| X | ||||||||||
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- Definition
If the value is true, then the document as an amendment to previously-filed/accepted document. No definition available.
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| X | ||||||||||
|
- Definition
End date of current fiscal year in the format --MM-DD. No definition available.
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| X | ||||||||||
|
- 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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| X | ||||||||||
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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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| X | ||||||||||
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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 this will be the filing date. The format of the date is CCYY-MM-DD. No definition available.
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| X | ||||||||||
|
- Definition
The type of document being provided (such as 10-K, 10-Q, N-1A, etc). The document type should be limited to the same value as the supporting SEC submission type. The acceptable values are as follows: S-1, S-3, S-4, S-11, F-1, F-3, F-4, F-9, F-10, 6-K, 8-K, 10, 10-K, 10-Q, 20-F, 40-F, N-1A, 485BPOS, NCSR, N-Q, and Other. No definition available.
|
| X | ||||||||||
|
- 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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| X | ||||||||||
|
- Definition
Indicate number of shares outstanding of each of registrant's classes of common stock, as of latest practicable date. Where multiple classes exist define each class by adding class of stock items such as Common Class A [Member], Common Class B [Member] onto the Instrument [Domain] of the Entity Listings, Instrument No definition available.
|
| X | ||||||||||
|
- Definition
Indicate "Yes" or "No" whether registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. This information should be based on the registrant's current or most recent filing containing the related disclosure. No definition available.
|
| X | ||||||||||
|
- Definition
Indicate whether the registrant is one of the following: (1) Large Accelerated Filer, (2) Accelerated Filer, (3) Non-accelerated Filer, or (4) Smaller Reporting Company. 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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| X | ||||||||||
|
- Details
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| X | ||||||||||
|
- Definition
State aggregate market value of voting and non-voting common equity held by non-affiliates computed by reference to price at which the common equity was last sold, or average bid and asked price of such common equity, as of the last business day of registrant's most recently completed second fiscal quarter. The public float should be reported on the cover page of the registrants form 10K. No definition available.
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
Indicate "Yes" or "No" if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. No definition available.
|
| X | ||||||||||
|
- Definition
Indicate "Yes" or "No" if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Is used on Form Type: 10-K, 10-Q, 8-K, 20-F, 6-K, 10-K/A, 10-Q/A, 20-F/A, 6-K/A, N-CSR, N-Q, N-1A. No definition available.
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Definition
Short-term note payable collateralized by accounts receivable No definition available.
|
| X | ||||||||||
|
- Definition
Total Common Stockholder's Equity attributable to Great Plains Energy No definition available.
|
| X | ||||||||||
|
- Definition
Sum of the carrying amounts of deferred costs for nuclear plant refueling outages that are expected to be recognized as a charge against earnings. No definition available.
|
| X | ||||||||||
|
- Definition
The total of investments and other long-term assets. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Any material consumed to produce energy. No definition available.
|
| X | ||||||||||
|
- Definition
Materials and items used for activities of the business. No definition available.
|
| X | ||||||||||
|
- Definition
Period end amount of total net PPE in service No definition available.
|
| X | ||||||||||
|
- Definition
Sum of stockholders' equity including noncontrolling interest and long-term debt, noncurrent No definition available.
|
| X | ||||||||||
|
- Definition
Carrying value as of the balance sheet date of liabilities 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
|
| X | ||||||||||
|
- 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. No definition available.
|
| X | ||||||||||
|
- Definition
Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at fiscal year-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, and unrealized gains and losses on certain investments in debt and equity securities 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
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Includes currency on hand as well as demand deposits with banks or financial institutions. It also includes other kinds of accounts that have the general characteristics of demand deposits in that the Entity may deposit additional funds at any time and also effectively may withdraw funds at any time without prior notice or penalty. Cash equivalents, excluding items classified as marketable securities, include short-term, highly liquid investments that are both readily convertible to known amounts of cash, and so near their maturity that they present minimal risk of changes in value because of changes in interest rates. Generally, only investments with original maturities of three months or less qualify under that definition. Original maturity means original maturity to the entity holding the investment. For example, both a three-month US Treasury bill and a three-year Treasury note purchased three months from maturity qualify as cash equivalents. However, a Treasury note purchased three years ago does not become a cash equivalent when its remaining maturity is three months. Compensating balance arrangements that do not legally restrict the withdrawal or usage of cash amounts may be reported as Cash and Cash Equivalents, while legally restricted deposits held as compensating balances against borrowing arrangements, contracts entered into with others, or company statements of intention with regard to particular deposits should not be reported as cash and cash equivalents. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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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| X | ||||||||||
|
- Definition
Represents the caption on the face of the balance sheet to indicate that the entity has entered into (1) purchase or supply arrangements that will require expending a portion of its resources to meet the terms thereof, and (2) is exposed to potential losses or, less frequently, gains, arising from (a) possible claims against a company's resources due to future performance under contract terms, and (b) possible losses or likely gains from uncertainties that will ultimately be resolved when one or more future events that are deemed likely to occur do occur or fail to occur. This caption alerts the reader that one or more notes to the financial statements disclose pertinent information about the entity's commitments and contingencies. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- Definition
Dollar value of issued common stock whether issued at par value, no par or stated value. This item includes treasury stock repurchased by the entity. Note: elements for number of common shares, par value and other disclosure concepts are in another section within stockholders' equity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
The current portion of the aggregate tax effects as of the balance sheet date of all future tax deductions arising from temporary differences between tax basis and generally accepted accounting principles basis recognition of assets, liabilities, revenues and expenses, which can only be deducted for tax purposes when permitted under enacted tax laws; after deducting the allocated valuation allowance, if any, to reduce such amount to net realizable value. Deferred tax liabilities and assets shall be classified as current or noncurrent based on the classification of the related asset or liability for financial reporting. A deferred tax liability or asset that is not related to an asset or liability for financial reporting, including deferred tax assets related to carryforwards, shall be classified according to the expected reversal date of the temporary difference. An unrecognized tax benefit that is directly related to a position taken in a tax year that results in a net operating loss carryforward should be presented as a reduction of the related deferred tax asset. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Represents the current portion of deferred tax liabilities, which result from applying the applicable tax rate to net taxable temporary differences pertaining to each jurisdiction to which the entity is obligated to pay income tax. A current taxable temporary difference is a difference between the tax basis and the carrying amount of a current asset or liability in the financial statements prepared in accordance with generally accepted accounting principles. In a classified statement of financial position, an enterprise shall separate deferred tax liabilities and assets into a current amount and a noncurrent amount. Deferred tax liabilities and assets shall be classified as current or noncurrent based on the classification of the related asset or liability for financial reporting. A deferred tax liability or asset that is not related to an asset or liability for financial reporting, including deferred tax assets related to carryforwards, shall be classified according to the expected reversal date of the temporary difference. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Represents the noncurrent portion of deferred tax liabilities, which result from applying the applicable tax rate to net taxable temporary differences pertaining to each jurisdiction to which the entity is obligated to pay income tax. A noncurrent taxable temporary difference is a difference between the tax basis and the carrying amount of a noncurrent asset or liability in the financial statements prepared in accordance with generally accepted accounting principles. In a classified statement of financial position, an enterprise shall separate deferred tax liabilities and assets into a current amount and a noncurrent amount. Deferred tax liabilities and assets shall be classified as current or noncurrent based on the classification of the related asset or liability for financial reporting. A deferred tax liability or asset that is not related to an asset or liability for financial reporting, including deferred tax assets related to carryforwards, shall be classified according to the expected reversal date of the temporary difference. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The carrying amount of the asset transferred to a third party to serve as a deposit, which typically serves as security against failure by the transferor to perform under terms of an agreement. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
Fair values as of the balance sheet date of all assets resulting from contracts that meet the criteria of being accounted for as derivative instruments which are expected to exist longer than 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
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
Carrying amount as of the balance sheet date, which is the cumulative amount paid, adjusted for any amortization recognized prior to adoption of FAS 142 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
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
|
| X | ||||||||||
|
- Definition
Carrying value as of the balance sheet date of [accrued] interest payable on all forms of debt, including trade payables, that has been incurred and is unpaid. 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
Total of all Liabilities and Stockholders' Equity items. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Total obligations incurred as part of normal operations that is expected to be repaid beyond the following twelve months or one business cycle. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Total of the portions of the carrying amounts as of the balance sheet date of long-term debt, which may include notes payable, bonds payable, debentures, mortgage loans, and commercial paper, which are scheduled to be repaid within one year or the normal operating cycle, if longer, and after deducting unamortized discount or premiums, if any. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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 (current maturities) or the normal operating cycle, if longer, and after deducting unamortized discount or premiums, if any. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- 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 (noncontrolling interest, minority interest). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The carrying amount as of the balance sheet of nuclear fuel held as property plant and equipment. This amount is net of amortization based on the energy produced over the life of the fuel. No definition available.
|
| X | ||||||||||
|
- Definition
Aggregate carrying amount, as of the balance sheet date, of noncurrent assets not separately disclosed in the balance sheet due to materiality considerations. 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
|
| X | ||||||||||
|
- Definition
Aggregate carrying amount, as of the balance sheet date, of current obligations not separately disclosed in the balance sheet due to materiality considerations. Current liabilities are expected to be paid within one year (or the normal operating cycle, if longer). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Aggregate carrying amount, as of the balance sheet date, of noncurrent obligations not separately disclosed in the balance sheet due to materiality considerations. 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
|
| X | ||||||||||
|
- Definition
For a classified balance sheet, the amount recognized in balance sheet as a current liability associated with an underfunded defined benefit plan. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
Value of all nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer) held by shareholders, which is net of related treasury stock. May be all or a portion of the number of preferred shares authorized. These shares represent the ownership interest of the preferred shareholders. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Sum of the amounts paid in advance for capitalized costs that will be expensed with the passage of time or the occurrence of a triggering event, and will be charged against earnings within one year or the normal operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Period end book value of accumulated depreciation on property, plant and equipment (PPE) that is owned by the regulated operations of the public utility. No definition available.
|
| X | ||||||||||
|
- Definition
Period end amount of construction work in progress in public utility No definition available.
|
| X | ||||||||||
|
- Definition
Period end amount of total net PPE No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Period end amount of total gross PPE No definition available.
|
| X | ||||||||||
|
- Definition
The total amount due to the entity within one year of the balance sheet date (or one operating cycle, if longer) from outside sources, including trade accounts receivable, notes and loans receivable, as well as any other types of receivables, net of allowances established for the purpose of reducing such receivables to an amount that approximates their net realizable value. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
The amount for the individual regulatory noncurrent liability as itemized in a table of regulatory noncurrent liabilities as of the end of the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The cumulative amount of the reporting entity's undistributed earnings or deficit. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Carrying amount at the balance sheet date of borrowings from a bank, not elsewhere enumerated in the taxonomy, with a maturity within one year (or within one operating cycle if longer) from the date of borrowing. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Carrying value as of the balance sheet date of obligations incurred and payable for statutory income, sales, use, payroll, excise, real, property and other taxes. 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
Value of common and preferred shares of an entity that were issued, repurchased by the entity, and are held in its treasury. Treasury stock is issued but is not outstanding. This stock has no voting rights and receives no dividends. Note that treasury stock may be recorded at its total cost or separately as par (or stated) value and additional paid in capital. Note: number of treasury shares concept is in another section within stockholders' equity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Amortization based on the energy produced over the life of the fuel. No definition available.
|
| X | ||||||||||
|
- Definition
Preferred Shares, Issued Four and One Half No definition available.
|
| X | ||||||||||
|
- Definition
Preferred Shares, Issued Four and Thirty Five Hundreths No definition available.
|
| X | ||||||||||
|
- Definition
Preferred Shares, Issued Four and Two Tenths No definition available.
|
| X | ||||||||||
|
- Definition
Preferred Shares, Issued Three and Eight Tenths No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- 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
|
| 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
|
| X | ||||||||||
|
- Definition
Face amount or stated value per share of nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer); generally not indicative of the fair market value per share. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Number of common and preferred shares that were previously issued and that were repurchased by the issuing entity and held in treasury on the financial statement date. This stock has no voting rights and receives no dividends. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Equity component of Allowance for Funds Used During Construction and the aggregate amount of other income amounts resulting from ancillary business-related activities (that is, excluding major activities considered part of the normal operations of the business) also known as other nonoperating income recognized for the period. Such amounts may include: (a) dividends, (b) interest on securities, (c) profits on securities (net of losses), and (d) miscellaneous other income items. No definition available.
|
| X | ||||||||||
|
- Definition
Taxes other than income taxes, if not included elsewhere, that could include, property tax or other selling and distribution-related taxes. No definition available.
|
| X | ||||||||||
|
- Definition
Expenses related to Great Plains Energy's organizational realignment process and voluntary separation program undertaken to assist in the management of overall costs within the level reflected in the Company's retial electric rates and to enhance organizational efficiency. No definition available.
|
| X | ||||||||||
|
- Definition
Aggregate dividends declared during the period for each share of common stock outstanding. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Cost of electricity purchased and sold during the reporting period. No definition available.
|
| X | ||||||||||
|
- Definition
Cost incurred for transmission operations and maintenance by total kilowatt-hours paid to sources other than affiliates. No definition available.
|
| X | ||||||||||
|
- Definition
Total costs of sales and operating expenses for the period. No definition available.
|
| X | ||||||||||
|
- Details
|
| 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
|
| X | ||||||||||
|
- Definition
The amount of net income or loss for the period per each share of common stock outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The amount of net income or loss for the period per each share of common stock and dilutive common stock equivalents outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| 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
|
| X | ||||||||||
|
- Definition
Fuel costs incurred that are directly related to goods produced and sold and services rendered during the reporting period. No definition available.
|
| X | ||||||||||
|
- Definition
Sum of operating profit and nonoperating income (expense) before income (loss) from equity method investments, income taxes, extraordinary items, cumulative effects of changes in accounting principles, and noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
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- Definition
This element represents the income or loss from continuing operations attributable to the economic entity which may also be defined as revenue less expenses and taxes from ongoing operations before extraordinary items, cumulative effects of changes in accounting principles, and noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
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- Definition
The amount of income (loss) from continuing operations per each share of common stock outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amount of income (loss) from continuing operations available to each share of common stock outstanding during the reporting period and each share that would have been outstanding assuming the issuance of common shares for all dilutive potential common shares outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- 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. Such amount typically reflects adjustments similar to those made in preparing consolidated statements, including adjustments to eliminate intercompany gains and losses, and to amortize, if appropriate, any difference between cost and underlying equity in net assets of the investee at the date of investment. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- Definition
The sum of the current income tax expense (benefit) and the deferred income tax expense (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
|
| X | ||||||||||
|
- Definition
Amount of net income (loss) for the period allocated to noncontrolling shareholders, partners, or other equity holders in one or more of the entities consolidated into the reporting entity's financial statements other than joint ventures, limited partnerships, operating partnerships or interests held by preferred unit holders. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- Definition
The portion of consolidated profit or loss for the period, net of income taxes, which is attributable to the parent. If the entity does not present consolidated financial statements, the amount of profit or loss for the period, net of income taxes. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| 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
|
| X | ||||||||||
|
- Definition
The net result for the period of deducting operating expenses from operating revenues. No definition available.
|
| X | ||||||||||
|
- Definition
The sum of expenses not otherwise specified in the taxonomy for managing and administering the affairs of an entity, including affiliates of the reporting entity, which are not directly or indirectly associated with the manufacture, sale or creation of a product or product line. No definition available.
|
| X | ||||||||||
|
- Definition
Any other expense items resulting from secondary business-related activities, excluding those considered part of the normal operations of the business that have not been previously categorized. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amount of dividends declared or paid in the period to preferred shareholders, or the amount for which the obligation to pay them dividends arose in the 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 | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Discloses the amount of operating expense for the period related to operations. No definition available.
|
| X | ||||||||||
|
- Definition
The average number of shares issued and outstanding that are used in calculating diluted EPS, determined based on the timing of issuance of shares in the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Number of [basic] shares, after adjustment for contingently issuable shares and other shares not deemed outstanding, determined by relating the portion of time within a reporting period that common shares have been outstanding to the total time in that period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Cash outflow due to change during the period in the allowance for other funds used during construction classified as an investing activity. No definition available.
|
| X | ||||||||||
|
- Definition
The noncash expense, not otherwise specified in the taxonomy, charged against earnings in the period to allocate the cost of nuclear fuel over the operating cycle of the nuclear plant. No definition available.
|
| X | ||||||||||
|
- Definition
For continuing operations and discontinued operations, the current period expense charged against earnings on long-lived, physical assets used in the normal conduct of business and not intended for resale to allocate or recognize the cost of assets over their useful lives; or to record the reduction in book value of an intangible asset over the benefit period of such asset. Examples include buildings, production equipment and customer lists. No definition available.
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Definition
Net money pool lending No definition available.
|
| X | ||||||||||
|
- Definition
All other activities that impact operating cash flows. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The amount of amortization of deferred charges applied against earnings during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Includes currency on hand as well as demand deposits with banks or financial institutions. It also includes other kinds of accounts that have the general characteristics of demand deposits in that the Entity may deposit additional funds at any time and also effectively may withdraw funds at any time without prior notice or penalty. Cash equivalents, excluding items classified as marketable securities, include short-term, highly liquid investments that are both readily convertible to known amounts of cash, and so near their maturity that they present minimal risk of changes in value because of changes in interest rates. Generally, only investments with original maturities of three months or less qualify under that definition. Original maturity means original maturity to the entity holding the investment. For example, both a three-month US Treasury bill and a three-year Treasury note purchased three months from maturity qualify as cash equivalents. However, a Treasury note purchased three years ago does not become a cash equivalent when its remaining maturity is three months. Compensating balance arrangements that do not legally restrict the withdrawal or usage of cash amounts may be reported as Cash and Cash Equivalents, while legally restricted deposits held as compensating balances against borrowing arrangements, contracts entered into with others, or company statements of intention with regard to particular deposits should not be reported as cash and cash equivalents. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net change between the beginning and ending balance of cash and cash equivalents. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The component of income tax expense for the period representing the net change in the entity's deferred tax assets and liabilities pertaining to continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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. Such amount typically reflects adjustments similar to those made in preparing consolidated statements, including adjustments to eliminate intercompany gains and losses, and to amortize, if appropriate, any difference between cost and underlying equity in net assets of the investee at the date of investment. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amount deducted from an entities' taxes, reflecting a percentage of an amount invested in certain assets spread over the useful life of those assets; includes deferred investment tax credits. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net cash inflow (outflow) from financing activity for the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The net cash inflow (outflow) from investing activity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| 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. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The total of the cash outflow during the period which has been paid to third parties in connection with debt origination, which will be amortized over the remaining maturity period of the associated long-term debt and the cost incurred directly for the issuance of equity securities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net cash outflow (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
|
| X | ||||||||||
|
- Definition
The cash outflow from the entity's earnings to the shareholders. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The cash outflow associated with the acquisition of long-lived, physical assets that are used in the normal conduct of business to produce goods and services and not intended for resale; includes cash outflows to pay for construction of self-constructed assets. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The cash outflow from the costs of decontaminating and decommissioning of facilities through collection of revenues derived from utility assessments, government appropriations, and so forth. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The cash inflow from the costs of decontaminating and decommissioning of facilities through collection of revenues derived from utility assessments, government appropriations, and so forth. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The cash inflow from the additional capital contribution to the entity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| 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
|
| X | ||||||||||
|
- Definition
The cash inflow from other borrowing not otherwise defined in the taxonomy. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net cash inflow (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
|
| X | ||||||||||
|
- Definition
The net cash inflow (outflow) for borrowing having initial term of repayment within one year or the normal operating cycle, if longer. 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 | ||||||||||
|
- Definition
Sum of common stock value, retained earnings, treasury stock and accumulated other comprehensive income (loss) No definition available.
|
| X | ||||||||||
|
- Definition
Aggregate cash dividends declared for performance shares during the period. No definition available.
|
| X | ||||||||||
|
- Definition
Loss on treasury stock reissued at less than the average acquired value. No definition available.
|
| X | ||||||||||
|
- Definition
Sum of change in common stock not separately disclosed in the statement of stockholders' equtiy due to materiality considerations. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Definition
Unearned Compensation related to Restricted Stock Awards issued during the period No definition available.
|
| X | ||||||||||
|
- Definition
Represents the expense recognized during the period arising from share-based compensation arrangements (for example, shares of stock, 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 | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Aggregate cash, stock, and paid-in-kind dividends declared for common shareholders during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
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
Decrease in noncontrolling interest balance from payment of dividends or other distributions to noncontrolling interest holders. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The portion of consolidated profit or loss for the period, net of income taxes, which is attributable to the parent. If the entity does not present consolidated financial statements, the amount of profit or loss for the period, net of income taxes. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The portion of net income (loss) attributable to the noncontrolling interest (if any) deducted in order to derive the portion attributable to the parent. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Net changes to accumulated comprehensive income during the period related to benefit plans, after tax. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Net of tax effect change in accumulated gains and losses from derivative instruments designated and qualifying as the effective portion of cash flow hedges after taxes. A cash flow hedge is a hedge of the exposure to variability in the cash flows of a recognized asset or liability or a forecasted transaction that is attributable to a particular risk. The change includes an entity's share of an equity investee's increase (decrease) in deferred hedging gains or losses. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- Definition
Number of shares of stock issued as of the balance sheet date, including shares that had been issued and were previously outstanding but which are now held in the treasury. No definition available.
|
| X | ||||||||||
|
- Definition
Number of new stock issued during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Total number of shares issued during the period, including shares forfeited, as a result of Restricted Stock Awards. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Number of treasury shares reissued during the period. Upon reissuance, these are common and preferred shares outstanding. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Value of new stock issued during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Value of stock related to Restricted Stock Awards forfeited during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Aggregate value of stock related to Restricted Stock Awards issued during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Value of treasury stock reissued during the period. Upon reissuance, common and preferred stock are outstanding. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Number of shares that have been repurchased during the period and are being held in treasury. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Cost of common and preferred stock that were repurchased during the period. Recorded using the cost method. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The aamortization of other comprehensive income for net gain recognized as a component of net period benefit cost during the period, before tax. 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
|
| 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 noncontrolling interests, if any. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners, 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
|
| 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 economic entity, including both controlling (parent) and noncontrolling interests. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners, including 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
|
| X | ||||||||||
|
- Definition
Net changes to accumulated comprehensive income during the period related to benefit plans, after tax. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Tax effects of the net changes to accumulated comprehensive income during the period related to benefit plans. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Net of tax effect change in accumulated gains and losses from derivative instruments designated and qualifying as the effective portion of cash flow hedges after taxes. A cash flow hedge is a hedge of the exposure to variability in the cash flows of a recognized asset or liability or a forecasted transaction that is attributable to a particular risk. The change includes an entity's share of an equity investee's increase (decrease) in deferred hedging gains or losses. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Net of tax effect of the reclassification adjustment for accumulated gains and losses from derivative instrument designated and qualifying as the effective portion of cash flow hedges included in accumulated comprehensive income that was realized in net income during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Pre tax change in accumulated gains and losses from derivative instrument designated and qualifying as the effective portion of cash flow hedges. A cash flow hedge is a hedge of the exposure to variability in the cash flows of a recognized asset or liability or a forecasted transaction that is attributable to a particular risk. Includes an entity's share of an equity investee's increase (decrease) in deferred hedging gains or losses. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Change in accumulated gains and losses from derivative instrument designated and qualifying as the effective portion of cash flow hedges, net of tax effect. The after tax effect change includes an entity's share of an equity investee's increase (decrease) in deferred hedging gains or losses. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Tax effect on the change in accumulated gains and losses from derivative instruments designated and qualifying as the effective portion of cash flow hedges. Includes an entity's share of an equity investee's increase (decrease) in deferred hedging gains or losses. 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
|
|
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
|
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Significant Accounting Policies |
Organization Great Plains Energy, a Missouri corporation incorporated in 2001, is a public utility holding company and does not own or operate any significant assets other than the stock of its subsidiaries. Great Plains Energy’s wholly owned direct subsidiaries with operations or active subsidiaries are as follows:
Each of Great Plains Energy’s and KCP&L’s consolidated financial statements includes the accounts of their subsidiaries. Intercompany transactions have been eliminated. Great Plains Energy’s sole reportable business segment is electric utility. See Note 16 for additional information. Basic and Diluted Earnings per Common Share Calculation To determine basic EPS, preferred stock dividend requirements and net income (loss) attributable to noncontrolling interest are deducted from net income before dividing by the average number of common shares outstanding. The effect of dilutive securities, calculated using the treasury stock method, assumes the issuance of common shares applicable to performance shares, restricted stock, stock options and Equity Units. The following table reconciles Great Plains Energy’s basic and diluted EPS.
The computation of diluted EPS for the three months ended June 30, 2011, excludes anti-dilutive shares consisting of 201,571 performance shares, 12,115 restricted stock shares and 154,096 stock options. The computation of diluted EPS year to date June 30, 2011, excludes anti-dilutive shares consisting of 201,571 performance shares, 43,641 restricted stock shares and 154,096 stock options. The computation of diluted EPS for the three months ended June 30, 2010, excludes anti-dilutive shares consisting of 41,604 performance shares, 93,106 restricted stock shares and 207,290 stock options. The computation of diluted EPS year to date June 30, 2010, excludes anti-dilutive shares consisting of 50,034 performance shares, 251,526 restricted stock shares and 213,248 stock options. Dividends Declared In August 2011, Great Plains Energy’s Board of Directors (Board) declared a quarterly dividend of $0.2075 per share on Great Plains Energy’s common stock. The common dividend is payable September 20, 2011, to shareholders of record as of August 29, 2011. The Board also declared regular dividends on Great Plains Energy’s preferred stock, payable December 1, 2011, to shareholders of record as of November 9, 2011. In August 2011, KCP&L’s Board of Directors declared a cash dividend payable to Great Plains Energy of $25 million payable on September 16, 2011. |
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| X | ||||||||||
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- Details
|
| X | ||||||||||
|
- Definition
This element may be used to describe all significant accounting policies of the reporting entity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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|
SUPPLEMENTAL CASH FLOW INFORMATION
|
6 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Supplemental Cash Flow Information |
Significant Non-Cash Items On January 1, 2010, Great Plains Energy and KCP&L adopted new accounting guidance for transfers of financial assets, which resulted in the recognition of $95.0 million of accounts receivable pledged as collateral and a corresponding short-term collateralized note payable on Great Plains Energy’s and KCP&L’s balance sheets. As a result, cash flows from operating activities were reduced by $95.0 million and cash flows from financing activities were raised by $95.0 million with no impact to the net change in cash year to date June 30, 2010. |
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- Definition
Designated to encapsulate the entire footnote disclosure that provides information on the supplemental cash flow activities, including cash, noncash, and part noncash transactions, for the period. Noncash is defined as information about all investing and financing activities of an enterprise during a period that affect recognized assets or liabilities but that do not result in cash receipts or cash payments in the period. "Part noncash" refers to that portion of the transaction not resulting in cash receipts or cash payments in the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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RECEIVABLES
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Receivables |
Great Plains Energy’s and KCP&L’s receivables are detailed in the following table.
Great Plains Energy’s and KCP&L’s other receivables at June 30, 2011, and December 31, 2010, consisted primarily of receivables from partners in jointly owned electric utility plants and wholesale sales receivables. Sale of Accounts Receivable – KCP&L KCP&L sells all of its retail electric accounts receivable to its wholly owned subsidiary, Receivables Company, which in turn sells an undivided percentage ownership interest in the accounts receivable to Victory Receivables Corporation, an independent outside investor. Receivables Company’s sale of the undivided percentage ownership interest in accounts receivable to Victory Receivables Corporation is accounted for as a secured borrowing with $95.0 million of accounts receivables pledged as collateral and a corresponding short-term collateralized note payable recognized on Great Plains Energy’s and KCP&L’s balance sheets at June 30, 2011, and December 31, 2010. KCP&L sells its receivables at a fixed price based upon the expected cost of funds and charge-offs. These costs comprise KCP&L’s loss on the sale of accounts receivable. KCP&L services the receivables and receives an annual servicing fee of 1.5% of the outstanding principal amount of the receivables sold to Receivables Company. KCP&L does not recognize a servicing asset or liability because management determined the collection agent fee earned by KCP&L approximates market value. The agreement expires in October 2011 and is expected to be renewed. Information regarding KCP&L’s sale of accounts receivable to Receivables Company is reflected in the following tables.
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- Definition
Includes disclosure of claims held for amounts due a company. Examples include trade accounts receivables, notes receivables, loans receivables. Also provides the disclosures pertaining to a transferor's continuing involvement in financial assets that it has transferred in a securitization or asset-backed financing arrangement, the nature of any restrictions on assets reported by an entity in its statement of financial position that relate to a transferred financial asset (including the carrying amounts of such assets), how servicing assets and servicing liabilities are reported, and (for securitization or asset-backed financing arrangements accounted for as sales) when a transferor has continuing involvement with the transferred financial assets and transfers of financial assets accounted for as secured borrowings, how the transfer of financial assets affects an entity's financial position, financial performance, and cash flows. No definition available.
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NUCLEAR PLANT
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Nuclear plant |
KCP&L owns 47% of Wolf Creek Generating Station (Wolf Creek), its only nuclear generating unit. Wolf Creek is located in Coffey County, Kansas, just northeast of Burlington, Kansas. Wolf Creek’s operating license expires in 2045. Wolf Creek is regulated by the Nuclear Regulatory Commission (NRC), with respect to licensing, operations and safety-related requirements. Wolf Creek had been on a status that called for heightened NRC oversight. In May 2011, the NRC moved Wolf Creek back to the lowest level of NRC oversight. In March 2011, the NRC established a task force to conduct a 90-day review and a longer-term review of U.S. nuclear power plant safety in the aftermath of a March 11, 2011, earthquake and tsunami that eventually resulted in station blackout and a level 7 event on the International Nuclear and Radiological Event Scale (the highest level event on the scale) at Japan’s Fukushima Daiichi nuclear power plant. On July 12, 2011, the task force issued an extensive report on the ramifications of the Fukushima earthquake/tsunami for nuclear power plant regulation in the U.S. The report confirms the safety of nuclear plants in the U.S., but also contains several recommendations to enhance nuclear plant safety and preparedness to manage severe events. The NRC will begin systematically reviewing the report and recommendations through their regulatory process. The timing and effects of any NRC action cannot be determined at this time. Spent Nuclear Fuel and High-Level Radioactive Waste Under the Nuclear Waste Policy Act of 1982, the Department of Energy (DOE) is responsible for the permanent disposal of spent nuclear fuel. KCP&L pays the DOE a quarterly fee of one-tenth of a cent for each kWh of net nuclear generation delivered and sold for the future disposal of spent nuclear fuel. These disposal costs are charged to fuel expense. In March 2010, the DOE filed a motion to withdraw its application to the NRC to construct a national repository for the disposal of spent nuclear fuel and high-level radioactive waste at Yucca Mountain, Nevada, which would bring the licensing process to an end. An NRC board denied the DOE’s motion to withdraw its application in June 2010, and the DOE appealed that decision to the full NRC in July 2010. The NRC has not yet decided that appeal. Additional lawsuits had been filed questioning the DOE’s legal authority to withdraw its license application but on July 1, 2011, a federal appellate court dismissed the lawsuits. Wolf Creek has an on-site storage facility designed to hold all spent fuel generated at the plant through 2025, and believes it will be able to expand on-site storage as needed past 2025. Management cannot predict when, or if, an alternative disposal site will be available to receive Wolf Creek’s spent nuclear fuel and will continue to monitor this activity. See Note 11 for a related legal proceeding. Low-Level Radioactive Waste Wolf Creek disposes of most of its low-level radioactive waste (Class A waste) at an existing third-party repository in Utah. Management expects that the site located in Utah will remain available to Wolf Creek for disposal of its Class A waste. Wolf Creek has contracted with a waste processor that will process, take title and store in another state most of the remainder of Wolf Creek’s low-level radioactive waste (Classes B and C waste, which is higher in radioactivity but much lower in volume). Should on-site waste storage be needed in the future, Wolf Creek has current storage capacity on site for about four years’ generation of Classes B and C waste and believes it will be able to expand that storage capacity as needed if it becomes necessary to do so. Nuclear Decommissioning Trust Fund The following table summarizes the change in Great Plains Energy’s and KCP&L’s nuclear decommissioning trust fund.
The nuclear decommissioning trust is reported at fair value on the balance sheets and is invested in assets as detailed in the following table.
The weighted average maturity of debt securities held by the trust at June 30, 2011, was approximately 7.5 years. The costs of securities sold are determined on the basis of specific identification. The following table summarizes the realized gains and losses from the sale of securities by the nuclear decommissioning trust fund.
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This element can be used to encapsulate the entire disclosure for plant used in connection with the generation of nuclear energy. No definition available.
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REGULATORY MATTERS
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Regulatory matters |
KCP&L Kansas Rate Case Proceedings In November 2010, KCC issued an order, effective December 1, 2010, for KCP&L, authorizing an increase in annual revenues of $21.8 million, a return on equity of 10.0%, an equity ratio of approximately 49.7% and a Kansas jurisdictional rate base of $1.781 billion. The annual revenue increase was subsequently adjusted by KCC in a January 2011 reconsideration order to $22.0 million. In February 2011, KCC issued an order granting KCP&L and another party to the case their respective petitions for reconsideration regarding rate case expenses and therefore, approximately $1.4 million of the annual revenue increase is considered as interim subject to refund or true-up pending the outcome of the reconsideration proceedings regarding rate case expenses. A hearing is scheduled for September 2011 with a decision expected in the fourth quarter of 2011. The rates authorized by KCC are effective unless and until modified by KCC or stayed by a court. KCP&L Missouri Rate Case Proceedings On June 4, 2010, KCP&L filed a request with the MPSC to increase its Missouri retail electric annual revenues by $92.1 million. The request was ultimately adjusted during the rate case proceedings by KCP&L to $66.5 million as the net result of lower fuel and purchased power costs and other updates to the case. KCP&L’s initial and updated requests reflected, among other things, a proposed annual offset to its revenue requirement for the Missouri jurisdictional portion of KCP&L’s annual non-firm wholesale electric sales margin (wholesale margin offset); the final update included a proposed wholesale margin offset of approximately $29.4 million. On April 12, 2011, the MPSC issued its order and on April 14, 2011, the MPSC Staff filed a report which quantified the authorized revenue increase as approximately $34.8 million on an annual basis, which reflects a wholesale margin offset of approximately $45.9 million and authorizes a return on equity of 10.0%, an equity ratio of approximately 46.3% and a Missouri jurisdictional rate base of approximately $2.0 billion. If the actual Missouri jurisdiction wholesale margin amount exceeds the $45.9 million level reflected in the MPSC order, the difference will be recorded as a regulatory liability and will be returned, with interest, to KCP&L Missouri customers in a future rate case. The MPSC order provides the opportunity for KCP&L to retain a larger amount of non-firm wholesale electric sales margin than KCP&L proposed; however, there are no assurances that KCP&L will achieve the $45.9 million wholesale margin offset amount and there are no means for KCP&L to recover any shortfall through its retail rates. The rates established by the MPSC order took effect on May 4, 2011. As a result of disallowances in the MPSC order, KCP&L recognized losses of $1.5 million for construction costs related to Iatan No. 2 and the Iatan No. 1 environmental project year to date June 30, 2011. KCP&L also recorded a $2.4 million loss for other disallowed costs in the MPSC order. In a related order, the MPSC required KCP&L and GMO to apply to the Internal Revenue Service to reallocate approximately $26.5 million of Iatan No. 2 qualifying advance coal project tax credits from KCP&L to GMO, which they have done and are awaiting a decision. If KCP&L and GMO are unsuccessful, the MPSC has indicated that it intends for GMO’s customers to be compensated for the tax credits and that it will consider the ratemaking treatment of the tax credits in a future rate case. Certain ratemaking treatments that may be pursued by the MPSC could trigger the loss or repayment to the Internal Revenue Service of a portion of unamortized deferred investment tax credits. At June 30, 2011, KCP&L and GMO had $128.9 million and $3.7 million, respectively, of unamortized deferred investment tax credits. GMO Missouri Rate Case Proceedings On June 4, 2010, GMO filed requests with the MPSC to increase its Missouri retail electric annual revenues by $75.8 million for its Missouri Public Service division, and $22.1 million for its St. Joseph Light & Power (L&P) division. GMO subsequently adjusted its requests during the rate case proceedings to $65.9 million and $23.2 million, respectively, as the net result of updates to the cases. On May 4, 2011, the MPSC issued its order and on May 10, 2011, the MPSC Staff filed a report which quantified the authorized revenue increases on an annual basis as $30.1 million for GMO’s Missouri Public Service division and $29.3 million for GMO’s L&P division. The MPSC order authorized a return on equity of 10.0%, an equity ratio of approximately 46.6% and a Missouri jurisdictional rate base of $1.76 billion. In response to applications for clarification and rehearing of the MPSC order, the MPSC, on May 27, 2011, issued an order of clarification and modification. The modified MPSC order revised the authorized annual revenue increase to approximately $35.7 million for GMO’s Missouri Public Service division and approximately $29.8 million for GMO’s L&P division, resulting primarily from a clarification of the amount of fuel costs shifted from GMO’s fuel adjustment clause to base rates. However, because the MPSC authorized an annual revenue increase that was greater than the amount originally requested by GMO and communicated to GMO’s customers, the modified MPSC order deferred approximately $7.7 million of the L&P division increase, which is the amount over GMO’s requested $22.1 million increase for that division, and will phase in the deferred revenue amount in equal parts over a two-year period, plus carrying costs. As a result of disallowances in the MPSC order, GMO recognized losses of $0.8 million for construction costs related to Iatan No. 2 and the Iatan No. 1 environmental project year to date June 30, 2011. GMO also recorded a $1.5 million loss for other disallowed costs in the MPSC order. Additionally, with respect to GMO’s Missouri Public Service division, the MPSC concluded that GMO’s decision to add Crossroads Energy Center (Crossroads) to its generation asset resources was prudent and reasonable; however, the order disallowed from rate base approximately $50 million for Crossroads, disallowed $4.9 million in associated annual transmission expense and offset rate base by approximately $15 million to reflect accumulated deferred taxes associated with Crossroads. GMO’s request included a net plant amount of approximately $104 million for Crossroads. In assessing the impact of the Crossroads disallowances, management considered that KCP&L’s and GMO’s generation asset resources include a diverse fuel mix consisting primarily of coal and nuclear fuel providing base load generation with natural gas facilities such as Crossroads to provide critical peaking and capacity support. This combined collection of generating assets meets KCP&L’s and GMO’s service obligations and produces joint cash flows based on system-wide average costs. Great Plains Energy conducted an analysis to assess the recoverability of the combined collection of generation asset resources and determined that no potential impairment exists. The rates established by the modified MPSC order took effect on June 25, 2011. On June 24, 2011, GMO filed its appeal of the MPSC order with the Cole County, Missouri, Circuit Court regarding the Crossroads issues discussed above. Other parties to the case have also filed appeals of the MPSC order. However, the rates authorized by the modified MPSC order will be effective unless and until modified by the MPSC or stayed by a court. SPP and NERC Inquiries The Southwest Power Pool, Inc. (SPP) conducted a compliance inquiry regarding a transmission system outage that occurred in the St. Joseph, Missouri area in the summer of 2009. The North American Electric Reliability Corporation (NERC) is also investigating the circumstances surrounding this transmission system outage. The outcome of the outage inquiry cannot be predicted at this time. MPSC Regulatory Approval of the GMO Acquisition Appeals of the MPSC order approving the GMO acquisition were filed with the Cole County, Missouri, Circuit Court, which affirmed the order in June 2009. That decision was appealed and the Missouri Court of Appeals, Western District, upheld the MPSC order in August 2010. The case was transferred to the Missouri Supreme Court in December 2010. On July 19, 2011, the Missouri Supreme Court affirmed the Circuit Court’s ruling that affirmed the MPSC order approving the GMO acquisition. Regulatory Assets and Liabilities Great Plains Energy’s and KCP&L’s regulatory assets and liabilities are detailed in the following tables.
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PENSION PLANS AND OTHER EMPLOYEE BENEFITS
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Pension Plans, Other Employee Benefits and Voluntary Separation Program |
Great Plains Energy maintains defined benefit pension plans for substantially all active and inactive employees, including officers, and also provides certain post-retirement health care and life insurance benefits for substantially all retired employees of KCP&L, GMO, and Wolf Creek Nuclear Operating Corporation (WCNOC). KCP&L and GMO record pension expense in accordance with rate orders from the MPSC and KCC that allow the difference between pension costs under Generally Accepted Accounting Principles (GAAP) and pension costs for ratemaking to be recognized as a regulatory asset or liability. The current rate orders allow similar regulatory treatment for post-retirement benefits. The differences between the financial and regulatory accounting methods are due to timing and will be eliminated over the life of the pension and post-retirement plans. The following tables provide Great Plains Energy’s components of net periodic benefit costs prior to the effects of capitalization and sharing with joint-owners of power plants.
Year to date June 30, 2011, Great Plains Energy contributed $31.6 million to the pension plans and expects to contribute an additional $82.2 million in 2011 to satisfy the funding requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA), and the MPSC and KCC rate orders, the majority of which is expected to be paid by KCP&L. Also in 2011, the Company expects to contribute $17.1 million to the post-retirement benefit plans, of which the majority will be funded by KCP&L. Voluntary Separation Program In March 2011, Great Plains Energy and KCP&L announced an organizational realignment and voluntary separation program to assist in the management of overall costs within the level reflected in the Companies’ retail electric rates and to enhance organizational efficiency. Savings from the realignment process and voluntary separation program, including approximately $15 million in labor costs on an annual basis, are expected to partially offset projected cost increases. Under the voluntary separation program, any non-union employee could voluntarily elect to separate and receive a severance payment equal to two weeks of salary for every year of employment, with a minimum severance payment equal to fourteen weeks of salary. There were 140 employees that made such elections and the majority separated on April 30, 2011. Great Plains Energy recorded $3.0 million and $12.7 million, respectively, for the three months ended and year to date June 30, 2011, related to this voluntary separation program reflecting severance and related payroll taxes to employees who elected to voluntarily separate. KCP&L recorded $2.4 million and $9.2 million, respectively, for the three months ended and year to date June 30, 2011, related to this voluntary separation program. At June 30, 2011, there was no material pension settlement charge from the voluntary separation program as a result of accelerated pension distributions. The Companies will continue to assess if a material pension settlement charge may result from additional accelerated pension distributions subsequent to June 30, 2011. If a pension settlement charge is incurred, the Companies expect to defer the charge and recover it over future periods pursuant to existing and past regulatory agreements. The amount of accelerated pension distributions resulting from the voluntary separation program may also result in increased pension funding requirements in 2011 under ERISA. |
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Description containing the entire pension and other postretirement benefits disclosure as a single block of text. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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EQUITY COMPENSATION
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Jun. 30, 2011
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| Equity Compensation |
Great Plains Energy’s Long-Term Incentive Plan is an equity compensation plan approved by Great Plains Energy’s shareholders. The Long-Term Incentive Plan permits the grant of restricted stock, stock options, limited stock appreciation rights, director shares, director deferred share units and performance shares to directors, officers and other employees of Great Plains Energy and KCP&L. Forfeiture rates are based on historical forfeitures and future expectations and are reevaluated annually. The following table summarizes Great Plains Energy’s and KCP&L’s equity compensation expense and associated income tax benefits.
Performance Shares Performance share activity year to date June 30, 2011, is summarized in the following table.
At June 30, 2011, the remaining weighted-average contractual term was 1.4 years. The weighted-average grant-date fair value of shares granted was $26.28 and $22.48 for the three months ended and year to date June 30, 2011, respectively. There were no shares granted for the three months ended June 30, 2010. The weighted-average grant-date fair value of shares granted year to date June 30, 2010, was $23.37. At June 30, 2011, there was $4.7 million of total unrecognized compensation expense, net of forfeiture rates, related to performance shares granted under the Long-Term Incentive Plan, which will be recognized over the remaining weighted-average contractual term. The total fair value of performance shares earned and paid year to date June 30, 2011 and 2010, was $0.8 million and insignificant, respectively. The fair value of performance share awards is estimated using a Monte Carlo simulation technique that uses the closing stock price at the valuation date and incorporates assumptions for inputs of expected volatilities, dividend yield and risk-free rates. Expected volatility is based on daily stock price change during a historical period commensurate with the remaining term of the performance period of the grant. The risk-free rate is based upon the rate at the time of the evaluation for zero-coupon government bonds with a maturity consistent with the remaining performance period of the grant. The dividend yield is based on the most recent dividends paid and the actual closing stock price on the valuation date. For shares granted in 2011, inputs for expected volatility, dividend yield and risk-free rates were 30%, 4.35%, and 1.15%, respectively. Restricted Stock Restricted stock activity year to date June 30, 2011, is summarized in the following table.
At June 30, 2011, the remaining weighted-average contractual term was 1.7 years. The weighted-average grant-date fair value of shares granted for the three months ended and year to date June 30, 2011, was $20.26 and $19.26, respectively. The weighted-average grant-date fair value of shares granted for the three months ended and year to date June 30, 2010, was $16.88 and $17.67, respectively. At June 30, 2011, there was $3.5 million of total unrecognized compensation expense, net of forfeiture rates, related to nonvested restricted stock granted under the Long-Term Incentive Plan, which will be recognized over the remaining weighted-average contractual term. The total fair value of shares vested for the three months ended and year to date June 30, 2011, was $0.6 million and $2.6 million, respectively. The total fair value of shares vested for the three months ended and year to date June 30, 2010, was $1.5 million and $6.4 million, respectively. |
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Disclosure of compensation-related costs for share-based compensation which may include disclosure of policies, compensation plan details, allocation of stock compensation, incentive distributions, share-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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SHORT-TERM BORROWINGS AND SHORT-TERM BANK LINES OF CREDIT
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| Short-term debt |
Great Plains Energy’s $200 Million Revolving Credit Facility Great Plains Energy’s $200 million revolving credit facility with a group of banks expires in August 2013. The facility’s terms permit transfers of unused commitments between this facility and the KCP&L and GMO facilities discussed below, with the total amount of the facility not exceeding $400 million at any one time. A default by Great Plains Energy or any of its significant subsidiaries on other indebtedness totaling more than $50.0 million is a default under the facility. Under the terms of this facility, Great Plains Energy is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the facility, not greater than 0.65 to 1.00 at all times. At June 30, 2011, Great Plains Energy was in compliance with this covenant. At June 30, 2011, Great Plains Energy had $27.0 million of outstanding cash borrowings with a weighted-average interest rate of 2.94% and had issued letters of credit totaling $11.6 million under the credit facility. At December 31, 2010, Great Plains Energy had $9.5 million of outstanding cash borrowings with a weighted-average interest rate of 3.06% and had issued letters of credit totaling $15.8 million under the credit facility. KCP&L’s $600 Million Revolving Credit Facility and Commercial Paper KCP&L’s $600 million revolving credit facility with a group of banks to provide support for its issuance of commercial paper and other general corporate purposes expires in August 2013. Great Plains Energy and KCP&L may transfer up to $200 million of unused commitments between Great Plains Energy’s and KCP&L’s facilities. A default by KCP&L on other indebtedness totaling more than $50.0 million is a default under the facility. Under the terms of this facility, KCP&L is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the facility, not greater than 0.65 to 1.00 at all times. At June 30, 2011, KCP&L was in compliance with this covenant. At June 30, 2011, KCP&L had $476.7 million of commercial paper outstanding, at a weighted-average interest rate of 0.38%, $31.4 million of letters of credit outstanding and no outstanding cash borrowings under the facility. At December 31, 2010, KCP&L had $263.5 million of commercial paper outstanding, at a weighted-average interest rate of 0.41%, $24.4 million of letters of credit outstanding and no outstanding cash borrowings under the facility. GMO’s $450 Million Revolving Credit Facility GMO’s $450 million revolving credit facility with a group of banks expires in August 2013. Great Plains Energy and GMO may transfer up to $200 million of unused commitments between Great Plains Energy’s and GMO’s facilities. A default by GMO, Great Plains Energy or any of its significant subsidiaries on other indebtedness totaling more than $50.0 million is a default under the facility. Under the terms of this facility, GMO is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the facility, not greater than 0.65 to 1.00 at all times. At June 30, 2011, GMO was in compliance with this covenant. At June 30, 2011, GMO had $65.0 million of outstanding cash borrowings with a weighed-average interest rate of 2.94% and had issued letters of credit totaling $13.2 million under the credit facility. At December 31, 2010, GMO had no outstanding cash borrowings and had issued letters of credit totaling $13.2 million under the credit facility. |
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LONG-TERM DEBT
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| Long-term debt |
Great Plains Energy’s and KCP&L’s long-term debt is detailed in the following table.
Fair Value of Long-Term Debt Fair value of long-term debt is based on quoted market prices, with the incremental borrowing rate for similar debt used to determine fair value if quoted market prices were not available. At June 30, 2011, and December 31, 2010, the book value of Great Plains Energy’s long-term debt, including current maturities, was $3.3 billion and $3.4 billion, respectively. At June 30, 2011, and December 31, 2010, the fair value of Great Plains Energy’s long-term debt, including current maturities, was $3.6 billion and $3.7 billion, respectively. At June 30, 2011, and December 31, 2010, the book value of KCP&L’s long-term debt, including current maturities, was $1.7 billion and $1.8 billion, respectively. At June 30, 2011, and December 31, 2010, the fair value of KCP&L’s long-term debt, including current maturities, was $1.8 billion and $1.9 billion, respectively. KCP&L General Mortgage Bonds and EIRR Bonds In April 2011, KCP&L purchased in lieu of redemption its $63.3 million EIRR Series 2007A-1, $10.0 million EIRR Series 2007A-2 and $39.5 million EIRR Series 1993B bonds. KCP&L opted to purchase rather than remarket the bonds given the poor conditions in the tax-exempt market. KCP&L issued commercial paper to fund the purchase of the bonds. As of June 30, 2011, the bonds were still outstanding, but were not reported as a liability on the balance sheet since they are being held by KCP&L. KCP&L has the ability to remarket these bonds to third parties whenever it determines market conditions are sufficiently attractive to do so. GMO Senior Notes GMO repaid its $137.3 million 7.95% Senior Notes that matured in February 2011 and $197.0 million 7.75% Senior Notes that matured in June 2011. Great Plains Energy Senior Notes In May 2011, Great Plains Energy issued $350.0 million of 4.85% unsecured Senior Notes, maturing in 2021. As a result of amortizing the loss recognized in Other Comprehensive Income (OCI) on Great Plains Energy’s three-year forward Starting Swaps (FSS), the effective interest rate is 7.34% through May 2014. Great Plains Energy 10.00% Equity Units Subordinated Notes Classified As Current Maturities In May 2009, Great Plains Energy issued $287.5 million of Equity Units. Equity Units, each with a stated amount of $50, initially consist of a 5% undivided beneficial interest in $1,000 principal amount of 10.00% subordinated notes due June 15, 2042, and a purchase contract requiring the holder to purchase the Company’s common stock by June 15, 2012 (the settlement date). Great Plains Energy must attempt to remarket the subordinated notes, in whole but not in part, between December 15, 2011, and June 12, 2012. The proceeds from a successful remarketing will be used to satisfy the holders’ obligation under the purchase contract. If the notes have not been successfully remarketed by June 12, 2012, the holders of all notes will have the right to put their notes to Great Plains Energy on June 15, 2012, in satisfaction of the holders’ obligation under the purchase contracts, and Great Plains Energy will issue to the holders newly issued shares of the Company’s common stock equal to the settlement rate. The settlement rate will vary according to the applicable market value of the Company’s common stock at the settlement date. |
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This element may be used as a single block of text to encapsulate the entire disclosure for long-term borrowings including data and tables. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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COMMITMENTS AND CONTINGENCIES
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| Notes to Financial Statements [Abstract] | |||||||||||||
| Commitments and contingencies |
Environmental Matters Great Plains Energy and KCP&L are subject to extensive regulation by federal, state and local authorities with regard to environmental matters primarily through their utility operations. In addition to imposing extensive and continuing compliance obligations, laws, regulations and permits authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. The cost of complying with current and future environmental requirements is expected to be material to Great Plains Energy and KCP&L. Failure to comply with environmental requirements or to timely recover environmental costs through rates could have a material adverse effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows. The following discussion groups environmental and certain associated matters into the broad categories of air and climate change, water, solid waste and remediation. Air and Climate Change Overview The Clean Air Act and associated regulations enacted by the Environmental Protection Agency (EPA) form a comprehensive program to preserve air quality. States are required to establish regulations and programs to address all requirements of the Clean Air Act and have the flexibility to enact more stringent requirements. All of Great Plains Energy’s and KCP&L’s generating facilities, and certain of their other facilities, are subject to the Clean Air Act. Great Plains Energy’s and KCP&L’s current estimate of capital expenditures (exclusive of AFUDC and property taxes) to comply with the currently-effective Clean Air Interstate Rule (CAIR), the replacement to CAIR or the Cross-State Air Pollution Rule (CSAPR), the best available retrofit technology (BART) rule, the SO2 national ambient air quality standard (NAAQS), the industrial boiler rule and proposed maximum achievable control technology (MACT) standards for mercury and other hazardous air pollutant emissions (all of which are discussed below) is approximately $1 billion. The actual cost of compliance with any existing, proposed or future rules may be significantly different from the cost estimate provided. The approximate $1 billion current estimate of capital expenditures reflects the following high-likelihood capital projects:
Other capital projects at KCP&L’s Montrose Nos. 1 and 2 and GMO’s Sibley Nos. 1 and 2 and Lake Road Nos. 4 and 6 are possible but are currently considered less likely. Any capacity and energy requirements resulting from a decision not to proceed with these less likely projects is currently expected to be met through renewable energy additions required under Missouri and Kansas renewable energy standards, demand side management programs, construction of combustion turbines and/or combined cycle units, and/or purchased power agreements. The estimate does not reflect the non-capital costs the Companies incur on an ongoing basis to comply with environmental laws, which may increase in the future due to the Companies’ ongoing compliance with current or future environmental laws. The Companies expect to seek recovery of the costs associated with environmental requirements through rate increases; however, there can be no assurance that such rate increases would be granted. The Companies may be subject to materially adverse rate treatment in response to competitive, economic, political, legislative or regulatory pressures and/or public perception of the Companies’ environmental reputation. Clean Air Interstate Rule (CAIR) and Cross-State Air Pollution Rule (CSAPR) The CAIR requires reductions in SO2 and NOx emissions in 28 states, including Missouri. The reductions in SO2 and NOx emissions are accomplished through statewide caps for NOx and SO2. Great Plains Energy’s and KCP&L’s fossil fuel-fired plants located in Missouri are subject to CAIR, while their fossil fuel-fired plants in Kansas are not. On July 11, 2008, the D.C. Circuit Court of Appeals vacated CAIR in its entirety and remanded the matter to the EPA to promulgate a new rule consistent with its opinion. On December 23, 2008, the Court issued an order remanding CAIR to the EPA to revise the rule consistent with its July 2008 order. The CAIR remains in effect through 2011. CAIR currently establishes a market-based cap-and-trade program with an emission allowance allocation. Facilities demonstrate compliance with CAIR by holding sufficient allowances for each ton of SO2 and NOx emitted in any given year. KCP&L and GMO are currently allowed to utilize unused SO2 emission allowances that they have either accumulated during previous years of the Acid Rain Program or purchased to meet the more stringent CAIR requirements. At June 30, 2011, KCP&L had accumulated unused SO2 emission allowances sufficient to support over 150,000 tons of SO2 emissions (enough to support expected requirements under the CAIR and the Acid Rain Program for the foreseeable future) under the provisions of the Acid Rain program, which are recorded in inventory at zero cost. At June 30, 2011, GMO had accumulated unused SO2 emission allowances sufficient to support just over 13,000 tons of SO2 emissions (enough to support expected requirements under the CAIR and Acid Rain Program through 2011), which it has received under the Acid Rain Program or purchased, and are recorded in inventory at average cost. KCP&L and GMO purchase NOx allowances as needed. In July 2011, the EPA finalized the CSAPR to replace the currently-effective CAIR. The CSAPR, like CAIR, will require the states within its scope to reduce power plant SO2 and NOx emissions that contribute to ozone and fine particle nonattainment in other states. The geographical scope of the CSAPR is broader than CAIR, and includes Kansas in addition to Missouri and other states. Kansas and Missouri are only included for fine particulate matter control in the final CSAPR, but the EPA concurrently proposed a supplemental notice of proposed rulemaking to include both states for ozone season control which the EPA intends to finalize in October 2011. The CSAPR would also impose more stringent emissions limitations than CAIR and, unlike CAIR, would not utilize Acid Rain Program allowances for compliance. In the CSAPR, the EPA set an emissions budget for each of the affected states. The CSAPR allows limited interstate emissions allowance trading among power plants; however, it does not permit trading of SO2 allowances between the Companies’ Kansas and Missouri power plants. Compliance with the CSAPR begins in 2012. There would be additional reductions in SO2 allowances allocable to the Companies’ Missouri power plants taking effect in 2014. There is no such 2014 additional reduction in SO2 allowances allocable to the Companies’ Kansas power plants. The finalized CSAPR is complex and Great Plains Energy and KCP&L are evaluating its impacts. The Companies project that they may not be allocated sufficient SO2 or NOX emissions allowances to cover their currently expected operations starting in 2012. Any shortfall in allocated allowances is anticipated to be addressed through a combination of permissible allowance trading, installing additional emission control equipment, changes in plant processes, or purchasing additional power in the wholesale market. Best Available Retrofit Technology (BART) Rule The EPA BART rule directs state air quality agencies to identify whether visibility-reducing emissions from sources subject to BART are below limits set by the state or whether retrofit measures are needed to reduce emissions. BART applies to specific eligible facilities including KCP&L’s LaCygne Nos. 1 and 2 in Kansas, KCP&L’s Iatan No. 1, in which GMO has an 18% interest, KCP&L’s Montrose No. 3 in Missouri, GMO’s Sibley Unit No. 3 and Lake Road Unit No. 6 in Missouri and Westar Energy, Inc.’s (Westar) Jeffrey Unit Nos. 1 and 2 in Kansas, in which GMO has an 8% interest. Both Missouri and Kansas have submitted BART plans to the EPA but neither Missouri nor Kansas has received EPA approval for their BART plans. Mercury and Other Hazardous Air Pollutant Emissions In January 2009, the EPA issued a memorandum stating that new electric steam generating units (EGUs) that began construction while the Clean Air Mercury Rule (CAMR) was effective are subject to a new source MACT determination on a case-by-case basis. In July 2009, the EPA sent letters notifying KCP&L that MACT determinations and schedules of compliance are required for coal and oil-fired EGUs that began actual construction or reconstruction after December 15, 2000, and identified Iatan No. 2 and Hawthorn No. 5 as affected EGUs. This was an outcome of the D.C. Court of Appeals’ vacatur of both the CAMR and the contemporaneously promulgated rule removing EGUs from MACT requirements. In May 2011, KCP&L received a letter from the Missouri Department of Natural Resources (MDNR) stating the MACT determination was not required for Hawthorn No. 5. It is not currently known how MACT determinations and schedules of compliance will impact the permitting or operating requirements for Iatan No. 2, but it is possible a MACT determination may ultimately require additional emission control equipment and permit limits. In April 2010, the EPA, in a court approved settlement, agreed to develop MACT standards for mercury and potentially other hazardous air pollutant emissions. In the settlement agreement, the EPA agreed to propose MACT standards in March 2011 with final standards by November 2011. In March 2011, the EPA issued a proposed rule that would reduce emissions of hazardous air pollutants from new and existing coal-fired EGUs with a capacity of 25MW or greater. The proposed rule would establish numerical emission limits for mercury, particulate matter (a surrogate for non-mercury metals), and hydrogen chloride (a surrogate for acid gases). The proposed rule would establish work practices, instead of numerical emission limits, for organic hazardous air pollutants, including dioxin/furan. Compliance with the rule would need to be addressed by installing additional emission control equipment, changes in plant operation, purchasing additional power in the wholesale market or a combination of these and other alternatives. Any final rule could have a significant adverse effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows. Industrial Boiler Rule In February 2011, the EPA issued a final rule that would reduce emissions of hazardous air pollutants from new and existing industrial boilers. The final rule establishes numeric emission limits for mercury, dioxin, particulate matter (as a surrogate for non-mercury metals), hydrogen chloride (as a surrogate for acid gases), and carbon monoxide (as a surrogate for non-dioxin organic hazardous air pollutants). The final rule establishes emission limits for KCP&L’s and GMO’s new and existing units that produce steam other than for the generation of electricity. The final rule does not apply to KCP&L’s and GMO’s electricity generating boilers, but would apply to most of GMO’s Lake Road boilers, which also serve steam customers, and to auxiliary boilers at other generating facilities. In May 2011, the EPA announced it would stay the effective date of the final rule during reconsideration. The EPA indicated it will propose a revised rule by the end of October 2011 and issue another final rule by the end of April 2012. New Source Review The Clean Air Act requires companies to obtain permits and, if necessary, install control equipment to reduce emissions when making a major modification or a change in operation if either is expected to cause a significant net increase in regulated emissions. In January 2004, Westar received notification from the EPA alleging that it had violated new source review requirements and Kansas environmental regulations by making modifications to the Jeffrey Energy Center without obtaining the proper permits. In February 2009, the Attorney General of the United States filed a complaint against Westar alleging that it violated the Clean Air Act and related federal and state regulations by making major modifications to the Jeffrey Energy Center beginning in 1994 without first obtaining appropriate permits authorizing this construction and without installing and operating best available control technology to control emissions. The Jeffrey Energy Center consists of three coal-fired units located in Kansas that is 92% owned by Westar and operated exclusively by Westar. GMO has an 8% interest in the Jeffrey Energy Center and is generally responsible for its 8% share of the facility’s operating costs and capital expenditures. In January 2010, Westar entered into a settlement agreement, which was approved by the court in March 2010. The settlement agreement requires, among other things, the installation of a selective catalytic reduction (SCR) system at one of the Jeffrey Energy Center units by the end of 2014 and the payment of a $3 million civil penalty. Westar has preliminarily estimated the cost of this SCR at approximately $240 million. This amount could materially change depending on final engineering and design. Depending on the NOx emission reductions attained by that SCR and attainable through the installation of other controls at the other two units, the settlement agreement may require the installation of a second SCR system on one of the other two units by the end of 2016. There is no assurance that GMO’s share of these costs would be recovered in rates and failure to recover such costs could have a significant adverse effect on Great Plains Energy’s results of operations, financial position and cash flows. KCP&L has received requests for information from the Kansas Department of Health and Environment (KDHE) pertaining to a past LaCygne No. 1 scrubber project. KCP&L is working with the KDHE to resolve this issue and management currently believes the outcome will not have a significant impact on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows. Collaboration Agreement In March 2007, KCP&L, the Sierra Club and the Concerned Citizens of Platte County entered into a Collaboration Agreement under which KCP&L agreed to pursue a set of initiatives including energy efficiency, additional wind generation, lower emission permit levels at its Iatan and LaCygne generating stations and other initiatives designed to offset CO2 emissions. Full implementation of the terms of the Collaboration Agreement will necessitate approval from the appropriate authorities, as some of the initiatives in the agreement require regulatory approval. In 2006, KCP&L installed 100MW of wind generation at its Spearville wind site. KCP&L agreed in the Collaboration Agreement to pursue increasing its wind generation capacity to 500MW in total by the end of 2012 with 100MW to be added by the end of 2010 and the remainder added by the end of 2012, subject to regulatory approval. In 2010, KCP&L completed a 48MW wind project adjacent to its existing Spearville wind site with wind turbines it already owned and also secured 52MW of renewable energy credits. During 2011, KCP&L entered into a 20-year power purchase agreement for approximately 131MW of wind generation beginning in 2012. KCP&L is evaluating alternatives to meet the remaining Collaboration Agreement wind generation capacity, including the purchase of renewable energy credits, power purchase agreements, KCP&L-built installations or some combination thereof. KCP&L had previously issued requests for proposals before entering into the 2011 power purchase agreement. In August 2011, KCP&L requested a refresh of those requests for proposals for up to 221MW of wind generation under power purchase agreements and/or the combination of power purchase agreements and arrangements where KCP&L would own and operate the facilities after development and construction. KCP&L has a consent agreement with the KDHE incorporating limits for stack particulate matter emissions, as well as limits for NOx and SO2 emissions, at its LaCygne Station that, consistent with the Collaboration Agreement, will be below the presumptive limits under BART. KCP&L further agreed to use its best efforts to install emission control technologies to reduce those emissions from the LaCygne Station prior to the required compliance date under BART, but in no event later than June 1, 2015. In February 2011, KCP&L filed a request with KCC for predetermination of the ratemaking treatment that will apply to the recovery of costs for its 50% share of the environmental equipment required to comply with BART at the LaCygne Station. The request for predetermination includes an estimated total project cost of $1.23 billion. KCP&L’s 50% share of the estimated cost is $615 million. A KCC decision on the predetermination filing is expected in August 2011. In a related proceeding, in January 2011, KCC opened a general investigation docket regarding KCP&L and Westar environmental retrofits upon the recommendation of the KCC Staff and the Citizens Utility Ratepayers Board. The Companies cannot predict the outcome or timing of this matter but the outcome could have the potential to impact the Companies’ resource planning in the future. In the Collaboration Agreement, KCP&L also agreed to offset an additional 711,000 tons of CO2 by the end of 2012. KCP&L currently expects to achieve this offset through a number of alternatives, including improving the efficiency of its coal-fired units, equipping certain gas-fired units for winter operation and, if necessary, possibly reducing output of, or retiring, one or more coal-fired units. Climate Change The Companies are subject to existing greenhouse gas reporting regulations and, as discussed below, are subject to certain greenhouse gas permitting requirements starting in 2011. Management believes it is likely that additional federal or relevant state or local laws or regulations could be enacted to address global climate change. At the international level, while the United States is not a current party to the Kyoto Protocol, it has agreed to undertake certain voluntary actions under the non-binding Copenhagen Accord and pursuant to subsequent international discussions relating to climate change, including the establishment of a goal to reduce greenhouse gas emissions. International agreements legally binding on the United States may be reached in the future. Such new laws or regulations could mandate new or increased requirements to control or reduce the emission of greenhouse gases, such as CO2, which are created in the combustion of fossil fuels. The Companies’ current generation capacity is primarily coal-fired and is estimated to produce about one ton of CO2 per MWh, or approximately 23 million tons and 17 million tons per year for Great Plains Energy and KCP&L, respectively. Laws have recently been passed in Missouri and Kansas, the states in which the Companies’ retail electric businesses are operated, setting renewable energy standards, and management believes that national clean or renewable energy standards are also likely. While management believes additional requirements addressing these matters will probably be enacted, the timing, provisions and impact of such requirements, including the cost to obtain and install new equipment to achieve compliance, cannot be reasonably estimated at this time. In addition, certain federal courts have held that state and local governments and private parties have standing to bring climate change tort suits seeking company-specific emission reductions and monetary or other damages. While the Companies are not a party to any climate change tort suit, there is no assurance that such suits may not be filed in the future or the outcome if such suits are filed. Such requirements or litigation outcomes could have the potential for a significant financial and operational impact on Great Plains Energy and KCP&L. The Companies would seek recovery of capital costs and expenses for compliance through rate increases; however, there can be no assurance that such rate increases would be granted. Legislation concerning the reduction of emissions of greenhouse gases, including CO2, is being considered at the federal and state levels. The timing and effects of any such legislation cannot be determined at this time. In the absence of new Congressional mandates, the EPA is proceeding with the regulation of greenhouse gases under the existing Clean Air Act. In May 2010, the EPA issued a final rule addressing greenhouse gas emissions from stationary sources under the Clean Air Act permitting programs. This final rule sets thresholds for greenhouse gas emissions that define when permits under the Prevention of Significant Deterioration (PSD) and Title V Operating Permit programs are required for new and existing industrial facilities. The EPA phased in the Clean Air Act permitting requirements for greenhouse gas emissions in two initial steps. In step 1, which started January 2, 2011, only sources currently subject to the PSD permitting program (i.e., those that are newly-constructed or modified in a way that significantly increases emissions of a pollutant other than greenhouse gas) are subject to Title V or PSD permitting requirements, respectively, for their greenhouse gas emissions. For these projects, only projects with new or increases of greenhouse gas emissions of 75,000 tons per year or more of total greenhouse gases, on a CO2 equivalent basis, need to determine the best available control technology for their greenhouse gas emissions. In addition, sources subject to the Title V Operating Permit Program need to address greenhouse gas emissions as those permits are applied for or renewed. In step 2, which started July 1, 2011, Title V and PSD permitting requirements now cover, for the first time, new construction projects that emit greenhouse gas emissions of at least 100,000 tons per year even if they do not exceed the permitting thresholds for any other pollutant. In addition, modifications at such existing facilities that increase greenhouse gas emissions by at least 75,000 tons per year are subject to permitting requirements, even if they do not significantly increase emissions of any other pollutant. Great Plains Energy’s and KCP&L’s generating facilities that trigger these thresholds for new installations, modifications or Title V operating permits are subject to this rule. In March 2011, the EPA announced it finalized a settlement agreement to issue a rule that will address greenhouse gas emissions from EGUs. The rule would establish new source performance standards for new and modified EGUs and emission guidelines for existing EGUs. Under the settlement agreement, the EPA committed to issuing proposed regulations by September 2011, and final regulations by May 2012. At the state level, a Kansas law enacted in May 2009 requires Kansas public electric utilities, including KCP&L, to have renewable energy generation capacity equal to at least 10% of their three-year average Kansas peak retail demand by 2011. The percentage increases to 15% by 2016 and 20% by 2020. A Missouri law enacted in November 2008 requires at least 2% of the electricity provided by Missouri investor-owned utilities (including KCP&L and GMO) to their Missouri retail customers to come from renewable resources, including wind, solar, biomass and hydropower, by 2011, increasing to 5% in 2014, 10% in 2018, and 15% in 2021, with a small portion (estimated to be about 2MW in 2011 for each of KCP&L and GMO) required to come from solar resources. KCP&L and GMO project that their existing renewable resources (including accumulated renewable energy credits) will be sufficient for compliance with the Missouri requirements, exclusive of the solar requirement, through 2021 and 2016, respectively. KCP&L and GMO project that the purchase of solar renewable energy credits will be sufficient for compliance with the Missouri solar requirements for the foreseeable future. KCP&L also projects that its existing renewable resources (including both accumulated renewable energy credits and purchased renewable energy credits) will be sufficient for compliance with the 2011 Kansas requirements. During 2011, KCP&L entered into a 20-year power purchase agreement for approximately 131MW of wind generation beginning in 2012. With the addition of this power purchase agreement along with its existing renewable resources, KCP&L anticipates its renewable resources will be sufficient for compliance with the Kansas requirements through 2012. KCP&L had previously issued requests for proposals before entering into the 2011 power purchase agreement. In August 2011, KCP&L requested a refresh of those requests for proposals for up to 221MW of wind generation under power purchase agreements and/or the combination of power purchase agreements and arrangements where KCP&L would own and operate the facilities after development and construction. Additionally, in November 2007, governors from six Midwestern states, including Kansas, signed the Midwestern Greenhouse Gas Reduction Accord, which has established the goal of reducing member states’ greenhouse gas emissions to 15% to 20% below 2005 levels by 2020, and 60% to 80% below 2005 levels by 2050. Greenhouse gas legislation or regulation has the potential of having significant financial and operational impacts on Great Plains Energy and KCP&L, including the potential costs and impacts of achieving compliance with limits that may be established. However, the ultimate financial and operational consequences to Great Plains Energy and KCP&L cannot be determined until such legislation is passed and/or regulations are issued. Management will continue to monitor the progress of relevant legislation and regulations. Ozone NAAQS In June 2007, monitor data indicated that the Kansas City area violated the 1997 primary eight-hour ozone NAAQS. Missouri and Kansas have implemented the responses established in the maintenance plans for control of ozone. The responses in both states do not require additional controls at Great Plains Energy’s and KCP&L’s generation facilities beyond the currently proposed controls for CSAPR and BART. The EPA has various options over and above the implementation of the maintenance plans for control of ozone to address the violation but has not yet acted. At this time, management is unable to predict how the EPA will respond or how that response will impact Great Plains Energy’s and KCP&L’s operations. However, the EPA’s response could have a significant effect on Great Plains Energy's and KCP&L's results of operations, financial position and cash flows. In March 2008, the EPA significantly strengthened its NAAQS for ground-level ozone. The EPA revised the primary eight-hour ozone standard, designed to protect public health, to a level of 0.075 parts per million (ppm). The EPA also strengthened the secondary eight-hour ozone standard to the level of 0.075 ppm making it identical to the revised primary standard. The previous primary and secondary standards, set in 1997, were effectively 0.084 ppm. In March 2009, the MDNR and KDHE submitted to the EPA their determinations that the Kansas City area is a nonattainment area under the 2008 primary eight-hour ozone standard. The EPA will make final designations of attainment and nonattainment areas. By 2013, states must submit state implementation plans outlining how states will reduce ozone to meet the standards in nonattainment areas. Although the impact on Great Plains Energy’s and KCP&L’s operations will not be known until after the final nonattainment designations and the state implementation plans are submitted, it could have a significant effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows. In January 2010, the EPA proposed to reconsider and further strengthen the 2008 NAAQS for ground-level ozone. The EPA proposed to strengthen the primary eight-hour ozone standard to a level within the range of 0.060-0.070 ppm. The EPA also proposed to establish a distinct cumulative, seasonal secondary standard, designed to protect sensitive vegetation and ecosystems, to within the range of 7-15 ppm-hours. It is anticipated EPA will finalize the standard in the third quarter of 2011. SO2 NAAQS In June 2010, the EPA strengthened the primary NAAQS for SO2. The EPA revised the primary SO2 standard by establishing a new 1-hour standard at a level of 0.075 ppm. The EPA revoked the two existing primary standards of 0.140 ppm evaluated over 24 hours and 0.030 ppm evaluated over an entire year. In July 2011, the MDNR recommended to the EPA that part of Jackson County, Missouri, be designated a nonattainment area for the new 1-hour SO2 standard. Although the impact on Great Plains Energy’s and KCP&L’s operations will not be known until after the nonattainment designations are approved and the state implementation plans are submitted, it could have a significant effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows. Montrose Station Notice of Violation In June 2009, KCP&L received notification from the MDNR alleging that its Montrose Station had excess particulate matter emissions in 2008. KCP&L is working with the MDNR to resolve this issue and management believes the outcome will not have a significant impact on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows. Water The Clean Water Act and associated regulations enacted by the EPA form a comprehensive program to preserve water quality. Like the Clean Air Act, states are required to establish regulations and programs to address all requirements of the Clean Water Act, and have the flexibility to enact more stringent requirements. All of Great Plains Energy’s and KCP&L’s generating facilities, and certain of their other facilities, are subject to the Clean Water Act. In March 2011, the EPA proposed regulations pursuant to Section 316(b) of the Clean Water Act regarding cooling water intake structures pursuant to a court approved settlement. KCP&L generation facilities with cooling water intake structures would be subject to a limit on how many fish can be killed by being pinned against intake screens (impingement) and would be required to conduct studies to determine whether and what site-specific controls, if any, would be required to reduce the number of aquatic organisms drawn into cooling water systems (entrainment). The EPA agreed to finalize the rule by July 2012. Although the impact on Great Plains Energy’s and KCP&L’s operations will not be known until after the rule is finalized, it could have a significant effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows. KCP&L holds a permit from the MDNR covering water discharge from its Hawthorn Station. The permit authorizes KCP&L to, among other things, withdraw water from the Missouri river for cooling purposes and return the heated water to the Missouri river. KCP&L has applied for a renewal of this permit and the EPA has submitted an interim objection letter regarding the allowable amount of heat that can be contained in the returned water. Until this matter is resolved, KCP&L continues to operate under its current permit. KCP&L cannot predict the outcome of this matter; however, while less significant outcomes are possible, this matter may require KCP&L to reduce its generation at Hawthorn Station, install cooling towers or both, any of which could have a significant impact on KCP&L. The outcome could also affect the terms of water permit renewals at KCP&L’s Iatan Station and at GMO’s Sibley and Lake Road Stations. Additionally, in September 2009, the EPA announced plans to revise the existing standards for water discharges from coal-fired power plants. In November 2010, the EPA filed a motion requesting court approval of a consent agreement in which the EPA agreed to propose a rule in July 2012 and to finalize it in January 2014. Until a rule is proposed and finalized, the financial and operational impacts to Great Plains Energy and KCP&L cannot be determined. Solid Waste Solid and hazardous waste generation, storage, transportation, treatment and disposal is regulated at the federal and state levels under various laws and regulations. In May 2010, the EPA proposed to regulate coal combustion residuals (CCRs) under the Resource Conservation and Recovery Act (RCRA) to address the risks from the disposal of CCRs generated from the combustion of coal at electric generating facilities. The EPA is considering two options in this proposal. Under the first option, the EPA would regulate CCRs as special wastes subject to regulation under subtitle C of RCRA (hazardous), when they are destined for disposal in landfills or surface impoundments. Under the second option, the EPA would regulate disposal of CCRs under subtitle D of RCRA (non-hazardous). The Companies principally use coal in generating electricity and dispose of the CCRs in both on-site facilities and facilities owned by third parties. The proposed CCR rule has the potential of having a significant financial and operational impact on Great Plains Energy and KCP&L in connection with achieving compliance with the proposed requirements. However, the financial and operational consequences to Great Plains Energy and KCP&L cannot be determined until an option is selected by the EPA and the final regulation is enacted. Remediation Certain federal and state laws, including the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) hold current and previous owners or operators of real property, and any person who arranges for the disposal or treatment of hazardous substances at a property, liable on a joint and several basis for the costs of cleaning up contamination at or migrating from such real property, even if they did not know of and were not responsible for such contamination. CERCLA and other laws also authorize the EPA and other agencies to issue orders compelling potentially responsible parties to clean up sites that are determined to present an actual or potential threat to human health or the environment. GMO is named as a potentially responsible party at two disposal sites for polychlorinated biphenyls (PCBs), and retains some environmental liability for several operations and investments it no longer owns. In addition, GMO also owns, or has acquired liabilities from companies that once owned or operated, former manufactured gas plant (MGP) sites, which are subject to the supervision of the EPA and various state environmental agencies. At June 30, 2011, and December 31, 2010, KCP&L had $0.3 million accrued for environmental remediation expenses, which covers ground water monitoring at a former MGP site. At June 30, 2011, and December 31, 2010, Great Plains Energy had $0.4 million accrued for environmental remediation expenses, which includes the $0.3 million at KCP&L, and additional potential remediation and ground water monitoring costs relating to two GMO sites. The amounts accrued were established on an undiscounted basis and Great Plains Energy and KCP&L do not currently have an estimated time frame over which the accrued amounts may be paid. In addition to the $0.4 million accrual above, at June 30, 2011, and December 31, 2010, Great Plains Energy had $2.1 million accrued for the future investigation and remediation of certain additional GMO identified MGP sites, PCB sites and retained liabilities. This estimate was based upon review of the potential costs associated with conducting investigative and remedial actions at identified sites, as well as the likelihood of whether such actions will be necessary. This estimate could change materially after further investigation, and could also be affected by the actions of environmental agencies and the financial viability of other potentially responsible parties. GMO has pursued recovery of remediation costs from insurance carriers and other potentially responsible parties. As a result of a settlement with an insurance carrier, approximately $2.3 million in insurance proceeds less an annual deductible is available to GMO to recover qualified MGP remediation expenses. GMO would seek recovery of additional remediation costs and expenses through rate increases; however, there can be no assurance that such rate increases would be granted. In January 2010, the EPA announced an advance notice of proposed rulemaking under CERCLA identifying classes of facilities for which the EPA will develop financial assurance requirements, including the electric power generation, transmission and distribution industry. The CERCLA financial assurance would be for risks associated with Great Plains Energy’s and KCP&L’s production, transportation, treatment, storage or disposal of CERCLA hazardous substances. The impact on Great Plains Energy and KCP&L cannot be determined until the regulations are finalized. In April 2010, the EPA announced an advance notice of proposed rulemaking for the use and distribution in commerce of certain PCBs, PCB items and certain other areas of the PCB regulations. The EPA is reassessing the use, distribution in commerce, marking, and storage for reuse of liquid PCBs in electric and non-electric equipment and the use of the 50 ppm level for excluded PCB products among other things. The impact on Great Plains Energy and KCP&L cannot be determined until the regulations are finalized.
KCP&L Spent Nuclear Fuel and Radioactive Waste In January 2004, KCP&L and the other two Wolf Creek owners filed a lawsuit against the United States in the U.S. Court of Federal Claims seeking $14.1 million of damages resulting from the government’s failure to begin accepting spent nuclear fuel for disposal in January 1998, as the government was required to do by the Nuclear Waste Policy Act of 1982. The Wolf Creek case was tried before a U.S. Court of Federal Claims judge in June 2010, and a decision was issued in November 2010, granting KCP&L and the other two Wolf Creek owners $10.6 million ($5.0 million KCP&L share) in damages. In January 2011, KCP&L and the other two Wolf Creek owners as well as the United States filed appeals of the decision to the U.S. Court of Appeals for the Federal Circuit. The court has set a briefing schedule. Briefing likely will conclude in the fourth quarter of 2011, and the parties will present their oral arguments to the court sometime thereafter. Iatan Levee Litigation On May 22, 2009, several farmers filed suit against Great Plains Energy and KCP&L in the Circuit Court of Platte County, Missouri, alleging negligence, private nuisance, trespass and violations of the Missouri Crop Protection Act and seeking unspecified compensatory and punitive damages. These allegations stem from flooding at or near the Iatan Station in 2007 and 2008. The farmers allege the flooding was a result of maintenance of a nearby levee. The petition seeks class certification from the courts. KCP&L has filed a motion seeking separate trials for each individual plaintiff. Written discovery and depositions are underway. This matter is set for trial in November 2011. Management cannot predict the outcome of this matter. GMO Price Reporting Litigation In response to complaints of manipulation of the California energy market, in July 2001, FERC issued an order requiring net sellers of power in the California markets from October 2, 2000, through June 20, 2001, at prices above a FERC determined competitive market clearing price to make refunds to net purchasers of power in the California market during that time period. Because MPS Merchant was a net purchaser of power during the refund period, it has received approximately $8 million in refunds through settlements with certain sellers of power. MPS Merchant estimates that it is entitled to approximately $12 million in additional refunds under the standards FERC has used in this case. FERC has stated that interest will be applied to the refunds but the amount of interest has not yet been determined. However, in December 2001, various parties appealed the FERC order to the United States Court of Appeals for the Ninth Circuit seeking review of a number of issues, including changing the refund period to include periods prior to October 2, 2000. MPS Merchant was a net seller of power during the period prior to October 2, 2000. On August 2, 2006, the U.S. Court of Appeals for the Ninth Circuit issued an order finding, among other things, that FERC did not provide a sufficient justification for refusing to exercise its remedial authority under the Federal Power Act to determine whether market participants violated FERC-approved tariffs during the period prior to October 2, 2000, and imposing a remedy for any such violations. The court remanded the matter to FERC for further consideration. In May 2011, FERC issued an order which clarified the scope of the hearing in the refund proceeding and ruled on requests for rehearing and motions to dismiss. A hearing is set for March 2012. If FERC ultimately includes the period prior to October 2, 2000, MPS Merchant could be found to owe refunds. FERC initiated a separate docket, generally referred to as the Pacific Northwest refund proceeding, to determine if any refunds were warranted related to the potential impact of the California market issues on buyers in the Pacific Northwest between December 25, 2000, and June 20, 2001. FERC rejected the refund requests, but its decision was remanded by the Court of Appeals for FERC to consider whether any acts of market manipulation support the imposition of refunds. Claims against MPS Merchant total $5.1 million for the period addressed under the Pacific Northwest refund proceedings. |
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Includes disclosure of commitments and contingencies. This element may be used as a single block of text to encapsulate the entire disclosure including data and tables. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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LEGAL PROCEEDINGS
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| Legal proceedings |
KCP&L Spent Nuclear Fuel and Radioactive Waste In January 2004, KCP&L and the other two Wolf Creek owners filed a lawsuit against the United States in the U.S. Court of Federal Claims seeking $14.1 million of damages resulting from the government’s failure to begin accepting spent nuclear fuel for disposal in January 1998, as the government was required to do by the Nuclear Waste Policy Act of 1982. The Wolf Creek case was tried before a U.S. Court of Federal Claims judge in June 2010, and a decision was issued in November 2010, granting KCP&L and the other two Wolf Creek owners $10.6 million ($5.0 million KCP&L share) in damages. In January 2011, KCP&L and the other two Wolf Creek owners as well as the United States filed appeals of the decision to the U.S. Court of Appeals for the Federal Circuit. The court has set a briefing schedule. Briefing likely will conclude in the fourth quarter of 2011, and the parties will present their oral arguments to the court sometime thereafter. Iatan Levee Litigation On May 22, 2009, several farmers filed suit against Great Plains Energy and KCP&L in the Circuit Court of Platte County, Missouri, alleging negligence, private nuisance, trespass and violations of the Missouri Crop Protection Act and seeking unspecified compensatory and punitive damages. These allegations stem from flooding at or near the Iatan Station in 2007 and 2008. The farmers allege the flooding was a result of maintenance of a nearby levee. The petition seeks class certification from the courts. KCP&L has filed a motion seeking separate trials for each individual plaintiff. Written discovery and depositions are underway. This matter is set for trial in November 2011. Management cannot predict the outcome of this matter. GMO Price Reporting Litigation In response to complaints of manipulation of the California energy market, in July 2001, FERC issued an order requiring net sellers of power in the California markets from October 2, 2000, through June 20, 2001, at prices above a FERC determined competitive market clearing price to make refunds to net purchasers of power in the California market during that time period. Because MPS Merchant was a net purchaser of power during the refund period, it has received approximately $8 million in refunds through settlements with certain sellers of power. MPS Merchant estimates that it is entitled to approximately $12 million in additional refunds under the standards FERC has used in this case. FERC has stated that interest will be applied to the refunds but the amount of interest has not yet been determined. However, in December 2001, various parties appealed the FERC order to the United States Court of Appeals for the Ninth Circuit seeking review of a number of issues, including changing the refund period to include periods prior to October 2, 2000. MPS Merchant was a net seller of power during the period prior to October 2, 2000. On August 2, 2006, the U.S. Court of Appeals for the Ninth Circuit issued an order finding, among other things, that FERC did not provide a sufficient justification for refusing to exercise its remedial authority under the Federal Power Act to determine whether market participants violated FERC-approved tariffs during the period prior to October 2, 2000, and imposing a remedy for any such violations. The court remanded the matter to FERC for further consideration. In May 2011, FERC issued an order which clarified the scope of the hearing in the refund proceeding and ruled on requests for rehearing and motions to dismiss. A hearing is set for March 2012. If FERC ultimately includes the period prior to October 2, 2000, MPS Merchant could be found to owe refunds. FERC initiated a separate docket, generally referred to as the Pacific Northwest refund proceeding, to determine if any refunds were warranted related to the potential impact of the California market issues on buyers in the Pacific Northwest between December 25, 2000, and June 20, 2001. FERC rejected the refund requests, but its decision was remanded by the Court of Appeals for FERC to consider whether any acts of market manipulation support the imposition of refunds. Claims against MPS Merchant total $5.1 million for the period addressed under the Pacific Northwest refund proceedings. |
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RELATED PARTY TRANSACTIONS AND RELATIONSHIPS
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| Related party transactions and relationships |
KCP&L employees manage GMO’s business and operate its facilities at cost. These costs totaled $27.7 million and $57.2 million, respectively, for the three months ended and year to date June 30, 2011, respectively. These costs totaled $20.1 million and $47.2 million, respectively, for the same periods in 2010. Additionally, KCP&L and GMO engage in wholesale electricity transactions with each other. KCP&L and GMO are also authorized to participate in the Great Plains Energy money pool, an internal financing arrangement in which funds may be lent on a short-term basis to KCP&L and GMO. The following table summarizes KCP&L’s related party receivables and payables.
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This element may be used for the entire related party transactions disclosure as a single block of text. Disclosure may include: the nature of the relationship(s), a description of the transactions, the amount of the transactions, the effects of any change in the method of establishing the terms of the transaction from the previous period, stated interest rate, expiration date, terms and manner of settlement per the agreement with the related party, and amounts due to or from related parties. If the entity and one or more other entities are under common ownership or management control and this control affects the operating results or financial position, disclosure includes the nature of the control relationship even if there are no transactions between the entities. Disclosure may also include the aggregate amount of current and deferred tax expense for each statement of earnings presented where the entity is a member of a group that files a consolidated tax return, the amount of any tax related balances due to or from affiliates as of the date of each statement of financial position presented, the principal provisions of the method by which the consolidated amount of current and deferred tax expense is allocated to the members of the group and the nature and effect of any changes in that method. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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DERIVATIVE INSTRUMENTS
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Instruments |
Great Plains Energy and KCP&L are exposed to a variety of market risks including interest rates and commodity prices. Management has established risk management policies and strategies to reduce the potentially adverse effects that the volatility of the markets may have on Great Plains Energy’s and KCP&L’s operating results. Commodity risk management activities, including the use of certain derivative instruments, are subject to the management, direction and control of an internal risk management committee. Management’s interest rate risk management strategy uses derivative instruments to adjust Great Plains Energy’s and KCP&L’s liability portfolio to optimize the mix of fixed and floating rate debt within an established range. In addition, Great Plains Energy and KCP&L use derivative instruments to hedge against future interest rate fluctuations on anticipated debt issuances. Management maintains commodity price risk management strategies that use derivative instruments to reduce the effects of fluctuations in fuel expense caused by commodity price volatility. Counterparties to commodity derivatives and interest rate swap agreements expose Great Plains Energy and KCP&L to credit loss in the event of nonperformance. This credit loss is limited to the cost of replacing these contracts at current market rates. Derivative instruments, excluding those instruments that qualify for the normal purchase normal sale election, which are accounted for by accrual accounting, are recorded on the balance sheet at fair value as an asset or liability. Changes in the fair value of derivative instruments are recognized currently in net income unless specific hedge accounting criteria are met, except GMO utility operations hedges that are recorded to a regulatory asset or liability consistent with MPSC regulatory orders, as discussed below. Great Plains Energy and KCP&L have posted collateral, in the ordinary course of business, for the aggregate fair value of all derivative instruments with credit risk-related contingent features that are in a liability position. At June 30, 2011, Great Plains Energy and KCP&L have posted collateral in excess of the aggregate fair value of its derivative instruments; therefore, if the credit risk-related contingent features underlying these agreements were triggered, Great Plains Energy and KCP&L would not be required to post additional collateral to its counterparties. The Dodd-Frank Wall Street Reform and Consumer Protection Act, signed into law in July 2010, includes provisions related to the swaps and over-the-counter derivative markets. The Companies currently expect that their commodity and interest rate hedges will be exempt from mandatory clearing and exchange trading requirements. Capital and margin requirements for these hedges are expected to be determined over the next year as regulatory agencies implement rules. While the Companies currently do not anticipate this law and the associated regulatory rules will have a material impact on their financial condition, the ultimate impact cannot be reasonably determined until the final rules are issued. Interest Rate Risk Management In May 2011, Great Plains Energy issued $350.0 million of long-term debt and settled six forward starting swaps (FSS) simultaneously with the issuance of this long-term fixed rate debt. Great Plains Energy had entered into the six FSS with notional amounts totaling $350.0 million to hedge against interest rate variability on the debt issuance. The six FSS were treated as cash flow hedges with no ineffectiveness recorded for the three months ended and year to date June 30, 2011 and 2010. A pre-tax loss of $26.1 million was recorded to OCI and is being reclassified to interest expense over the first three years of the ten-year debt. At June 30, 2011, a $1.1 million loss has been reclassified from OCI to interest expense. Commodity Risk Management KCP&L’s risk management policy is to use derivative instruments to mitigate its exposure to market price fluctuations on a portion of its projected natural gas purchases to meet generation requirements for retail and firm wholesale sales. At June 30, 2011, KCP&L had fully hedged 2011 and had hedged 68% of 2012 and 31% of 2013 projected natural gas usage for retail load and firm MWh sales, primarily by utilizing futures contracts and financial instruments. KCP&L has designated the natural gas hedges as cash flow hedges. The fair values of these instruments are recorded as derivative assets or liabilities with an offsetting entry to OCI for the effective portion of the hedge. To the extent the hedges are not effective, any ineffective portion of the change in fair market value would be recorded currently in fuel expense. KCP&L has not recorded any ineffectiveness on natural gas hedges for the three months ended and year to date June 30, 2011 and 2010. GMO’s risk management policy is to use derivative instruments to mitigate price exposure to natural gas price volatility in the market. The fair value of the portfolio relates to financial contracts that will settle against actual purchases of natural gas and purchased power. At June 30, 2011, GMO had financial contracts in place to hedge approximately 74%, 61% and 38% of the expected on-peak natural gas and natural gas equivalent purchased power price exposure for 2011, 2012 and 2013, respectively. GMO has designated its natural gas hedges as economic hedges (non-hedging derivatives). In connection with GMO’s 2005 Missouri electric rate case, it was agreed that the settlement costs of these contracts would be recognized in fuel expense. The settlement cost is included in GMO’s FAC. A regulatory asset has been recorded to reflect the change in the timing of recognition authorized by the MPSC. To the extent recovery of actual costs incurred is allowed, amounts will not impact earnings, but will impact cash flows due to the timing of the recovery mechanism. MPS Merchant manages the daily delivery of its remaining contractual commitments with economic hedges (non-hedging derivatives) to reduce its exposure to changes in market prices. Within the trading portfolio, MPS Merchant takes certain positions to hedge physical sale or purchase contracts. MPS Merchant records the fair value of physical trading energy contracts as derivative assets or liabilities with an offsetting entry to the consolidated statements of income. The notional and recorded fair values of open positions for derivative instruments are summarized in the following table. The fair values of these derivatives are recorded on the consolidated balance sheets. The fair values below are gross values before netting agreements and netting of cash collateral.
The fair value of Great Plains Energy’s and KCP&L’s open derivative positions are summarized in the following tables. The tables contain both derivative instruments designated as hedging instruments as well as non-hedging derivatives under GAAP. The fair values below are gross values before netting agreements and netting of cash collateral.
The following tables summarize the amount of gain (loss) recognized in OCI or earnings for interest rate and commodity hedges.
The following table summarizes the amount of gain (loss) recognized in a regulatory balance sheet account or earnings for GMO utility commodity hedges. GMO utility commodity derivatives fair value changes are recorded to either a regulatory asset or liability consistent with MPSC regulatory orders.
Great Plains Energy’s income statement reflects gains (losses) for the change in fair value of the MPS Merchant commodity contract derivatives not designated as hedging instruments of $(0.9) million and $1.0 million, respectively, for the three months ended and year to date June 30, 2011, and $(0.4) million and $1.6 million, respectively, for the same periods in 2010. The amounts recorded in accumulated OCI related to the cash flow hedges are summarized in the following table.
Great Plains Energy’s accumulated OCI in the table above at June 30, 2011, includes $20.3 million that is expected to be reclassified to expenses over the next twelve months. KCP&L’s accumulated OCI includes $8.8 million that is expected to be reclassified to expense over the next twelve months. |
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This element can be used to disclose the entity's entire derivative instruments and hedging activities disclosure as a single block of text. Describes an entity's risk management strategies, derivatives in hedging activities and non-hedging derivative instruments, the assets, obligations, liabilities, revenues and expenses arising there from, 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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FAIR VALUE MEASUREMENTS
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fair value measurements |
GAAP defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. GAAP establishes a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad categories, giving the highest priority to quoted prices in active markets for identical assets or liabilities and lowest priority to unobservable inputs. A definition of the various levels, as well as discussion of the various measurements within the levels, is as follows: Level 1 – Unadjusted quoted prices for identical assets or liabilities in active markets that Great Plains Energy and KCP&L have access to at the measurement date. Assets categorized within this level consist of Great Plains Energy’s and KCP&L’s various exchange traded derivative instruments and equity and U.S. Treasury securities that are actively traded within KCP&L’s decommissioning trust fund and GMO’s SERP rabbi trust fund. Level 2 – Market-based inputs for assets or liabilities that are observable (either directly or indirectly) or inputs that are not observable but are corroborated by market data. Assets and liabilities categorized within this level consist of Great Plains Energy’s and KCP&L’s various non-exchange traded derivative instruments traded in over-the-counter markets and certain debt securities within KCP&L’s decommissioning trust fund and GMO’s SERP rabbi trust fund. Level 3 – Unobservable inputs, reflecting Great Plains Energy’s and KCP&L’s own assumptions about the assumptions market participants would use in pricing the asset or liability. Assets categorized within this level consist of Great Plains Energy’s various non-exchange traded derivative instruments traded in over-the-counter markets for which sufficiently observable market data is not available to corroborate the valuation inputs. The following tables include Great Plains Energy’s and KCP&L’s balances of financial assets and liabilities measured at fair value on a recurring basis at June 30, 2011, and December 31, 2010.
The following tables reconcile the beginning and ending balances for all level 3 assets and liabilities, net measured at fair value on a recurring basis for the three months ended and year to date June 30, 2011 and 2010.
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This item represents the complete disclosure regarding the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments, 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 Company 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 risk is 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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TAXES
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Taxes |
Components of income tax expense are detailed in the following tables.
Income Tax Expense (Benefit) and Effective Income Tax Rates Income tax expense (benefit) and the effective income tax rates reflected in the financial statements and the reasons for their differences from the statutory federal rates are detailed in the following tables.
Uncertain Tax Positions At June 30, 2011, and December 31, 2010, Great Plains Energy had $24.9 million and $42.0 million, respectively, of liabilities related to unrecognized tax benefits. Of these amounts, $15.1 million and $17.3 million, respectively, at June 30, 2011, and December 31, 2010, is expected to impact the effective tax rate if recognized. The $17.1 million decrease in unrecognized tax benefits is primarily due to a decrease of $18.4 million related to the settlement of the IRS audit for Great Plains Energy’s 2006-2008 tax years. The tax benefit recognized related to the 2006-2008 IRS audit was offset by an increase of $16.4 million in deferred income tax liabilities, which resulted in an increase to net income of $2.0 million. At June 30, 2011, and December 31, 2010, KCP&L had $7.3 million and $19.1 million, respectively, of liabilities related to unrecognized tax benefits. Of these amounts, $0.3 million at June 30, 2011, and December 31, 2010, is expected to impact the effective tax rate if recognized. The $11.8 million decrease in unrecognized tax benefits is primarily due to a decrease of $12.1 million related to the settlement of the IRS audit for Great Plains Energy’s 2006-2008 tax years. The tax benefit recognized related to the 2006-2008 IRS audit was mostly offset by an increase in deferred income tax liabilities, which resulted in an insignificant impact to net income. The following table reflects activity for Great Plains Energy and KCP&L related to the liability for unrecognized tax benefits.
Great Plains Energy and KCP&L recognize interest accrued related to unrecognized tax benefits in interest expense and penalties in non-operating expenses. At June 30, 2011, and December 31, 2010, accrued interest related to unrecognized tax benefits for Great Plains Energy was $6.0 million and $6.7 million, respectively. Amounts accrued for penalties with respect to unrecognized tax benefits were $1.1 million at June 30, 2011, and December 31, 2010. KCP&L had accrued interest related to unrecognized tax benefits of $0.3 million and $1.4 million at June 30, 2011, and December 31, 2010, respectively. Amounts accrued for penalties with respect to unrecognized tax benefits for KCP&L are insignificant. The Companies are unable to estimate the amount of unrecognized tax benefits that may be recognized in the next twelve months. |
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Description containing the entire income tax disclosure. Examples include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information. This element may be used as a single block of text to encapsulate the entire disclosure including data and tables. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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SEGMENTS AND RELATED INFORMATION
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Segments and Related Information |
Great Plains Energy has one reportable segment based on its method of internal reporting, which generally segregates reportable segments based on products and services, management responsibility and regulation. The one reportable business segment is electric utility, consisting of KCP&L and GMO’s regulated utility operations. Other includes GMO activity other than its regulated utility operations, unallocated corporate charges, consolidating entries and intercompany eliminations. Intercompany eliminations include insignificant amounts of intercompany financing-related activities. The summary of significant accounting policies applies to the reportable segment. Segment performance is evaluated based on net income attributable to Great Plains Energy. The following tables reflect summarized financial information concerning Great Plains Energy’s reportable segment.
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This element may be used to capture the complete disclosure of 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% 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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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Organization |
Organization Great Plains Energy, a Missouri corporation incorporated in 2001, is a public utility holding company and does not own or operate any significant assets other than the stock of its subsidiaries. Great Plains Energy’s wholly owned direct subsidiaries with operations or active subsidiaries are as follows:
Each of Great Plains Energy’s and KCP&L’s consolidated financial statements includes the accounts of their subsidiaries. Intercompany transactions have been eliminated. Great Plains Energy’s sole reportable business segment is electric utility. See Note 16 for additional information. |
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| Basic and Diluted Earnings per Common Share Calculations | Basic and Diluted Earnings per Common Share Calculation To determine basic EPS, preferred stock dividend requirements and net income (loss) attributable to noncontrolling interest are deducted from net income before dividing by the average number of common shares outstanding. The effect of dilutive securities, calculated using the treasury stock method, assumes the issuance of common shares applicable to performance shares, restricted stock, stock options and Equity Units. The following table reconciles Great Plains Energy’s basic and diluted EPS.
The computation of diluted EPS for the three months ended June 30, 2011, excludes anti-dilutive shares consisting of 201,571 performance shares, 12,115 restricted stock shares and 154,096 stock options. The computation of diluted EPS year to date June 30, 2011, excludes anti-dilutive shares consisting of 201,571 performance shares, 43,641 restricted stock shares and 154,096 stock options. The computation of diluted EPS for the three months ended June 30, 2010, excludes anti-dilutive shares consisting of 41,604 performance shares, 93,106 restricted stock shares and 207,290 stock options. The computation of diluted EPS year to date June 30, 2010, excludes anti-dilutive shares consisting of 50,034 performance shares, 251,526 restricted stock shares and 213,248 stock options. |
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Discloses the methodology and assumptions used to compute basic and diluted earnings (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
Description containing the entire organization, consolidation and basis of presentation of financial statements disclosure. May be provided in more than one note to the financial statements, as long as users are provided with an understanding of (1) the significant judgments and assumptions made by an enterprise in determining whether it must consolidate a VIE and/or disclose information about its involvement with a VIE, (2) the nature of restrictions on a consolidated VIE's assets reported by an enterprise in its statement of financial position, including the carrying amounts of such assets, (3) the nature of, and changes in, the risks associated with an enterprise's involvement with the VIE, and (4) how an enterprise's involvement with the VIE affects the enterprise's financial position, financial performance, and cash flows. Describes procedure if disclosures are provided in more than one note to the financial statements. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Reconciliation of Great Plains Energy's basic and diluted earnings per share | The following table reconciles Great Plains Energy’s basic and diluted EPS.
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This element may be used to capture the reconciliation of earnings per share, as a single block of text, which may include the individual income and share amount effects of all securities that affect earnings per share, the effect that has been given to preferred dividends in arriving at income available to common stockholders in computing basic earnings per share, securities (including those issuable pursuant to contingent stock agreements) that could potentially dilute basic EPS in the future that were not included in the computation of diluted EPS because to do so would have been antidilutive for the period(s) presented and a description of any transaction that occurs after the end of the most recent period but before issuance of the financial statements that would have changed materially the number of common shares or potential common shares outstanding at the end of the period if the transaction had occurred before the end of the period. No definition available.
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SUPPLEMENTAL CASH FLOW INFORMATION (Tables)
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Jun. 30, 2011
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| Cash Flow, Supplemental Disclosures [Text Block] |
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Additional detail information for the operating portion of the statement of cash flows as well as the supplemental information regarding cash paid for interest and income taxes and non-cash transactions. No definition available.
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RECEIVABLES (Tables)
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Schedule of accounts receivable | Great Plains Energy’s and KCP&L’s receivables are detailed in the following table.
|
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| Schedule of accounts receivable sold | Information regarding KCP&L’s sale of accounts receivable to Receivables Company is reflected in the following tables.
|
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| X | ||||||||||
|
- Definition
Disclosure itemizing the receivables purchased (sold) and the gain (loss) on the sale. It also discloses the cash flows recognized on the sales of receivables. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Disclosure itemizing the various types of trade accounts and notes receivable, and for each the gross carrying value, allowance, and net carrying value as of the balance sheet date. Presentation is categorized by current, noncurrent and unclassified receivables. This disclosure may include (1) the basis at which such receivables are carried in the entity's statements of financial position (2) how the level of the valuation allowance for receivables is determined (3) when impairments, charge-offs or recoveries are recognized for such receivables (4) the treatment of origination fees and costs, including the amortization method for net deferred fees or costs (5) the treatment of any premiums or discounts or unearned income (6) the entity's income recognition policies for such receivables, including those that are impaired, past due or placed on nonaccrual status and (7) the treatment of foreclosures or repossessions (8) the nature and amount of any guarantees to repurchase receivables. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
NUCLEAR PLANT (Tables)
|
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2011
|
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Changes in nuclear decommissioning trust fund | The following table summarizes the change in Great Plains Energy’s and KCP&L’s nuclear decommissioning trust fund.
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| Detail of assets held in nuclear decommissioning trust fund | The nuclear decommissioning trust is reported at fair value on the balance sheets and is invested in assets as detailed in the following table.
|
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| Gains and losses from the sale of securities by the nuclear decommissioning trust fund | The following table summarizes the realized gains and losses from the sale of securities by the nuclear decommissioning trust fund.
|
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| X | ||||||||||
|
- Definition
Disclosure that summarizes the change in nuclear decommissioning trust fund during the period. No definition available.
|
| X | ||||||||||
|
- Definition
This item represents the entire disclosure related to nuclear decommissioning trust fund which consist of all investments in certain debt and equity securities (and other assets). The nuclear decommission fund is maintained to pay for the costs of decontaminating and decommissioning of facilities through collection of revenues derived from utility assessments and government appropriations. No definition available.
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| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
This item represents the entire disclosure related to realized gain or loss on sale of securities related to nuclear decommissioning trust fund. No definition available.
|
|
REGULATORY MATTERS (Tables)
|
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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|
Jun. 30, 2011
|
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Regulatory assets |
|
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| Regulatory liabilities |
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| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Detailed information about assets that are created when regulatory agencies permit public utilities to defer certain costs included in rate-setting to the balance sheet, which is reported as a single block of text. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- Definition
Description containing the entire regulatory liabilities disclosure as a single block of text. Detailed information about liabilities that result from rate actions of a regulator. Rate actions of a regulator can impose a liability on a regulated enterprise resulting in a regulatory liability. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
PENSION PLANS AND OTHER EMPLOYEE BENEFITS (Tables)
|
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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|
Jun. 30, 2011
|
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Components of Net Periodic Benefit Costs | The following tables provide Great Plains Energy’s components of net periodic benefit costs prior to the effects of capitalization and sharing with joint-owners of power plants.
|
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| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
This element may be used to capture the entire disclosure for an employer that sponsors one or more defined benefit pension plans or one or more other defined benefit postretirement plans, of certain information, separately for pension plans and other postretirement benefit plans including the entity's schedule of fair value of plan assets for defined benefit or other postretirement plans. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
EQUITY COMPENSATION (Tables)
|
6 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
|
Jun. 30, 2011
|
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| Notes to Financial Statements [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Equity compensation expense and associated income tax benefits | The following table summarizes Great Plains Energy’s and KCP&L’s equity compensation expense and associated income tax benefits.
|
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Performance share activity | Performance share activity year to date June 30, 2011, is summarized in the following table.
|
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| Restricted stock activity | Restricted stock activity year to date June 30, 2011, is summarized in the following table.
|
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| X | ||||||||||
|
- Definition
Summary of Great Plains Energy's and KCPL's equity compensation expense and associated income tax benefits. No definition available.
|
| X | ||||||||||
|
- Definition
Roll forward of performance share activity. No definition available.
|
| X | ||||||||||
|
- Definition
Roll forward of restricted stock activity. No definition available.
|
| X | ||||||||||
|
- Details
|
|
LONG-TERM DEBT (Tables)
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6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Long-term debt | Great Plains Energy’s and KCP&L’s long-term debt is detailed in the following table.
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| X | ||||||||||
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- Details
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| X | ||||||||||
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- Definition
This element may be used to capture the complete disclosure pertaining to long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the company, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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RELATED PARTY TRANSACTIONS AND RELATIONSHIPS (Tables)
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6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Kansas City Power and Light Company's related party receivables and payables |
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- Details
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| X | ||||||||||
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- Definition
Disclosure that shows the schedule of payables to be paid to and receivables to be collected from related parties, net as of the balance sheet date within one year 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. No definition available.
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DERIVATIVE INSTRUMENTS (Tables)
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6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Values of open positions for derivative instruments |
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| Fair value of open derivative positions, gross values before netting agreements and netting of cash collateral | The fair value of Great Plains Energy’s and KCP&L’s open derivative positions are summarized in the following tables. The tables contain derivative instruments designated as hedging instruments as well as derivative instruments as well as non-hedging derivatives under GAAP. The fair values below are gross values before netting agreements and netting of cash collateral.
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| Gain (loss) recognized in other comprehensive income or earnings for interest rate and commodity hedges | The following tables summarize the amount of gain (loss) recognized in OCI or earnings for interest rate and commodity hedges.
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| Gain (loss) recognized in a regulatory balance sheet account or earnings for utility commodity hedges | The following table summarizes the amount of gain (loss) recognized in a regulatory balance sheet account or earnings for GMO utility commodity hedges. GMO utility commodity derivatives fair value changes are recorded to either a regulatory asset or liability consistent with MPSC regulatory orders.
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| Accumulated other comprehensive income related to cash flow hedges | The amounts recorded in accumulated OCI related to the cash flow hedges are summarized in the following table.
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- Definition
This element can be used for disclosing the entity's tabular disclosure of utility commodity derivatives fair value changes recorded to either a regulatory asset or liability consistent with Missouri Public Service Commission regulatory orders No definition available.
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| X | ||||||||||
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| X | ||||||||||
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- Definition
This element can be used for disclosing the entity's tabular disclosure cash flow hedges included in accumulated other comprehensive income. No definition available.
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| X | ||||||||||
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- Definition
Schedule 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, gains and losses initially recognized in other comprehensive income) on derivative instruments designated and qualifying as hedging instruments in fair value hedges and related hedged items designated and qualifying in fair value hedges. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
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- Definition
This element can be used as an alternative for disclosing the entity's 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 as a single block of text. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
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- Definition
A table or schedule that identifies and provides pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item. No definition available.
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FAIR VALUE MEASUREMENTS (Tables)
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6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balances of financial assets measured at fair value |
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| Balances of financial liabilities measured at fair value |
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| Reconciled balances for Level 3 assets, net measured at fair value |
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| X | ||||||||||
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- Details
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| X | ||||||||||
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- Definition
This element represents the disclosure related to assets, including [financial] instruments measured at fair value that are classified in stockholders' equity, if any, that are measured at fair value on a recurring basis. The disclosures contemplated herein include the fair value measurements at the reporting date by the level within the fair value hierarchy in which the fair value measurements in their entirety fall, segregating fair value measurements using quoted prices in active markets for identical assets (Level 1), significant other observable inputs (Level 2), and significant unobservable inputs (Level 3). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
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- Definition
This element represents, for the fair value measurement of assets using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (1) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets), and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (2) purchases, sales, issuances, and settlements (net); and (3) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- Definition
This element represents the disclosure related to liabilities, including [financial] instruments measured at fair value that are classified in stockholders' equity, if any, that are measured at fair value on a recurring basis. The disclosures contemplated herein include the fair value measurements at the reporting date by the level within the fair value hierarchy in which the fair value measurements in their entirety fall, segregating fair value measurements using quoted prices in active markets for identical assets (Level 1), significant other observable inputs (Level 2), and significant unobservable inputs (Level 3). Reference 1: http://www.xbrl.org/2003/role/presentationRef
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TAXES (Tables)
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6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Components of income tax expense (benefit) | Components of income tax expense are detailed in the following tables.
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| Income tax expense (benefit) and effective income tax rates |
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| Liability for unrecognized tax benefits |
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| X | ||||||||||
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- Definition
The components of provision for (benefit from) income taxes. No definition available.
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| X | ||||||||||
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- Definition
The element details the reconciling items, in expense (benefit) and rate, from the U.S. federal statutory amounts and rate to the effective income tax amounts and rate. No definition available.
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| X | ||||||||||
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- Details
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| X | ||||||||||
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- Definition
The disclosure required for tax positions taken in the tax returns filed or to be filed for which it is more likely than not that the tax position will not be sustained upon examination by taxing authorities (i.e., uncertain tax positions) and other types of income tax contingencies, including: (1) the policy on classification of interest and penalties; (2) a tabular reconciliation of the total amounts of unrecognized tax benefits at the beginning and end of the period; the total amount(s) of: (3) unrecognized tax benefits that, if recognized, would affect the effective tax rate, and (4) interest and penalties recognized in each of the income statement and balance sheet; (5) for positions for which it is reasonably possible that the total amounts unrecognized will significantly change within 12 months of the reporting date the: (i) nature of the uncertainty, (ii) nature of the event that could occur that would cause the change, and (iii) an estimate of the range of the reasonably possible change or a statement that an estimate of the range cannot be made; and (6) a description of tax years that remain subject to examination by major tax jurisdictions. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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|
SEGMENTS AND RELATED INFORMATION (Tables)
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6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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|
Jun. 30, 2011
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| Notes to Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Summarized Financial Information based on segments | The following tables reflect summarized financial information concerning Great Plains Energy’s reportable segment.
|
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| X | ||||||||||
|
- Details
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| X | ||||||||||
|
- Definition
This element may be used to capture the complete disclosure about the profit or loss and total assets for each reportable segment, as a single block of text. 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
|
|
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)
|
3 Months Ended | 6 Months Ended | ||
|---|---|---|---|---|
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Jun. 30, 2011
|
Jun. 30, 2010
|
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| Income [Abstract] | ||||
| Income from continuing operations | $ 43,400,000 | $ 64,400,000 | $ 45,700,000 | $ 84,700,000 |
| Income from continuing operations available for common shareholders | 43,000,000 | 63,900,000 | 45,000,000 | 83,800,000 |
| Common Shares Outstanding [Abstract] | ||||
| Add: effect of dilutive securities | 3,300,000 | 1,500,000 | 3,100,000 | 1,600,000 |
| Basic EPS from continuing operations | $ 0.32 | $ 0.47 | $ 0.33 | $ 0.62 |
| Diluted EPS from continuing operations | $ 0.31 | $ 0.47 | $ 0.32 | $ 0.61 |
|
Great Plains Energy Incorporated [Member]
|
||||
| Income [Abstract] | ||||
| Less: Net income attributable to noncontrolling interest | 0 | 100,000 | (100,000) | 100,000 |
| Less: preferred stock dividend requirements | 400,000 | 400,000 | 800,000 | 800,000 |
| Common Shares Outstanding [Abstract] | ||||
| Average number of common shares outstanding | 135,600,000 | 135,100,000 | 135,500,000 | 135,000,000 |
| Diluted average number of common shares outstanding | 138,900,000 | 136,600,000 | 138,600,000 | 136,600,000 |
|
Great Plains Energy Incorporated [Member] | Dividend Declared [Member]
|
||||
| Dividends Declared [Line Iems] | ||||
| Subsequent Event Date | Aug. 01, 2011 | Aug. 01, 2011 | ||
| Subsequent Event Description | Great Plains Energys Board of Directors declared a quarterly dividend and also declared regular dividends on Great Plains Energys preferred stock. | |||
| Subsequent Event Amount | 0.2075 | |||
|
Kansas City Power and Light Company [Member] | Dividend Declared [Member]
|
||||
| Dividends Declared [Line Iems] | ||||
| Subsequent Event Date | Aug. 01, 2011 | Aug. 01, 2011 | ||
| Subsequent Event Description | KCP&Ls Board of Directors declared a cash dividend payable to Great Plains Energy. | |||
| Subsequent Event Amount | $ 25,000,000 | |||
|
Performance shares [Member]
|
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| Great Plains Energy anti-dilutive shares [Line Items] | ||||
| Antidilutive securities excluded from computation of earnings per share, amount | 201,571 | 41,604 | 201,571 | 50,034 |
|
Restricted Stock [Member]
|
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| Great Plains Energy anti-dilutive shares [Line Items] | ||||
| Antidilutive securities excluded from computation of earnings per share, amount | 12,115 | 93,106 | 43,641 | 251,526 |
|
Stock options [Member]
|
||||
| Great Plains Energy anti-dilutive shares [Line Items] | ||||
| Antidilutive securities excluded from computation of earnings per share, amount | 154,096 | 207,290 | 154,096 | 213,248 |
| X | ||||||||||
|
- Definition
Net income after adjustments for dividends on preferred stock (declared in the period) and/or cumulative preferred stock (accumulated for the period). No definition available.
|
| X | ||||||||||
|
- Definition
Securities (including those issuable pursuant to contingent stock agreements) that could potentially dilute basic earnings per share (EPS) in the future that were not included in the computation of diluted EPS because to do so would increase EPS amounts or decrease loss per share amounts for the period presented. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
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- Details
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| X | ||||||||||
|
- Definition
This element represents the income or loss from continuing operations attributable to the economic entity which may also be defined as revenue less expenses and taxes from ongoing operations before extraordinary items, cumulative effects of changes in accounting principles, and noncontrolling interest. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amount of income (loss) from continuing operations per each share of common stock outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amount of income (loss) from continuing operations available to each share of common stock outstanding during the reporting period and each share that would have been outstanding assuming the issuance of common shares for all dilutive potential common shares outstanding during the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Aggregate awards of share options and nonvested shares to be issued to an employee under a share-based compensation arrangement are considered options for purposes of computing diluted earnings per share. Such share-based awards shall be considered to be outstanding as of the grant date for purposes of computing diluted earnings per share even though their exercise may be contingent upon vesting. Those share-based awards are included in the diluted Earnings Per Share (EPS) computation even if the employee may not receive (or be able to sell) the stock until some future date. Accordingly, all shares to be issued shall be included in computing diluted EPS if the effect is dilutive. The dilutive effect of share-based compensation arrangements shall be computed using the treasury stock method. If the equity share options or other equity instruments are outstanding for only part of a period, the shares issuable shall be weighted to reflect the portion of the period during which the equity instruments were outstanding. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Amount of net income (loss) for the period allocated to noncontrolling shareholders, partners, or other equity holders in one or more of the entities consolidated into the reporting entity's financial statements other than joint ventures, limited partnerships, operating partnerships or interests held by preferred unit holders. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The amount of dividends declared or paid in the period to preferred shareholders, or the amount for which the obligation to pay them dividends arose in the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Reflects the known or estimated financial effect of the event, or transaction that occurred between the balance sheet date and the date the financial statements are issued. If an estimate cannot be made, that fact shall be disclosed. No definition available.
|
| X | ||||||||||
|
- Definition
Date of subsequent event occurrence or of indication that subsequent event occurred. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Describes the event or transaction that occurred between the balance sheet date and the date the financial statements are issued. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The average number of shares issued and outstanding that are used in calculating diluted EPS, determined based on the timing of issuance of shares in the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Number of [basic] shares, after adjustment for contingently issuable shares and other shares not deemed outstanding, determined by relating the portion of time within a reporting period that common shares have been outstanding to the total time in that period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Short-term note payable collateralized by accounts receivable No definition available.
|
| X | ||||||||||
|
- Definition
The net change during the reporting period in the regulatory assets and liabilities for fuel adjustment clauses. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the impact of disallowed construction costs in the MPSC and KCC rate orders for Iatan Nos. 1 and 2 No definition available.
|
| X | ||||||||||
|
- Definition
The net change during the reporting period in amount due within one year (or one business cycle) from an undivided percentage ownership interest in accounts receivable sold to an independedt outside investor. No definition available.
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Definition
The net change during the reporting period in the value of materials and supplies held in inventory. No definition available.
|
| X | ||||||||||
|
- Definition
Cash flow impact of the Energy Cost Adjustment tariff in KCPL's Kansas retail rates No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
All other activities that impact operating cash flows. No definition available.
|
| X | ||||||||||
|
- Definition
Cash payments and transactions that do not result in cash inflows or outflows in the period in which they occur, but affect net income and thus are removed when calculating net cash flow from operating activities using the indirect cash flow method made during the current period for operating activities other than those that have been specifically listed above. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of cash paid during the current period for settlement of forward starting swaps No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Represents the cash flow impact of uncertain tax position activity No definition available.
|
| X | ||||||||||
|
- Definition
Future cash outflow to pay for construction in progress expenditures that have occurred. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of cash paid during the current period to foreign, federal, state, and local authorities as taxes on income. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Change in recurring obligations of a business that arise from the acquisition of merchandise, materials, supplies and services used in the production and sale of goods and services. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net change during the reporting period in amount due within one year (or one business cycle) from customers for the credit sale of goods and services. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net change during the period in the amount of cash payments due to taxing authorities for taxes that are based on the reporting entity's earnings. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The adjustment that is a result of the capitalization of construction costs representing net cost of borrowed funds and a reasonable rate on other funds used during the period of construction. As a result of this capitalization, net income is increased. When calculating net cash generated by operating activities, this adjustment must be backed out of net income. This element pertains to certain regulated industries, such as public utilities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net change during the reporting period in the value of fuel held in inventory. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net change during the reporting period in interest payable, which represents the amount owed to note holders, bond holders, and other parties for interest earned on loans or credit extended to the reporting entity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net change during the reporting period in the amount due to fund pension and non-pension benefits to employees, retired and disabled former employees. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amount of cash paid during the current period for interest owed on money borrowed, net of interest capitalized. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The cash inflow from other borrowing not otherwise defined in the taxonomy. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
No authoritative reference available. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
All amounts that are due or paid to outside investor related specifically to accounts receivable sold No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Cash paid to transferring entity for sale of accounts receivable No definition available.
|
| X | ||||||||||
|
- Definition
Short-term note payable collateralized by accounts receivable No definition available.
|
| X | ||||||||||
|
- Definition
Maximum percentage amounts that, per contract, are due to the servicer in exchange for servicing the financial asset and would no longer be received by a servicer if the beneficial owners of the serviced assets (or their trustees or agents) were to exercise their actual or potential authority under the contract to shift the servicing to another servicer. Depending on the servicing contract, those fees may include some or all of the difference between the interest rate collected on the asset being serviced and the rate to be paid to the beneficial owners of the asset. No definition available.
|
| X | ||||||||||
|
- Definition
Amount paid for interest on intercompany notes No definition available.
|
| X | ||||||||||
|
- Definition
Proceeds received from customers related to the accounts receivable transferred to receivables company No definition available.
|
| X | ||||||||||
|
- Definition
Receivables of Kansas City Power and Light Company sold to its wholly owned subsidiary Receivables Company. No definition available.
|
| X | ||||||||||
|
- Definition
Amounts 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. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
A valuation allowance for trade and other receivables due to an Entity within one year (or the normal operating cycle, whichever is longer) that are expected to be uncollectible. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
All amounts that are due to the servicer of a financial asset, excluding contractually specified servicing fees and late fees. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Reflects the net positive (negative) amount derived from subtracting from net proceeds of sale the carrying amounts, net of allocated reserves, of financial assets transferred to third parties in transactions that qualify for sales treatment. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The total amount due to the entity within one year of the balance sheet date (or one operating cycle, if longer) from outside sources, including trade accounts receivable, notes and loans receivable, as well as any other types of receivables, net of allowances established for the purpose of reducing such receivables to an amount that approximates their net realizable value. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
NUCLEAR PLANT (Details) (USD $)
In Millions, unless otherwise specified |
3 Months Ended | 6 Months Ended | 12 Months Ended | ||
|---|---|---|---|---|---|
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Dec. 31, 2010
|
|
|
Equity securities [Member]
|
|||||
| Nuclear decommissioning trust fund [Abstract] | |||||
| Nuclear decommissioning trust fund beginning balance | $ 85.5 | ||||
| Ending balance of nuclear decommissioning trust fund | 89.4 | 89.4 | 85.5 | ||
| Investments in decommissioning trust fund [Line Items] | |||||
| Cost basis | 73.7 | 73.7 | 73.4 | ||
| Gross unrealized gains | 17.1 | 13.1 | |||
| Gross unrealized losses | (1.4) | (1.0) | |||
| Fair value | 89.4 | 89.4 | 85.5 | ||
|
Debt securities [Member]
|
|||||
| Nuclear decommissioning trust fund [Abstract] | |||||
| Nuclear decommissioning trust fund beginning balance | 40.6 | ||||
| Ending balance of nuclear decommissioning trust fund | 44.5 | 44.5 | 40.6 | ||
| Investments in decommissioning trust fund [Line Items] | |||||
| Cost basis | 41.8 | 41.8 | 38.1 | ||
| Gross unrealized gains | 2.8 | 2.6 | |||
| Gross unrealized losses | (0.1) | (0.1) | |||
| Fair value | 44.5 | 44.5 | 40.6 | ||
|
Other [Member]
|
|||||
| Nuclear decommissioning trust fund [Abstract] | |||||
| Nuclear decommissioning trust fund beginning balance | 3.1 | ||||
| Ending balance of nuclear decommissioning trust fund | 4.3 | 4.3 | 3.1 | ||
| Investments in decommissioning trust fund [Line Items] | |||||
| Cost basis | 4.3 | 4.3 | 3.1 | ||
| Gross unrealized gains | 0 | 0 | |||
| Gross unrealized losses | 0 | 0 | |||
| Fair value | 4.3 | 4.3 | 3.1 | ||
|
Kansas City Power and Light Company [Member]
|
|||||
| Nuclear decommissioning trust fund [Abstract] | |||||
| Nuclear decommissioning trust fund beginning balance | 129.2 | 112.5 | 112.5 | ||
| Contributions to nuclear decommissioning trust fund | 1.7 | 3.7 | |||
| Nuclear decommissioning trust fund earned income, net of fees | 3.4 | 2.0 | |||
| Net realized gains/(losses)on nuclear decommissioning trust fund | 0.1 | 6.7 | |||
| Net unrealized gains/(losses) on nuclear decommissioning trust fund | 3.8 | 4.3 | |||
| Ending balance of nuclear decommissioning trust fund | 138.2 | 138.2 | 129.2 | ||
| Investments in decommissioning trust fund [Line Items] | |||||
| Cost basis | 119.8 | 119.8 | 114.6 | ||
| Gross unrealized gains | 19.9 | 15.7 | |||
| Gross unrealized losses | (1.5) | (1.1) | |||
| Fair value | 138.2 | 138.2 | 129.2 | ||
| Weighted average maturity of debt securities | 7.5 | 7.5 | |||
| Realized Gains on investments in decommissioning trust fund | 0.7 | 0.2 | 0.8 | 7.0 | |
| Realized Losses on investments in decommissioning trust fund | (0.7) | (0.1) | (0.7) | (0.5) | |
|
Kansas City Power and Light Company [Member] | Equity securities [Member]
|
|||||
| Nuclear decommissioning trust fund [Abstract] | |||||
| Nuclear decommissioning trust fund beginning balance | 85.5 | ||||
| Ending balance of nuclear decommissioning trust fund | 89.4 | 89.4 | 85.5 | ||
| Investments in decommissioning trust fund [Line Items] | |||||
| Cost basis | 73.7 | 73.7 | 73.4 | ||
| Gross unrealized gains | 17.1 | 13.1 | |||
| Gross unrealized losses | (1.4) | (1.0) | |||
| Fair value | 89.4 | 89.4 | 85.5 | ||
|
Kansas City Power and Light Company [Member] | Debt securities [Member]
|
|||||
| Nuclear decommissioning trust fund [Abstract] | |||||
| Nuclear decommissioning trust fund beginning balance | 40.6 | ||||
| Ending balance of nuclear decommissioning trust fund | 44.5 | 44.5 | 40.6 | ||
| Investments in decommissioning trust fund [Line Items] | |||||
| Cost basis | 41.8 | 41.8 | 38.1 | ||
| Gross unrealized gains | 2.8 | 2.6 | |||
| Gross unrealized losses | (0.1) | (0.1) | |||
| Fair value | 44.5 | 44.5 | 40.6 | ||
|
Kansas City Power and Light Company [Member] | Other [Member]
|
|||||
| Nuclear decommissioning trust fund [Abstract] | |||||
| Nuclear decommissioning trust fund beginning balance | 3.1 | ||||
| Ending balance of nuclear decommissioning trust fund | 4.3 | 4.3 | 3.1 | ||
| Investments in decommissioning trust fund [Line Items] | |||||
| Cost basis | 4.3 | 4.3 | 3.1 | ||
| Gross unrealized gains | 0 | 0 | |||
| Gross unrealized losses | 0 | 0 | |||
| Fair value | $ 4.3 | $ 4.3 | $ 3.1 | ||
| X | ||||||||||
|
- Definition
This represents total contributions to the decommissioning trust fund during the current period. No definition available.
|
| X | ||||||||||
|
- Definition
This represents income earned, net of fees, on decommissioning trust fund investments during the current period. No definition available.
|
| X | ||||||||||
|
- Definition
This represents the net realized gains (losses) on decommissioning trust fund investments during the current period. No definition available.
|
| X | ||||||||||
|
- Definition
This represents the net unrealized gains (losses) on decommissioning trust fund investments during the current period. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
This represents the weighted average number of years when the debt securities held in the decommissioning trust fund are scheduled to be fully repaid. No definition available.
|
| 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 made for accretion, amortization, other-than-temporary impairments, and hedging, if any. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
This item represents the gross unrealized gains for securities which are categorized neither as held-to-maturity nor trading securities. Such gross unrealized gains are the excess of the fair value of the Available-for-sale Securities over their carrying value as of the reporting date. Such gross unrealized gains are included in other comprehensive income in the statement of shareholders' equity, unless the Available-for-sale Security is designated as a hedge. All or a portion of the unrealized holding gain of an available-for-sale security that is designated as being hedged in a fair value hedge shall be recognized in earnings during the period of the hedge. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
This item represents the gross unrealized losses for securities which are categorized neither as held-to-maturity nor trading securities. Such gross unrealized losses are the excess of the carrying value of the Available-for-sale Securities over their fair value as of the reporting date. Such gross unrealized losses are included in other comprehensive income in the statement of shareholders' equity, unless the Available-for-sale Security is designated as a hedge or is determined to have had an other than temporary decline in fair value below its amortized cost basis. All or a portion of the unrealized holding loss of an Available-for-sale Security that is designated as being hedged in a fair value hedge shall be recognized in earnings during the period of the hedge, as should other than temporary declines in fair value below costs basis. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Details
|
|
REGULATORY MATTERS (Details) (USD $)
In Millions, unless otherwise specified |
6 Months Ended | ||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
|
Jun. 30, 2011
|
Dec. 31, 2010
|
||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | $ 949.7 | $ 924.0 | |||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 267.7 | 258.2 | |||||||||||||||||||||||||
|
Emission allowances [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 84.4 | 86.4 | |||||||||||||||||||||||||
|
Asset retirement obligations [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 51.1 | 44.9 | |||||||||||||||||||||||||
|
Pension [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 39.1 | 37.1 | |||||||||||||||||||||||||
|
Cost of removal, liability [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 62.8 | 62.8 | |||||||||||||||||||||||||
|
Other [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 30.3 | 27.0 | |||||||||||||||||||||||||
|
Taxes recoverable through future rates [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 144.1 | 142.5 | |||||||||||||||||||||||||
|
Loss on reacquired debt [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 7.2 | 5.7 | |||||||||||||||||||||||||
|
Cost of removal, asset [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 9.3 | 8.5 | |||||||||||||||||||||||||
|
Asset retirement obligations [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 42.7 | 40.3 | |||||||||||||||||||||||||
|
Pension settlements [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 6.8 | 9.0 | |||||||||||||||||||||||||
|
Pension and post-retirement costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 473.7 | 483.8 | |||||||||||||||||||||||||
|
Deferred customer programs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 64.2 | 60.3 | |||||||||||||||||||||||||
|
Rate case expenses [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 15.3 | 15.6 | |||||||||||||||||||||||||
|
Skill set realignment costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 4.1 | 4.8 | |||||||||||||||||||||||||
|
Fuel adjustment clauses [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 56.4 | 45.5 | |||||||||||||||||||||||||
|
Acquisition transition costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 50.1 | 51.8 | |||||||||||||||||||||||||
|
St. Joseph Light and Power acquisition [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 2.3 | 2.6 | |||||||||||||||||||||||||
|
Storm damage [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 2.4 | 3.2 | |||||||||||||||||||||||||
|
Derivative instruments [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 1.5 | 3.1 | |||||||||||||||||||||||||
|
Iatan No. 1 and Common facilities depreciation and carrying costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 22.9 | 19.4 | |||||||||||||||||||||||||
|
Iatan No. 2 construction accounting costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 43.5 | 23.7 | |||||||||||||||||||||||||
|
Other [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 3.2 | 4.2 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member]
|
|||||||||||||||||||||||||||
| Regulatory Proceedings [Line Items] | |||||||||||||||||||||||||||
| Deferred tax credits (note) | 128.9 | ||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 683.6 | 679.6 | |||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 147.2 | 141.3 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Emission allowances [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 84.0 | 85.9 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Asset retirement obligations [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 51.1 | 44.9 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Pension [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 0.2 | 0 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Cost of removal, liability [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 0 | 0 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Other [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 11.9 | 10.5 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Taxes recoverable through future rates [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 119.1 | 117.2 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Loss on reacquired debt [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 6.6 | [1] | 5.0 | ||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Cost of removal, asset [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 9.3 | 8.5 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Asset retirement obligations [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 29.4 | 27.5 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Pension settlements [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 6.8 | [2] | 9.0 | ||||||||||||||||||||||||
| Amount not included in rate base | 3.7 | ||||||||||||||||||||||||||
| Regulatory amortization period | 2012 | ||||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Pension and post-retirement costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 357.7 | [3] | 377.1 | ||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Deferred customer programs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 46.1 | [4] | 44.7 | ||||||||||||||||||||||||
| Amount not included in rate base | 11.6 | ||||||||||||||||||||||||||
| Regulatory amortization period | various | ||||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Rate case expenses [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 10.7 | [5] | 12.3 | ||||||||||||||||||||||||
| Amount not included in rate base | 10.7 | ||||||||||||||||||||||||||
| Regulatory amortization period | various | ||||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Skill set realignment costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 4.1 | [6] | 4.8 | ||||||||||||||||||||||||
| Amount not included in rate base | 2.6 | ||||||||||||||||||||||||||
| Regulatory amortization period | 2017 | ||||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Fuel adjustment clauses [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 18.9 | [5] | 8.4 | ||||||||||||||||||||||||
| Amount not included in rate base | 18.9 | ||||||||||||||||||||||||||
| Regulatory amortization period | various | ||||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Acquisition transition costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 27.7 | [7] | 29.3 | ||||||||||||||||||||||||
| Amount not included in rate base | 27.7 | ||||||||||||||||||||||||||
| Regulatory amortization period | 2016 | ||||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | St. Joseph Light and Power acquisition [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 0 | 0 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Storm damage [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 0 | 0 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Derivative instruments [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 0 | 0 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Iatan No. 1 and Common facilities depreciation and carrying costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 16.7 | 15.1 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Iatan No. 2 construction accounting costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 28.0 | 17.2 | |||||||||||||||||||||||||
|
Kansas City Power and Light Company [Member] | Other [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 2.5 | [8] | 3.5 | ||||||||||||||||||||||||
| Regulatory amortization period | various | ||||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member]
|
|||||||||||||||||||||||||||
| Regulatory Proceedings [Line Items] | |||||||||||||||||||||||||||
| Deferred tax credits (note) | 3.7 | ||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 266.1 | 244.4 | |||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 120.5 | 116.9 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Emission allowances [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 0.4 | 0.5 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Asset retirement obligations [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 0 | 0 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Pension [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 38.9 | 37.1 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Cost of removal, liability [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 62.8 | [9] | 62.8 | ||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Other [Member]
|
|||||||||||||||||||||||||||
| Regulatory Liabilities [Line Items] | |||||||||||||||||||||||||||
| Non current liabilities | 18.4 | 16.5 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Taxes recoverable through future rates [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 25.0 | 25.3 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Loss on reacquired debt [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 0.6 | [1] | 0.7 | ||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Cost of removal, asset [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 0 | 0 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Asset retirement obligations [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 13.3 | 12.8 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Pension settlements [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 0 | 0 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Pension and post-retirement costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 116.0 | [3] | 106.7 | ||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Deferred customer programs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 18.1 | 15.6 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Rate case expenses [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 4.6 | [5] | 3.3 | ||||||||||||||||||||||||
| Amount not included in rate base | 4.6 | ||||||||||||||||||||||||||
| Regulatory amortization period | various | ||||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Skill set realignment costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 0 | 0 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Fuel adjustment clauses [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 37.5 | [5] | 37.1 | ||||||||||||||||||||||||
| Amount not included in rate base | 37.5 | ||||||||||||||||||||||||||
| Regulatory amortization period | various | ||||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Acquisition transition costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 22.4 | [7] | 22.5 | ||||||||||||||||||||||||
| Amount not included in rate base | 22.4 | ||||||||||||||||||||||||||
| Regulatory amortization period | 2016 | ||||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | St. Joseph Light and Power acquisition [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 2.3 | [10] | 2.6 | ||||||||||||||||||||||||
| Amount not included in rate base | 2.3 | ||||||||||||||||||||||||||
| Regulatory amortization period | 2015 | ||||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Storm damage [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 2.4 | [11] | 3.2 | ||||||||||||||||||||||||
| Amount not included in rate base | 2.4 | ||||||||||||||||||||||||||
| Regulatory amortization period | 2012 | ||||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Derivative instruments [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 1.5 | [12] | 3.1 | ||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Iatan No. 1 and Common facilities depreciation and carrying costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 6.2 | 4.3 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Iatan No. 2 construction accounting costs [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 15.5 | 6.5 | |||||||||||||||||||||||||
|
KCPL Greater Missouri Operations Company [Member] | Other [Member]
|
|||||||||||||||||||||||||||
| Regulatory Assets [Line Items] | |||||||||||||||||||||||||||
| Non current assets amount | 0.7 | [8] | 0.7 | ||||||||||||||||||||||||
| Regulatory amortization period | various | ||||||||||||||||||||||||||
|
Rate jurisdiction - Kansas [Member] | Kansas City Power and Light Company [Member]
|
|||||||||||||||||||||||||||
| Regulatory Proceedings [Line Items] | |||||||||||||||||||||||||||
| Return on equity | 10.00% | ||||||||||||||||||||||||||
| Rate-making equity ratio | 49.70% | ||||||||||||||||||||||||||
| Effective date | Dec. 01, 2010 | ||||||||||||||||||||||||||
| Annual revenue increase authorized | 21.8 | ||||||||||||||||||||||||||
| Jurisdictional rate base | 1,781 | ||||||||||||||||||||||||||
| Adjusted annual revenue increased authorized | 22.0 | ||||||||||||||||||||||||||
| Annual revenue increase authorized but considered as interim subject to refund or true-up | 1.4 | ||||||||||||||||||||||||||
|
Rate jurisdiction - Missouri [Member] | Kansas City Power and Light Company [Member]
|
|||||||||||||||||||||||||||
| Regulatory Proceedings [Line Items] | |||||||||||||||||||||||||||
| File date | Jun. 04, 2010 | ||||||||||||||||||||||||||
| Annual revenue increase | 92.1 | ||||||||||||||||||||||||||
| Adjusted annual revenue increase | 66.5 | ||||||||||||||||||||||||||
| Return on equity | 10.00% | ||||||||||||||||||||||||||
| Rate-making equity ratio | 46.30% | ||||||||||||||||||||||||||
| Effective date | May 04, 2011 | ||||||||||||||||||||||||||
| Annual revenue increase authorized | 34.8 | ||||||||||||||||||||||||||
| Jurisdictional rate base | 2,000 | ||||||||||||||||||||||||||
| Wholesale margin offset requested | 29.4 | ||||||||||||||||||||||||||
| Wholesale margin offset authorized | 45.9 | ||||||||||||||||||||||||||
| Disallowed construction costs on Iatan Nos 1 and 2 | 1.5 | ||||||||||||||||||||||||||
| Other disallowed costs | 2.4 | ||||||||||||||||||||||||||
| Qualifying advance coal project tax credits to be reallocated from KCPL to GMO | 26.5 | ||||||||||||||||||||||||||
|
Rate jurisdiction - Missouri [Member] | KCPL Greater Missouri Operations Company [Member]
|
|||||||||||||||||||||||||||
| Regulatory Proceedings [Line Items] | |||||||||||||||||||||||||||
| Jurisdictional rate base | 1,760 | ||||||||||||||||||||||||||
| Disallowed construction costs on Iatan Nos 1 and 2 | 0.8 | ||||||||||||||||||||||||||
| Other disallowed costs | 1.5 | ||||||||||||||||||||||||||
|
Rate jurisdiction - Missouri public service division [Member] | KCPL Greater Missouri Operations Company [Member]
|
|||||||||||||||||||||||||||
| Regulatory Proceedings [Line Items] | |||||||||||||||||||||||||||
| File date | Jun. 04, 2010 | ||||||||||||||||||||||||||
| Annual revenue increase | 75.8 | ||||||||||||||||||||||||||
| Adjusted annual revenue increase | 65.9 | ||||||||||||||||||||||||||
| Return on equity | 10.00% | ||||||||||||||||||||||||||
| Rate-making equity ratio | 46.60% | ||||||||||||||||||||||||||
| Effective date | Jun. 25, 2011 | ||||||||||||||||||||||||||
| Annual revenue increase authorized | 30.1 | ||||||||||||||||||||||||||
| Adjusted annual revenue increased authorized | 35.7 | ||||||||||||||||||||||||||
| Amount of Crossroads disallowed from rate base | 50.0 | ||||||||||||||||||||||||||
| Amount of Crossroads transmission expense disallowed | 4.9 | ||||||||||||||||||||||||||
| Amount of Crossroads accumulated deferred taxes offset against rate base | 15.0 | ||||||||||||||||||||||||||
| Amount of Crossroads requested in rate base | 104.0 | ||||||||||||||||||||||||||
|
Rate jurisdiction - St. Joseph Light and Power division [Member] | KCPL Greater Missouri Operations Company [Member]
|
|||||||||||||||||||||||||||
| Regulatory Proceedings [Line Items] | |||||||||||||||||||||||||||
| File date | Jun. 04, 2010 | ||||||||||||||||||||||||||
| Annual revenue increase | 22.1 | ||||||||||||||||||||||||||
| Adjusted annual revenue increase | 23.2 | ||||||||||||||||||||||||||
| Return on equity | 10.00% | ||||||||||||||||||||||||||
| Rate-making equity ratio | 46.60% | ||||||||||||||||||||||||||
| Effective date | Jun. 25, 2011 | ||||||||||||||||||||||||||
| Annual revenue increase authorized | 29.3 | ||||||||||||||||||||||||||
| Adjusted annual revenue increased authorized | 29.8 | ||||||||||||||||||||||||||
| Deferred annual revenue increase | $ 7.7 | ||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||
| X | ||||||||||
|
- Definition
The annual increase in revenue from retail rate increase related to pending request filed with the state and adjusted subsequent to the original request. No definition available.
|
| X | ||||||||||
|
- Definition
The annual increase in revenue from retail rate increase adjusted from the original authorization approved by the state. No definition available.
|
| X | ||||||||||
|
- Definition
Amount included in regulatory assets but not included in rate base and amortized through various periods. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of accumulated deferred taxes on Crossroads Energy Center offset against GMO Missouri rate base. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of Crossroads Energy Center disallowed from GMO Missouri rate base. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of Crossroads Energy Center requested to be included in GMO Missouri rate base. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of Crossroads Energy Center transmission expense disallowed from GMO Missouri retail revenue rates. No definition available.
|
| X | ||||||||||
|
- Definition
The annual increase in revenue from retail rate increase related to pending request filed with the state. No definition available.
|
| X | ||||||||||
|
- Definition
The annual increase in revenue from retail rate increase authorized by the state. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the annual increase in revenue from retail rate increase authorized by the state that is considered as interim subject to refund or true-up pending reconsideration proceedings. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of authorized annual increase in revenue from retail rate increase that was deferred. No definition available.
|
| X | ||||||||||
|
- 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. No definition available.
|
| X | ||||||||||
|
- Definition
Losses recognized as a result of disallowed construction costs on Iatan Nos 1 and 2. No definition available.
|
| X | ||||||||||
|
- Definition
The date the retail rate increase was effective. No definition available.
|
| X | ||||||||||
|
- Definition
The date the retail rate increase was requested. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of utility assets on which rates are based. A return is earned on these assets. No definition available.
|
| X | ||||||||||
|
- Definition
Losses recognized as a result of other disallowed costs in rate orders. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of qualifying advance coal project tax credits the Missouri Public Service Commission required KCPL to reallocate to GMO. No definition available.
|
| X | ||||||||||
|
- Definition
Discloses the equity percentage of total capitalization used in the rate making process. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The amount of net income returned as a percentage of shareholders equity. Return on equity measures a corporation's profitability by revealing how much profit a company generates with the money shareholders have invested. No definition available.
|
| X | ||||||||||
|
- Definition
The authorized amount of annual offset to the revenue requirement due to the annual non-firm wholesale electric sales margin. No definition available.
|
| X | ||||||||||
|
- Definition
The requested amount of annual offset to the revenue requirement due to the annual non-firm wholesale electric sales margin. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The amount for the individual regulatory noncurrent liability as itemized in a table of regulatory noncurrent liabilities as of the end of the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amortization period for recovery of the individual regulatory noncurrent asset in a schedule of regulatory noncurrent assets Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
PENSION PLANS AND OTHER EMPLOYEE BENEFITS (Details) (USD $)
In Millions, unless otherwise specified |
3 Months Ended | 6 Months Ended | ||
|---|---|---|---|---|
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Jun. 30, 2011
|
Jun. 30, 2010
|
|
| Voluntary Separation Program [Line Items] | ||||
| Annual Savings In Labor Costs Expected From Voluntary Savings Program | $ 15.0 | $ 15.0 | ||
| Employees who elected to voluntarily separate (in employees) | 140 | 140 | ||
| Date of employee separation | Apr. 30, 2011 | Apr. 30, 2011 | ||
|
Great Plains Energy Incorporated [Member]
|
||||
| Voluntary Separation Program [Line Items] | ||||
| Voluntary separation program | 3.0 | 0 | 12.7 | 0 |
|
Pension Benefits [Member]
|
||||
| Components of net periodic benefit costs [Abstract] | ||||
| Service cost | 7.8 | 7.6 | 15.6 | 15.2 |
| Interest cost | 12.6 | 12.3 | 25.1 | 24.6 |
| Expected return on plan assets | (9.7) | (9.2) | (19.3) | (18.3) |
| Prior service cost | 1.2 | 1.2 | 2.3 | 2.4 |
| Recognized net actuarial loss (gain) | 9.5 | 9.4 | 19.2 | 18.7 |
| Transition obligation | 0 | 0 | 0 | 0 |
| Settlement charge | 0.2 | 0 | 0.2 | 0 |
| Net periodic benefit costs before regulatory adjustment | 21.6 | 21.3 | 43.1 | 42.6 |
| Regulatory adjustment | (5.9) | (8.1) | (12.3) | (16.5) |
| Net periodic benefit costs | 15.7 | 13.2 | 30.8 | 26.1 |
| Contributions made by the Company | 31.6 | |||
| Additional contribution expected in the year | 82.2 | 82.2 | ||
|
Other Benefits [Member]
|
||||
| Components of net periodic benefit costs [Abstract] | ||||
| Service cost | 0.8 | 0.9 | 1.6 | 1.8 |
| Interest cost | 1.9 | 2.2 | 3.9 | 4.4 |
| Expected return on plan assets | (0.5) | (0.6) | (0.9) | (1.1) |
| Prior service cost | 1.8 | 1.8 | 3.6 | 3.6 |
| Recognized net actuarial loss (gain) | (0.2) | 0 | (0.3) | 0 |
| Transition obligation | 0.4 | 0.4 | 0.7 | 0.7 |
| Settlement charge | 0 | 0 | 0 | 0 |
| Net periodic benefit costs before regulatory adjustment | 4.2 | 4.7 | 8.6 | 9.4 |
| Regulatory adjustment | 0.1 | 0 | 0.3 | 0 |
| Net periodic benefit costs | 4.3 | 4.7 | 8.9 | 9.4 |
| Additional contribution expected in the year | $ 17.1 | $ 17.1 | ||
| X | ||||||||||
|
- Definition
Expected annual savings in labor costs due to the voluntary separation program No definition available.
|
| X | ||||||||||
|
- Definition
Date that the majority of employees separated from the Company under the voluntary separation program No definition available.
|
| 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 remainder of the fiscal year. Estimated contributions may be presented in the aggregate combining (1) contributions required by funding regulations or laws, (2) discretionary contributions, and (3) noncash contributions. No definition available.
|
| X | ||||||||||
|
- Definition
The total amount of net periodic benefit cost for defined benefit plans for the period before regulatory adjustments. No definition available.
|
| X | ||||||||||
|
- Definition
Difference between pension costs under GAAP and pension costs for ratemaking purposes. This difference is due to timing and will be eliminated over the life of the pension plans. No definition available.
|
| X | ||||||||||
|
- Definition
Number of employees who elected to separate from the Company under the voluntary separation program No definition available.
|
| X | ||||||||||
|
- Definition
Expenses related to Great Plains Energy's organizational realignment process and voluntary separation program undertaken to assist in the management of overall costs within the level reflected in the Company's retial electric rates and to enhance organizational efficiency. No definition available.
|
| X | ||||||||||
|
- Details
|
| 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 amount of the transition obligation or asset recognized in net periodic benefit cost. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amount of contributions made by the employer. 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 or loss, prior service cost or credit, transition asset or obligation, and gain or loss due to settlements or curtailments). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The amount of net (gain) loss recognized in net periodic benefit cost as a result of an irrevocable action that relieves the employer (or the plan) of primary responsibility for a benefit obligation and eliminates significant risks related to the obligation and the assets used to effect the settlement. Examples of transactions that constitute a settlement include (a) making lump-sum cash payments to plan participants in exchange for their rights to receive specified benefits and (b) purchasing nonparticipating annuity contracts to cover vested benefits. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| 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
|
|
EQUITY COMPENSATION (Details) (USD $)
In Millions, except Share data, unless otherwise specified |
3 Months Ended | 6 Months Ended | ||||||
|---|---|---|---|---|---|---|---|---|
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Jun. 30, 2011
|
Jun. 30, 2010
|
|||||
| Employee Service Share-based Compensation, Aggregate Disclosures [Abstract] | ||||||||
| Compensation expense | $ 1.7 | $ 2.3 | $ 3.3 | $ 2.6 | ||||
| Income tax benefits | 0.8 | 0.5 | 1.4 | 0.6 | ||||
|
Performance Shares [Member]
|
||||||||
| Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | ||||||||
| Balance at beginning of period (in number of shares) | 431,784 | |||||||
| Granted (in number of shares) | 139,897 | |||||||
| Earned (in number of shares) | (68,258) | |||||||
| Forfeited (in number of shares) | (30,705) | |||||||
| Balance at end of period (in number of shares) | 472,718 | 472,718 | ||||||
| Weighted-average grant date fair value per share price, beginning of period (in dollars per shares) | $ 18.01 | [1] | ||||||
| Granted and issued (in dollars per shares) | $ 26.28 | $ 0.00 | $ 22.48 | [1] | $ 23.37 | |||
| Earned (in dollars per shares) | $ 11.04 | [1] | ||||||
| Forfeited (in dollars per shares) | $ 19.86 | [1] | $ 19.86 | [1] | ||||
| Weighted-average grant date fair value per share price, end of period (in dollars per shares) | $ 20.22 | [1] | $ 20.22 | [1] | ||||
| Expected volatility (in hundredths) | 30.00% | |||||||
| Expected dividend yields (in hundredths) | 4.35% | |||||||
| Risk-free interest rates (in hundredths) | 1.15% | |||||||
| Remaining weighted-average contractual term (in years) | 1.4 | |||||||
| Total unrecognized compensation expense, net of forfeiture rates | 4.7 | 4.7 | ||||||
| Total fair value of shares vested | 0.8 | |||||||
|
Restricted Stock [Member]
|
||||||||
| Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | ||||||||
| Balance at beginning of period (in number of shares) | 406,657 | |||||||
| Granted and issued (in number of shares) | 152,154 | |||||||
| Vested (in number of shares) | (149,688) | |||||||
| Forfeited (in number of shares) | (45,269) | |||||||
| Balance at end of period (in number of shares) | 363,854 | 363,854 | ||||||
| Weighted-average grant date fair value per share price, beginning of period (in dollars per shares) | $ 16.23 | [1] | ||||||
| Granted and issued (in dollars per shares) | $ 20.26 | $ 16.88 | $ 19.26 | [1] | $ 17.67 | |||
| Vested (in dollars per shares) | $ 17.29 | [1] | ||||||
| Forfeited (in dollars per shares) | $ 17.37 | [1] | $ 17.37 | [1] | ||||
| Weighted-average grant date fair value per share price, end of period (in dollars per shares) | $ 16.98 | [1] | $ 16.98 | [1] | ||||
| Remaining weighted-average contractual term (in years) | 1.7 | |||||||
| Total unrecognized compensation expense, net of forfeiture rates | 3.5 | 3.5 | ||||||
| Total fair value of shares vested | 0.6 | 1.5 | 2.6 | 6.4 | ||||
|
Kansas City Power and Light Company [Member]
|
||||||||
| Employee Service Share-based Compensation, Aggregate Disclosures [Abstract] | ||||||||
| Compensation expense | 1.2 | 1.6 | 2.3 | 1.8 | ||||
| Income tax benefits | $ 0.6 | $ 0.2 | $ 1.0 | $ 0.2 | ||||
|
||||||||
| X | ||||||||||
|
- Definition
Represents the number of performance shares earned during the reporting period. No definition available.
|
| X | ||||||||||
|
- Definition
The weighted average fair value as of grant dates pertaining to a share-based award plan other than a stock option plan for which the grantee earned the right during the reporting period, by satisfying performance requirements, to receive shares in accordance with the terms of the arrangement. No definition available.
|
| X | ||||||||||
|
- Definition
The number of shares granted and issued under a share-based award plan pertaining to restricted stock grants made during the period. No definition available.
|
| X | ||||||||||
|
- Definition
The estimated dividend rate (a percentage of the share price) to be paid (expected dividends) to holders of the underlying shares over the term of the stock based awards. No definition available.
|
| X | ||||||||||
|
- Definition
The risk-free interest rate assumption that is used in valuing stock based awards on its own shares. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the expense recognized during the period arising from share-based compensation arrangements (for example, shares of stock, 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 | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The total recognized tax benefit related to compensation cost for share-based payment arrangements recognized in income during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
As of the latest balance-sheet date presented, the total compensation cost related to outstanding, nonvested share-based compensation awards not yet recognized (will be charged against earnings as services are performed or other vesting criteria are met). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The number of shares under a share-based award plan other than a stock option plan that were settled during the reporting period due to a failure to satisfy vesting conditions pertaining to all option plans. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The weighted average fair value as of the grant date of share-based award plans other than stock option plans that were not exercised or put into effect during the reporting period as a result of the occurrence of a terminating event specified in the contractual agreement of the plan. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The number of shares issuable under a share-based award plan pertaining to grants made during the period on other than stock option plans (for example, phantom stock plan, stock appreciation rights plan, performance target plan). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The weighted average fair value at grant for nonvested share-based awards issued during the period on other than stock option plans (for example, phantom stock plan, stock appreciation rights plan, performance target plan). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The number of outstanding awards on nonstock option plans (for example, phantom stock plan, stock appreciation rights plan, revenue or profit achievement stock award plan) for which the employer is contingently obligated to issue equity instruments or transfer assets to an employee who has not yet satisfied service or performance criteria necessary to gain title to proceeds from the sale of the award or underlying shares. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The weighted average fair value of nonvested awards on share-based plans excluding option plans (for example, phantom stock plan, stock appreciation rights plan, revenue or profit achievement stock award plan) for which the employer is contingently obligated to issue equity instruments or transfer assets to an employee who has not yet satisfied service or performance criteria necessary to gain title to proceeds from the sale of the award or underlying shares. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The decrease in the number of shares potentially issuable under a share-based award plan pertaining to awards for which the grantee has gained the right during the reporting period, by satisfying service and performance requirements, to receive or retain shares, other instruments, or cash in accordance with the terms of the arrangement. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The total fair value of share-based awards for which the grantee gained the right during the reporting period, by satisfying service and performance requirements, to receive or retain shares, other instruments, or cash in accordance with the terms of the arrangement. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The weighted average fair value as of grant dates pertaining to a share-based award plan other than a stock option plan for which the grantee gained the right during the reporting period, by satisfying service and performance requirements, to receive or retain shares, other instruments, or cash in accordance with the terms of the arrangement. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The estimated measure of the percentage amount by which a share price is expected to fluctuate during a period. Volatility also may be defined as a probability-weighted measure of the dispersion of returns about the mean. The volatility of a share price is the standard deviation of the continuously compounded rates of return on the share over a specified period. That is the same as the standard deviation of the differences in the natural logarithms of the stock prices plus dividends, if any, over the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The weighted average period between the balance-sheet date and expiration for all awards outstanding under the plan, which may be expressed in a decimal value for number of years. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
SHORT-TERM BORROWINGS AND SHORT-TERM BANK LINES OF CREDIT (Details) (USD $)
In Millions, unless otherwise specified |
6 Months Ended | |
|---|---|---|
|
Jun. 30, 2011
|
Dec. 31, 2010
|
|
| Line of Credit Facility [Line Items] | ||
| Amount of revolving credit facility | $ 200.0 | |
| Revolving credit facility expiration date | August 2013 | |
| Covenant term - amount considered as default | 50.0 | |
| Amount of outstanding cash borrowings | 27.0 | 9.5 |
| Weighted average interest rate from outstanding borrowings | 2.94% | 3.06% |
| Line of Credit Facility, Covenant Compliance | in compliance | |
| Amount of letters of credit outstanding | 11.6 | 15.8 |
| Covenant Term Ratio Of Consolidated Indebtedness To Consolidated Capitalization Ratio, Maximum | 0.65 | |
|
Great Plains Energy Incorporated [Member]
|
||
| Line of Credit Facility [Line Items] | ||
| Amount of outstanding cash borrowings | 92.0 | 9.5 |
| Amount of outstanding commercial paper borrowings | 476.7 | 263.5 |
|
Kansas City Power and Light Company [Member]
|
||
| Line of Credit Facility [Line Items] | ||
| Amount of revolving credit facility | 600.0 | |
| Revolving credit facility expiration date | August 2013 | |
| Covenant term - amount considered as default | 50.0 | |
| Amount of outstanding cash borrowings | 0 | 0 |
| Amount of outstanding commercial paper borrowings | 476.7 | 263.5 |
| Weighted average interest rate from outstanding borrowings | 0.38% | 0.41% |
| Line of Credit Facility, Covenant Compliance | in compliance | |
| Amount of letters of credit outstanding | 31.4 | 24.4 |
| Covenant Term Ratio Of Consolidated Indebtedness To Consolidated Capitalization Ratio, Maximum | 0.65 | |
|
KCPL Greater Missouri Operations Company [Member]
|
||
| Line of Credit Facility [Line Items] | ||
| Amount of revolving credit facility | 450.0 | |
| Revolving credit facility expiration date | August 2013 | |
| Covenant term - amount considered as default | 50.0 | |
| Amount of outstanding cash borrowings | 65.0 | 0 |
| Weighted average interest rate from outstanding borrowings | 2.94% | |
| Line of Credit Facility, Covenant Compliance | in compliance | |
| Amount of letters of credit outstanding | $ 13.2 | $ 13.2 |
| Covenant Term Ratio Of Consolidated Indebtedness To Consolidated Capitalization Ratio, Maximum | 0.65 |
| X | ||||||||||
|
- Definition
Amount of other indebtedness considered a default under the revolving credit facility. No definition available.
|
| X | ||||||||||
|
- Definition
The maximum ratio of consolidated indebtedness to consolidated capitalization ratio, as defined in the agreement that the company is required to comply with at all times. No definition available.
|
| X | ||||||||||
|
- Definition
Amount of letters of credit issued under the credit facility as of the balance-sheet date. No definition available.
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
Identification of whether the entity has been in compliance with any credit facility debt covenants during the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
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| X | ||||||||||
|
- Definition
Reflects when the credit facility terminates, which may be presented in a variety of ways (year, month and year, day, month and year, quarter). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
Carrying amount at the balance sheet date of borrowings from a bank, not elsewhere enumerated in the taxonomy, with a maturity within one year (or within one operating cycle if longer) from the date of borrowing. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
|
LONG-TERM DEBT (Details) (USD $)
|
6 Months Ended | |||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
|
Jun. 30, 2011
|
Dec. 31, 2010
|
|||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Long-term debt excluding current maturities | $ 2,860,800,000 | $ 2,942,700,000 | ||||||||||||
| Fair value value of long-term debt, including current maturities | 3,600,000,000 | 3,700,000,000 | ||||||||||||
|
Kansas City Power and Light Company [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Current maturities | (162,700,000) | (150,300,000) | ||||||||||||
| Unamortized discount | (1,800,000) | (2,000,000) | ||||||||||||
| Long-term debt excluding current maturities | 1,504,700,000 | 1,629,700,000 | ||||||||||||
| Fair value value of long-term debt, including current maturities | 1,800,000,000 | 1,900,000,000 | ||||||||||||
|
Kansas City Power and Light Company [Member] | General Mortgage Bonds [Member] | General Mortgage bonds EIRR due 2012-2035 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Debt Instrument Maturity Date Range Start | 2012 | |||||||||||||
| Debt Instrument Maturity Date Range End | 2035 | |||||||||||||
| Principal outstanding | 119,300,000 | [1] | 158,800,000 | [1] | ||||||||||
| Weighted-average interest rate (in hundredths) | 4.87% | [2] | ||||||||||||
| Bonds purchased in lieu of redemption | 39,500,000 | |||||||||||||
|
Kansas City Power and Light Company [Member] | General Mortgage Bonds [Member] | General Mortgage bonds Series 2009 due 2019 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 400,000,000 | 400,000,000 | ||||||||||||
| Interest rate (in hundredths) | 7.15% | |||||||||||||
| Year Due | 2019 | |||||||||||||
| Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths) | 8.59% | [3] | ||||||||||||
|
Kansas City Power and Light Company [Member] | General Mortgage Bonds [Member] | General Mortgage bonds EIRR series 2005 due 2035 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 50,000,000 | 50,000,000 | ||||||||||||
| Interest rate (in hundredths) | 4.65% | |||||||||||||
| Year Due | 2035 | |||||||||||||
|
Kansas City Power and Light Company [Member] | General Mortgage Bonds [Member] | General Mortgage bonds Series 2007A-1 due 2035 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 0 | [4] | 63,300,000 | |||||||||||
| Year Due | 2035 | |||||||||||||
| Bonds purchased in lieu of redemption | 63,300,000 | |||||||||||||
|
Kansas City Power and Light Company [Member] | General Mortgage Bonds [Member] | General Mortgage bonds EIRR series 2007A-2 due 2035 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 0 | [4] | 10,000,000 | |||||||||||
| Year Due | 2035 | |||||||||||||
| Bonds purchased in lieu of redemption | 10,000,000 | |||||||||||||
|
Kansas City Power and Light Company [Member] | General Mortgage Bonds [Member] | General Mortgage bonds EIRR series 2007B due 2035 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 73,200,000 | 73,200,000 | ||||||||||||
| Interest rate (in hundredths) | 5.375% | |||||||||||||
| Year Due | 2035 | |||||||||||||
|
Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior notes due 2011 KCPL [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 150,000,000 | 150,000,000 | ||||||||||||
| Interest rate (in hundredths) | 6.50% | |||||||||||||
| Year Due | 2011 | |||||||||||||
|
Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior notes due 2017 KCPL [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 250,000,000 | 250,000,000 | ||||||||||||
| Interest rate (in hundredths) | 5.85% | |||||||||||||
| Year Due | 2017 | |||||||||||||
| Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths) | 5.72% | [3] | ||||||||||||
|
Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior notes due 2018 KCPL [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 350,000,000 | 350,000,000 | ||||||||||||
| Interest rate (in hundredths) | 6.375% | |||||||||||||
| Year Due | 2018 | |||||||||||||
| Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths) | 7.49% | [3] | ||||||||||||
|
Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior notes due 2035 KCPL [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 250,000,000 | 250,000,000 | ||||||||||||
| Interest rate (in hundredths) | 6.05% | |||||||||||||
| Year Due | 2035 | |||||||||||||
| Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths) | 5.78% | [3] | ||||||||||||
|
Kansas City Power and Light Company [Member] | Environmental Improvement Revenue Refunding Bonds [Member] | EIRR bonds due 2038 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 23,400,000 | 23,400,000 | ||||||||||||
| Interest rate (in hundredths) | 4.90% | |||||||||||||
| Year Due | 2038 | |||||||||||||
|
Kansas City Power and Light Company [Member] | Other Long-Term Debt [Member] | Other due 2011-2018 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Debt Instrument Maturity Date Range Start | 2011 | |||||||||||||
| Debt Instrument Maturity Date Range End | 2018 | |||||||||||||
| Principal outstanding | 3,300,000 | 3,300,000 | ||||||||||||
|
Other Great Plains Energy [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Current maturities | (288,600,000) | (335,400,000) | ||||||||||||
| Unamortized discount | (800,000) | (500,000) | ||||||||||||
|
Other Great Plains Energy [Member] | GMO First Mortgage Bonds [Member] | First mortgage bonds due 2011-2021 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Debt Instrument Maturity Date Range Start | 2012 | |||||||||||||
| Debt Instrument Maturity Date Range End | 2021 | |||||||||||||
| Principal outstanding | 11,200,000 | 12,400,000 | ||||||||||||
| Interest rate (in hundredths) | 9.44% | |||||||||||||
|
Other Great Plains Energy [Member] | GMO Pollution Control Bonds [Member] | Pollution control bonds SJLP due 2013 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 5,600,000 | 5,600,000 | ||||||||||||
| Interest rate (in hundredths) | 5.85% | |||||||||||||
| Year Due | 2013 | |||||||||||||
|
Other Great Plains Energy [Member] | GMO Pollution Control Bonds [Member] | Pollution control bonds Wamego Series 1996 due 2026 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 7,300,000 | 7,300,000 | ||||||||||||
| Year Due | 2026 | |||||||||||||
| Variable rate (in hundredths) | 0.157% | [5] | ||||||||||||
|
Other Great Plains Energy [Member] | GMO Pollution Control Bonds [Member] | Pollution control bonds state environmental 1993 due 2028 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 5,000,000 | 5,000,000 | ||||||||||||
| Year Due | 2028 | |||||||||||||
| Variable rate (in hundredths) | 0.373% | [5] | ||||||||||||
|
Other Great Plains Energy [Member] | GMO Senior Notes [Member] | Senior notes 7.95 percent series due 2011 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 0 | 137,300,000 | ||||||||||||
| Interest rate (in hundredths) | 7.95% | |||||||||||||
|
Other Great Plains Energy [Member] | GMO Senior Notes [Member] | Senior notes 7.75 percent series due 2011 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 0 | 197,000,000 | ||||||||||||
| Interest rate (in hundredths) | 7.75% | |||||||||||||
|
Other Great Plains Energy [Member] | GMO Senior Notes [Member] | Senior notes 11.875 percent series due 2012 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 500,000,000 | 500,000,000 | ||||||||||||
| Interest rate (in hundredths) | 11.875% | |||||||||||||
| Year Due | 2012 | |||||||||||||
|
Other Great Plains Energy [Member] | GMO Senior Notes [Member] | Senior notes 8.27 percent series due 2021 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 80,900,000 | 80,900,000 | ||||||||||||
| Interest rate (in hundredths) | 8.27% | |||||||||||||
| Year Due | 2021 | |||||||||||||
|
Other Great Plains Energy [Member] | GMO Senior Notes [Member] | Fair value adjustment [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Fair value adjustment | 32,000,000 | 49,900,000 | ||||||||||||
|
Other Great Plains Energy [Member] | Great Plains Energy Senior Notes [Member] | Senior notes due 2013 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 250,000,000 | 250,000,000 | ||||||||||||
| Interest rate (in hundredths) | 2.75% | |||||||||||||
| Year Due | 2013 | |||||||||||||
| Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths) | 3.67% | [3] | ||||||||||||
|
Other Great Plains Energy [Member] | Great Plains Energy Senior Notes [Member] | Senior notes due 2017 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 100,000,000 | 100,000,000 | ||||||||||||
| Interest rate (in hundredths) | 6.875% | |||||||||||||
| Year Due | 2017 | |||||||||||||
| Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths) | 7.33% | [3] | ||||||||||||
|
Other Great Plains Energy [Member] | Great Plains Energy Senior Notes [Member] | Equity Units subordinated notes due 2042 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 287,500,000 | 287,500,000 | ||||||||||||
| Interest rate (in hundredths) | 10.00% | |||||||||||||
| Year Due | 2012 | |||||||||||||
|
Other Great Plains Energy [Member] | Great Plains Energy Senior Notes [Member] | Senior Notes Due2021 Member [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 350,000,000 | 0 | ||||||||||||
| Interest rate (in hundredths) | 4.85% | |||||||||||||
| Year Due | 2021 | |||||||||||||
| Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths) | 7.34% | [3] | ||||||||||||
|
Other Great Plains Energy [Member] | GMO Medium Term Notes [Member] | Medium term notes notes 7.16 percent series due 2013 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 6,000,000 | 6,000,000 | ||||||||||||
| Interest rate (in hundredths) | 7.16% | |||||||||||||
| Year Due | 2013 | |||||||||||||
|
Other Great Plains Energy [Member] | GMO Medium Term Notes [Member] | Medium term notes notes 7.33 percent series due 2023 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 3,000,000 | 3,000,000 | ||||||||||||
| Interest rate (in hundredths) | 7.33% | |||||||||||||
| Year Due | 2023 | |||||||||||||
|
Other Great Plains Energy [Member] | GMO Medium Term Notes [Member] | Medium term notes notes 7.17 percent series due 2023 [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Principal outstanding | 7,000,000 | 7,000,000 | ||||||||||||
| Interest rate (in hundredths) | 7.17% | |||||||||||||
| Year Due | 2023 | |||||||||||||
|
Great Plains Energy Incorporated [Member]
|
||||||||||||||
| Long-term debt [line items] | ||||||||||||||
| Current maturities | (451,300,000) | (485,700,000) | ||||||||||||
| Long-term debt excluding current maturities | $ 2,860,800,000 | $ 2,942,700,000 | ||||||||||||
|
||||||||||||||
| X | ||||||||||
|
- Definition
Environmental Improvement Revenue Refunding bonds that were purchased rather than remarketed given the poor conditions in the tax-exempt market. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the unamortized portion of the adjustment to record GMOs debt related to Senior Notes that were not reflected in retail rates as of the acquisition date. No definition available.
|
| X | ||||||||||
|
- Definition
Reflects the calculation as of the balance-sheet date of the average interest rate weighted by the amount of long-term debt outstanding by type or by instrument at that time. No definition available.
|
| X | ||||||||||
|
- Definition
Including current and noncurrent portions, aggregate carrying amount of long-term borrowings as of the balance sheet date before deducting unamortized discount or premiums (if any). May include notes payable, bonds payable, commercial loans, mortgage loans, convertible debt, subordinated debt and other types of debt, which had initial maturities beyond one year or beyond the normal operating cycle, if longer. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Estimated fair value of the debt instrument at the balance-sheet date. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The effective interest rate at the end of the reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Interest rate stated in the contractual debt agreement. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Description of the maturity date of the debt instrument including whether the debt matures serially and, if so, a brief description of the serial maturities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
When presenting a range of maturity dates, the latest date when the outstanding debt instruments are required to be repaid. May be presented in a variety of ways (for example: year only, month and year, day, month and year, and number of years). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
When presenting a range of maturity dates, the earliest date when the outstanding debt instruments are required to be repaid. May be presented in a variety of ways (for example: year only, month and year, day, month and year, and number of years). 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
Total of the portions of the carrying amounts as of the balance sheet date of long-term debt, which may include notes payable, bonds payable, debentures, mortgage loans, and commercial paper, which are scheduled to be repaid within one year or the normal operating cycle, if longer, and after deducting unamortized discount or premiums, if any. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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 (current maturities) or the normal operating cycle, if longer, and after deducting unamortized discount or premiums, if any. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The portion of the carrying amount of long-term borrowings outstanding as of the balance-sheet date, including current maturities, which accrues interest at a rate subject to change from time to time. No definition available.
|
|
COMMITMENTS AND CONTINGENCIES (Details) (USD $)
|
6 Months Ended | 12 Months Ended |
|---|---|---|
|
Jun. 30, 2011
|
Dec. 31, 2010
|
|
| Air and climate change [Abstract] | ||
| Current estimate of capital expenditures | $ 1,000,000,000 | |
| Clean Air Interstate Rule (CAIR) and Cross-State Air Pollution Rule (CSAPR) [Abstract] | ||
| States required to reduce emissions for of SO2 and NOX under the CAIR (in number of states) | 28 | |
| Mercury and Other Hazardous Air Pollutant Emissions [Abstract] | ||
| Capacity of electric steam generating units that fall under MACT standards (in megawatts) | 25 | |
| Climate Change [Abstract] | ||
| CO2 produced per year (in millions of tons) | 23 | |
| Collaboration Agreement with the Sierra Club and the Concerned Citizens of Platte County [Abstract] | ||
| Midwestern states whose governors signed the Midwestern Greenhouse Gas Reduction Accord (in number of states) | 6 | |
| Initial Midwestern Greenhouse Gas Reduction Accord minimum percentage reduction goal below 2005 levels by 2020 (in hundredths) | 15.00% | |
| Initial Midwestern Greenhouse Gas Reduction Accord maximum percentage reduction goal below2005 levels by 2020 (in hundredths) | 20.00% | |
| Long-range Midwestern Greenhouse Gas Reduction Accord minimum percentage reduction goal below 2005 levels by 2050 (in hundredths) | 60.00% | |
| Long-range Midwestern Greenhouse Gas Reduction Accord maximum percentage reduction goal below 2005 levels by 2050 (in hundredths) | 80.00% | |
| Ozone National Ambient Air Quality Standard (NAAQS) [Abstract] | ||
| Primary eight-hour ozone standard, as revised March 2008 (in parts per million) | 0.075 | |
| Secondary eight-hour ozone standard, as revised March 2008 (in parts per million) | 0.075 | |
| Primary and secondary eight-hour ozone standard, prior to March 2008 (in parts per million) | 0.084 | |
| Minimum primary eight-hour ozone standard, proposed in January 2010 (in parts per million) | 0.060 | |
| Maximum primary eight-hour ozone standard, proposed in January 2010 (in parts per million) | 0.070 | |
| Minimum cumulative, seasonal secondary ozone standard, as proposed in January 2010 (in parts per million) | 7 | |
| Maximum cumulative, seasonal secondary ozone standard, as proposed in January 2010 (in parts per million) | 15 | |
| SO2 National Ambient Air Quality Standard (NAAQS) [Abstract] | ||
| Primary one-hour sulfur dioxide standard, as revised June 2010 (in parts per million) | 0.075 | |
| Primary twenty-four hour sulfur dioxide standard, prior to June 2010 (in parts per million) | 0.140 | |
| Primary one-year sulfur dioxide standard, prior to June 2010 (in parts per million) | 0.030 | |
| Remediation [Abstract] | ||
| Accrued environmental remediation expenses | 400,000 | 400,000 |
| Amount accrued for future investigation remediation and of GMO retained liabilities | 2,100,000 | 2,100,000 |
| The level for excluded PCB products (parts per million) | 50 | |
|
Jeffrey Units Nos 1 and 2 [Member]
|
||
| New Source Review [Abstract] | ||
| Coal fired units at Jeffrey Energy Center, a jointly owned facility (in number of coal fired facilities) | 3 | |
|
LaCygne Station [Member]
|
||
| Collaboration Agreement with the Sierra Club and the Concerned Citizens of Platte County [Abstract] | ||
| Predetermination request for environmental equipment required at LaCygne Station to comply with BART | 1,230,000,000 | |
|
Kansas City Power and Light Company [Member]
|
||
| Clean Air Interstate Rule (CAIR) and Cross-State Air Pollution Rule (CSAPR) [Abstract] | ||
| Sulfur dioxide emissions supported by accumulated unused emission allowances (in tons) | 150,000 | |
| Climate Change [Abstract] | ||
| CO2 produced per year (in millions of tons) | 17 | |
| Greenhouse gas, on a CO2 equivalent basis, emissions that prompt need for control technology (in tons per year) | 75,000 | |
| Minimum greenhouse gas emissions by stationary sources to qualify for regulation (in tons per year) | 100,000 | |
| Minimum additional greenhouse gas emissions by stationary sources after a modification (in tons per year) | 75,000 | |
| Minimum required renewable energy generation capacity percentage in Kansas by 2011 | 10.00% | |
| Minimum required renewable energy generation capacity percentage in Kansas by 2016 | 15.00% | |
| Minimum required renewable energy generation capacity percentage in Kansas by 2020 | 20.00% | |
| Minimum required renewable energy generation capacity percentage in Missouri by 2011 | 2.00% | |
| Minimum required renewable energy generation capacity percentage in Missouri by 2014 | 5.00% | |
| Minimum required renewable energy generation capacity percentage in Missouri by 2018 | 10.00% | |
| Minimum required renewable energy generation capacity percentage in Missouri by 2021 | 15.00% | |
| Estimated electricity required to come from solar resources by 2011 (in megawatts) | 2 | |
| Collaboration Agreement with the Sierra Club and the Concerned Citizens of Platte County [Abstract] | ||
| Additional CO2 agreed to be offset (in tons) | 711,000 | |
| Wind generation capacity installed at Spearville wind site in 2006 (in megawatts) | 100 | |
| Increased wind generation capacity agreed to pursue in Collaboration Agreement by 2012 - Total (in megawatts) | 500 | |
| Wind project completed in 2010 (in megawatts) | 48 | |
| Renewable energy credits secured (in megawatts) | 52 | |
| Power purchase agreement (in years) | 20 | |
| Power purchase agreement (in megawatts) | 131 | |
| Remediation [Abstract] | ||
| Accrued environmental remediation expenses | 300,000 | 300,000 |
|
Kansas City Power and Light Company [Member] | LaCygne Station [Member]
|
||
| Best Available Retrofit Technology Rule (BART) [Abstract] | ||
| Entity's ownership percentage in facility (in hundredths) | 50.00% | |
| Collaboration Agreement with the Sierra Club and the Concerned Citizens of Platte County [Abstract] | ||
| Predetermination request for environmental equipment required at LaCygne Station to comply with BART | 615,000,000 | |
|
KCPL Greater Missouri Operations Company [Member]
|
||
| Clean Air Interstate Rule (CAIR) and Cross-State Air Pollution Rule (CSAPR) [Abstract] | ||
| Sulfur dioxide emissions supported by accumulated unused emission allowances (in tons) | 13,000 | |
| Climate Change [Abstract] | ||
| Minimum required renewable energy generation capacity percentage in Missouri by 2011 | 2.00% | |
| Minimum required renewable energy generation capacity percentage in Missouri by 2014 | 5.00% | |
| Minimum required renewable energy generation capacity percentage in Missouri by 2018 | 10.00% | |
| Minimum required renewable energy generation capacity percentage in Missouri by 2021 | 15.00% | |
| Estimated electricity required to come from solar resources by 2011 (in megawatts) | 2 | |
| Remediation [Abstract] | ||
| Estimated amount of insurance proceeds available to cover qualified remediation expenses | 2,300,000 | |
|
KCPL Greater Missouri Operations Company [Member] | Iatan No 1 [Member]
|
||
| Best Available Retrofit Technology Rule (BART) [Abstract] | ||
| Entity's ownership percentage in facility (in hundredths) | 18.00% | |
|
KCPL Greater Missouri Operations Company [Member] | Jeffrey Units Nos 1 and 2 [Member]
|
||
| Best Available Retrofit Technology Rule (BART) [Abstract] | ||
| Entity's ownership percentage in facility (in hundredths) | 8.00% | |
|
Westar Energy Inc [Member]
|
||
| New Source Review [Abstract] | ||
| Amount of civil penalty settlement payment | 3,000,000 | |
| Estimated cost to install a selective catalytic reduction system at Jeffrey Energy Center pursuant to a settlement agreement | $ 240,000,000 | |
|
Westar Energy Inc [Member] | Jeffrey Units Nos 1 and 2 [Member]
|
||
| Best Available Retrofit Technology Rule (BART) [Abstract] | ||
| Entity's ownership percentage in facility (in hundredths) | 92.00% |
| X | ||||||||||
|
- Definition
Total costs accrued as of the balance sheet date for the future investigation and remediation of certain additional GMO identified MGP sites, PCB sites and retained liabilities. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the additional tons of CO2 that KCPL agreed to offset by the end of 2012 pursuant to the 2007 Collaboration Agreement. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the total amount of increased wind generation capacity KCPL agreed to pursue in the 2007 Collaboration Agreement by the end of 2012. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Represents the amount of civil penalty paid to settle the Justice Department's allegations of Clean Air Act violations at Jeffrey Energy Center. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
New MACT rules will apply to all new or existing coal-fired electric generating units with a capacity equal to or greater than this amount. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Represents the estimated cost to install a selective catalytic reduction system at Jeffrey Energy Center pursuant to a settlement agreement related to Westar Energy, Incorporated's alleged Clean Air Act violations. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the current estimate of capital expenditures (exclusive of AFUDC and property taxes) required to comply with the currently effective Clean Air Interstate Rule CAIR, the replacement to CAIR or the Cross-State Air Pollution Rule, and with the best available retrofit technology rule, the SO2 national ambient air quality standard, the industrial boiler rule and proposed maximum achievable control technology standards for mercury and other hazardous air pollutant emissions. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the estimated amount of insurance proceeds available, less an annual deductible, to GMO cover qualified MGP remediation expenses. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the company-specific estimated megawatts of electricity required to be provided by KCPL and GMO to their Missouri retail customers from solar resources by 2011, pursuant to a law passed in 2008. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the estimated number of tons of CO2 produced each year based on current generation capacity. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the initial Midwestern Greenhouse Gas Reduction Accord minimum percentage reduction goal of greenhouse gas emissions below 2005 levels by 2020. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the initial Midwestern Greenhouse Gas Reduction Accord minimum percentage reduction goal of greenhouse gas emissions below 2005 levels by 2020. No definition available.
|
| X | ||||||||||
|
- Definition
The length of a purchase power agreement entered into. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the maximum cumulative ozone level in parts per million during seasonal hours, as proposed in January 2010 by the Environmental Protection Agency to protect sensitive vegetation and ecosystems. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the Environmental Protection Agency's maximum primary eight-hour ozone standard in parts per million, as proposed in January 2010. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Represents the minimum increase as a result of a modification to a major stationary emissions source, in tons per year, of GHG emissions required to be eligible for permitting U.S. Environmental Protection Agency regulations effective July 1, 2011. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the minimum cumulative ozone level in parts per million during seasonal hours, as proposed in January 2010 by the Environmental Protection Agency to protect sensitive vegetation and ecosystems. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the minimum level, in tons per year, of GHG emissions required to be eligible for permitting per U.S. Environmental Protection Agency regulations effective July 1, 2011. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the minimum level, in tons per year, of GHG emissions required to be eligible for permitting per U.S. Environmental Protection Agency regulations effective January 1, 2011. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the Environmental Protection Agency's minimum primary eight-hour ozone standard in parts per million, as proposed in January 2010. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the renewable energy generation capacity based on a three-year average of Kansas peak retail demand required to be in place by 2020. This law was passed in 2009 and applies to all Kansas public electric utilities, including KCPL. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the renewable energy generation capacity based on a three-year average of Kansas peak retail demand required to be in place by 2016. This law was passed in 2009 and applies to all Kansas public electric utilities, including KCPL. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the renewable energy generation capacity based on a three-year average of Kansas peak retail demand required to be in place by 2011. This law was passed in 2009 and applies to all Kansas public electric utilities, including KCPL. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the percentage of electricity provided by Missouri investor-owned utilities (including KCPL and GMO) to their Missouri retail customers required to come from renewable resources by 2014, pursuant to a law passed in 2008. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the percentage of electricity provided by Missouri investor-owned utilities (including KCPL and GMO) to their Missouri retail customers required to come from renewable resources by 2018, pursuant to a law passed in 2008. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the percentage of electricity provided by Missouri investor-owned utilities (including KCPL and GMO) to their Missouri retail customers required to come from renewable resources by 2021, pursuant to a law passed in 2008. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the percentage of electricity provided by Missouri investor-owned utilities (including KCPL and GMO) to their Missouri retail customers required to come from renewable resources by 2011, pursuant to a law passed in 2008. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Represents the number of coal fired units located at Jeffrey Energy Center. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the megawatts of wind generation capacity installed at the Spearville wind site by KCPL in 2006. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the number of Midwestern states, including Kansas, whose governors signed the Midwestern Greenhouse Gas Reduction Accord, which established the goal of reducing member states' greenhouse gas emission levels to predefined levels by certain dates. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the number of states required to reduce emissions of SO2 and NOX under the CAIR, including Missouri. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the tons of sulfur dioxide emissions that will be covered by unused emission allowances accumulated by the entities. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Represents the parts per million level used for excluded PCB products currently being reassessed by the Environmental Protection Agency. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of the predetermination request in Kansas for environmental equipment required at LaCygne Station to comply with BART. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the Environmental Protection Agency's primary and secondary eight-hour ozone standards in parts per million, prior to March 2008. No definition available.
|
| X | ||||||||||
|
- Definition
Amount of megawatts secured under power purchase agreement No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Renewable energy credits secured. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the Environmental Protection Agency's primary eight-hour ozone standard in parts per million, as revised in March 2008. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the Environmental Protection Agency's secondary eight-hour ozone standard in parts per million, as revised in March 2008. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the primary one-hour sulfur dioxide standard as revised by the Environmental Protection Agency in June 2010 to replace the exisiting 24-hour and one-year standards. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the primary twenty-four hour sulfur dioxide standard revoked by the Environmental Protection Agency in June 2010. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the primary one-year sulfur dioxide standard revoked by the Environmental Protection Agency in June 2010. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the long-range Midwestern Greenhouse Gas Reduction Accord minimum percentage reduction goal of greenhouse gas emissions below 2005 levels by 2050. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the long-range Midwestern Greenhouse Gas Reduction Accord minimum percentage reduction goal of greenhouse gas emissions below 2005 levels by 2050. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
KCPL completed a wind project in 2010 adjacent to its existing Spearville wind site. No definition available.
|
| X | ||||||||||
|
- Definition
Total costs accrued as of the balance sheet date for environmental loss contingencies. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The proportionate share of interest (percent) in a jointly owned utility plant. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
LEGAL PROCEEDINGS (Details) (Pending or Threatened Litigation [Member], USD $)
In Millions, unless otherwise specified |
Jun. 30, 2011
|
|---|---|
|
Kansas City Power and Light Company [Member] | Spent Nuclear Fuel and Radioactive Waste [Member]
|
|
| Loss Contingencies [Line Items] | |
| Amount of pending claims against the United States in the U.S. Court | $ 14.1 |
| Amount awarded but subject to appeal | 5.0 |
|
KCPL Greater Missouri Operations Company [Member] | Price Reporting Litigation [Member]
|
|
| Loss Contingencies [Line Items] | |
| Approximate amount of refunds received as a net purchaser of power through settlements with sellers of power | 8.0 |
| Estimated additional refunds entitled to receive | 12.0 |
| Amount of claims addressed under refund proceedings | 5.1 |
|
Total Wolf Creek including KCPL [Member] | Spent Nuclear Fuel and Radioactive Waste [Member]
|
|
| Loss Contingencies [Line Items] | |
| Amount awarded but subject to appeal | $ 10.6 |
| X | ||||||||||
|
- Definition
Pertains to the amount awarded to Kansas City Power and Light Company by the U.S. Court of Federal for damages from the government's failure to begin accepting spent nuclear fuel for disposal as required by the Nuclear Waste Policy Act of 1982. All amounts are subject to appeal. No definition available.
|
| X | ||||||||||
|
- Definition
Claims against MPS Merchant Services, Inc. for the period between December 25, 2000 and June 20, 2001 related to the potential impact of California market issues on buyers in the Pacific Northwest. No definition available.
|
| X | ||||||||||
|
- Definition
Pertains to the amount of pending claims filed by Kansas City Power and Light Company against the United States in the U.S. Court of Federal for damages from government's failure to begin accepting spent nuclear fuel for disposal as required by the Nuclear Waste Policy Act of 1982. No definition available.
|
| X | ||||||||||
|
- Definition
The approximate amount of refunds received by MPS Merchant Services, Inc., a wholly owned subsidiary of KCPL Greater Missouri Operations Company, for net purchases of power in the California energy markets between October 2, 2000 through June 20, 2001. No definition available.
|
| X | ||||||||||
|
- Definition
The approximate amount of additional refunds MPS Merchant Services, Inc. estimates it is entitled to for net purchases of power in the California energy markets between October 2, 2000 through June 20, 2001. No definition available.
|
| X | ||||||||||
|
- Details
|
|
RELATED PARTY TRANSACTIONS AND RELATIONSHIPS (Details) (USD $)
In Millions, unless otherwise specified |
3 Months Ended | 6 Months Ended | ||||||||
|---|---|---|---|---|---|---|---|---|---|---|
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Jun. 30, 2011
Kansas City Power and Light Company [Member]
KCPL Greater Missouri Operations Company [Member]
|
Dec. 31, 2010
Kansas City Power and Light Company [Member]
KCPL Greater Missouri Operations Company [Member]
|
Jun. 30, 2011
Kansas City Power and Light Company [Member]
Great Plains Energy Incorporated [Member]
|
Dec. 31, 2010
Kansas City Power and Light Company [Member]
Great Plains Energy Incorporated [Member]
|
Jun. 30, 2011
Kansas City Power and Light Company [Member]
MPS Merchant Services, Inc. [Member]
|
Dec. 31, 2010
Kansas City Power and Light Company [Member]
MPS Merchant Services, Inc. [Member]
|
|
| Notes to Financial Statements [Abstract] | ||||||||||
| KCPL employees to manage GMO's business and operate its facilities at cost | $ 27.7 | $ 20.1 | $ 57.2 | $ 47.2 | ||||||
| Kansas City Power and Light Company's related party receivables and payables [Line Items] | ||||||||||
| Receivable from related party | $ 6.0 | $ 29.6 | $ 14.7 | $ 13.3 | $ 9.6 | $ 0.3 | ||||
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
Amount of transactions with related party during the financial reporting period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
|
DERIVATIVE INSTRUMENTS (Details) (USD $)
In Millions, unless otherwise specified |
6 Months Ended | 12 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | 6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
|
Jun. 30, 2011
|
Dec. 31, 2013
|
Dec. 31, 2012
|
Dec. 31, 2011
|
Jun. 30, 2011
Commodity contract derivatives not designated as hedging instruments [Member]
|
Jun. 30, 2010
Commodity contract derivatives not designated as hedging instruments [Member]
|
Jun. 30, 2011
Commodity contract derivatives not designated as hedging instruments [Member]
|
Jun. 30, 2010
Commodity contract derivatives not designated as hedging instruments [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Income Tax Benefit Expense [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Income Tax Benefit Expense [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Income Tax Benefit Expense [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Income Tax Benefit Expense [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Interest Rate Contract [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Interest Rate Contract [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Interest Rate Contract [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Interest Rate Contract [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Interest Rate Contract [Member]
Interest charges [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Interest Rate Contract [Member]
Interest charges [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Interest Rate Contract [Member]
Interest charges [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Interest Rate Contract [Member]
Interest charges [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
Fuel [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
Fuel [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
Fuel [Member]
|
Jun. 30, 2010
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
Fuel [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
Derivative Instrument, Current and Noncurrent [Member]
|
Dec. 31, 2010
Kansas City Power & Light Company [Member]
Commodity Contract [Member]
Derivative Instrument, Current and Noncurrent [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Cash flow hedges [Member]
|
Dec. 31, 2010
Kansas City Power & Light Company [Member]
Cash flow hedges [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Cash flow hedges [Member]
Assets, current [Member]
|
Dec. 31, 2010
Kansas City Power & Light Company [Member]
Cash flow hedges [Member]
Assets, current [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Cash flow hedges [Member]
Liabilities, current [Member]
|
Dec. 31, 2010
Kansas City Power & Light Company [Member]
Cash flow hedges [Member]
Liabilities, current [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Cash flow hedges [Member]
Deferred income taxes [Member]
|
Dec. 31, 2010
Kansas City Power & Light Company [Member]
Cash flow hedges [Member]
Deferred income taxes [Member]
|
Jun. 30, 2011
Kansas City Power & Light Company [Member]
Futures contracts [Member]
Cash flow hedges [Member]
|
Dec. 31, 2010
Kansas City Power & Light Company [Member]
Futures contracts [Member]
Cash flow hedges [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Income Tax Benefit Expense [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Income Tax Benefit Expense [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Income Tax Benefit Expense [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Income Tax Benefit Expense [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
Interest charges [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
Interest charges [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
Interest charges [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
Interest charges [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
Fuel [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
Fuel [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
Fuel [Member]
|
Jun. 30, 2010
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
Fuel [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Interest Rate Contract [Member]
Derivative Instrument, Current and Noncurrent [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
Derivative Instrument, Current and Noncurrent [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Commodity Contract [Member]
Derivative Instrument, Current and Noncurrent [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Cash flow hedges [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Cash flow hedges [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Cash flow hedges [Member]
Assets, current [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Cash flow hedges [Member]
Assets, current [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Cash flow hedges [Member]
Liabilities, current [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Cash flow hedges [Member]
Liabilities, current [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Cash flow hedges [Member]
Deferred income taxes [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Cash flow hedges [Member]
Deferred income taxes [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Futures contracts [Member]
Cash flow hedges [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Futures contracts [Member]
Cash flow hedges [Member]
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Futures contracts [Member]
Non-hedging derivatives
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Futures contracts [Member]
Non-hedging derivatives
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Option contracts [Member]
Non-hedging derivatives
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Option contracts [Member]
Non-hedging derivatives
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Forward contracts [Member]
Non-hedging derivatives
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Forward contracts [Member]
Non-hedging derivatives
|
Jun. 30, 2011
Total (Great Plains Energy) [Member]
Anticipated debt issuance [Member]
Forward Starting Swaps [Member]
|
Dec. 31, 2010
Total (Great Plains Energy) [Member]
Anticipated debt issuance [Member]
Forward Starting Swaps [Member]
|
|
| Interest rate risk management [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Amount of long term debt issued | $ 350.0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Number of Forward Starting Swaps settled with debt issued (in number of forward starting swaps) | 6 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Loss recorded in other comprehensive income on Forward Starting Swaps settled with debt issued | 26.1 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Reclassification period for loss recorded in other comprehensive income (years) | 3 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Amount of loss reclassified from other comprehensive income to interest expense | 1.1 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Percentage of projected natural gas usage hedged at KCPL (in hundredths) | 31.00% | 68.00% | 100.00% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Percentage of expected on-peak natural gas and natural gas equivalent purchased power price exposure that is hedged at GMO | 38.00% | 61.00% | 74.00% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Notional Contract Amount | 2.0 | 4.0 | 2.0 | 4.0 | 25.1 | 59.5 | 0.9 | 0.2 | 145.0 | 202.8 | 0 | 350.0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fair Value | (0.1) | 0 | (0.1) | 0 | (0.6) | (2.5) | 0.1 | 0 | 10.0 | 8.9 | 0 | (20.8) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Asset, Fair Value [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Asset Designated as Hedging Instrument, Fair Value | 0 | 0.1 | 0 | 0.1 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Asset Not Designated as Hedging Instrument, Fair Value | 0 | 10.1 | 9.4 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Asset, Fair Value, Total | 10.1 | 10.1 | 9.5 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Liability, Fair Value [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Liability Designated as Hedging Instrument, Fair Value | 0.1 | 0.1 | 0.1 | 0.1 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Liability Not Designated as Hedging Instrument, Fair Value | 20.8 | 0.6 | 3.0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Liability, Fair Value, Total | 0.7 | 0.7 | 23.9 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative Instruments, Gain (Loss) [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Gain(Loss) Reclassified from Accumulated OCI into Income (Effective Portion) | (1.4) | (1.4) | (2.7) | (2.7) | 0.8 | 0.8 | 1.7 | 1.7 | (2.2) | (2.2) | (4.4) | (4.4) | 0 | 0 | 0 | 0 | (2.5) | (1.4) | (4.2) | (2.8) | 1.4 | 0.9 | 2.6 | 1.8 | (3.9) | (2.3) | (6.8) | (4.6) | 0 | 0 | 0 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion) | (0.1) | (0.2) | (0.1) | (0.4) | 0 | 0 | 0 | 0.2 | 0 | 0 | 0 | 0 | (0.1) | (0.2) | (0.1) | (0.6) | (3.7) | (8.8) | (3.3) | (13.5) | 2.2 | 5.5 | 2.1 | 8.6 | (5.8) | (14.1) | (5.3) | (21.5) | (0.1) | (0.2) | (0.1) | (0.6) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Gain(Loss) Reclassified from Regulatory Account into Income (Effective Portion) | (1.0) | (2.1) | (2.9) | (4.3) | (1.0) | (2.1) | (2.9) | (4.3) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Amount of Gain (Loss) Recognized on Regulatory Account on Derivatives (Effective Portion) | (1.0) | 0.4 | (1.3) | (5.9) | (1.0) | 0.4 | (1.3) | (5.9) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivatives included in accumulated other comprehensive income recorded value [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Recorded amount included in accumulated other comprehensive income | (33.8) | (36.4) | 11.7 | 12.0 | (67.0) | (71.6) | 21.5 | 23.2 | (53.8) | (54.7) | 11.7 | 12.0 | (99.7) | (101.5) | 34.2 | 34.8 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Accumulated other comprehensive income that is expected to be reclassified in the next twelve months | 8.8 | 20.3 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Trading Activity, Gains and Losses, Net [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Gains (losses) reflected in the income statement for changes in fair value of commodity contracts not designated as hedging | $ (0.9) | $ (0.4) | $ 1.0 | $ 1.6 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| X | ||||||||||
|
- Definition
Amount of long-term debt issued that was hedged by Forward Starting Swaps No definition available.
|
| X | ||||||||||
|
- Definition
Represents the cumulative amount of loss on settled Forward Starting Swaps reclassified from other comprehensive income to interest expense No definition available.
|
| X | ||||||||||
|
- Definition
The income statement location of the effective portion of net gain or loss reclassified from regulatory account into income on derivative instruments designated and qualifying as hedging instruments. No definition available.
|
| X | ||||||||||
|
- Definition
The effective portion of gains and losses (net) on derivative instruments designated and qualifying as hedging instruments that was recognized in regulatory account during the current period. No definition available.
|
| X | ||||||||||
|
- Definition
The value recorded in accumulated other comprehensive income. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Loss recorded in other comprehensive income on Forward Starting Swaps settled simultaneously with the issuance of long-term fixed rate debt. No definition available.
|
| X | ||||||||||
|
- Definition
Number of Forward Starting Swaps that settled simultaneously with the issuance of long-term fixed rate debt. No definition available.
|
| X | ||||||||||
|
- Definition
Percentage of expected on-peak natural gas and natural gas equivalent purchased power price exposure that is hedged at GMO No definition available.
|
| X | ||||||||||
|
- Definition
Percentage of projected natural gas usage hedged at KCPL (in hundredths) No definition available.
|
| X | ||||||||||
|
- Definition
Period for losses recorded in other comprehensive income to be reclassified to interest expense. No definition available.
|
| X | ||||||||||
|
- Definition
Total monetary amount specified by the derivative(s). Expressed as an absolute value. No definition available.
|
| X | ||||||||||
|
- Definition
The estimated net amount of existing gains (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
|
| X | ||||||||||
|
- Definition
Fair value of a derivative asset (or nonderivative instrument) that is designated and qualifies as a hedging instrument, presented on a gross basis even when the derivative instrument is subject to master netting arrangements and qualifies for net presentation in the statement of financial position. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Fair value of a derivative asset that is not designated or qualifying as a hedging instrument, presented on a gross basis even when the derivative instrument is subject to master netting arrangements and qualifies for net presentation in the statement of financial position. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The net amount as of the balance sheet date of the fair value of derivative assets and derivative liabilities that in accordance with the entity's accounting policy were not offset against collateral under a master netting arrangement. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Fair value of derivative asset, presented on a gross basis even when the derivative instrument is subject to master netting arrangements and qualifies for net presentation in the statement of financial position. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Fair value of derivative liability, presented on a gross basis even when the derivative instrument is subject to master netting arrangements and qualifies for net presentation in the statement of financial position. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The income statement location of the effective portion of net gain or 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
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Definition
Fair value of a derivative liability (or nonderivative instrument) that is designated and qualifies as a hedging instrument, presented on a gross basis even when the derivative instrument is subject to master netting arrangements and qualifies for net presentation in the statement of financial position. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
Fair value of a derivative liability that is not designated or qualifying as a hedging instrument, presented on a gross basis even when the derivative instrument is subject to master netting arrangements and qualifies for net presentation in the statement of financial position. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The net gain or loss on trading activities (including both derivative and nonderivative instruments) recognized in the statement of financial performance. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
FAIR VALUE MEASUREMENTS (Details) (USD $)
In Millions, unless otherwise specified |
6 Months Ended | 6 Months Ended | 3 Months Ended | 6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
|
Jun. 30, 2010
|
Jun. 30, 2011
|
Dec. 31, 2010
|
Jun. 30, 2011
Estimate of Fair Value, Fair Value Disclosure [Member]
|
Dec. 31, 2010
Estimate of Fair Value, Fair Value Disclosure [Member]
|
Jun. 30, 2011
Fair Value, Netting [Member]
|
Dec. 31, 2010
Fair Value, Netting [Member]
|
Jun. 30, 2011
Fair Value, Inputs, Level 1 [Member]
|
Dec. 31, 2010
Fair Value, Inputs, Level 1 [Member]
|
Jun. 30, 2011
Fair Value, Inputs, Level 2 [Member]
|
Dec. 31, 2010
Fair Value, Inputs, Level 2 [Member]
|
Jun. 30, 2011
Fair Value, Inputs, Level 3 [Member]
|
Dec. 31, 2010
Fair Value, Inputs, Level 3 [Member]
|
Jun. 30, 2010
Kansas City Power and Light Company [Member]
State and local obligations [Member]
|
Jun. 30, 2011
Kansas City Power and Light Company [Member]
Estimate of Fair Value, Fair Value Disclosure [Member]
|
Dec. 31, 2010
Kansas City Power and Light Company [Member]
Estimate of Fair Value, Fair Value Disclosure [Member]
|
Jun. 30, 2011
Kansas City Power and Light Company [Member]
Fair Value, Netting [Member]
|
Dec. 31, 2010
Kansas City Power and Light Company [Member]
Fair Value, Netting [Member]
|
Jun. 30, 2011
Kansas City Power and Light Company [Member]
Fair Value, Inputs, Level 1 [Member]
|
Dec. 31, 2010
Kansas City Power and Light Company [Member]
Fair Value, Inputs, Level 1 [Member]
|
Jun. 30, 2011
Kansas City Power and Light Company [Member]
Fair Value, Inputs, Level 2 [Member]
|
Dec. 31, 2010
Kansas City Power and Light Company [Member]
Fair Value, Inputs, Level 2 [Member]
|
Jun. 30, 2011
Kansas City Power and Light Company [Member]
Fair Value, Inputs, Level 3 [Member]
|
Dec. 31, 2010
Kansas City Power and Light Company [Member]
Fair Value, Inputs, Level 3 [Member]
|
Jun. 30, 2011
Other Great Plains Energy [Member]
Derivative Instruments [Member]
|
Jun. 30, 2010
Other Great Plains Energy [Member]
Derivative Instruments [Member]
|
Jun. 30, 2011
Other Great Plains Energy [Member]
Derivative Instruments [Member]
|
Jun. 30, 2010
Other Great Plains Energy [Member]
Derivative Instruments [Member]
|
Jun. 30, 2011
Other Great Plains Energy [Member]
Estimate of Fair Value, Fair Value Disclosure [Member]
|
Dec. 31, 2010
Other Great Plains Energy [Member]
Estimate of Fair Value, Fair Value Disclosure [Member]
|
Jun. 30, 2011
Other Great Plains Energy [Member]
Fair Value, Netting [Member]
|
Dec. 31, 2010
Other Great Plains Energy [Member]
Fair Value, Netting [Member]
|
Jun. 30, 2011
Other Great Plains Energy [Member]
Fair Value, Inputs, Level 1 [Member]
|
Dec. 31, 2010
Other Great Plains Energy [Member]
Fair Value, Inputs, Level 1 [Member]
|
Jun. 30, 2011
Other Great Plains Energy [Member]
Fair Value, Inputs, Level 2 [Member]
|
Dec. 31, 2010
Other Great Plains Energy [Member]
Fair Value, Inputs, Level 2 [Member]
|
Jun. 30, 2011
Other Great Plains Energy [Member]
Fair Value, Inputs, Level 3 [Member]
|
Dec. 31, 2010
Other Great Plains Energy [Member]
Fair Value, Inputs, Level 3 [Member]
|
|||||||||||||||||||||||||||||||||||||||
| Assets [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative instruments, assets | $ 10.0 | [1] | $ 8.9 | [1] | $ (0.1) | [1],[2] | $ (0.6) | [1],[2] | $ 0.1 | [1] | $ 0.6 | [1] | $ 5.1 | [1] | $ 5.2 | [1] | $ 4.9 | [1] | $ 3.7 | [1] | $ 0 | [1] | $ 0 | [1] | $ 0 | [1],[2] | $ (0.1) | [1],[2] | $ 0 | [1] | $ 0.1 | [1] | $ 0 | [1] | $ 0 | [1] | $ 0 | [1] | $ 0 | [1] | $ 10.0 | [1] | $ 8.9 | [1] | $ (0.1) | [1],[2] | $ (0.5) | [1],[2] | $ 0.1 | [1] | $ 0.5 | [1] | $ 5.1 | [1] | $ 5.2 | [1] | $ 4.9 | [1] | $ 3.7 | [1] | ||||||||||||||||
| Nuclear decommissioning trust [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Equity securities related to nuclear decommissioning trust | 89.4 | [3] | 85.5 | [3] | 0 | [2],[3] | 0 | [2],[3] | 89.4 | [3] | 85.5 | [3] | 0 | [3] | 0 | [3] | 0 | [3] | 0 | [3] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Debt securities related to nuclear decommissioning trust [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.S. Treasury | 11.8 | [3] | 8.9 | [3] | 0 | [2],[3] | 0 | [2],[3] | 11.8 | [3] | 8.9 | [3] | 0 | [3] | 0 | [3] | 0 | [3] | 0 | [3] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.S. Agency | 3.5 | [3] | 4.8 | [3] | 0 | [2],[3] | 0 | [2],[3] | 0 | [3] | 0 | [3] | 3.5 | [3] | 4.8 | [3] | 0 | [3] | 0 | [3] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| State and local obligations | 2.5 | [3] | 2.5 | [3] | 0 | [2],[3] | 0 | [2],[3] | 0 | [3] | 0 | [3] | 2.5 | [3] | 2.5 | [3] | 0 | [3] | 0 | [3] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Corporate bonds | 26.0 | [3] | 23.7 | [3] | 0 | [2],[3] | 0 | [2],[3] | 0 | [3] | 0 | [3] | 26.0 | [3] | 23.7 | [3] | 0 | [3] | 0 | [3] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Foreign governments | 0.7 | [3] | 0.7 | [3] | 0 | [2],[3] | 0 | [2],[3] | 0 | [3] | 0 | [3] | 0.7 | [3] | 0.7 | [3] | 0 | [3] | 0 | [3] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other | 0.6 | [3] | 0.4 | [3] | 0 | [2],[3] | 0 | [2],[3] | 0 | [3] | 0 | [3] | 0.6 | [3] | 0.4 | [3] | 0 | [3] | 0 | [3] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total nuclear decommissioning trust | 134.5 | [3] | 126.5 | [3] | 0 | [2],[3] | 0 | [2],[3] | 101.2 | [3] | 94.4 | [3] | 33.3 | [3] | 32.1 | [3] | 0 | [3] | 0 | [3] | 134.5 | [3] | 126.5 | [3] | 0 | [2],[3] | 0 | [2],[3] | 101.2 | [3] | 94.4 | [3] | 33.3 | [3] | 32.1 | [3] | 0 | [3] | 0 | [3] | ||||||||||||||||||||||||||||||||||||
| SERP rabbi trust [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Equity securities related to SERP rabbi trust | 0.1 | [4] | 0.2 | [4] | 0 | [2],[4] | 0 | [2],[4] | 0.1 | [4] | 0.2 | [4] | 0 | [4] | 0 | [4] | 0 | [4] | 0 | [4] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Debt securities related to SERP rabbi trust | 7.1 | [4] | 7.0 | [4] | 0 | [2],[4] | 0 | [2],[4] | 0 | [4] | 0 | [4] | 7.1 | [4] | 7.0 | [4] | 0 | [4] | 0 | [4] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total SERP rabbi trust | 7.2 | [4] | 7.2 | [4] | 0 | [2],[4] | 0 | [2],[4] | 0.1 | [4] | 0.2 | [4] | 7.1 | [4] | 7.0 | [4] | 0 | [4] | 0 | [4] | 7.2 | [4] | 7.2 | [4] | 0 | [2],[4] | 0 | [2],[4] | 0.1 | [4] | 0.2 | [4] | 7.1 | [4] | 7.0 | [4] | 0 | [4] | 0 | [4] | ||||||||||||||||||||||||||||||||||||
| Total assets | 151.7 | 142.6 | (0.1) | [2] | (0.6) | [2] | 101.4 | 95.2 | 45.5 | 44.3 | 4.9 | 3.7 | 134.5 | 126.5 | 0 | [2] | (0.1) | [2] | 101.2 | 94.5 | 33.3 | 32.1 | 0 | 0 | 17.2 | 16.1 | (0.1) | [2] | (0.5) | [2] | 0.2 | 0.7 | 12.2 | 12.2 | 4.9 | 3.7 | ||||||||||||||||||||||||||||||||||||||||
| Liabilities [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivative instruments, liabilities | 0 | [1] | 20.8 | [1] | (0.7) | [1],[2] | (3.1) | [1],[2] | 0.7 | [1] | 3.1 | [1] | 0 | [1] | 20.8 | [1] | 0 | [1] | 0 | [1] | 0 | [1] | 0 | [1] | (0.1) | [1],[2] | (0.1) | [1],[2] | 0.1 | [1] | 0.1 | [1] | 0 | [1] | 0 | [1] | 0 | [1] | 0 | [1] | 0 | [1] | 20.8 | [1] | (0.6) | [1],[2] | (3.0) | [1],[2] | 0.6 | [1] | 3.0 | [1] | 0 | [1] | 20.8 | [1] | 0 | [1] | 0 | [1] | ||||||||||||||||
| Total liabilities | 0 | 20.8 | (0.7) | [2] | (3.1) | [2] | 0.7 | 3.1 | 0 | 20.8 | 0 | 0 | 0 | [1] | 0 | (0.1) | [1],[2] | (0.1) | [2] | 0.1 | [1] | 0.1 | 0 | [1] | 0 | 0 | [1] | 0 | 0 | 20.8 | (0.6) | [2] | (3.0) | [2] | 0.6 | 3.0 | 0 | 20.8 | 0 | 0 | ||||||||||||||||||||||||||||||||||||
| Cash and cash equivalents from nuclear decommissioning trust excluded from fair value disclosure | 3.7 | 2.7 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash and cash equivalents from SERP rabbi trust excluded from fair value disclosure | 13.9 | 14.6 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash collateral posted with third parties as part of netting agreements | 0.6 | 2.5 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fair value measurement using significant unobservable input (level 3) reconciliation [Roll Forward] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Beginning balance | 4.3 | 0.2 | 5.7 | 5.4 | 3.7 | 4.1 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total realized/unrealized gains or (losses) [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Included in non-operating income | (5.9) | 0 | 2.1 | (3.4) | 7.1 | (5.9) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Purchase, issuances, and settlements | 6.8 | (0.2) | (2.9) | 3.2 | (5.9) | 7.0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Ending balance | 5.2 | 0 | 4.9 | 5.2 | 4.9 | 5.2 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total unrealized gains and (losses) included in non-operating income relating to assets and liabilities still on the consolidated balance sheet | $ 1.3 | $ 0 | $ (0.6) | $ (0.2) | $ 1.5 | $ 1.3 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
This element represents the cash and cash equivalents that are part of the nuclear decommissioning trust that are not subject to the fair value requirements. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the cash and cash equivalents that are part of the SERP rabbi trust that are not subject to the fair value requirements. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the cash collatereal posted with third parties as part of netting agreements. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to corporate bonds debt securites that are part of the nuclear decommissioning trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to debt securites that are part of the SERP rabbi trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to equity securites that are part of the nuclear decommissioning trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to equity securites that are part of the SERP rabbi trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to foreign governments debt securites that are part of the nuclear decommissioning trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to other assets that are part of the nuclear decommissioning trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to state and local obligations debt securites that are part of the nuclear decommissioning trust. No definition available.
|
| X | ||||||||||
|
- Definition
The total fair value of assets measured on recurring basis. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to the nuclear decommissioning trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to the SERP rabbi trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to U.S. agency debt securites that are part of the nuclear decommissioning trust. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents the fair value disclosure of assets measured on a recurring basis that are related to U.S. treasury debt securites that are part of the nuclear decommissioning trust. No definition available.
|
| X | ||||||||||
|
- Definition
The total fair value of liabilities measured on recurring basis. No definition available.
|
| X | ||||||||||
|
- Definition
This element represents purchases, sales, issuances, and settlements (net) which have taken place during the period in relation to assets and liabilities measured at fair value on a recurring basis using unobservable inputs (Level 3). No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
This item represents the amount of the total change in unrealized (holding) gains or losses for the period which are included in the statement of income (or changes in net assets) in other income. Such unrealized (holding) gains or losses relate to those assets still held at the reporting date for which fair value is measured on a recurring basis using significant unobservable inputs (Level 3). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
This element represents a certain statement of financial position asset caption which represents a class of assets, or which may include an individual asset, measured at fair value on a recurring basis. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
This element represents a certain statement of financial position liability caption which represents a class of liabilities, or which may include an individual liability, measured at fair value on a recurring basis. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
This element represents total gains or losses for the period (realized and unrealized), arising from assets measured at fair value on a recurring basis using unobservable inputs (Level 3), which are included in earnings or resulted in a change in net asset value. 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
|
| X | ||||||||||
|
- Details
|
|
TAXES (Details) (USD $)
In Millions, unless otherwise specified |
3 Months Ended | 6 Months Ended | 12 Months Ended | ||
|---|---|---|---|---|---|
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Dec. 31, 2010
|
|
| Investment tax credit [Abstract] | |||||
| Income tax expense (benefit) on continuing operations | $ (19.8) | $ (32.0) | $ (15.2) | $ (41.7) | |
| Income tax expense (benefit), reconciliation [Abstract] | |||||
| Total | (19.8) | (32.0) | (15.2) | (41.7) | |
|
Kansas City Power and Light Company [Member]
|
|||||
| Current income taxes [Abstract] | |||||
| Federal | 1.3 | 21.6 | 2.4 | 37.8 | |
| State | 0.2 | 4.1 | 0.5 | 7.2 | |
| Total | 1.5 | 25.7 | 2.9 | 45.0 | |
| Deferred income taxes [Abstract] | |||||
| Federal | 23.2 | 4.4 | 19.9 | (10.0) | |
| State | 4.7 | (0.5) | 4.5 | (2.2) | |
| Total | 27.9 | 3.9 | 24.4 | (12.2) | |
| Noncurrent income taxes [Abstract] | |||||
| Federal | (11.5) | 0.4 | (10.6) | 0.9 | |
| State | (1.2) | 0.1 | (1.1) | 0.2 | |
| Total | (12.7) | 0.5 | (11.7) | 1.1 | |
| Investment tax credit [Abstract] | |||||
| Deferral | 0 | (8.3) | 0 | (4.1) | |
| Amortization | (0.5) | (0.3) | (0.5) | (0.7) | |
| Total | (0.5) | (8.6) | (0.5) | (4.8) | |
| Total income tax expense (benefit) | 16.2 | 21.5 | 15.1 | 29.1 | |
| Income tax expense (benefit) on continuing operations | 16.2 | 21.5 | 15.1 | 29.1 | |
| Income tax expense (benefit), reconciliation [Abstract] | |||||
| Federal statutory income tax | 17.4 | 24.4 | 18.4 | 33.8 | |
| Differences between book and tax depreciation not normalized | 0.8 | (2.0) | 1.6 | (4.1) | |
| Amortization of investment tax credits | (0.5) | (0.3) | (0.5) | (0.7) | |
| Federal income tax credits | (3.7) | (2.2) | (6.7) | (4.1) | |
| State income taxes | 1.8 | 2.4 | 2.0 | 3.1 | |
| Medicare Part D Subsidy Legislation | 0 | 2.8 | |||
| Changes in uncertain tax positions, net | 0.4 | 0 | 0.4 | 0 | |
| Other | 0 | (0.8) | (0.1) | (1.7) | |
| Total | 16.2 | 21.5 | 15.1 | 29.1 | |
| Income tax rate, reconciliation [Abstract] | |||||
| Federal statutory income tax (in hundredths) | 35.00% | 35.00% | 35.00% | 35.00% | |
| Differences between book and tax depreciation not normalized (in hundredths) | 1.60% | (2.90%) | 3.00% | (4.30%) | |
| Amortization of investment tax credits (in hundredths) | (1.00%) | (0.50%) | (0.90%) | (0.70%) | |
| Federal income tax credits (in hundredths) | (7.60%) | (3.10%) | (12.90%) | (4.30%) | |
| State income taxes (in hundredths) | 3.80% | 3.40% | 3.90% | 3.20% | |
| Medicare Part D Subsidy Legislation (in hundredths) | 0.00% | 2.90% | |||
| Changes in uncertain tax positions, net (in hundredths) | 0.90% | 0.00% | 0.80% | 0.00% | |
| Other (in hundredths) | (0.20%) | (1.10%) | (0.30%) | (1.70%) | |
| Total (in hundredths) | 32.50% | 30.80% | 28.60% | 30.10% | |
| Income Tax Contingency [Line Items] | |||||
| Amount of unrecognized tax benefit liabilities expected to impact the effect tax rate, if recognized. | 0.3 | 0.3 | 0.3 | ||
| Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||||
| Beginning balance | 19.1 | 20.9 | 20.9 | ||
| Additions for current year tax positions | 0 | 1.3 | |||
| Additions for prior year tax positions | 0.6 | 1.5 | |||
| Reductions for prior year tax positons | (12.4) | (1.6) | |||
| Settlements | 0 | (2.9) | |||
| Statute Expirations | 0 | (0.1) | |||
| Foreign currency translation adjustments | 0 | 0 | |||
| Ending balance | 7.3 | 7.3 | 19.1 | ||
| Accrued interest related to unrecognized tax benefits | 0.3 | 0.3 | 1.4 | ||
|
Great Plains Energy Incorporated [Member]
|
|||||
| Current income taxes [Abstract] | |||||
| Federal | 2.7 | (0.1) | 3.8 | (0.9) | |
| State | (4.7) | 1.5 | (4.0) | 2.3 | |
| Foreign | (0.1) | 0.4 | (0.4) | 0.4 | |
| Total | (2.1) | 1.8 | (0.6) | 1.8 | |
| Deferred income taxes [Abstract] | |||||
| Federal | 32.3 | 30.9 | 28.9 | 34.7 | |
| State | 11.4 | 3.3 | 7.4 | 4.2 | |
| Total | 43.7 | 34.2 | 36.3 | 38.9 | |
| Noncurrent income taxes [Abstract] | |||||
| Federal | (19.0) | 4.7 | (18.0) | 5.5 | |
| State | (2.0) | 0.5 | (1.9) | 0.7 | |
| Foreign | (0.1) | (0.3) | 0.2 | 0 | |
| Total | (21.1) | 4.9 | (19.7) | 6.2 | |
| Investment tax credit [Abstract] | |||||
| Deferral | 0 | (8.3) | 0 | (4.1) | |
| Amortization | (0.7) | (0.6) | (0.8) | (1.1) | |
| Total | (0.7) | (8.9) | (0.8) | (5.2) | |
| Total income tax expense (benefit) | 19.8 | 32.0 | 15.2 | 41.7 | |
| Income tax expense (benefit) on continuing operations | 19.8 | 32.0 | 15.2 | 41.7 | |
| Income tax expense (benefit), reconciliation [Abstract] | |||||
| Federal statutory income tax | 22.1 | 33.7 | 21.4 | 44.2 | |
| Differences between book and tax depreciation not normalized | 1.1 | (2.5) | 1.9 | (5.1) | |
| Amortization of investment tax credits | (0.7) | (0.6) | (0.8) | (1.1) | |
| Federal income tax credits | (3.8) | (2.2) | (6.8) | (4.1) | |
| State income taxes | 2.6 | 3.6 | 3.0 | 4.5 | |
| Medicare Part D Subsidy Legislation | 0 | 2.8 | |||
| Changes in uncertain tax positions, net | (1.6) | (0.3) | (1.3) | 0 | |
| Valuation allowance | 0.2 | 0 | (2.2) | 0 | |
| Other | (0.1) | 0.3 | 0 | 0.5 | |
| Total | 19.8 | 32.0 | 15.2 | 41.7 | |
| Income tax rate, reconciliation [Abstract] | |||||
| Federal statutory income tax (in hundredths) | 35.00% | 35.00% | 35.00% | 35.00% | |
| Differences between book and tax depreciation not normalized (in hundredths) | 1.60% | (2.60%) | 3.00% | (4.00%) | |
| Amortization of investment tax credits (in hundredths) | (1.10%) | (0.60%) | (1.40%) | (0.90%) | |
| Federal income tax credits (in hundredths) | (6.00%) | (2.30%) | (11.10%) | (3.30%) | |
| State income taxes (in hundredths) | 4.10% | 3.70% | 4.90% | 3.50% | |
| Medicare Part D Subsidy Legislation (in hundredths) | 0.00% | 2.20% | |||
| Changes in uncertain tax positions, net (in hundredths) | (2.50%) | (0.30%) | (2.20%) | 0.00% | |
| Valuation allowance (in hundredths) | 0.30% | 0.00% | (3.60%) | 0.00% | |
| Other (in hundredths) | 0.00% | 0.40% | 0.40% | 0.50% | |
| Total (in hundredths) | 31.40% | 33.30% | 25.00% | 33.00% | |
| Income Tax Contingency [Line Items] | |||||
| Amount of unrecognized tax benefit liabilities expected to impact the effect tax rate, if recognized. | 15.1 | 15.1 | 17.3 | ||
| Deferred income tax liability impact of audit settlements | 16.4 | ||||
| Net income impact of audit settlements | 2.0 | ||||
| Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||||
| Beginning balance | 42.0 | 51.4 | 51.4 | ||
| Additions for current year tax positions | 0.7 | 2.7 | |||
| Additions for prior year tax positions | 0.6 | 2.1 | |||
| Reductions for prior year tax positons | (18.7) | (10.6) | |||
| Settlements | 0 | (3.8) | |||
| Statute Expirations | 0 | (0.3) | |||
| Foreign currency translation adjustments | 0.3 | 0.5 | |||
| Ending balance | 24.9 | 24.9 | 42.0 | ||
| Accrued interest related to unrecognized tax benefits | 6.0 | 6.0 | 6.7 | ||
| Accrued penalities for unrecognized tax benefits | $ 1.1 | $ 1.1 | $ 1.1 | ||
| X | ||||||||||
|
- Definition
Represents the deferred income tax liability impact of audit settlements No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference between the effective income tax rate and domestic federal statutory income tax rate attributable to changes in uncertain tax positions, net of the valuation allowance on those changes. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference between total income tax expense (benefit) as reported in the Income Statement for the period and the expected income tax expense (benefit) computed by applying the domestic federal statutory income tax rates to pretax income from continuing operations attributable to changes in uncertain tax positions, net of the valuation allowance on those changes. No definition available.
|
| X | ||||||||||
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- Details
|
| X | ||||||||||
|
- Definition
The amount of the deferred portion of the investment tax credit, gross. No definition available.
|
| X | ||||||||||
|
- Definition
The amount of the deferred portion of the investment tax credit, net of current period amortization. No definition available.
|
| X | ||||||||||
|
- Definition
Represents the net income impact of audit settlements No definition available.
|
| X | ||||||||||
|
- Definition
The noncurrent component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted federal tax law to the domestic taxable income (loss) from continuing operations. No definition available.
|
| X | ||||||||||
|
- Definition
The noncurrent component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of foreign enacted tax law to the foreign taxable income (loss) from continuing operations. No definition available.
|
| X | ||||||||||
|
- Definition
The noncurrent component of income tax expense for the period representing amounts of income taxes paid or payable (or refundable) for the period for all income tax obligations as determined by applying the provisions of relevant enacted tax laws to relevant amounts of taxable income (loss) from continuing operations. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The noncurrent component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted state and local tax law to relevant amounts of taxable income (loss) from continuing operations. No definition available.
|
| X | ||||||||||
|
- Definition
The total income tax expense (benefit) for the period, including the amount attributable to discontinued operations. No definition available.
|
| X | ||||||||||
|
- Definition
The gross amount of decreases in unrecognized tax benefits resulting from foreign currency translation adjusments of tax positions. No definition available.
|
| X | ||||||||||
|
- Definition
The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted federal tax law to the domestic taxable income (loss) from continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of foreign enacted tax law to the foreign taxable income (loss) from continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The component of income tax expense for the period representing amounts of income taxes paid or payable (or refundable) for the period for all income tax obligations as determined by applying the provisions of relevant enacted tax laws to relevant amounts of taxable income (loss) from continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted state and local tax law to relevant amounts of taxable income (loss) from continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The component of total income tax expense for the period comprised of the net change during the period in the entity's domestic deferred tax assets and liabilities attributable to continuing operations as determined by applying the provisions of the federally enacted tax law. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The component of income tax expense for the period representing the net change in the entity's deferred tax assets and liabilities pertaining to continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The component of total income tax expense for the period comprised of the net change in the entity's state and local deferred tax assets and liabilities attributable to continuing operations as determined by applying the provisions of the applicable enacted tax laws. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- 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
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The domestic federal statutory tax rate applicable under enacted tax laws to the Company's pretax income from continuing operations for the period. The "statutory" tax rate shall be the regular tax rate if there are alternative tax systems. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The portion of the difference between the effective income tax rate and domestic federal statutory income tax rate attributable to changes in the valuation allowance for deferred tax assets. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference between the effective income tax rate and domestic federal statutory income tax rate attributable to the deduction received under enacted tax laws for Medicare prescription drug benefits. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference between the effective income tax rate and domestic federal statutory income tax rate that can be explained by the different depreciation methods allowed under generally accepted accounting principles and enacted tax laws. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference between the effective income tax rate and domestic federal statutory income tax rate attributable to all other items not otherwise listed in the existing taxonomy. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference between the effective income tax rate and domestic federal statutory income tax rate that can be explained by the state and local income tax expense (benefit), net of the federal tax benefit (expense) thereon, recorded during the period. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference between the effective income tax rate and domestic federal statutory income tax rate that can be explained by investment tax credits generated or utilized under enacted tax laws during the period. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference between the effective income tax rate and domestic federal statutory income tax rate that can be explained by tax credits, not otherwise listed in the existing taxonomy, generated or utilized under enacted tax laws during the period. No definition available.
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The sum of the current income tax expense (benefit) and the deferred income tax expense (benefit) pertaining to continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The portion of the difference between total income tax expense (benefit) as reported in the Income Statement and the expected income tax expense (benefit) computed by applying the domestic federal statutory income tax rates to pretax income from continuing operations attributable to changes in the valuation allowance for deferred tax assets in the period. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The portion of the difference between total income tax expense (benefit) as reported in the Income Statement for the period and the expected income tax expense (benefit) computed by applying the domestic federal statutory income tax rates to pretax income from continuing operations attributable to the subsidy for Medicare prescription drug benefits received tax-free. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The amount of income tax expense (benefit) for the period computed by applying the domestic federal statutory tax rates to pretax income from continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The portion of the difference between total income tax expense (benefit) as reported in the Income Statement for the period and the expected income tax expense (benefit) computed by applying the domestic federal statutory income tax rates to pretax income from continuing operations attributable to the different depreciation methods allowed under generally accepted accounting principles and enacted tax laws. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference, between total income tax expense (benefit) as reported in the Income Statement for the year/accounting period and the expected income tax expense (benefit) computed by applying the domestic federal statutory income tax rates to pretax income from continuing operations, that is attributable to all other items not otherwise listed in the existing taxonomy. No definition available.
|
| X | ||||||||||
|
- Definition
The portion of the difference, between total income tax expense (benefit) as reported in the Income Statement for the period and the expected income tax expense (benefit) computed by applying the domestic federal statutory income tax rates to pretax income from continuing operations, that is attributable to state and local income tax expense (benefit). Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The portion of the difference between total income tax expense (benefit) as reported in the Income Statement and the expected income tax expense (benefit) computed by applying the domestic federal statutory income tax rates to pretax income from continuing operations attributable to other tax credits generated or utilized under enacted tax laws during the period. No definition available.
|
| X | ||||||||||
|
- Definition
The amount deducted from an entities' taxes, reflecting a percentage of an amount invested in certain assets spread over the useful life of those assets; includes deferred investment tax credits. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Details
|
| X | ||||||||||
|
- Definition
The gross amount of unrecognized tax benefits (tax reductions recognized in financial reports but excluded from tax returns) pertaining to uncertain tax positions taken in tax returns as of the beginning balance sheet date, excluding amounts pertaining to examined tax returns. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The gross amount of decreases in unrecognized tax benefits resulting from tax positions taken in prior period tax returns, excluding amounts pertaining to examined tax returns. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The gross amount of decreases in unrecognized tax benefits resulting from settlements with taxing authorities. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
This element represents the amount of statutory penalties accrued as of the date of the statement of financial position for a tax position claimed or expected to be claimed by the entity, in its tax return, that does not meet the minimum statutory threshold to avoid payment of penalties. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The gross amount of increases in unrecognized tax benefits resulting from tax positions that have been or will be taken in the tax return for the current period, excluding amounts pertaining to examined tax returns. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The gross amount of increases in unrecognized tax benefits resulting from tax positions taken in prior period tax returns, excluding amounts pertaining to examined tax returns. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
This element represents the amount of interest expense accrued as of the date of the statement of financial position for an underpayment of income taxes computed by applying the applicable statutory rate of interest to the difference between a tax position recognized for financial reporting purposes and the amount previously taken or expected to be taken in a tax return of the entity. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The gross amount of decreases in unrecognized tax benefits resulting from lapses of the applicable statutes of limitations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
|
SEGMENTS AND RELATED INFORMATION (Details) (USD $)
In Millions, unless otherwise specified |
3 Months Ended | 6 Months Ended | 12 Months Ended | ||||||
|---|---|---|---|---|---|---|---|---|---|
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Jun. 30, 2011
|
Jun. 30, 2010
|
Dec. 31, 2010
|
|||||
| Segment Reporting Information [Line Items] | |||||||||
| Operating revenues | $ 565.1 | $ 552.0 | $ 1,058.0 | $ 1,058.9 | |||||
| Depreciation and amortization | (67.6) | (81.0) | (140.0) | (163.2) | |||||
| Interest charges | (50.3) | (46.7) | (95.2) | (93.2) | |||||
| Income tax (expense) benefit | (19.8) | (32.0) | (15.2) | (41.7) | |||||
| Net income attributable to Great Plains Energy | 43.4 | 64.3 | 45.8 | 84.6 | |||||
| Assets | 8,922.2 | 8,922.2 | 8,818.2 | ||||||
| Capital expenditures | 193.2 | [1] | 618.1 | [1] | |||||
|
Electric Utility [Member]
|
|||||||||
| Segment Reporting Information [Line Items] | |||||||||
| Operating revenues | 565.1 | 552.0 | 1,058.0 | 1,058.9 | |||||
| Depreciation and amortization | (67.6) | (81.0) | (140.0) | (163.2) | |||||
| Interest charges | (40.3) | (36.4) | (74.6) | (72.6) | |||||
| Income tax (expense) benefit | (26.0) | (36.8) | (26.9) | (48.4) | |||||
| Net income attributable to Great Plains Energy | 49.0 | 71.7 | 56.0 | 96.6 | |||||
| Assets | 9,278.5 | 9,278.5 | 9,152.7 | ||||||
| Capital expenditures | 193.2 | [1] | 618.1 | [1] | |||||
|
Other [Member]
|
|||||||||
| Segment Reporting Information [Line Items] | |||||||||
| Operating revenues | 0 | 0 | 0 | 0 | |||||
| Depreciation and amortization | 0 | 0 | 0 | 0 | |||||
| Interest charges | (10.0) | (10.3) | (20.6) | (20.6) | |||||
| Income tax (expense) benefit | 6.2 | 4.8 | 11.7 | 6.7 | |||||
| Net income attributable to Great Plains Energy | (5.6) | (7.4) | (10.2) | (12.0) | |||||
| Assets | 65.2 | 65.2 | 66.3 | ||||||
| Capital expenditures | 0 | [1] | 0 | [1] | |||||
|
Eliminations Member [Member]
|
|||||||||
| Segment Reporting Information [Line Items] | |||||||||
| Assets | (421.5) | (421.5) | (400.8) | ||||||
| Capital expenditures | $ 0 | [1] | $ 0 | [1] | |||||
|
|||||||||
| X | ||||||||||
|
- 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
|
| 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
|
| X | ||||||||||
|
- Definition
The sum of the current income tax expense (benefit) and the deferred income tax expense (benefit) pertaining to continuing operations. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| 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
|
| X | ||||||||||
|
- Definition
The portion of consolidated profit or loss for the period, net of income taxes, which is attributable to the parent. If the entity does not present consolidated financial statements, the amount of profit or loss for the period, net of income taxes. Reference 1: http://www.xbrl.org/2003/role/presentationRef
|
| X | ||||||||||
|
- Definition
Amount of depreciation, depletion, and amortization expense for the reportable segment. Must be disclosed if the amount (a) is included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) is 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
|
| X | ||||||||||
|
- 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. Must be disclosed 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
|
| X | ||||||||||
|
- Details
|