-kind dividends declared for preferred shareholders during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Foreign exchange rate used to translate amounts denominated in functional currency to reporting currency. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Decrease in noncontrolling interest balance from payment of dividends or other distributions by the non-wholly owned subsidiary or partially owned entity, included in the consolidation of the parent entity, to the noncontrolling interest holders. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Represents an increase in noncontrolling interest from issuance of additional equity interests to noncontrolling interest holders or the sale of a portion of the parent's controlling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The parent entity's interest in net assets of the subsidiary, expressed as a percentage. No definition available.
|
X | ||||||||||
- Definition The excess of (1) fair value of the consideration transferred to the holders of the preferred stock over (2) the carrying amount of the preferred stock in the registrant's balance sheet, during the accounting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Price of a single share of a number of saleable stocks of a company. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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X | ||||||||||
- Definition Aggregate change in value for stock issued during the period as a result of employee stock purchase plan. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Equity impact of the value of new stock issued during the period. Includes shares issued in an initial public offering or a secondary public offering. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Equity impact of the value of stock that has been repurchased during the period and has not been retired and is not held in treasury. Some state laws may mandate the circumstances under which an entity may acquire its own stock and prescribe the accounting treatment therefore. This element is used when state law does not recognize treasury stock. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of stockholders' equity (deficit), net of receivables from officers, directors, owners, and affiliates of the entity, attributable to both the parent and noncontrolling interests. Amount excludes temporary equity. Alternate caption for the concept is permanent equity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA - COMPREHENSIVE INCOME AND EQUITY 2 (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||
---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2013 |
||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | $ (219) | $ (376) | ||
Other Comprehensive Income Before Reclassifications | [1] | (1) | (120) | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 5 | 281 | ||
Net Other Comprehensive Income | [1] | 4 | 161 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | (215) | (215) | ||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | (10) | (11) | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 1 | 2 | ||
Net Other Comprehensive Income | [1] | 1 | 2 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | (9) | (9) | ||
Southern California Gas Company [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | (18) | |||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 1 | |||
Net Other Comprehensive Income | [1] | 1 | |||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | (17) | (17) | ||
Foreign Currency Translation Adjustments [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | (96) | (240) | ||
Other Comprehensive Income Before Reclassifications | [1] | 5 | (121) | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 0 | 270 | ||
Net Other Comprehensive Income | [1] | 5 | 149 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | (91) | (91) | ||
Foreign Currency Translation Adjustments [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | 0 | 0 | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 0 | 0 | ||
Net Other Comprehensive Income | [1] | 0 | 0 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | 0 | 0 | ||
Foreign Currency Translation Adjustments [Member] | Southern California Gas Company [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | 0 | |||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 0 | |||
Net Other Comprehensive Income | [1] | 0 | |||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | 0 | 0 | ||
Unamortized Net Actuarial Loss [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | (98) | (102) | ||
Other Comprehensive Income Before Reclassifications | [1] | 0 | 0 | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 3 | 7 | ||
Net Other Comprehensive Income | [1] | 3 | 7 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | (95) | (95) | ||
Unamortized Net Actuarial Loss [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | (11) | (12) | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 1 | 2 | ||
Net Other Comprehensive Income | [1] | 1 | 2 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | (10) | (10) | ||
Unamortized Net Actuarial Loss [Member] | Southern California Gas Company [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | (4) | |||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 0 | |||
Net Other Comprehensive Income | [1] | 0 | |||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | (4) | (4) | ||
Unamortized Prior Service Credit [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | 1 | 1 | ||
Other Comprehensive Income Before Reclassifications | [1] | 0 | 0 | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 0 | 0 | ||
Net Other Comprehensive Income | [1] | 0 | 0 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | 1 | 1 | ||
Unamortized Prior Service Credit [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | 1 | 1 | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 0 | 0 | ||
Net Other Comprehensive Income | [1] | 0 | 0 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | 1 | 1 | ||
Unamortized Prior Service Credit [Member] | Southern California Gas Company [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | 1 | |||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 0 | |||
Net Other Comprehensive Income | [1] | 0 | |||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | 1 | 1 | ||
Financial Instrustments [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | (26) | (35) | ||
Other Comprehensive Income Before Reclassifications | [1] | (6) | 1 | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 2 | 4 | ||
Net Other Comprehensive Income | [1] | (4) | 5 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | (30) | (30) | ||
Financial Instrustments [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | 0 | 0 | ||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 0 | 0 | ||
Net Other Comprehensive Income | [1] | 0 | 0 | ||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | 0 | 0 | ||
Financial Instrustments [Member] | Southern California Gas Company [Member] | |||||
Changes In Components Of Accumulated Other Comprehensive Income [Line Items] | |||||
Component Of Accumulated Other Comprehensive Income Loss, Beginning Balance | [1] | (15) | |||
Amounts Reclassified From Accumulated Other Comprehensive Income | [1] | 1 | |||
Net Other Comprehensive Income | [1] | 1 | |||
Component Of Accumulated Other Comprehensive Income Loss, Ending Balance | [1] | $ (14) | $ (14) | ||
|
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- Definition Amounts reclassified from accumulated other comprehensive income. No definition available.
|
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- References No definition available.
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- Definition Component of accumulated other comprehensive income (loss). No definition available.
|
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- Definition Net other comprehensive income. No definition available.
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- Definition Other comprehensive income before reclassifications. No definition available.
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OTHER FINANCIAL DATA - COMPREHENSIVE INCOME AND EQUITY 3 (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||
---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2013 |
||||
Interest Expense [Member] | Interest Rate Instruments [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | $ 3 | $ 9 | |||
Interest Expense [Member] | Interest Rate Instruments [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 2 | 6 | |||
Interest Expense [Member] | Interest Rate Instruments [Member] | Southern California Gas Company [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 1 | ||||
Cost of Natural Gas, Electric Fuel and Purchased Power [Member] | Commodity Contracts Not Subject To Rate Recovery [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | (5) | ||||
Equity Earnings Before Income Tax [Member] | Foreign Currency Translation [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 270 | ||||
Equity Earnings Before Income Tax [Member] | Interest Rate Instruments [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 3 | 7 | |||
Income Before Tax [Member] | Interest Rate Instruments [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 6 | 11 | |||
Income Before Tax [Member] | Amortization of Actuarial Loss [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | [1] | 5 | 12 | ||
Income Before Tax [Member] | Amortization of Actuarial Loss [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | [1] | 2 | 3 | ||
Income Tax Expense [Member] | Interest Rate Instruments [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | (2) | (1) | |||
Income Tax Expense [Member] | Interest Rate Instruments [Member] | Southern California Gas Company [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 0 | ||||
Income Tax Expense [Member] | Amortization of Actuarial Loss [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | [1] | (2) | (5) | ||
Income Tax Expense [Member] | Amortization of Actuarial Loss [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | [1] | (1) | (1) | ||
Income After Tax [Member] | Interest Rate Instruments [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 4 | 10 | |||
Income After Tax [Member] | Interest Rate Instruments [Member] | Southern California Gas Company [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 1 | ||||
Income After Tax [Member] | Amortization of Actuarial Loss [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | [1] | 3 | 7 | ||
Income After Tax [Member] | Amortization of Actuarial Loss [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | [1] | 1 | 2 | ||
Earnings Attributable To Noncontrolling Interests [Member] | Interest Rate Instruments [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | (2) | (6) | |||
Earnings Attributable To Noncontrolling Interests [Member] | Interest Rate Instruments [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | (2) | (6) | |||
Total [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | 0 | 0 | |||
Total [Member] | Interest Rate Instruments [Member] | |||||
Reclassifications From Accumulated Other Comprehensive Income [Line Items] | |||||
Amount Reclassified From Accumulated Other Comprehensive Income Loss | $ 2 | $ 4 | |||
|
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- Definition Amount reclassified from accumulated other comprehensive income (loss). No definition available.
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OTHER FINANCIAL DATA - COMPREHENSIVE INCOME AND EQUITY 4 (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||
---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Other comprehensive income before reclassifications, financial instruments | $ (2) | $ (3) | $ 3 | $ (8) | |||
Amounts reclassified from accumulated other comprehensive income, pension and other postretirement benefits | 2 | (7) | 5 | (4) | |||
Amounts reclassified from accumulated other comprehensive income, financial instruments | 2 | 2 | 1 | 3 | |||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Amounts reclassified from accumulated other comprehensive income, pension and other postretirement benefits | 1 | 0 | 1 | 0 | |||
Southern California Gas Company [Member] | |||||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Amounts reclassified from accumulated other comprehensive income, financial instruments | 0 | 1 | 0 | 1 | |||
Total Shareholders' Equity | |||||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Other comprehensive income before reclassifications, financial instruments | [1] | (2) | (3) | 3 | (8) | ||
Amounts reclassified from accumulated other comprehensive income, pension and other postretirement benefits | [1] | 2 | (7) | 5 | (4) | ||
Amounts reclassified from accumulated other comprehensive income, financial instruments | [1] | 2 | 2 | 1 | 3 | ||
Total Shareholders' Equity | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Amounts reclassified from accumulated other comprehensive income, pension and other postretirement benefits | [1] | 1 | 0 | 1 | 0 | ||
Total Shareholders' Equity | Southern California Gas Company [Member] | |||||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Amounts reclassified from accumulated other comprehensive income, financial instruments | [1] | 0 | 1 | 0 | 1 | ||
Noncontrolling Interests | |||||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Other comprehensive income before reclassifications, financial instruments | 0 | 0 | 0 | 0 | |||
Amounts reclassified from accumulated other comprehensive income, pension and other postretirement benefits | 0 | 0 | 0 | 0 | |||
Amounts reclassified from accumulated other comprehensive income, financial instruments | 0 | 0 | 0 | 0 | |||
Noncontrolling Interests | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Amounts reclassified from accumulated other comprehensive income, pension and other postretirement benefits | 0 | 0 | 0 | 0 | |||
Noncontrolling Interests | Southern California Gas Company [Member] | |||||||
Income Tax Expense Associated With Other Comprehensive Income [Line Items] | |||||||
Amounts reclassified from accumulated other comprehensive income, financial instruments | $ 0 | $ 0 | $ 0 | $ 0 | |||
|
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- References No definition available.
|
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- Definition Tax effect of the income statement impact of the reclassification adjustment of accumulated gain (loss) from derivative instruments designated and qualifying as the effective portion of cash flow hedges realized in net income. Also includes reclassification adjustments of an entity's share of an equity investee's deferred hedging gain (loss) realized in net income. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition Tax effect of the income statement impact of the reclassification adjustment for actuarial gain (loss) recognized as a component of net periodic benefit cost. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition Tax effect of the change in accumulated gain (loss) from derivative instruments designated and qualifying as the effective portion of cash flow hedges. Also includes an entity's share of an equity investee's increase (decrease) in deferred hedging gain (loss). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||||||
---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
Dec. 31, 2012 |
||||
San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Due from affiliate, current | $ 1 | $ 1 | $ 39 | |||||
Due to affiliate, current | 13 | 13 | 19 | |||||
Revenues from unconsolidated affiliates | 3 | $ 2 | 8 | $ 6 | ||||
Southern California Gas Company [Member] | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Due from affiliate, current | 14 | 14 | 24 | |||||
Due to affiliate, current | 20 | 20 | 37 | |||||
Revenues from unconsolidated affiliates | $ 17 | $ 17 | 48 | $ 48 | ||||
Affiliate Of Investee [Member] | Parent Company Member | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Interest rate on due from affiliate, noncurrent | ||||||||
Loan to unconsolidated affiliate, principal | ||||||||
Loan to unconsolidated affiliate, accrued interest | ||||||||
Due to/from Sempra Energy | San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Due to affiliate, current | 11 | 11 | 19 | |||||
Income taxes due from (to) Sempra Energy | [1] | (2) | (2) | 12 | ||||
Due to/from Sempra Energy | Southern California Gas Company [Member] | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Due from affiliate, current | 12 | 12 | 24 | |||||
Income taxes due from (to) Sempra Energy | [1] | 130 | 130 | 99 | ||||
Subsidiary Of Common Parent S D G E [Member] | Southern California Gas Company [Member] | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Due from affiliate, current | 2 | 2 | 0 | |||||
Due to affiliate, current | 0 | 0 | 37 | |||||
Subsdiary Of Common Parent So Cal Gas [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Due from affiliate, current | 0 | 0 | 37 | |||||
Due to affiliate, current | 2 | 2 | 0 | |||||
Subsidiary Of Common Parent Other Affiliates [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Due from affiliate, current | 1 | 1 | 2 | |||||
Subsidiary Of Common Parent Other Affiliates [Member] | Southern California Gas Company [Member] | ||||||||
Transactions With Affiliates Disclosure [Line Items] | ||||||||
Due to affiliate, current | $ 20 | $ 20 | $ 0 | |||||
|
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|
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- References No definition available.
|
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- Definition Income taxes due to (from) Sempra Energy. No definition available.
|
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- Definition The aggregate amount of receivables to be collected from related parties where one party can exercise control or significant influence over another party; including affiliates, owners or officers and their immediate families, pension trusts, and so forth, at the financial statement date. which are usually due within one year (or one business cycle). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying amount as of the balance sheet date of obligations due all related parties. For classified balance sheets, represents the current portion of such liabilities (due within one year or within the normal operating cycle if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
|
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- Definition Identify the stated interest rate per the agreement, for example, leasing and debt arrangements between related parties. No definition available.
|
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- Definition Amount of revenue, fees and commissions earned from transactions between (a) a parent company and its subsidiaries; (b) subsidiaries of a common parent; (c) an entity and trusts for the benefit of employees, for example, but not limited to, pension and profit-sharing trusts that are managed by or under the trusteeship of the entity's management; (d) an entity and its principal, owners, management, or members of their immediate families; and (e) affiliates. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA - OTHER INCOME (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||||
---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | $ 16 | $ 44 | $ 79 | $ 137 | |||||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | 10 | 5 | 30 | 59 | |||||
Southern California Gas Company [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | 2 | 6 | 9 | 14 | |||||
Allowance for Cost of Equity Funds Used During Construction [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | 14 | 13 | 44 | 80 | |||||
Allowance for Cost of Equity Funds Used During Construction [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | 10 | 6 | 30 | 61 | |||||
Allowance for Cost of Equity Funds Used During Construction [Member] | Southern California Gas Company [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | 4 | 7 | 14 | 19 | |||||
Regulatory Interest, Net [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | [1] | 1 | 0 | 3 | 1 | ||||
Regulatory Interest, Net [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | [1] | 1 | 0 | 3 | 1 | ||||
Gains (losses) on interest rate and foreign exchange instruments [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | 4 | 1 | 17 | 11 | |||||
Gain (Loss) on Investments [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | [2] | (6) | 17 | 16 | 27 | ||||
Other Income, Sundry [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | 3 | 13 | (1) | 18 | |||||
Other Income, Sundry [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | (1) | (1) | (3) | (3) | |||||
Other Income, Sundry [Member] | Southern California Gas Company [Member] | |||||||||
Component of Other Income, Nonoperating [Line Items] | |||||||||
Other income (expense), net | $ (2) | $ (1) | $ (5) | $ (5) | |||||
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- Definition The aggregate amount of income or expense from ancillary business-related activities (that is to say, excluding major activities considered part of the normal operations of the business). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items] | ||||
Income tax expense (benefit) | $ 117 | $ 49 | $ 327 | $ 48 |
Effective income tax rate | 27.00% | 15.00% | 30.00% | 8.00% |
Income tax expense from corporate reorganization related to IEnova IPO | $ 63 | |||
Income tax benefit related to life insurance contract holding period | $ 54 | |||
Income tax benefit related to repairs deductions for first and second quarters of 2012 | $ 11 | 0 | ||
Income tax benefit related to repairs deductions for 2011 and first and second quarters of 2012 | 33 | |||
San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items] | ||||
Income tax expense (benefit) | $ 84 | $ 38 | $ 147 | $ 151 |
Effective income tax rate | 38.00% | 17.00% | 33.00% | 27.00% |
Income tax benefit related to repairs deductions for first and second quarters of 2012 | $ 11 | $ 0 | ||
Income tax benefit related to repairs deductions for 2011 and first and second quarters of 2012 | 33 | |||
Southern California Gas Company [Member] | ||||
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items] | ||||
Income tax expense (benefit) | $ 38 | $ 37 | $ 107 | $ 105 |
Effective income tax rate | 27.00% | 34.00% | 29.00% | 35.00% |
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- Definition Income tax benefit related to life insurance contract holding period. No definition available.
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- Definition Income tax benefit related to repairs deductions for 2011 and first and second quarters of 2012. No definition available.
|
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- Definition Income tax benefit related to repairs deductions for first and second quarters of 2012. No definition available.
|
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- References No definition available.
|
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- Definition Income tax expense from corporate reorganization related to IEnova IPO. No definition available.
|
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- Definition A ratio calculated by dividing the reported amount of income tax expense attributable to continuing operations for the period by GAAP-basis pretax income from continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The sum of the current income tax expense or benefit and the deferred income tax expense or benefit pertaining to continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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OTHER FINANCIAL DATA - INVENTORY (Details) - USD ($) $ in Millions |
Sep. 30, 2013 |
Dec. 31, 2012 |
|||
---|---|---|---|---|---|
Inventory [Line Items] | |||||
Energy Related Inventory, Natural Gas in Storage | $ 288 | $ 240 | |||
Energy Related Inventory, Liquefied Natural Gas | 8 | 16 | |||
Energy Related Inventory, Materials And Supplies | 167 | 152 | |||
Inventory, Total | 463 | 408 | [1] | ||
S D G E Segment [Member] | |||||
Inventory [Line Items] | |||||
Energy Related Inventory, Natural Gas in Storage | 5 | 3 | |||
Energy Related Inventory, Liquefied Natural Gas | 0 | 0 | |||
Energy Related Inventory, Materials And Supplies | 73 | 79 | |||
Inventory, Total | 78 | 82 | |||
So Cal Gas Segment [Member] | |||||
Inventory [Line Items] | |||||
Energy Related Inventory, Natural Gas in Storage | 150 | 128 | |||
Energy Related Inventory, Liquefied Natural Gas | 0 | 0 | |||
Energy Related Inventory, Materials And Supplies | 27 | 23 | |||
Inventory, Total | 177 | 151 | |||
Sempra South American Utilities Segment [Member] | |||||
Inventory [Line Items] | |||||
Energy Related Inventory, Natural Gas in Storage | 0 | 0 | |||
Energy Related Inventory, Liquefied Natural Gas | 0 | 0 | |||
Energy Related Inventory, Materials And Supplies | 43 | 34 | |||
Inventory, Total | 43 | 34 | |||
Sempra Mexico Segment [Member] | |||||
Inventory [Line Items] | |||||
Energy Related Inventory, Natural Gas in Storage | 0 | 0 | |||
Energy Related Inventory, Liquefied Natural Gas | 3 | 8 | |||
Energy Related Inventory, Materials And Supplies | 16 | 8 | |||
Inventory, Total | 19 | 16 | |||
Sempra Natural Gas Segment [Member] | |||||
Inventory [Line Items] | |||||
Energy Related Inventory, Natural Gas in Storage | 133 | 109 | |||
Energy Related Inventory, Liquefied Natural Gas | 5 | 8 | |||
Energy Related Inventory, Materials And Supplies | 6 | 5 | |||
Inventory, Total | 144 | 122 | |||
Sempra Renewables Segment [Member] | |||||
Inventory [Line Items] | |||||
Energy Related Inventory, Natural Gas in Storage | 0 | 0 | |||
Energy Related Inventory, Liquefied Natural Gas | 0 | 0 | |||
Energy Related Inventory, Materials And Supplies | 2 | 3 | |||
Inventory, Total | $ 2 | $ 3 | |||
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- Definition Energy related inventory, materials and supplies. No definition available.
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- References No definition available.
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- Definition Carrying amount as of the balance sheet date of natural gas in storage, which is a mixture of gases (liquefied or otherwise), used for fuel and manufacturing purposes, which is ready for sale. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying amount (lower of cost or market) as of the balance sheet date of inventories less all valuation and other allowances. Excludes noncurrent inventory balances (expected to remain on hand past one year or one operating cycle, if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DEBT AND CREDIT FACILITIES (Details) - USD ($) $ in Millions |
Sep. 30, 2013 |
Jun. 30, 2013 |
Dec. 31, 2012 |
---|---|---|---|
Line Of Credit Facility, Sempra Energy Consolidated [Member] | |||
Line of Credit Facility [Line Items] | |||
Committed lines of credit, maximum borrowing capacity | $ 4,100 | ||
Committed lines of credit, remaining borrowing capacity | $ 3,600 | ||
Weighted average interest rate on total short-term debt outstanding | 1.02% | 0.72% | |
Line Of Credit Facility, Sempra Energy [Member] | |||
Line of Credit Facility [Line Items] | |||
Committed lines of credit, maximum borrowing capacity | $ 1,067 | ||
Committed lines of credit, maximum ratio of indebtedness to total capitalization | 65.00% | ||
Committed lines of credit, capacity for issuance of letters of credit | $ 635 | ||
Other instruments supported by committed lines of credit | 12 | ||
Line Of Credit Facility, Sempra Global [Member] | |||
Line of Credit Facility [Line Items] | |||
Committed lines of credit, maximum borrowing capacity | $ 2,189 | ||
Committed lines of credit, maximum ratio of indebtedness to total capitalization | 65.00% | ||
Outstanding commercial paper supported by committed lines of credit | $ 445 | ||
Commercial paper noncurrent | $ 300 | ||
Line Of Credit Facility, S D G E [Member] | |||
Line of Credit Facility [Line Items] | |||
Committed lines of credit, maximum borrowing capacity | $ 658 | ||
Committed lines of credit, maximum ratio of indebtedness to total capitalization | 65.00% | ||
Committed lines of credit, remaining borrowing capacity | $ 658 | ||
Line Of Credit Facility, So Cal Gas [Member] | |||
Line of Credit Facility [Line Items] | |||
Committed lines of credit, maximum borrowing capacity | $ 658 | ||
Committed lines of credit, maximum ratio of indebtedness to total capitalization | 65.00% | ||
Committed lines of credit, remaining borrowing capacity | $ 658 | ||
Line Of Credit Facility, California Utilities Combined [Member] | |||
Line of Credit Facility [Line Items] | |||
Committed lines of credit, maximum borrowing capacity | 877 | ||
Committed lines of credit, capacity for issuance of letters of credit | $ 200 | ||
Line Of Credit Facility, Copper Mountain Solar 2 [Member] | |||
Line of Credit Facility [Line Items] | |||
Committed lines of credit, capacity for issuance of letters of credit | $ 60 |
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- Definition Committed lines of credit, capacity for issuance of letters of credit. No definition available.
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- Definition Committed lines of credit, maximum ratio of indebtedness to total capitalization. No definition available.
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- Definition Other instruments supported by committed lines of credit. No definition available.
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- Definition Carrying value as of the balance sheet date of short-term borrowings using unsecured obligations issued by banks, corporations and other borrowers to investors. The maturities of these money market securities generally do not exceed 270 days. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Carrying value as of the balance sheet date of long-term unsecured obligations issued by corporations and other borrowers to investors (with maturities initially due after one year or beyond the operating cycle if longer), excluding current portion. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
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- Definition Maximum borrowing capacity under the credit facility without consideration of any current restrictions on the amount that could be borrowed or the amounts currently outstanding under the facility. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of borrowing capacity currently available under the credit facility (current borrowing capacity less the amount of borrowings outstanding). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Reflects the calculation as of the balance sheet date of the average interest rate weighted by the amount of short-term debt outstanding by type or by instrument at that time. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DEBT AND CREDIT FACILITIES 2 (Details) - USD ($) $ in Millions |
Sep. 30, 2013 |
Jun. 30, 2013 |
---|---|---|
Sempra Mexico [Member] | ||
Debt Instrument [Line Items] | ||
Debt Proceeds Used For Repayment of Intercompany Debt | $ 357 | |
Other Long Term Debt, Fixed Rate Due 2014 [Member] | Chilquinta Energia [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Face Amount | $ 306 | |
Retired Debt Instrument, Face Amount | $ 86 | |
Retired Debt Instrument, Interest Rate, Stated Percentage | 2.75% | |
Other Long Term Debt, Fixed Rate Due 2014 [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | ||
Debt Instrument [Line Items] | ||
Retired Debt Instrument, Face Amount | $ 115 | |
Retired Debt Instrument, Interest Rate, Stated Percentage | 5.90% | |
Other Long Term Debt, Fixed Rate Due 2021 [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | ||
Debt Instrument [Line Items] | ||
Retired Debt Instrument, Face Amount | $ 60 | |
Retired Debt Instrument, Interest Rate, Stated Percentage | 5.85% | |
Other Long Term Debt, Fixed Rate Due 2023 [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Face Amount | $ 450 | |
Debt Instrument, Interest Rate, Stated Percentage | 3.60% | |
Other Long Term Debt, Fixed Rate Due 2023 [Member] | Sempra Mexico [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 6.30% | |
Debt Instrument, Interest Rate, After Cross Currency Swap | 4.12% | |
Other Long Term Debt, Floating Rate Due 2018 [Member] | Sempra Mexico [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Face Amount | $ 102 | |
Debt Instrument, Interest Rate, Stated Percentage | 2.66% | |
Other Long Term Debt, Variable Rate Due May 2023 [Member] | Copper Mountain Solar 2 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate At Period End | 2.81% | |
Other Long Term Debt, Due May 2023 [Member] | Copper Mountain Solar 2 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Maximum Borrowing Amount | $ 286 | |
Debt Instrument, Outstanding Borrowings | $ 146 | |
Other Long Term Debt, Floating to Fixed Rate Due May 2023 [Member] | Copper Mountain Solar 2 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate, After Floating To Fixed Swap | 5.33% |
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- Definition Debt instrument, interest rate, after floating to fixed swap. No definition available.
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- Definition Debt instrument, maximum borrowing amount. No definition available.
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- Definition Debt instrument, outstanding borrowings. No definition available.
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- Definition Retired debt instrument, face amount. No definition available.
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- Definition Retired debt instrument, interest rate, stated percentage. No definition available.
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- Definition Debt proceeds used for repayment of intercompany debt. No definition available.
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- Definition The stated principal amount of the debt instrument at time of issuance, which may vary from the carrying amount because of unamortized premium or discount. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The effective interest rate at the end of the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Interest rate stated in the contractual debt agreement. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DEBT AND CREDIT FACILITIES 3 (Details) - USD ($) $ in Millions |
3 Months Ended | |||
---|---|---|---|---|
Sep. 30, 2013 |
Jun. 30, 2013 |
Mar. 31, 2013 |
Jun. 30, 2012 |
|
Flat Ridge II [Member] | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Proceeds from return of capital | $ 148 | |||
Liability for guarantee obligation associated with cash flow requirements | 3 | |||
Flat Ridge II [Member] | Term Loan, Due June 2023 [Member] | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Long-term debt outstanding | 242 | |||
Flat Ridge II [Member] | Fixed Rate Note, Due June 2035 [Member] | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Long-term debt outstanding | $ 110 | |||
Mehoopany Wind [Member] | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Proceeds from return of capital | $ 13 | $ 17 | ||
Liability for guarantee obligation associated with cash flow requirements | 11 | |||
Mehoopany Wind [Member] | Term Loan, Due May 2031 [Member] | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Long-term debt outstanding | $ 162 | |||
Mesquite Solar 1 [Member] | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Deconsolidation of debt | $ 297 | |||
Copper Mountain 2 [Member] | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Deconsolidation of debt | $ 146 |
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- Definition Liability for guarantee obligation associated with cash flow requirements. No definition available.
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- Definition Long-term debt outstanding. No definition available.
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- Definition Reduction in Long Term Debt Including Current Portion due to deconsolidation. No definition available.
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- Definition Proceeds from return of capital. No definition available.
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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
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DERIVATIVE FINANCIAL INSTRUMENTS (Details) |
Sep. 30, 2013 |
Dec. 31, 2012 |
|||||
---|---|---|---|---|---|---|---|
S D G E Segment [Member] | |||||||
Schedule Of Commodity Derivative Volumes [Line Items] | |||||||
Commodity derivative volumes, natural gas (in millions of million British thermal units) | [1] | 34 | 25 | ||||
Commodity derivative volumes, congestion revenue rights (in millions of megawatt hours) | [2] | 27 | 30 | ||||
Sempra Mexico Segment [Member] | |||||||
Schedule Of Commodity Derivative Volumes [Line Items] | |||||||
Commodity derivative volumes, natural gas (in millions of million British thermal units) | [1] | 0 | 1 | ||||
Sempra Natural Gas Segment [Member] | |||||||
Schedule Of Commodity Derivative Volumes [Line Items] | |||||||
Commodity derivative volumes, natural gas (in millions of million British thermal units) | [1] | 46 | 36 | ||||
Commodity derivative volumes, electric power (in millions of megawatt hours) | [2] | 2 | 1 | ||||
|
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- Definition Commodity derivative volumes, congestion revenue rights (in millions of megawatt hours). No definition available.
|
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- Definition Commodity derivative volumes, electric power (in millions of megawatt hours). No definition available.
|
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- Definition Commodity derivative volumes, natural gas (in millions of million British thermal units). No definition available.
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- References No definition available.
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DERIVATIVE FINANCIAL INSTRUMENTS 2 (Details) - USD ($) $ in Millions |
3 Months Ended | 12 Months Ended | |||
---|---|---|---|---|---|
Sep. 30, 2013 |
Dec. 31, 2012 |
||||
Cash Flow Hedges | |||||
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items] | |||||
Notional Amount of Interest Rate Derivatives | [1] | $ 419 | $ 439 | ||
Cash Flow Hedges | Maximum [Member] | |||||
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items] | |||||
Maturities of interest rate derivatives | [1] | 2028 | 2028 | ||
Cash Flow Hedges | Minimum [Member] | |||||
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items] | |||||
Maturities of interest rate derivatives | [1] | 2013 | 2013 | ||
Fair Value Hedges | |||||
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items] | |||||
Notional Amount of Interest Rate Derivatives | $ 500 | $ 500 | |||
Fair Value Hedges | Maximum [Member] | |||||
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items] | |||||
Maturities of interest rate derivatives | 2016 | 2016 | |||
Fair Value Hedges | Minimum [Member] | |||||
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items] | |||||
Maturities of interest rate derivatives | 2013 | 2013 | |||
San Diego Gas and Electric Company and Subsidiary [Member] | Cash Flow Hedges | |||||
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items] | |||||
Notional Amount of Interest Rate Derivatives | [1] | $ 337 | $ 345 | ||
Maturities of interest rate derivatives | [1] | 2019 | 2019 | ||
|
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- Definition Maturities of interest rate derivatives. No definition available.
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- References No definition available.
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- Definition Aggregate notional amount of interest rate derivatives, which relates to the currency amount specified in the interest rate derivative instruments. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DERIVATIVE FINANCIAL INSTRUMENTS 3 (Details) - USD ($) $ in Millions |
Sep. 30, 2013 |
Dec. 31, 2012 |
|||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Fixed Price Contracts And Other Derivatives, Current Assets [Member] | |||||||||||||
Derivative Instruments in Hedges, at Fair Value, Net [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | [1] | $ 15 | $ 7 | ||||||||||
Commodity contracts not subject to rate recovery | 5 | 1 | |||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | 9 | 8 | |||||||||||
Commodity contracts not subject to rate recovery | 67 | 117 | |||||||||||
Associated offsetting commodity contracts not subject to rate recovery | (55) | (102) | |||||||||||
Associated cash collateral commodity contracts not subject to rate recovery | 0 | 0 | |||||||||||
Commodity contracts subject to rate recovery | 6 | 30 | |||||||||||
Associated cash collateral commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | (2) | (4) | |||||||||||
Net amount presented on balance sheet | 45 | 57 | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | 14 | 22 | |||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 17 | 13 | |||||||||||
Total | 76 | 92 | |||||||||||
Fixed Price Contracts And Other Derivatives, Current Assets [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||||||
Derivative Instruments in Hedges, at Fair Value, Net [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | [1] | 0 | 0 | ||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Commodity contracts subject to rate recovery | 5 | 28 | |||||||||||
Associated cash collateral commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | (1) | (3) | |||||||||||
Net amount presented on balance sheet | 4 | 25 | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | [2] | 2 | 1 | ||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 15 | 12 | |||||||||||
Total | 21 | 38 | |||||||||||
Fixed Price Contracts And Other Derivatives, Current Assets [Member] | Southern California Gas Company [Member] | |||||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Commodity contracts subject to rate recovery | [3] | 1 | 2 | ||||||||||
Associated offsetting commodity contracts subject to rate recovery | [3] | (1) | (1) | ||||||||||
Net amount presented on balance sheet | [3] | 0 | 1 | ||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | [2],[3] | 3 | 2 | ||||||||||
Additional margin posted for commodity contracts subject to rate recovery | [3] | 2 | 1 | ||||||||||
Total | [3] | 5 | 4 | ||||||||||
Fixed Price Contracts And Other Derivatives, Noncurrent Assets [Member] | |||||||||||||
Derivative Instruments in Hedges, at Fair Value, Net [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | [1] | 13 | 12 | ||||||||||
Commodity contracts not subject to rate recovery | 0 | 0 | |||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | 26 | 40 | |||||||||||
Commodity contracts not subject to rate recovery | 11 | 15 | |||||||||||
Associated offsetting commodity contracts not subject to rate recovery | (8) | (12) | |||||||||||
Associated cash collateral commodity contracts not subject to rate recovery | 0 | 0 | |||||||||||
Commodity contracts subject to rate recovery | 49 | 35 | |||||||||||
Associated cash collateral commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | (1) | 0 | |||||||||||
Net amount presented on balance sheet | 90 | 90 | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | 0 | 0 | |||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Total | 90 | 90 | |||||||||||
Fixed Price Contracts And Other Derivatives, Noncurrent Assets [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||||||
Derivative Instruments in Hedges, at Fair Value, Net [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | [1] | 0 | 0 | ||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Commodity contracts subject to rate recovery | 49 | 35 | |||||||||||
Associated cash collateral commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | (1) | 0 | |||||||||||
Net amount presented on balance sheet | 48 | 35 | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | [2] | 0 | 0 | ||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Total | 48 | 35 | |||||||||||
Fixed Price Contracts And Other Derivatives, Noncurrent Assets [Member] | Southern California Gas Company [Member] | |||||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Net amount presented on balance sheet | 0 | 0 | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | [2] | 0 | 0 | ||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Total | 0 | 0 | |||||||||||
Fixed Price Contracts And Other Derivatives, Current Liabilities [Member] | |||||||||||||
Derivative Instruments in Hedges, at Fair Value, Net [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | [1] | (19) | (19) | ||||||||||
Commodity contracts not subject to rate recovery | 0 | 0 | |||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | (7) | (8) | |||||||||||
Commodity contracts not subject to rate recovery | (70) | (116) | |||||||||||
Associated offsetting commodity contracts not subject to rate recovery | 55 | 102 | |||||||||||
Associated cash collateral commodity contracts not subject to rate recovery | 6 | 4 | |||||||||||
Commodity contracts subject to rate recovery | (23) | (35) | |||||||||||
Associated cash collateral commodity contracts subject to rate recovery | 12 | 22 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | 2 | 4 | |||||||||||
Net amount presented on balance sheet | (44) | (46) | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | 0 | 0 | |||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Total | (44) | (46) | |||||||||||
Fixed Price Contracts And Other Derivatives, Current Liabilities [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||||||
Derivative Instruments in Hedges, at Fair Value, Net [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | [1] | (16) | (17) | ||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Commodity contracts subject to rate recovery | (22) | (33) | |||||||||||
Associated cash collateral commodity contracts subject to rate recovery | 12 | 22 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | 1 | 3 | |||||||||||
Net amount presented on balance sheet | (25) | (25) | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | [2] | 0 | 0 | ||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Total | (25) | (25) | |||||||||||
Fixed Price Contracts And Other Derivatives, Current Liabilities [Member] | Southern California Gas Company [Member] | |||||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Commodity contracts subject to rate recovery | [4] | (1) | (2) | ||||||||||
Associated offsetting commodity contracts subject to rate recovery | [4] | 1 | 1 | ||||||||||
Net amount presented on balance sheet | [4] | 0 | (1) | ||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | [4] | 0 | 0 | [2] | |||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | [4] | 0 | [2] | |||||||||
Total | [4] | 0 | (1) | ||||||||||
Fixed Price Contracts And Other Derivatives, Noncurrent Liabilities [Member] | |||||||||||||
Derivative Instruments in Hedges, at Fair Value, Net [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | [1] | (77) | (64) | ||||||||||
Commodity contracts not subject to rate recovery | 0 | 0 | |||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | (21) | (35) | |||||||||||
Commodity contracts not subject to rate recovery | (10) | (27) | |||||||||||
Associated offsetting commodity contracts not subject to rate recovery | 8 | 12 | |||||||||||
Associated cash collateral commodity contracts not subject to rate recovery | 1 | 7 | |||||||||||
Commodity contracts subject to rate recovery | (8) | (1) | |||||||||||
Associated cash collateral commodity contracts subject to rate recovery | 1 | 1 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | 1 | 0 | |||||||||||
Net amount presented on balance sheet | (105) | (107) | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | 0 | 0 | |||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Total | (105) | (107) | |||||||||||
Fixed Price Contracts And Other Derivatives, Noncurrent Liabilities [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||||||
Derivative Instruments in Hedges, at Fair Value, Net [Abstract] | |||||||||||||
Interest rate and foreign exchange instruments | [1] | (43) | (64) | ||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Commodity contracts subject to rate recovery | (8) | (1) | |||||||||||
Associated cash collateral commodity contracts subject to rate recovery | 1 | 1 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | 1 | 0 | |||||||||||
Net amount presented on balance sheet | (49) | (64) | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | [2] | 0 | 0 | ||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Total | (49) | (64) | |||||||||||
Fixed Price Contracts And Other Derivatives, Noncurrent Liabilities [Member] | Southern California Gas Company [Member] | |||||||||||||
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract] | |||||||||||||
Commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Associated offsetting commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Net amount presented on balance sheet | 0 | 0 | |||||||||||
Additional margin posted for commodity contracts not subject to rate recovery | [2] | 0 | 0 | ||||||||||
Additional margin posted for commodity contracts subject to rate recovery | 0 | 0 | |||||||||||
Total | $ 0 | $ 0 | |||||||||||
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- Definition Additional margin posted for commodity contracts not subject to rate recovery. No definition available.
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- Definition Additional margin posted for commodity contracts subject to rate recovery. No definition available.
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- Definition Derivative commodity contracts not subject to rate recovery. No definition available.
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- Definition Derivative commodity contracts not subject to rate recovery, nondesignated. No definition available.
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- Definition Derivative commodity contracts subject to rate recovery, nondesignated. No definition available.
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- Definition Interest rate instruments designated as hedging instruments. No definition available.
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- Definition Interest rate instruments not designated as hedging instruments. No definition available.
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- Definition Associated offsetting commodity contracts not subject to rate recovery. No definition available.
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- Definition Associated cash collateral commodity contracts subject to rate recovery. No definition available.
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- Definition Other derivatives as hedging instruments at fair value net before cash collateral. No definition available.
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- Definition Aggregate net fair value of all derivative instruments designated as hedging instruments. Includes instruments designated as cash flow hedges, fair value hedges, and hedges of net investments in foreign operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DERIVATIVE FINANCIAL INSTRUMENTS 4 (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||||
---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
||||||
Cash Flow Hedges | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion) | $ (10) | $ (15) | $ 13 | $ (36) | |||||
Gain (loss) reclassified from AOCI into earnings (effective portion) | (6) | (7) | (11) | (9) | |||||
Cash Flow Hedges | Interest Expense | Interest Rate And Foreign Exchange Instruments [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion) | [1] | (8) | (6) | (3) | (21) | ||||
Gain (loss) reclassified from AOCI into earnings (effective portion) | [1] | (3) | (3) | (9) | (5) | ||||
Cash Flow Hedges | Interest Expense | Interest Rate Instruments | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion) | [1] | (3) | (6) | 8 | (16) | ||||
Gain (loss) reclassified from AOCI into earnings (effective portion) | [1] | (2) | (2) | (6) | (3) | ||||
Cash Flow Hedges | Interest Expense | Interest Rate Instruments | Southern California Gas Company [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion) | 0 | 0 | 0 | 0 | |||||
Gain (loss) reclassified from AOCI into earnings (effective portion) | 0 | (1) | (1) | (2) | |||||
Cash Flow Hedges | Equity Earnings Before Income Tax [Member] | Interest Rate Instruments | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion) | (3) | (6) | 11 | (12) | |||||
Gain (loss) reclassified from AOCI into earnings (effective portion) | (3) | (4) | (7) | (4) | |||||
Cash Flow Hedges | Cost of Natural Gas, Electric Fuel and Purchased Power [Member] | Commodity Contracts Not Subject To Rate Recovery | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion) | 1 | (3) | 5 | (3) | |||||
Gain (loss) reclassified from AOCI into earnings (effective portion) | 0 | 0 | 5 | 0 | |||||
Fair Value Hedges | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | [2] | 3 | 5 | 2 | 11 | ||||
Fair Value Hedges | Interest Expense | Interest Rate Instruments | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 2 | 1 | 6 | 5 | |||||
Fair Value Hedges | Other Income, Net | Interest Rate Instruments | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 1 | 4 | (4) | 6 | |||||
Undesignated Derivatives | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 6 | 38 | 7 | 40 | |||||
Undesignated Derivatives | Southern California Gas Company [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 1 | 1 | 0 | 0 | |||||
Undesignated Derivatives | Other Income, Net | Interest Rate And Foreign Exchange Instruments [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 4 | 1 | 17 | 11 | |||||
Undesignated Derivatives | Equity Earnings Net Of Income Tax [Member] | Interest Rate And Foreign Exchange Instruments [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 0 | 0 | (3) | 0 | |||||
Undesignated Derivatives | Revenues: Energy-Related Businesses [Member] | Commodity Contracts Not Subject To Rate Recovery | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 1 | (5) | 2 | (3) | |||||
Undesignated Derivatives | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 0 | 41 | (9) | 32 | |||||
Undesignated Derivatives | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 0 | 41 | (9) | 32 | |||||
Undesignated Derivatives | Other Operation And Maintenance [Member] | Commodity Contracts Not Subject To Rate Recovery | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 0 | 1 | 0 | 1 | |||||
Undesignated Derivatives | Other Operation And Maintenance [Member] | Commodity Contracts Not Subject To Rate Recovery | Southern California Gas Company [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 0 | 1 | 0 | 1 | |||||
Undesignated Derivatives | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | 1 | 0 | 0 | (1) | |||||
Undesignated Derivatives | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member] | Southern California Gas Company [Member] | |||||||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||||||
Gain (loss) on derivative recognized in earnings | $ 1 | $ 0 | $ 0 | $ (1) | |||||
|
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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
|
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- Definition The effective portion of net gain (loss) reclassified from accumulated other comprehensive income into income on derivative instruments designated and qualifying as hedging instruments. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition The amount of net gains and losses recognized in income during the period on derivative instruments designated and qualifying as hedging instruments in fair value hedges and related hedged items designated and qualifying in fair value hedges, on derivative instruments designated and qualifying as hedging instruments in cash flow hedges, and on derivative instruments not designated as hedging instruments. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition The effective portion of gains and losses (net) on derivative instruments designated and qualifying as hedging instruments that was recognized in other comprehensive income during the current period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DERIVATIVE FINANCIAL INSTRUMENTS 5 (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Cash Flow Hedge Disclosure [Line Items] | ||||
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months | $ (22) | |||
Maximum length of time hedged in cash flow hedge | 15 | |||
Joint Venture Maximum Length Of Time Hedged In Cash Flow Hedge | 22 | |||
Cash flow hedge ineffectiveness | $ 0 | $ 1 | $ 1 | $ 1 |
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest | $ (11) | |||
San Diego Gas and Electric Company and Subsidiary [Member] | ||||
Cash Flow Hedge Disclosure [Line Items] | ||||
Maximum length of time hedged in cash flow hedge | 6 | |||
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest | $ (10) | |||
Southern California Gas Company [Member] | ||||
Cash Flow Hedge Disclosure [Line Items] | ||||
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months | $ (1) |
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- References No definition available.
|
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- Definition Cash flow hedge gain (loss) to be reclassified within twelve months for noncontrolling interest. No definition available.
|
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- Definition Cash flow hedge ineffectiveness. No definition available.
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- Definition Joint venture maximum length time hedged In cash flow hedge. No definition available.
|
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- Definition Maximum length of time hedged in cash flow hedge. No definition available.
|
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- Definition The estimated net amount of existing gains or losses on cash flow hedges at the reporting date expected to be reclassified to earnings within the next 12 months. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DERIVATIVE FINANCIAL INSTRUMENTS 6 (Details) - USD ($) $ in Millions |
Sep. 30, 2013 |
Dec. 31, 2012 |
---|---|---|
Derivative Credit Risk Related Contingent Features [Line Items] | ||
Derivative, Net Liability Position, Aggregate Fair Value | $ 3 | $ 8 |
Additional Collateral Aggregate Fair Value | 3 | |
San Diego Gas and Electric Company and Subsidiary [Member] | ||
Derivative Credit Risk Related Contingent Features [Line Items] | ||
Derivative, Net Liability Position, Aggregate Fair Value | 2 | $ 6 |
Additional Collateral Aggregate Fair Value | $ 2 |
X | ||||||||||
- References No definition available.
|
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- Definition The aggregate fair value of additional assets that would be required to be posted as collateral for derivative instruments with credit-risk-related contingent features if the credit-risk-related contingent features were triggered at the end of the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition The aggregate fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability position at the end of the reporting period. For nonderivative instruments that are designated and qualify as hedging instruments, the fair value amounts are the carrying value of the nonderivative hedging instrument, including the adjustment for the foreign currency transaction gain (loss) on that instrument. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
Dec. 31, 2012 |
|||||||||
Schedule of Available-for-sale Securities [Line Items] | |||||||||||||
Cost | $ 609 | $ 609 | $ 594 | ||||||||||
Gross unrealized gains | 380 | 380 | 317 | ||||||||||
Gross unrealized losses | (8) | (8) | (3) | ||||||||||
Estimated fair value | 981 | 981 | 908 | ||||||||||
Proceeds from sales | 181 | $ 204 | 507 | $ 524 | |||||||||
Gross realized gains | 2 | 3 | 13 | 12 | |||||||||
Gross realized losses | 8 | $ 1 | 15 | $ 6 | |||||||||
Total Debt Securities | |||||||||||||
Schedule of Available-for-sale Securities [Line Items] | |||||||||||||
Cost | 367 | 367 | 325 | ||||||||||
Gross unrealized gains | 10 | 10 | 25 | ||||||||||
Gross unrealized losses | (6) | (6) | (1) | ||||||||||
Estimated fair value | 371 | 371 | 349 | ||||||||||
Debt Securities Issued By The U.S. Treasury And Other U.S. Government Corporations And Agencies | |||||||||||||
Schedule of Available-for-sale Securities [Line Items] | |||||||||||||
Cost | 130 | [1] | 130 | [1] | 147 | ||||||||
Gross unrealized gains | 4 | [1] | 4 | [1] | 9 | ||||||||
Gross unrealized losses | (1) | [1] | (1) | [1] | 0 | ||||||||
Estimated fair value | 133 | [1] | 133 | [1] | 156 | ||||||||
Municipal Bonds | |||||||||||||
Schedule of Available-for-sale Securities [Line Items] | |||||||||||||
Cost | 102 | [2] | 102 | [2] | 57 | ||||||||
Gross unrealized gains | 3 | [2] | 3 | [2] | 6 | ||||||||
Gross unrealized losses | (1) | [2] | (1) | [2] | 0 | ||||||||
Estimated fair value | 104 | [2] | 104 | [2] | 63 | ||||||||
Other Debt Securities | |||||||||||||
Schedule of Available-for-sale Securities [Line Items] | |||||||||||||
Cost | 135 | [3] | 135 | [3] | 121 | ||||||||
Gross unrealized gains | 3 | [3] | 3 | [3] | 10 | ||||||||
Gross unrealized losses | (4) | [3] | (4) | [3] | (1) | ||||||||
Estimated fair value | 134 | [3] | 134 | [3] | 130 | ||||||||
Equity Securities | |||||||||||||
Schedule of Available-for-sale Securities [Line Items] | |||||||||||||
Cost | 231 | 231 | 249 | ||||||||||
Gross unrealized gains | 370 | 370 | 292 | ||||||||||
Gross unrealized losses | (2) | (2) | (2) | ||||||||||
Estimated fair value | 599 | 599 | 539 | ||||||||||
Cash And Cash Equivalents | |||||||||||||
Schedule of Available-for-sale Securities [Line Items] | |||||||||||||
Cost | 11 | 11 | 20 | ||||||||||
Gross unrealized gains | 0 | 0 | 0 | ||||||||||
Gross unrealized losses | 0 | 0 | 0 | ||||||||||
Estimated fair value | $ 11 | $ 11 | $ 20 | ||||||||||
|
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- Definition Amount of investment in debt and equity securities categorized neither as held-to-maturity nor trading. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition This item represents the cost of debt and equity securities, which are categorized neither as held-to-maturity nor trading, net of adjustments including accretion, amortization, collection of cash, previous other-than-temporary impairments recognized in earnings (less any cumulative-effect adjustments recognized, as defined), and fair value hedge accounting adjustments, if any. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition This item represents the gross profit realized on the sale of debt or equity securities categorized neither as held-to-maturity nor trading securities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The total amount of proceeds received for the sale of securities, categorized neither as held-to-maturity nor trading securities, during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition This item represents the gross loss realized on the sale of debt or equity securities categorized neither as held-to-maturity nor trading securities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
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- Definition This item represents the gross unrealized losses for securities, at a point in time, which are categorized neither as held-to-maturity nor trading securities. No definition available.
|
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- Definition This item represents the gross unrealized gains for securities, at a point in time, which are categorized neither as held-to-maturity nor trading securities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
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FAIR VALUE MEASUREMENTS 3 (Details) - USD ($) $ in Millions |
Sep. 30, 2013 |
Dec. 31, 2012 |
|||
---|---|---|---|---|---|
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | $ 599 | $ 539 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 133 | 156 | |||
Nuclear decomissioning trusts - Municipal debt securities | 104 | 63 | |||
Nuclear decommissioning trusts - Other debt securities | 134 | 130 | |||
Nuclear decommissioning trusts - Total debt securities | 371 | 349 | |||
Total nuclear decommissioning trusts | [1] | 970 | 888 | ||
Interest rate instruments, assets | 63 | 68 | |||
Commodity contracts subject to rate recovery, assets | 69 | 74 | |||
Commodity contracts not subject to rate recovery, assets | 34 | 43 | |||
Investments | 1 | ||||
Total fair value of assets measured on a recurring basis | 1,136 | 1,074 | |||
Interest rate instruments, liabilities | 124 | 126 | |||
Commodity contracts subject to rate recovery, liabilities | 15 | 9 | |||
Commodity contracts not subject to rate recovery, liabilities | 10 | 18 | |||
Total fair value of liabilities measured on a recurring basis | 149 | 153 | |||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 599 | 539 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 133 | 156 | |||
Nuclear decomissioning trusts - Municipal debt securities | 104 | 63 | |||
Nuclear decommissioning trusts - Other debt securities | 134 | 130 | |||
Nuclear decommissioning trusts - Total debt securities | 371 | 349 | |||
Total nuclear decommissioning trusts | [1] | 970 | 888 | ||
Commodity contracts subject to rate recovery, assets | 67 | 73 | |||
Commodity contracts not subject to rate recovery, assets | 2 | 1 | |||
Total fair value of assets measured on a recurring basis | 1,039 | 962 | |||
Interest rate instruments, liabilities | 59 | 81 | |||
Commodity contracts subject to rate recovery, liabilities | 15 | 8 | |||
Total fair value of liabilities measured on a recurring basis | 74 | 89 | |||
Southern California Gas Company [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Commodity contracts subject to rate recovery, assets | 2 | 1 | |||
Commodity contracts not subject to rate recovery, assets | 3 | 3 | |||
Total fair value of assets measured on a recurring basis | 5 | 4 | |||
Commodity contracts subject to rate recovery, liabilities | 1 | ||||
Total fair value of liabilities measured on a recurring basis | 1 | ||||
Level 1 | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 599 | 539 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 77 | 87 | |||
Nuclear decomissioning trusts - Municipal debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Other debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Total debt securities | 77 | 87 | |||
Total nuclear decommissioning trusts | [1] | 676 | 626 | ||
Interest rate instruments, assets | 0 | 0 | |||
Commodity contracts subject to rate recovery, assets | 12 | 13 | |||
Commodity contracts not subject to rate recovery, assets | 22 | 28 | |||
Investments | 1 | ||||
Total fair value of assets measured on a recurring basis | 710 | 668 | |||
Interest rate instruments, liabilities | 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | 13 | 23 | |||
Commodity contracts not subject to rate recovery, liabilities | 2 | 6 | |||
Total fair value of liabilities measured on a recurring basis | 15 | 29 | |||
Level 1 | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 599 | 539 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 77 | 87 | |||
Nuclear decomissioning trusts - Municipal debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Other debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Total debt securities | 77 | 87 | |||
Total nuclear decommissioning trusts | [1] | 676 | 626 | ||
Commodity contracts subject to rate recovery, assets | 10 | 12 | |||
Commodity contracts not subject to rate recovery, assets | 2 | 1 | |||
Total fair value of assets measured on a recurring basis | 688 | 639 | |||
Interest rate instruments, liabilities | 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | 13 | 23 | |||
Total fair value of liabilities measured on a recurring basis | 13 | 23 | |||
Level 1 | Southern California Gas Company [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Commodity contracts subject to rate recovery, assets | 2 | 1 | |||
Commodity contracts not subject to rate recovery, assets | 3 | 3 | |||
Total fair value of assets measured on a recurring basis | 5 | 4 | |||
Commodity contracts subject to rate recovery, liabilities | 0 | ||||
Total fair value of liabilities measured on a recurring basis | 0 | ||||
Level 2 | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 0 | 0 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 56 | 69 | |||
Nuclear decomissioning trusts - Municipal debt securities | 104 | 63 | |||
Nuclear decommissioning trusts - Other debt securities | 134 | 130 | |||
Nuclear decommissioning trusts - Total debt securities | 294 | 262 | |||
Total nuclear decommissioning trusts | [1] | 294 | 262 | ||
Interest rate instruments, assets | 63 | 68 | |||
Commodity contracts subject to rate recovery, assets | 0 | 0 | |||
Commodity contracts not subject to rate recovery, assets | 12 | 15 | |||
Investments | 0 | ||||
Total fair value of assets measured on a recurring basis | 369 | 345 | |||
Interest rate instruments, liabilities | 124 | 126 | |||
Commodity contracts subject to rate recovery, liabilities | 15 | 9 | |||
Commodity contracts not subject to rate recovery, liabilities | 15 | 23 | |||
Total fair value of liabilities measured on a recurring basis | 154 | 158 | |||
Level 2 | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 0 | 0 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 56 | 69 | |||
Nuclear decomissioning trusts - Municipal debt securities | 104 | 63 | |||
Nuclear decommissioning trusts - Other debt securities | 134 | 130 | |||
Nuclear decommissioning trusts - Total debt securities | 294 | 262 | |||
Total nuclear decommissioning trusts | [1] | 294 | 262 | ||
Commodity contracts subject to rate recovery, assets | 0 | 0 | |||
Commodity contracts not subject to rate recovery, assets | 0 | 0 | |||
Total fair value of assets measured on a recurring basis | 294 | 262 | |||
Interest rate instruments, liabilities | 59 | 81 | |||
Commodity contracts subject to rate recovery, liabilities | 15 | 8 | |||
Total fair value of liabilities measured on a recurring basis | 74 | 89 | |||
Level 2 | Southern California Gas Company [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Commodity contracts subject to rate recovery, assets | 0 | 0 | |||
Commodity contracts not subject to rate recovery, assets | 0 | 0 | |||
Total fair value of assets measured on a recurring basis | 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | 1 | ||||
Total fair value of liabilities measured on a recurring basis | 1 | ||||
Level 3 | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 0 | 0 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 0 | 0 | |||
Nuclear decomissioning trusts - Municipal debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Other debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Total debt securities | 0 | 0 | |||
Total nuclear decommissioning trusts | [1] | 0 | 0 | ||
Interest rate instruments, assets | 0 | 0 | |||
Commodity contracts subject to rate recovery, assets | 57 | 61 | |||
Commodity contracts not subject to rate recovery, assets | 0 | 0 | |||
Investments | 0 | ||||
Total fair value of assets measured on a recurring basis | 57 | 61 | |||
Interest rate instruments, liabilities | 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | 0 | 0 | |||
Commodity contracts not subject to rate recovery, liabilities | 0 | 0 | |||
Total fair value of liabilities measured on a recurring basis | 0 | 0 | |||
Level 3 | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 0 | 0 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 0 | 0 | |||
Nuclear decomissioning trusts - Municipal debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Other debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Total debt securities | 0 | 0 | |||
Total nuclear decommissioning trusts | [1] | 0 | 0 | ||
Commodity contracts subject to rate recovery, assets | 57 | 61 | |||
Commodity contracts not subject to rate recovery, assets | 0 | 0 | |||
Total fair value of assets measured on a recurring basis | 57 | 61 | |||
Interest rate instruments, liabilities | 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | 0 | 0 | |||
Total fair value of liabilities measured on a recurring basis | 0 | 0 | |||
Level 3 | Southern California Gas Company [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Commodity contracts subject to rate recovery, assets | 0 | 0 | |||
Commodity contracts not subject to rate recovery, assets | 0 | 0 | |||
Total fair value of assets measured on a recurring basis | 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | 0 | ||||
Total fair value of liabilities measured on a recurring basis | 0 | ||||
Collateral Netted [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 0 | 0 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 0 | 0 | |||
Nuclear decomissioning trusts - Municipal debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Other debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Total debt securities | 0 | 0 | |||
Total nuclear decommissioning trusts | [1] | 0 | 0 | ||
Interest rate instruments, assets | 0 | 0 | |||
Commodity contracts subject to rate recovery, assets | 0 | 0 | |||
Commodity contracts not subject to rate recovery, assets | 0 | 0 | |||
Investments | 0 | ||||
Total fair value of assets measured on a recurring basis | 0 | 0 | |||
Interest rate instruments, liabilities | 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | (13) | (23) | |||
Commodity contracts not subject to rate recovery, liabilities | (7) | (11) | |||
Total fair value of liabilities measured on a recurring basis | (20) | (34) | |||
Collateral Netted [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Nuclear decommissioning trusts - equity securities | 0 | 0 | |||
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies | 0 | 0 | |||
Nuclear decomissioning trusts - Municipal debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Other debt securities | 0 | 0 | |||
Nuclear decommissioning trusts - Total debt securities | 0 | 0 | |||
Total nuclear decommissioning trusts | [1] | 0 | 0 | ||
Commodity contracts subject to rate recovery, assets | 0 | 0 | |||
Commodity contracts not subject to rate recovery, assets | 0 | 0 | |||
Total fair value of assets measured on a recurring basis | 0 | 0 | |||
Interest rate instruments, liabilities | 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | (13) | (23) | |||
Total fair value of liabilities measured on a recurring basis | (13) | (23) | |||
Collateral Netted [Member] | Southern California Gas Company [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Commodity contracts subject to rate recovery, assets | 0 | 0 | |||
Commodity contracts not subject to rate recovery, assets | 0 | 0 | |||
Total fair value of assets measured on a recurring basis | $ 0 | 0 | |||
Commodity contracts subject to rate recovery, liabilities | 0 | ||||
Total fair value of liabilities measured on a recurring basis | $ 0 | ||||
|
X | ||||||||||
- Definition Fair value assets measured on a recurring basis commodity contracts not subject to rate recovery. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Fair value assets measured on a recurring basis nuclear decommissioning trusts, interest rate instruments. No definition available.
|
X | ||||||||||
- Definition Fair value assets measured on a recurring basis nuclear decommissioning trusts, equity securities. No definition available.
|
X | ||||||||||
- Definition Fair value assets measured on a recurring basis nuclear decommissioning trusts, municipal debt securities. No definition available.
|
X | ||||||||||
- Definition Fair value assets measured on a recurring basis nuclear decommissioning trusts, other debt securities. No definition available.
|
X | ||||||||||
- Definition Fair value assets measured on a recurring basis nuclear decommissioning trusts, total. No definition available.
|
X | ||||||||||
- Definition Fair value assets measured on a recurring basis nuclear decommissioning trusts, total debt securities. No definition available.
|
X | ||||||||||
- Definition Fair value assets measured on a recurring basis nuclear decommissioning trusts, U.S. debt securities. No definition available.
|
X | ||||||||||
- Definition Total fair value of assets measured on a recurring basis. No definition available.
|
X | ||||||||||
- Definition Fair value liabilities measured on a recurring basis, commodity contracts not subject to rate recovery. No definition available.
|
X | ||||||||||
- Definition Fair value liabilities measured on a recurring basis, commodity contracts subject to rate recovery. No definition available.
|
X | ||||||||||
- Definition Total fair value of liabilities measured on a recurring basis, interest rate instruments. No definition available.
|
X | ||||||||||
- Definition Total fair value of liabilities measured on a recurring basis. No definition available.
|
X | ||||||||||
- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
|
X | ||||||||||
- Definition This element represents the portion of the balance sheet assertion valued at fair value by the entity whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. This item represents investment securities as of the balance sheet date which may include marketable securities, derivative financial instruments, and investments accounted for under the equity method. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Details
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FAIR VALUE MEASUREMENTS 4 (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
|
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Balance at beginning of period | $ 47 | $ 13 | $ 61 | $ 23 |
Realized and unrealized gains (losses) | 1 | 16 | (2) | 23 |
Allocated transmission instruments | 15 | 17 | 15 | 18 |
Settlements | (6) | (23) | (17) | (41) |
Balance at end of period | 57 | 23 | 57 | 23 |
Change in unrealized gains (losses) relating to instruments still held at period end | 2 | 0 | 1 | 0 |
CRR Auction Rate Per MWh, Minimum | (8) | (3) | (8) | (3) |
CRR Auction Rate Per MWh, Maximum | $ 8 | $ 5 | $ 8 | $ 5 |
X | ||||||||||
- Definition CRR auction rate per MWh, maximum. No definition available.
|
X | ||||||||||
- Definition CRR auction rate per MWh, minimum. No definition available.
|
X | ||||||||||
- Definition Change in unrealized gains (losses) relating to instruments still held at period end. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition A roll forward is a reconciliation of a concept from the beginning of a period to the end of a period. No definition available.
|
X | ||||||||||
- Definition Amount of gain (loss) recognized in earnings, arising from assets measured at fair value on a recurring basis using unobservable inputs (level 3). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Settlements that have taken place during the period in relation to assets measured at fair value and categorized within Level 3 of the fair value hierarchy. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition This element represents an asset measured at fair value using significant unobservable inputs (Level 3) which is required for reconciliation purposes of beginning and ending balances. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
FAIR VALUE MEASUREMENTS 5 (Details) - USD ($) $ in Millions |
Sep. 30, 2013 |
Dec. 31, 2012 |
||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | $ 1 | |||||||||||||||
Level 1 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | 1 | |||||||||||||||
Level 2 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | 0 | |||||||||||||||
Level 3 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | 0 | |||||||||||||||
Collateral Netted [Member] | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | 0 | |||||||||||||||
San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Preferred stock pending redemption | $ 82 | 0 | [1] | |||||||||||||
Carrying Amount | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | [2] | 12 | ||||||||||||||
Fair value of financial instruments, Total long-term debt | [3] | 11,750 | 11,873 | |||||||||||||
Preferred Stock Of Subsidiaries Fair Value Disclosure | 20 | 99 | ||||||||||||||
Debt Instrument Unamortized Discount | 15 | 16 | ||||||||||||||
Capital Lease Obligations | 184 | 189 | ||||||||||||||
Commercial Paper Noncurrent | 300 | |||||||||||||||
Carrying Amount | San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [4] | 4,402 | 4,135 | |||||||||||||
Contingently Redeemable Preferred Stock Fair Value Disclosure | [5] | 79 | ||||||||||||||
Debt Instrument Unamortized Discount | 11 | 12 | ||||||||||||||
Capital Lease Obligations | 181 | 185 | ||||||||||||||
Carrying Amount | Southern California Gas Company [Member] | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [6] | 1,413 | 1,413 | |||||||||||||
Preferred Stock Fair Value Disclosure | 22 | 22 | ||||||||||||||
Debt Instrument Unamortized Discount | 4 | 4 | ||||||||||||||
Capital Lease Obligations | 2 | 4 | ||||||||||||||
Fair Value | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | [2] | 36 | ||||||||||||||
Fair value of financial instruments, Total long-term debt | [3] | 12,563 | 13,243 | |||||||||||||
Preferred Stock Of Subsidiaries Fair Value Disclosure | 21 | 107 | ||||||||||||||
Fair Value | Level 1 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | [2] | 0 | ||||||||||||||
Fair value of financial instruments, Total long-term debt | [3] | 0 | 0 | |||||||||||||
Preferred Stock Of Subsidiaries Fair Value Disclosure | 0 | 0 | ||||||||||||||
Fair Value | Level 2 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | [2] | 0 | ||||||||||||||
Fair value of financial instruments, Total long-term debt | [3] | 11,818 | 12,287 | |||||||||||||
Preferred Stock Of Subsidiaries Fair Value Disclosure | 21 | 107 | ||||||||||||||
Fair Value | Level 3 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Investments, Fair Value Disclosure | [2] | 36 | ||||||||||||||
Fair value of financial instruments, Total long-term debt | [3] | 745 | 956 | |||||||||||||
Preferred Stock Of Subsidiaries Fair Value Disclosure | 0 | 0 | ||||||||||||||
Fair Value | San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [4] | 4,662 | 4,588 | |||||||||||||
Contingently Redeemable Preferred Stock Fair Value Disclosure | [5] | 85 | ||||||||||||||
Fair Value | San Diego Gas and Electric Company and Subsidiary [Member] | Level 1 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [4] | 0 | 0 | |||||||||||||
Contingently Redeemable Preferred Stock Fair Value Disclosure | [5] | 0 | ||||||||||||||
Fair Value | San Diego Gas and Electric Company and Subsidiary [Member] | Level 2 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [4] | 4,325 | 4,243 | |||||||||||||
Contingently Redeemable Preferred Stock Fair Value Disclosure | [5] | 85 | ||||||||||||||
Fair Value | San Diego Gas and Electric Company and Subsidiary [Member] | Level 3 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [4] | 337 | 345 | |||||||||||||
Contingently Redeemable Preferred Stock Fair Value Disclosure | [5] | 0 | ||||||||||||||
Fair Value | Southern California Gas Company [Member] | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [6] | 1,504 | 1,599 | |||||||||||||
Preferred Stock Fair Value Disclosure | 23 | 24 | ||||||||||||||
Fair Value | Southern California Gas Company [Member] | Level 1 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [6] | 0 | 0 | |||||||||||||
Preferred Stock Of Subsidiaries Fair Value Disclosure | 0 | 0 | ||||||||||||||
Fair Value | Southern California Gas Company [Member] | Level 2 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [6] | 1,504 | 1,599 | |||||||||||||
Preferred Stock Fair Value Disclosure | 23 | 24 | ||||||||||||||
Fair Value | Southern California Gas Company [Member] | Level 3 | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||||||||||||||
Fair value of financial instruments, Total long-term debt | [6] | 0 | 0 | |||||||||||||
Preferred Stock Of Subsidiaries Fair Value Disclosure | $ 0 | $ 0 | ||||||||||||||
|
X | ||||||||||
- Definition Contingently redeemable preferred stock fair value disclosure. No definition available.
|
X | ||||||||||
- Definition Preferred stock fair value disclosure. No definition available.
|
X | ||||||||||
- Definition Preferred stock of subsidiaries fair value disclosure. No definition available.
|
X | ||||||||||
- References No definition available.
|
X | ||||||||||
- Definition Amount equal to the present value (the principal) at the beginning of the lease term of minimum lease payments during the lease term (excluding that portion of the payments representing executory costs such as insurance, maintenance, and taxes to be paid by the lessor, together with any profit thereon) net of payments or other amounts applied to the principal through the balance sheet date. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Carrying value as of the balance sheet date of long-term unsecured obligations issued by corporations and other borrowers to investors (with maturities initially due after one year or beyond the operating cycle if longer), excluding current portion. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition The amount of debt discount that was originally recognized at the issuance of the instrument that has yet to be amortized. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
|
X | ||||||||||
- Definition This element represents the portion of the balance sheet assertion valued at fair value by the entity whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. This item represents investment securities as of the balance sheet date which may include marketable securities, derivative financial instruments, and investments accounted for under the equity method. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
X | ||||||||||
- Definition This element represents the portion of the balance sheet assertion valued at fair value by the entity whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. This item represents notes payable as of the balance sheet date. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Details
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- Details
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- Details
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- Details
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- Details
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CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 1 (Details) - USD ($) $ in Thousands |
3 Months Ended | 12 Months Ended | |||||
---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Dec. 31, 2015 |
Dec. 31, 2014 |
Dec. 31, 2013 |
Jun. 30, 2013 |
Mar. 31, 2013 |
Dec. 31, 2012 |
|
Utility Subsidiaries [Member] | |||||||
General Rate Case [Line Items] | |||||||
General Rate Case, Revenue Attrition Mechanism Fixed Annual Factor | 2.75% | 2.75% | 2.65% | ||||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||||
Schedule of Cost of Capital [Line Items] | |||||||
Authorized Return On Rate Base Previous | 8.40% | ||||||
Authorized Return On Rate Base | 7.79% | ||||||
General Rate Case [Line Items] | |||||||
General Rate Case, Annual Revenue Requirement Increase | $ 119,000 | ||||||
General Rate Case, Percentage Annual Revenue Requirement Increase | 7.40% | ||||||
General Rate Case, Revenue Requirement | $ 1,733,000 | ||||||
General Rate Case, Total Earnings Impact | $ 69,000 | ||||||
General Rate Case, Cumulative Earnings Impact | $ 17,000 | $ 52,000 | |||||
General Rate Case, Regulatory Asset | 366,000 | ||||||
General Rate Case, Noncurrent Regulatory Asset | $ 203,000 | ||||||
FERC Electric Transmission Formula Rate Filing [Line Items] | |||||||
Proposed Return On Ferc Rate Base | 11.30% | ||||||
Likely Return On Ferc Rate Base | 10.00% | ||||||
Proposed Recovery Related To Excess Wildfire Claims In Transmission Rates | $ 23,200 | ||||||
Opposition Proposed Ferc Rate Base, Lower Range | 8.00% | ||||||
Opposition Proposed Ferc Rate Base, Upper Range | 10.00% | ||||||
Southern California Gas Company [Member] | |||||||
Schedule of Cost of Capital [Line Items] | |||||||
Authorized Return On Rate Base Previous | 8.68% | ||||||
Authorized Return On Rate Base | 8.02% | ||||||
General Rate Case [Line Items] | |||||||
General Rate Case, Annual Revenue Requirement Increase | $ 115,000 | ||||||
General Rate Case, Percentage Annual Revenue Requirement Increase | 6.20% | ||||||
General Rate Case, Revenue Requirement | $ 1,959,000 | ||||||
General Rate Case, Total Earnings Impact | $ 37,000 | ||||||
General Rate Case, Cumulative Earnings Impact | $ 12,000 | $ 25,000 | |||||
General Rate Case, Regulatory Asset | 117,000 | ||||||
General Rate Case, Noncurrent Regulatory Asset | $ 65,000 |
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CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 2 (Details) - USD ($) $ in Thousands |
3 Months Ended | |
---|---|---|
Sep. 30, 2013 |
Mar. 31, 2012 |
|
San Diego Gas and Electric Company and Subsidiary [Member] | ||
Utility Incentive Awards [Line Items] | ||
Unrecorded Energy Efficiency Award, Program Year 2011 | $ 3,900 | |
San Diego Gas and Electric Company and Subsidiary [Member] | Loss from Catastrophes [Member] | ||
Wildfire [Line Items] | ||
Potential Impact On Earnings | 186,000 | |
Southern California Gas Company [Member] | ||
Utility Incentive Awards [Line Items] | ||
Recognized Gas Cost Incentive Mechanism Award | 5,400 | $ 6,200 |
Unrecorded Gas Cost Incentive Mechanism Award | 5,800 | |
Unrecorded Energy Efficiency Award, Program Year 2011 | $ 3,100 |
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CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF UTILITY PROJECTS (Details) $ in Millions |
Sep. 30, 2013
USD ($)
|
---|---|
East County Substation [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |
Schedule Of Utility Projects [Line Items] | |
Estimated Project Cost | $ 435 |
Aliso Canyon Natural Gas Storage Compressor Replacement [Member] | Southern California Gas Company [Member] | |
Schedule Of Utility Projects [Line Items] | |
Estimated Project Cost | 200 |
South Bay Substation [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |
Schedule Of Utility Projects [Line Items] | |
Estimated Project Cost, Lower Range | 145 |
Estimated Project Cost, Upper Range | $ 175 |
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CALIFORNIA UTILITIES' REGULATORY MATTERS - NUCLEAR PLANT (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | 17 Months Ended | 21 Months Ended | ||||||
---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
Jun. 06, 2013 |
Sep. 30, 2013 |
Dec. 31, 2012 |
[1] | |||
Nuclear Plant [Line Items] | ||||||||||
Nuclear decommissioning trusts | $ 981 | $ 981 | $ 981 | $ 908 | ||||||
Nuclear Plant Investment [Line Items] | ||||||||||
Loss From Plant Closure | $ 0 | $ 0 | $ 200 | $ 0 | ||||||
Nuclear Plant, SDGE [Member] | ||||||||||
Nuclear Plant [Line Items] | ||||||||||
Nuclear Plant, Ownership Percentage | 20.00% | 20.00% | 20.00% | |||||||
Nuclear Plant, Replacement Power Costs | $ 166 | |||||||||
Nuclear Plant, Revenue Recognized Associated with SONGS | $ 300 | |||||||||
Nuclear Plant, Replacement Power Costs Authorized | $ 93 | $ 93 | $ 93 | |||||||
Authorized Recovery Amount, Nuclear Decommissioning Trust Funding | 8 | |||||||||
Requested Recovery Amount, Nuclear Decommissioning Trust Funding | 16 | |||||||||
San Diego Gas and Electric Company and Subsidiary [Member] | ||||||||||
Nuclear Plant [Line Items] | ||||||||||
Nuclear decommissioning trusts | 981 | 981 | 981 | $ 908 | ||||||
Nuclear Plant Investment [Line Items] | ||||||||||
Nuclear Plant, Net Property, Plant and Equipment | 516 | 516 | 516 | |||||||
Nuclear Plant, Materials Inventory | 10 | 10 | 10 | |||||||
Nuclear Plant, Replacement Power Costs In Excess Of Authorized | 74 | |||||||||
Regulatory Asset, Nuclear Plant Closure | $ 431 | $ 431 | 431 | |||||||
Nuclear Plant, Miscellaneous Costs | 31 | |||||||||
Nuclear Plant, Operations And Maintenance Expenses | $ 220 | |||||||||
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- Definition Loss from plant closure. No definition available.
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- Definition Decommission fund to pay for the costs of decontaminating and decommissioning of facilities through collection of revenues derived from utility assessments and government appropriations. Decommission fund investment for the process whereby a power station, at the end of its economic life, is taken permanently out of service and its site made available for other purposes. In the case of a nuclear station this comprises three different states of clearance. Immediately after the final closure, radioactive material such as nuclear fuel and operational waste is removed and the buildings surrounding the reactor shield are dismantled and finally the reactor itself is dismantled. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) $ in Thousands, £ in Millions |
3 Months Ended | 9 Months Ended | |||||||
---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013
USD ($)
|
Sep. 30, 2013
GBP (£)
|
Sep. 30, 2012
USD ($)
|
Sep. 30, 2013
USD ($)
|
Sep. 30, 2012
USD ($)
|
Dec. 31, 2012
USD ($)
|
[1] | |||
Loss Contingencies [Line Items] | |||||||||
Loss Contingency Accrual, at Carrying Value | $ 177,000 | $ 177,000 | |||||||
Regulatory Assets Arising From Wildfire Litigation Costs | 339,000 | 339,000 | $ 364,000 | ||||||
San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Loss Contingencies [Line Items] | |||||||||
Loss Contingency Accrual, at Carrying Value | 164,000 | 164,000 | |||||||
Regulatory Assets Arising From Wildfire Litigation Costs | 339,000 | 339,000 | $ 364,000 | ||||||
Southern California Gas Company [Member] | |||||||||
Loss Contingencies [Line Items] | |||||||||
Loss Contingency Accrual, at Carrying Value | 5,000 | 5,000 | |||||||
Loss from Catastrophes [Member] | S D G E Segment [Member] | |||||||||
Loss From Loss Contingencies [Line Items] | |||||||||
Loss Contingency, Loss (Gain) in Period | (500) | $ (800) | (200) | $ 4,100 | |||||
Loss from Catastrophes [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Loss Contingencies [Line Items] | |||||||||
Loss Contingency Accrual, at Carrying Value | 164,000 | 164,000 | |||||||
Payments for Legal Settlements | 14,750 | ||||||||
Claims Payments By Insurers To All Claimants | $ 1,600,000 | ||||||||
Percentage of Total Claims to be Paid by Company | 57.50% | 57.50% | |||||||
Total Individual And Business Claims | $ 550,000 | ||||||||
Liability Insurance Coverage, Maximum | 1,100,000 | 1,100,000 | |||||||
Litigation Settlement, Gross | 824,000 | ||||||||
Payments For Legal Settlements In Excess Of Recovered Amounts | 285,000 | ||||||||
Loss Contingency Accrual Carrying Value, Current | 127,000 | 127,000 | |||||||
Loss Contingency Accrual Carrying Value, Noncurrent | 37,000 | 37,000 | |||||||
Potential Impact On Earnings | 186,000 | 186,000 | |||||||
Portion of Regulatory Assets Arising From Wildfire Litigation Related To CPUC Operations | 315,000 | 315,000 | |||||||
Liberty Gas Storage Litigation [Member] | |||||||||
Loss Contingencies [Line Items] | |||||||||
Loss Contingency Monetary Damages Sought | 56,700 | 56,700 | |||||||
Estimated Gain Loss On Contract Termination | 215,000 | 215,000 | |||||||
HMRC VAT Claim [Member] | |||||||||
Loss Contingencies [Line Items] | |||||||||
VAT Tax Claim Amount | £ | £ 86 | ||||||||
Sunrise Powerlink Construction [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Loss Contingencies [Line Items] | |||||||||
Fixed Fee Contract Amount | 456,000 | 456,000 | |||||||
Sunrise Mechanics Lien 1 [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Loss Contingencies [Line Items] | |||||||||
Unbilled Change Orders | 99,200 | 99,200 | |||||||
Sunrise Mechanics Lien 2 [Member] | San Diego Gas and Electric Company and Subsidiary [Member] | |||||||||
Loss Contingencies [Line Items] | |||||||||
Unbilled Change Orders | $ 81,100 | $ 81,100 | |||||||
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- Definition Regulatory assets arising from wildfire litigation costs. No definition available.
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- Definition This element represents the gross amount awarded, to be received by, or to be remitted to the entity in settlement of litigation occurring during the period. No definition available.
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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. No definition available.
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- Definition The carrying amount as of the balance sheet date of the combined total of loss contingency liabilities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The portion of the carrying amount as of the balance sheet date of the combined total of loss contingency liabilities which is expected to be resolved within one year or the normal operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The portion of the carrying amount as of the balance sheet date of the combined total of loss contingency liabilities which is expected to be resolved after one year or beyond the normal operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The amount of loss pertaining to the specified contingency that was charged against earnings in the period, including the effects of revisions in previously reported estimates. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The amount of cash paid for the settlement of litigation or for other legal issues during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Total amount of unbilled change orders from customers under long-term contracts or programs associated with unpriced change orders or other similar items subject to uncertainty concerning their determination or ultimate realization. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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COMMITMENTS AND CONTINGENCIES - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company and Subsidiary [Member] $ in Thousands |
Sep. 30, 2013
USD ($)
|
---|---|
Schedule Of Nuclear Insurance [Line Items] | |
Nuclear Liability Insurance Coverage, Maximum | $ 375,000 |
Secondary Financial Protection, Maximum | 13,200,000 |
Secondary Financial Protection, Company Contribution, Maximum | 50,930 |
Secondary Financial Protection, Company Contribution, Annual Maximum | 7,600 |
Nuclear Property Insurance Coverage, Maximum | 2,750,000 |
Nuclear Property Damage Insurance, Premium Assessment | 9,700 |
Nuclear Property Insurance Terrorism Coverage, Maximum | 3,240,000 |
Nuclear Property Insurance, Deductible Per Event | $ 2,500 |
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COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) $ in Millions |
3 Months Ended |
---|---|
Sep. 30, 2013
USD ($)
| |
San Diego Gas and Electric Company and Subsidiary [Member] | |
Payments Under Contractual Commitments [Line Items] | |
Increase (Decrease) In Purchased Power Commitments, Payments Due, Current | $ (1) |
Increase (Decrease) In Purchased Power Commitments, Payments Due In Two Years | 77 |
Increase (Decrease) In Purchased Power Commitments, Payments Due In Three Years | 140 |
Increase (Decrease) In Purchased Power Commitments, Payments Due In Four Years | 141 |
Increase (Decrease) In Purchased Power Commitments, Payments Due In Five Years | 141 |
Increase (Decrease) In Purchased Power Commitments, Payments Due Thereafter | 2,600 |
Increase (Decrease) In Purchase Commitment Amount | 3,100 |
Operating Leases [Line Items] | |
Operating Leases Future Minimum Payments, Due Current | (18) |
Operating Leases, Future Minimum Payments, Due in Two Years | 3 |
Operating Leases, Future Minimum Payments, Due in Three Years | 3 |
Operating Leases, Future Minimum Payments, Due in Four Years | 3 |
Operating Leases, Future Minimum Payments, Due in Five Years | 1 |
Operating Leases, Future Minimum Payments, Due Thereafter | 84 |
Southern California Gas Company [Member] | |
Payments Under Contractual Commitments [Line Items] | |
Increase (Decrease) In Natural Gas Contracts Commitments | 156 |
Decrease In Natural Gas Contracts Commitments, Fulfillment | 554 |
Increase In Natural Gas Contracts Commitments, New Contracts | 710 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due, Current | (357) |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due In Two Years | 245 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due In Three Years | 41 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due In Four Years | 67 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due In Five Years | 70 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due Thereafter | 90 |
Sempra Natural Gas [Member] | |
Payments Under Contractual Commitments [Line Items] | |
Increase (Decrease) In Liquefied Natural Gas Commitments, Payments Due, Current | (424) |
Increase (Decrease) In Liquefied Natural Gas Commitments, Payments Due In Two Years | (37) |
Increase (Decrease) In Liquefied Natural Gas Commitments, Payments Due In Three Years | (42) |
Increase (Decrease) In Liquefied Natural Gas Commitments, Payments Due In Four Years | (59) |
Increase (Decrease) In Liquefied Natural Gas Commitments, Payments Due In Five Years | (66) |
Increase (Decrease) In Liquefied Natural Gas Commitments, Payments Due Thereafter | (731) |
Increase (Decrease) In Natural Gas Contracts Commitments | 22 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due, Current | (36) |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due In Two Years | 10 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due In Three Years | 7 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due In Four Years | 7 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due In Five Years | 7 |
Increase (Decrease) In Natural Gas Contracts Commitments, Payments Due Thereafter | 27 |
Sempra Natural Gas [Member] | Operations And Maintenance Mesquite Power [Member] | |
Payments Under Contractual Commitments [Line Items] | |
Contractual Commitments, Payments Due, Current | 1 |
Contractual Commitments, Payments Due In Two Years | 2 |
Contractual Commitments, Payments Due In Three Years | 2 |
Contractual Commitments, Payments Due In Four Years | 2 |
Contractual Commitments, Payments Due In Five Years | 2 |
Contractual Commitments, Payments Due Thereafter | 27 |
Sempra Renewables [Member] | |
Long-term Purchase Commitment [Line Items] | |
Guarantee Obligations Maximum Exposure | 250 |
Guarantee Obligations Current Carrying Value | 11 |
Operating Leases [Line Items] | |
Operating Leases, Future Minimum Payments, Due in Two Years | 2 |
Operating Leases, Future Minimum Payments, Due in Three Years | 2 |
Operating Leases, Future Minimum Payments, Due in Four Years | 2 |
Operating Leases, Future Minimum Payments, Due in Five Years | 2 |
Operating Leases, Future Minimum Payments, Due Thereafter | 76 |
Sempra Rockies Marketing [Member] | |
Payments Under Contractual Commitments [Line Items] | |
Contractual Commitments, Payments Due, Current | 3 |
Contractual Commitments, Payments Due In Two Years | 14 |
Contractual Commitments, Payments Due In Three Years | 14 |
Contractual Commitments, Payments Due In Four Years | 14 |
Contractual Commitments, Payments Due In Five Years | 14 |
Contractual Commitments, Payments Due Thereafter | 83 |
Pipeline Safety Enhancement Program [Member] | |
Long-term Purchase Commitment [Line Items] | |
Long-term Purchase Commitment, Amount | 372 |
Payments Under Contractual Commitments [Line Items] | |
Increase (Decrease) In Construction Commitments, Payments Due, Current | 91 |
Increase (Decrease) In Construction Commitments, Payments Due In Two Years | 71 |
Increase (Decrease) In Construction Commitments, Payments Due In Three Years | 70 |
Increase (Decrease) In Construction Commitments, Payments Due In Four Years | 70 |
Increase (Decrease) In Construction Commitments, Payments Due In Five Years | 70 |
Energia Sierra Juarez wind project [Member] | |
Long-term Purchase Commitment [Line Items] | |
Long-term Purchase Commitment, Amount | 215 |
Energia Sierra Juarez Wind and Sasabe-Guaymas projects [Member] | |
Payments Under Contractual Commitments [Line Items] | |
Increase (Decrease) In Construction Commitments, Payments Due, Current | 12 |
Increase (Decrease) In Construction Commitments, Payments Due In Two Years | 219 |
Increase (Decrease) In Construction Commitments, Payments Due In Three Years | 179 |
Increase (Decrease) In Construction Commitments, Payments Due In Four Years | 2 |
Sasabe-Guaymas Natural Gas Pipeline Project [Member] | |
Long-term Purchase Commitment [Line Items] | |
Long-term Purchase Commitment, Amount | 197 |
HQ Build to suit lease [Member] | |
Payments Under Contractual Commitments [Line Items] | |
Contractual Commitments, Payments Due In Three Years | 4 |
Contractual Commitments, Payments Due In Four Years | 10 |
Contractual Commitments, Payments Due In Five Years | 10 |
Contractual Commitments, Payments Due Thereafter | 287 |
Broken Bow 2 and Copper Mountain Solar 3 projects [Member] | |
Payments Under Contractual Commitments [Line Items] | |
Contractual Commitments, Payments Due, Current | 106 |
Contractual Commitments, Payments Due In Two Years | 453 |
Contractual Commitments, Payments Due In Three Years | 38 |
Operations And Maintenance Mesquite Power [Member] | Sempra Natural Gas [Member] | |
Long-term Purchase Commitment [Line Items] | |
Long-term Purchase Commitment, Amount | 36 |
Broken Bow 2 [Member] | Sempra Renewables [Member] | |
Long-term Purchase Commitment [Line Items] | |
Long-term Purchase Commitment, Amount | 82 |
Copper Mountain Solar 3 [Member] | Sempra Renewables [Member] | |
Long-term Purchase Commitment [Line Items] | |
Long-term Purchase Commitment, Amount | $ 515 |
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- Definition Maximum potential amount of future payments (undiscounted) the guarantor could be required to make under the guarantee or each group of similar guarantees before reduction for potential recoveries under recourse or collateralization provisions. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of required minimum rental payments maturing in the next fiscal year following the latest fiscal year for operating leases having an initial or remaining non-cancelable letter-terms in excess of one year. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of required minimum rental payments maturing in the third fiscal year following the latest fiscal year for operating leases having an initial or remaining non-cancelable letter-terms in excess of one year. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of required minimum rental payments maturing after the fifth fiscal year following the latest fiscal year for operating leases having an initial or remaining non-cancelable letter-terms in excess of one year. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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SEGMENT INFORMATION (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2013 |
Sep. 30, 2012 |
Sep. 30, 2013 |
Sep. 30, 2012 |
Dec. 31, 2012 |
|||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | $ 2,551 | $ 2,507 | $ 7,852 | $ 6,979 | |||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | 100.00% | 100.00% | 100.00% | 100.00% | |||||||||||
Segment reporting information, Interest Expense | $ 137 | $ 126 | $ 413 | $ 352 | |||||||||||
Segment reporting information, Interest Income | 5 | 5 | 15 | 14 | |||||||||||
Segment reporting information, Depreciation and Amortization | $ 286 | $ 280 | $ 828 | $ 803 | |||||||||||
Segment reporting information, Percentage of Consolidated Depreciation and Amortization | 100.00% | 100.00% | 100.00% | 100.00% | |||||||||||
Segment reporting information, Income Tax Expense (Benefit) | $ 117 | $ 49 | $ 327 | $ 48 | |||||||||||
Segment reporting information, Equity Earnings (Losses) Recorded Before Tax | 3 | (94) | 21 | (375) | |||||||||||
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax | 8 | 10 | 13 | 29 | |||||||||||
Segment reporting information, Earnings (Losses) | $ 296 | $ 268 | $ 719 | $ 566 | |||||||||||
Segment reporting information, Percentage of Consolidated Earnings (Losses) | 100.00% | 100.00% | 100.00% | 100.00% | |||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Expenditures for Property, Plant & Equipment | $ 1,785 | $ 2,241 | |||||||||||||
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment | 100.00% | 100.00% | |||||||||||||
Segment reporting information, Assets | $ 36,901 | $ 36,901 | $ 36,499 | [1] | |||||||||||
Segment reporting information, Percentage of Consolidated Assets | 100.00% | 100.00% | 100.00% | ||||||||||||
Segment Reporting Information Investments In Equity Method Investees | $ 1,472 | $ 1,472 | $ 1,427 | ||||||||||||
Earnings (losses) reclassified between segments | $ (12) | $ (12) | |||||||||||||
S D G E Segment [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | $ 1,063 | $ 1,092 | $ 3,066 | $ 2,706 | |||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | 42.00% | 44.00% | 39.00% | 39.00% | |||||||||||
Segment reporting information, Interest Expense | $ 50 | $ 49 | $ 147 | $ 124 | |||||||||||
Segment reporting information, Interest Income | 0 | 0 | 1 | 0 | |||||||||||
Segment reporting information, Depreciation and Amortization | $ 126 | $ 128 | $ 367 | $ 359 | |||||||||||
Segment reporting information, Percentage of Consolidated Depreciation and Amortization | 44.00% | 46.00% | 44.00% | 45.00% | |||||||||||
Segment reporting information, Income Tax Expense (Benefit) | $ 84 | $ 38 | $ 147 | $ 151 | |||||||||||
Segment reporting information, Earnings (Losses) | [2] | $ 129 | $ 174 | $ 285 | $ 374 | ||||||||||
Segment reporting information, Percentage of Consolidated Earnings (Losses) | 44.00% | 65.00% | 40.00% | 66.00% | |||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Expenditures for Property, Plant & Equipment | $ 679 | $ 998 | |||||||||||||
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment | 38.00% | 44.00% | |||||||||||||
Segment reporting information, Assets | $ 15,275 | $ 15,275 | $ 14,744 | ||||||||||||
Segment reporting information, Percentage of Consolidated Assets | 41.00% | 41.00% | 40.00% | ||||||||||||
Segment Reporting Information, Intersegment Revenue | $ 3 | $ 3 | $ 7 | $ 6 | |||||||||||
So Cal Gas Segment [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | $ 807 | $ 728 | $ 2,694 | $ 2,328 | |||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | 32.00% | 29.00% | 34.00% | 33.00% | |||||||||||
Segment reporting information, Interest Expense | $ 17 | $ 17 | $ 52 | $ 51 | |||||||||||
Segment reporting information, Depreciation and Amortization | $ 100 | $ 91 | $ 280 | $ 268 | |||||||||||
Segment reporting information, Percentage of Consolidated Depreciation and Amortization | 35.00% | 33.00% | 34.00% | 33.00% | |||||||||||
Segment reporting information, Income Tax Expense (Benefit) | $ 38 | $ 37 | $ 107 | $ 105 | |||||||||||
Segment reporting information, Earnings (Losses) | [3] | $ 102 | $ 71 | $ 266 | $ 190 | ||||||||||
Segment reporting information, Percentage of Consolidated Earnings (Losses) | 34.00% | 26.00% | 37.00% | 34.00% | |||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Expenditures for Property, Plant & Equipment | $ 521 | $ 462 | |||||||||||||
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment | 29.00% | 21.00% | |||||||||||||
Segment reporting information, Assets | $ 9,288 | $ 9,288 | $ 9,071 | ||||||||||||
Segment reporting information, Percentage of Consolidated Assets | 25.00% | 25.00% | 25.00% | ||||||||||||
Segment Reporting Information, Intersegment Revenue | $ 17 | $ 17 | $ 48 | $ 48 | |||||||||||
All Other Segments [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Interest Expense | 60 | 62 | 182 | 185 | |||||||||||
Segment reporting information, Interest Income | 2 | 2 | 1 | 1 | |||||||||||
Segment reporting information, Depreciation and Amortization | $ 5 | $ 3 | $ 10 | $ 9 | |||||||||||
Segment reporting information, Percentage of Consolidated Depreciation and Amortization | 2.00% | 1.00% | 1.00% | 1.00% | |||||||||||
Segment reporting information, Income Tax Expense (Benefit) | $ (42) | $ (27) | $ (48) | $ (108) | |||||||||||
Segment reporting information, Equity Earnings (Losses) Recorded Before Tax | 0 | (1) | 0 | (2) | |||||||||||
Segment reporting information, Earnings (Losses) | $ (43) | $ (4) | $ (149) | $ (25) | |||||||||||
Segment reporting information, Percentage of Consolidated Earnings (Losses) | (15.00%) | (2.00%) | (21.00%) | (5.00%) | |||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Expenditures for Property, Plant & Equipment | $ 1 | $ 3 | |||||||||||||
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment | 0.00% | 0.00% | |||||||||||||
Segment reporting information, Assets | $ 621 | $ 621 | $ 818 | ||||||||||||
Segment reporting information, Percentage of Consolidated Assets | 2.00% | 2.00% | 2.00% | ||||||||||||
Segment Reporting Information Investments In Equity Method Investees | $ 76 | $ 76 | $ 134 | ||||||||||||
Adjustments and Eliminations [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | $ 0 | $ 0 | $ (2) | $ (2) | |||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | 0.00% | 0.00% | 0.00% | 0.00% | |||||||||||
Intercompany Eliminations Segment [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Interest Expense | $ (37) | $ (43) | $ (95) | $ (121) | |||||||||||
Segment reporting information, Interest Income | (33) | (17) | (70) | (43) | |||||||||||
Intersegment Revenues Segment [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | [4] | $ (108) | $ (171) | $ (303) | $ (359) | ||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | (4.00%) | (7.00%) | (4.00%) | (5.00%) | |||||||||||
Intersegment Receivables Segment [Member] | |||||||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Assets | $ (4,066) | $ (4,066) | $ (1,619) | ||||||||||||
Segment reporting information, Percentage of Consolidated Assets | (11.00%) | (11.00%) | (4.00%) | ||||||||||||
Sempra South American Utilities Segment [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | $ 364 | $ 356 | $ 1,119 | $ 1,061 | |||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | 14.00% | 14.00% | 14.00% | 15.00% | |||||||||||
Segment reporting information, Interest Expense | $ 8 | $ 6 | $ 20 | $ 22 | |||||||||||
Segment reporting information, Interest Income | 3 | 3 | 11 | 11 | |||||||||||
Segment reporting information, Depreciation and Amortization | $ 14 | $ 15 | $ 44 | $ 42 | |||||||||||
Segment reporting information, Percentage of Consolidated Depreciation and Amortization | 5.00% | 5.00% | 5.00% | 5.00% | |||||||||||
Segment reporting information, Income Tax Expense (Benefit) | $ 16 | $ 27 | $ 50 | $ 57 | |||||||||||
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax | 0 | 0 | (14) | 0 | |||||||||||
Segment reporting information, Earnings (Losses) | $ 39 | $ 40 | $ 110 | $ 118 | |||||||||||
Segment reporting information, Percentage of Consolidated Earnings (Losses) | 13.00% | 15.00% | 15.00% | 21.00% | |||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Expenditures for Property, Plant & Equipment | $ 120 | $ 117 | |||||||||||||
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment | 7.00% | 5.00% | |||||||||||||
Segment reporting information, Assets | $ 3,492 | $ 3,492 | $ 3,310 | ||||||||||||
Segment reporting information, Percentage of Consolidated Assets | 10.00% | 10.00% | 9.00% | ||||||||||||
Segment Reporting Information Investments In Equity Method Investees | $ (2) | $ (2) | $ 0 | ||||||||||||
Sempra Mexico Segment [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | $ 188 | $ 181 | $ 519 | $ 435 | |||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | 7.00% | 7.00% | 7.00% | 6.00% | |||||||||||
Segment reporting information, Interest Expense | $ 0 | $ 3 | $ 5 | $ 6 | |||||||||||
Segment reporting information, Interest Income | 0 | 0 | 1 | 1 | |||||||||||
Segment reporting information, Depreciation and Amortization | $ 16 | $ 15 | $ 47 | $ 46 | |||||||||||
Segment reporting information, Percentage of Consolidated Depreciation and Amortization | 5.00% | 5.00% | 6.00% | 6.00% | |||||||||||
Segment reporting information, Income Tax Expense (Benefit) | $ 16 | $ 31 | $ 44 | $ 61 | |||||||||||
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax | 8 | 10 | 27 | 29 | |||||||||||
Segment reporting information, Earnings (Losses) | $ 39 | $ 42 | $ 96 | $ 122 | |||||||||||
Segment reporting information, Percentage of Consolidated Earnings (Losses) | 13.00% | 16.00% | 13.00% | 22.00% | |||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Expenditures for Property, Plant & Equipment | $ 280 | $ 13 | |||||||||||||
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment | 16.00% | 1.00% | |||||||||||||
Segment reporting information, Assets | $ 3,315 | $ 3,315 | $ 2,591 | ||||||||||||
Segment reporting information, Percentage of Consolidated Assets | 9.00% | 9.00% | 7.00% | ||||||||||||
Segment Reporting Information Investments In Equity Method Investees | $ 367 | $ 367 | $ 340 | ||||||||||||
Segment Reporting Information, Intersegment Revenue | 23 | $ 78 | 68 | $ 161 | |||||||||||
Sempra Renewables Segment [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | $ 25 | $ 27 | $ 76 | $ 49 | |||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | 1.00% | 1.00% | 1.00% | 1.00% | |||||||||||
Segment reporting information, Interest Expense | $ 5 | $ 6 | $ 22 | $ 13 | |||||||||||
Segment reporting information, Interest Income | 7 | 2 | 14 | 3 | |||||||||||
Segment reporting information, Depreciation and Amortization | $ 5 | $ 4 | $ 20 | $ 10 | |||||||||||
Segment reporting information, Percentage of Consolidated Depreciation and Amortization | 2.00% | 1.00% | 3.00% | 1.00% | |||||||||||
Segment reporting information, Income Tax Expense (Benefit) | $ 9 | $ (12) | $ (8) | $ (47) | |||||||||||
Segment reporting information, Equity Earnings (Losses) Recorded Before Tax | (10) | (6) | (12) | (7) | |||||||||||
Segment reporting information, Earnings (Losses) | $ 37 | $ 13 | $ 56 | $ 47 | |||||||||||
Segment reporting information, Percentage of Consolidated Earnings (Losses) | 13.00% | 5.00% | 8.00% | 8.00% | |||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Expenditures for Property, Plant & Equipment | $ 119 | $ 564 | |||||||||||||
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment | 7.00% | 25.00% | |||||||||||||
Segment reporting information, Assets | $ 1,898 | $ 1,898 | $ 2,439 | ||||||||||||
Segment reporting information, Percentage of Consolidated Assets | 5.00% | 5.00% | 7.00% | ||||||||||||
Segment Reporting Information Investments In Equity Method Investees | $ 701 | $ 701 | $ 592 | ||||||||||||
Sempra Natural Gas Segment [Member] | |||||||||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | |||||||||||||||
Segment reporting information, Revenues | $ 212 | $ 294 | $ 683 | $ 761 | |||||||||||
Segment reporting information, Percentage of Total Consolidated Revenues | 8.00% | 12.00% | 9.00% | 11.00% | |||||||||||
Segment reporting information, Interest Expense | $ 34 | $ 26 | $ 80 | $ 72 | |||||||||||
Segment reporting information, Interest Income | 26 | 15 | 57 | 41 | |||||||||||
Segment reporting information, Depreciation and Amortization | $ 20 | $ 24 | $ 60 | $ 69 | |||||||||||
Segment reporting information, Percentage of Consolidated Depreciation and Amortization | 7.00% | 9.00% | 7.00% | 9.00% | |||||||||||
Segment reporting information, Income Tax Expense (Benefit) | $ (4) | $ (45) | $ 35 | $ (171) | |||||||||||
Segment reporting information, Equity Earnings (Losses) Recorded Before Tax | 13 | (87) | 33 | (366) | |||||||||||
Segment reporting information, Earnings (Losses) | $ (7) | $ (68) | $ 55 | $ (260) | |||||||||||
Segment reporting information, Percentage of Consolidated Earnings (Losses) | (2.00%) | (25.00%) | 8.00% | (46.00%) | |||||||||||
Segment Reporting Information, Additional Information [Abstract] | |||||||||||||||
Segment reporting information, Expenditures for Property, Plant & Equipment | $ 65 | $ 84 | |||||||||||||
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment | 3.00% | 4.00% | |||||||||||||
Segment reporting information, Assets | $ 7,078 | $ 7,078 | $ 5,145 | ||||||||||||
Segment reporting information, Percentage of Consolidated Assets | 19.00% | 19.00% | 14.00% | ||||||||||||
Segment Reporting Information Investments In Equity Method Investees | $ 330 | $ 330 | $ 361 | ||||||||||||
Segment Reporting Information, Intersegment Revenue | $ 65 | $ 73 | $ 180 | $ 144 | |||||||||||
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- Definition Earnings reclassified between segments. No definition available.
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- Definition Segment reporting information, earnings (losses). No definition available.
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- Definition Segment reporting information, equity earnings (losses) recorded net of tax. No definition available.
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- Definition Segment reporting information, investments in equity method investees. No definition available.
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- Definition Segment reporting information, percentage of consolidated assets. No definition available.
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- Definition Segment reporting information, percentage of consolidated depreciation and amortization. No definition available.
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- Definition Segment reporting information, Percentage of Consolidated Earnings (Losses). No definition available.
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- Definition Segment reporting information, percentage of consolidated expenditures for property, plant & equipment. No definition available.
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- Definition Segment reporting information, percentage of total consolidated revenues. No definition available.
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- Definition Total expenditures for additions to long-lived assets other than financial instruments, long-term customer relationships of a financial institution, mortgage and other servicing rights, deferred policy acquisition costs, and deferred tax assets of the reportable segment; if the amount: (a) is included in the determination of segment assets reviewed by the chief operating decision maker or (b) is otherwise regularly provided to the chief operating decision maker, even if not included in the determination of segment assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Sum of the carrying amounts as of the balance sheet date of all assets that are recognized. Assets are probable future economic benefits obtained or controlled by an entity as a result of past transactions or events. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The aggregate expense recognized in the current period that allocates the cost of tangible assets, intangible assets, or depleting assets to periods that benefit from use of the assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition This item represents the entity's proportionate share for the period of the net income (loss) of its investee (such as unconsolidated subsidiaries and joint ventures) to which the equity method of accounting is applied. This item includes income or expense related to stock-based compensation based on the investor's grant of stock to employees of an equity method investee. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The sum of the current income tax expense or benefit and the deferred income tax expense or benefit pertaining to continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition The cost of borrowed funds accounted for as interest that was charged against earnings during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Income derived from investments in debt securities and on cash and cash equivalents the earnings of which reflect the time value of money or transactions in which the payments are for the use or forbearance of money. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of revenue from transactions with other operating segments of the same entity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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- Definition Amount of total revenue for the reportable segments, including revenue from external customers, transactions with other operating segments of the same entity, and (gross) interest revenue. All considered to be "operating revenue" for purposes of the taxonomy. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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