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.

+ References+ Details

Consolidated Statements Of Income (USD $) In Thousands, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
REVENUES	$ 2,261,470	$ 2,170,991	$ 2,056,171
OPERATING EXPENSES:
Fuel and purchased power	589,990	630,793	583,361
Operating and maintenance	612,871	557,752	520,409
Depreciation and amortization	270,464	285,322	271,937
Selling, general and administrative	226,012	184,695	207,607
Total Operating Expenses	1,699,337	1,658,562	1,583,314
INCOME FROM OPERATIONS	562,133	512,429	472,857
OTHER INCOME (EXPENSE):
Investment earnings	7,411	9,301	7,026
Other income	35,378	8,652	5,369
Other expense	(19,987)	(18,398)	(16,655)
Total Other Income (Expense)	22,802	(445)	(4,260)
Interest expense	176,337	172,460	174,941
INCOME BEFORE INCOME TAXES	408,598	339,524	293,656
Income tax expense	126,136	103,344	85,032
NET INCOME	282,462	236,180	208,624
Less: Net income attributable to noncontrolling interests	7,316	5,941	4,728
NET INCOME ATTRIBUTABLE TO WESTAR ENERGY	275,146	230,239	203,896
Preferred dividends	1,616	970	970
NET INCOME ATTRIBUTABLE TO COMMON STOCK	$ 273,530	$ 229,269	$ 202,926
Basic earnings per common share	$ 2.15	$ 1.95	$ 1.81
Diluted earnings per common share	$ 2.15	$ 1.93	$ 1.80
AVERAGE EQUIVALENT COMMON SHARES OUTSTANDING	126,711,869	116,890,552	111,629,292
DIVIDENDS DECLARED PER COMMON SHARE	$ 1.32	$ 1.28	$ 1.24

Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net income	$ 282,462	$ 236,180	$ 208,624
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	270,464	285,322	271,937
Amortization of nuclear fuel	24,369	21,151	25,089
Amortization of deferred regulatory gain from sale-leaseback	(5,495)	(5,495)	(5,495)
Amortization of corporate-owned life insurance	28,792	25,650	20,650
Non-cash compensation	7,255	8,422	11,373
Net changes in energy marketing assets and liabilities	(372)	926	(1,284)
Net deferred income taxes and credits	126,248	111,723	120,169
Stock-based compensation excess tax benefits	(1,698)	(1,180)	(641)
Allowance for equity funds used during construction	(11,706)	(5,550)	(3,104)
Gain on sale of non-utility investment	0	(7,246)	0
Gain on settlement of contractual obligations with former officers	0	(22,039)	0
Changes in working capital items:
Accounts receivable	2,408	(1,638)	(11,434)
Fuel inventory and supplies	(19,227)	(21,485)	(12,266)
Prepaid expenses and other	(3,630)	(50,138)	8,475
Accounts payable	(19,161)	3,008	30,330
Accrued taxes	11,937	18,633	27,565
Other current liabilities	(105,169)	(107,012)	(80,660)
Changes in other assets	13,015	(10,167)	(42,544)
Changes in other liabilities	(1,386)	(16,369)	40,918
Cash Flows from Operating Activities	599,106	462,696	607,702
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Additions to property, plant and equipment	(810,209)	(697,451)	(540,076)
Purchase of securities within trusts	(20,473)	(49,737)	(192,350)
Sale of securities within trusts	21,604	47,534	191,603
Proceeds from Trust	2,022	0	0
Investment in corporate-owned life insurance	(18,404)	(19,214)	(19,162)
Proceeds from investment in corporate-owned life insurance	33,542	1,295	2,204
Proceeds from federal grant	4,775	8,561	3,180
Investment in affiliated company	(8,669)	(1,943)	(280)
Proceeds from sale of non-utility investment	0	9,246	0
Other investing activities	(1,525)	193	(1,164)
Cash Flows used in Investing Activities	(797,337)	(701,516)	(556,045)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Short-term debt, net	52,900	54,081	(16,060)
Proceeds from long-term debt	541,374	0	0
Retirements of long-term debt	(220,563)	(371)	(1,695)
Repayment of capital leases	(2,679)	(2,233)	(2,981)
Borrowings against cash surrender value of corporate-owned life insurance	67,791	67,562	74,134
Repayment of borrowings against cash surrender value of corporate-owned life insurance	(34,838)	(3,421)	(3,430)
Stock-based compensation excess tax benefits	1,698	1,180	641
Preferred stock redemption	(22,567)	0	0
Issuance of common stock	6,996	294,942	54,651
Distributions to shareholders of noncontrolling interests	(3,295)	(1,917)	(2,093)
Cash dividends paid	(158,182)	(138,233)	(129,146)
Cash Flows from (used in) Financing Activities	200,521	241,431	(54,589)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	2,290	2,611	(2,932)
CASH AND CASH EQUIVALENTS:
Beginning of period	3,539	928	3,860
End of period	5,829	3,539	928
Variable Interest Entity [Member]
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Retirements of long-term debt	$ (28,114)	$ (30,159)	$ (28,610)

Consolidated Statements Of Changes In Equity (USD $) In Thousands, except Share data	Total	Cumulative Preferred Stock [Member]	Common Stock [Member]	Paid-In Capital [Member]	Retained Earnings [Member]	Noncontrolling Interests [Member]
Beginning balance at Dec. 31, 2009	$ 2,266,785	$ 21,436	$ 545,360	$ 1,339,790	$ 360,199	$ 0
Beginning balance, shares at Dec. 31, 2009		214,363	109,072,000
Net income	208,624	0	0	0	203,896	4,728
Issuance of stock, value	66,039	0	15,280	50,759	0	0
Issuance of stock, shares		0	3,056,068
Preferred dividends	(970)	0	0	0	(970)	0
Dividends on common stock	(139,478)	0	0	0	(139,478)	0
Transfer to/from temporary equity	(22)	0	0	(22)	0	0
Amortization of restricted stock	10,710	0	0	10,710	0	0
Stock compensation and tax benefit	(2,657)	0	0	(2,657)	0	0
Consolidation of noncontrolling interests	3,435	0	0	0	0	3,435
Distributions to shareholders of noncontrolling interests	(2,093)	0	0	0	0	(2,093)
Ending balance at Dec. 31, 2010	2,410,373	21,436	560,640	1,398,580	423,647	6,070
Ending balance, shares at Dec. 31, 2010		214,363	112,128,068
Net income	236,180	0	0	0	230,239	5,941
Issuance of stock, value	310,933	0	67,852	243,081	0	0
Issuance of stock, shares		0	13,570,328
Preferred dividends	(970)	0	0	0	(970)	0
Dividends on common stock	(151,700)	0	0	0	(151,700)	0
Transfer to/from temporary equity	3,465	0	0	3,465	0	0
Amortization of restricted stock	7,698	0	0	7,698	0	0
Stock compensation and tax benefit	(13,321)	0	0	(13,321)	0	0
Distributions to shareholders of noncontrolling interests	(1,917)	0	0	0	0	(1,917)
Ending balance at Dec. 31, 2011	2,800,741	21,436	628,492	1,639,503	501,216	10,094
Ending balance, shares at Dec. 31, 2011		214,363	125,698,396
Net income	282,462	0	0	0	275,146	7,316
Issuance of stock, value	23,170	0	4,027	19,143	0	0
Issuance of stock, shares		0	805,352
Stock redemption, shares		(214,363)	0
Stock redemption, value	(21,436)	(21,436)	0
Preferred dividends	(1,616)	0	0	0	(1,616)	0
Dividends on common stock	(168,097)	0	0	0	(168,097)	0
Amortization of restricted stock	6,430	0	0	6,430	0	0
Stock compensation and tax benefit	(8,104)	0	0	(8,104)	0	0
Distributions to shareholders of noncontrolling interests	(3,295)	0	0	0	0	(3,295)
Ending balance at Dec. 31, 2012	$ 2,910,255	$ 0	$ 632,519	$ 1,656,972	$ 606,649	$ 14,115
Ending balance, shares at Dec. 31, 2012		0	126,503,748

Description Of Business	12 Months Ended
Description Of Business	Dec. 31, 2012
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Description Of Business	DESCRIPTION OF BUSINESS We are the largest electric utility in Kansas. Unless the context otherwise indicates, all references in this Annual Report on Form 10-K to "the company," "we," "us," "our" and similar words are to Westar Energy, Inc. and its consolidated subsidiaries. The term "Westar Energy" refers to Westar Energy, Inc., a Kansas corporation incorporated in 1924, alone and not together with its consolidated subsidiaries. We provide electric generation, transmission and distribution services to approximately 690,000 customers in Kansas. Westar Energy provides these services in central and northeastern Kansas, including the cities of Topeka, Lawrence, Manhattan, Salina and Hutchinson. Kansas Gas and Electric Company (KGE), Westar Energy's wholly-owned subsidiary, provides these services in south-central and southeastern Kansas, including the city of Wichita. Both Westar Energy and KGE conduct business using the name Westar Energy. Our corporate headquarters is located at 818 South Kansas Avenue, Topeka, Kansas 66612.

Summary Of Significant Accounting Policies

12 Months Ended

Dec. 31, 2012

Summary Of Significant Accounting Policies

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

We prepare our consolidated financial statements in accordance with GAAP for the United States of America. Our consolidated financial statements include all operating divisions, majority owned subsidiaries and variable interest entities (VIEs) of which we maintain a controlling interest or are the primary beneficiary reported as a single reportable segment. Undivided interests in jointly-owned generation facilities are included on a proportionate basis. Intercompany accounts and transactions have been eliminated in consolidation.

Use of Management's Estimates

When we prepare our consolidated financial statements, we are required to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities at the date of our consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. We evaluate our estimates on an ongoing basis, including those related to depreciation, unbilled revenue, valuation of investments, forecasted fuel costs included in our retail energy cost adjustment (RECA) billed to customers, income taxes, pension and post-retirement benefits, our asset retirement obligations (AROs) including the decommissioning of Wolf Creek Generating Station (Wolf Creek), environmental issues, VIEs, contingencies and litigation. Actual results may differ from those estimates under different assumptions or conditions.

Regulatory Accounting

We apply accounting standards that recognize the economic effects of rate regulation. Accordingly, we have recorded regulatory assets and liabilities when required by a regulatory order or based on regulatory precedent. See Note 3, "Rate Matters and Regulation," for additional information regarding our regulatory assets and liabilities.

Cash and Cash Equivalents

We consider investments that are highly liquid and have maturities of three months or less when purchased to be cash equivalents.

Restricted Cash

Pursuant to Westar Energy's Articles of Incorporation, Westar Energy deposited cash in a separate bank account to effect the redemption of all of Westar Energy's preferred stock in 2012. See Note 16, "Common and Preferred Stock," for additional information regarding the preferred stock redemption.

Fuel Inventory and Supplies

We state fuel inventory and supplies at average cost. Following are the balances for fuel inventory and supplies stated separately.



	As of December 31,
	2012		2011
	(In Thousands)
Fuel inventory	$	94,664	$	86,408
Supplies	154,352		142,710
Total	$	249,016	$	229,118

Property, Plant and Equipment

We record the value of property, plant and equipment, including that of VIEs, at cost. For plant, cost includes contracted services, direct labor and materials, indirect charges for engineering and supervision, and an allowance for funds used during construction (AFUDC). AFUDC represents the allowed cost of capital used to finance utility construction activity. We compute AFUDC by applying a composite rate to qualified construction work in progress. We credit other income (for equity funds) and interest expense (for borrowed funds) for the amount of AFUDC capitalized as construction cost on the accompanying consolidated statements of income as follows:



	Year Ended December 31,
	2012		2011			2010
	(Dollars In Thousands)
Borrowed funds	$	10,399	$	5,589		$	4,295
Equity funds	11,706		5,550			3,104
Total	$	22,105	$	11,139		$	7,399
Average AFUDC Rates	5.0%		3.6		%	2.6		%

We charge maintenance costs and replacements of minor items of property to expense as incurred, except for maintenance costs incurred for our planned refueling and maintenance outages at Wolf Creek. As authorized by regulators, we defer and amortize to expense ratably over the period between planned outages incremental maintenance costs incurred for such outages. When a unit of depreciable property is retired, we charge to accumulated depreciation the original cost less salvage value.

Depreciation

We depreciate utility plant using a straight-line method. The depreciation rates are based on an average annual composite basis using group rates that approximated 2.6% in 2012, 3.0% in 2011 and 2.9% in 2010.

Depreciable lives of property, plant and equipment are as follows.



	Years
Fossil fuel generating facilities	6	to	78
Nuclear fuel generating facility	33	to	71
Wind generating facilities	19	to	20
Transmission facilities	15	to	75
Distribution facilities	15	to	70
Other	5	to	30

Nuclear Fuel

We record as property, plant and equipment our share of the cost of nuclear fuel used in the process of refinement, conversion, enrichment and fabrication. We reflect this at original cost and amortize such amounts to fuel expense based on the quantity of heat consumed during the generation of electricity as measured in millions of British thermal units (MMBtu). The accumulated amortization of nuclear fuel in the reactor was $69.2 million as of December 31, 2012, and $44.8 million as of December 31, 2011. The cost of nuclear fuel charged to fuel and purchased power expense was $28.3 million in 2012, $24.6 million in 2011 and $29.2 million in 2010.

Cash Surrender Value of Life Insurance

We recorded on our consolidated balance sheets in other long-term assets the following amounts related to corporate-owned life insurance policies.



	As of December 31,
	2012			2011
	(In Thousands)
Cash surrender value of policies	$	1,370,788		$	1,345,443
Borrowings against policies	(1,241,343		)	(1,208,389		)
Corporate-owned life insurance, net	$	129,445		$	137,054

We record as income increases in cash surrender value and death benefits. We offset against policy income the interest expense that we incur on policy loans. Income from death benefits is highly variable from period to period.

Revenue Recognition

Electricity Sales

We record revenue at the time we deliver electricity to customers. We determine the amounts delivered to individual customers through systematic monthly readings of customer meters. At the end of each month, we estimate how much electricity we have delivered since the prior meter reading and record the corresponding unbilled revenue.

Our unbilled revenue estimate is affected by factors including fluctuations in energy demand, weather, line losses and changes in the composition of customer classes. We recorded estimated unbilled revenue of $62.5 million as of December 31, 2012, and $54.0 million as of December 31, 2011.

Energy Marketing Contracts

We account for energy marketing derivative contracts under the fair value method of accounting. Under this method, we recognize changes in the portfolio value as gains or losses in the period of change. With the exception of certain fuel supply and electricity contracts, which we record as regulatory assets or regulatory liabilities, we include the net change in fair value in revenues on our consolidated statements of income. We record the unrealized gains and losses in other current assets and other current liabilities or in other assets and other long-term liabilities on our consolidated balance sheets as appropriate. We use quoted market prices to value our energy marketing derivative contracts when such data are available. When market prices are not readily available or determinable, we use alternative approaches, such as model pricing. The prices we use to value these transactions reflect our best estimate of the fair value of these contracts. Results actually achieved from these activities could vary materially from intended results and could affect our consolidated financial results.

Allowance for Doubtful Accounts

We determine our allowance for doubtful accounts based on the age of our receivables. We charge receivables off when they are deemed uncollectible, which is based on a number of factors including specific facts surrounding an account and management's judgment.

Income Taxes

We use the asset and liability method of accounting for income taxes. Under this method, we recognize deferred tax assets and liabilities for the future tax consequences attributable to temporary differences between the financial statement carrying amounts and the tax basis of existing assets and liabilities. We recognize the future tax benefits to the extent that realization of such benefits is more likely than not. We amortize deferred investment tax credits over the lives of the related properties as required by tax laws and regulatory practices. We recognize production tax credits in the year that electricity is generated to the extent that realization of such benefits is more likely than not.

We record deferred tax assets to carry forward into future periods capital losses, operating losses and tax credits. However, when we believe based on available evidence that we do not, or will not, have sufficient future capital gains or taxable income in the appropriate taxing jurisdiction to realize the entire benefit during the applicable carryforward period, we record a valuation allowance against the deferred tax asset.

The application of income tax law is complex. Laws and regulations in this area are voluminous and often ambiguous. Accordingly, we must make judgments regarding income tax exposure. Interpretations of and guidance surrounding income tax laws and regulations change over time. As a result, changes in our judgments can materially affect amounts we recognize in our consolidated financial statements. See Note 10, "Taxes," for additional detail on our accounting for income taxes.

Sales Tax

We account for the collection and remittance of sales tax on a net basis. As a result, we do not reflect sales tax in our consolidated statements of income.

Earnings Per Share

We have participating securities in the form of unvested restricted share units (RSUs) with nonforfeitable rights to dividend equivalents that receive dividends on an equal basis with dividends declared on common shares. As a result, we apply the two-class method of computing basic and diluted earnings per share (EPS).

Under the two-class method, we reduce net income attributable to common stock by the amount of dividends declared in the current period. We allocate the remaining earnings to common stock and RSUs to the extent that each security may share in earnings as if all of the earnings for the period had been distributed. We determine the total earnings allocated to each security by adding together the amount allocated for dividends and the amount allocated for a participation feature. To compute basic EPS, we divide the earnings allocated to common stock by the weighted average number of common shares outstanding. Diluted EPS includes the effect of potential issuances of common shares resulting from our forward sale agreements, RSUs with forfeitable rights to dividend equivalents and stock options. We compute the dilutive effect of potential issuances of common shares using the treasury stock method.

The following table reconciles our basic and diluted EPS from net income.



	Year Ended December 31,
	2012		2011		2010
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	282,462	$	236,180	$	208,624
Less: Net income attributable to noncontrolling interests	7,316		5,941		4,728
Net income attributable to Westar Energy, Inc.	275,146		230,239		203,896
Less: Preferred dividends	1,616		970		970
Net income allocated to RSUs	778		772		1,259
Net income allocated to common stock	$	272,752	$	228,497	$	201,667

Weighted average equivalent common shares outstanding – basic	126,711,869		116,890,552		111,629,292
Effect of dilutive securities:
RSUs	97,757		188,025		140,077
Forward sale agreements	89,160		1,211,645		245,496
Employee stock options	—		—		59
Weighted average equivalent common shares outstanding – diluted (a)	126,898,786		118,290,222		112,014,924

Earnings per common share, basic	$	2.15	$	1.95	$	1.81
Earnings per common share, diluted	$	2.15	$	1.93	$	1.80

_______________


(a)	For the years ended December 31, 2012, 2011 and 2010, we had no antidilutive shares.

Supplemental Cash Flow Information



	Year Ended December 31,
	2012			2011			2010
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	143,564		$	145,570		$	145,463
Interest on financing activities of VIEs	16,214			18,167			20,191
Income taxes, net of refunds	(4,378		)	(17,519		)	(34,980		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	89,354			105,435			64,423
Property, plant and equipment additions of VIEs	—			—			356,964
Jeffrey Energy Center (JEC) 8% leasehold interest	—			—			(108,706		)
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	12,803			15,103			18,777
Debt of VIEs	—			—			337,951
Capital lease for JEC 8% leasehold interest	—			—			(106,423		)
Assets acquired through capital leases	10,683			43,011			910

Investment Earnings - Sale of Non-utility Investment

In 2011, we recorded a $7.2 million gain on the sale of a non-utility investment.

Rate Matters And Regulation

The entire disclosure for all significant accounting policies of the reporting entity.

+ References+ Details

Rate Matters And Regulation

12 Months Ended

Dec. 31, 2012

Regulated Operations [Abstract]

RATE MATTERS AND REGULATION

Regulatory Assets and Regulatory Liabilities

Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery in customer prices. Regulatory liabilities represent probable future reductions in revenue or refunds to customers through the price setting process. Regulatory assets and liabilities reflected on our consolidated balance sheets are as follows.



	As of December 31,
	2012		2011
	(In Thousands)
Regulatory Assets:
Deferred employee benefit costs	$	542,174	$	560,915
Amounts due from customers for future income taxes, net	169,091		168,804
Depreciation	73,672		76,298
Debt reacquisition costs	67,721		66,856
Treasury yield hedges	28,573		33,753
Asset retirement obligations	22,633		22,196
Ad valorem tax	21,812		6,622
Energy efficiency program costs	18,835		16,521
Disallowed plant costs	16,106		16,236
Wolf Creek outage	14,143		25,033
Storm costs	11,076		25,747
Retail energy cost adjustment	4,262		19,587
Other regulatory assets	12,574		7,522
Total regulatory assets	$	1,002,672	$	1,046,090

Regulatory Liabilities:
Removal costs	$	128,971	$	82,338
Deferred regulatory gain from sale leaseback	92,046		97,541
Nuclear decommissioning	25,937		12,544
La Cygne dismantling costs	18,093		15,680
Retail energy cost adjustment	16,595		25,225
Kansas tax credits	10,781		8,497
Other post-retirement benefits costs	10,722		11,125
Gain on sale of oil	6,219		5,822
Fuel supply and electricity contracts	4,387		6,177
Other regulatory liabilities	9,424		6,438
Total regulatory liabilities	$	323,175	$	271,387

Below we summarize the nature and period of recovery for each of the regulatory assets listed in the table above.

•

Deferred employee benefit costs: Includes $485.5 million for pension and post-retirement benefit obligations and $56.7 million for actual pension expense in excess of the amount of such expense recognized in setting our prices. During 2013, we will amortize to expense approximately $44.2 million of the benefit obligations and approximately $9.8 million of the excess pension expense. As authorized in the April 2012 KCC order discussed below, we are amortizing the excess pension expense as of the time of our filing with the KCC over a five-year period. We do not earn a return on this asset.

•

Amounts due from customers for future income taxes, net: In accordance with various orders, we have reduced our prices to reflect the income tax benefits associated with certain income tax deductions, thereby passing on these benefits to customers at the time we receive them. We believe it is probable that the net future increases in income taxes payable will be recovered from customers when these temporary income tax benefits reverse in future periods. We have recorded a regulatory asset, net of the regulatory liability, for these amounts on which we do not earn a return. We also have recorded a regulatory liability for our obligation to customers for income taxes recovered in earlier periods when corporate income tax rates were higher than current income tax rates. This benefit will be returned to customers as these temporary differences reverse in future periods. The income tax-related regulatory assets and liabilities as well as unamortized investment tax credits are also temporary differences for which deferred income taxes have been provided. These items are measured by the expected cash flows to be received or settled in future prices. We do not earn a return on this asset.


•	Depreciation: Represents the difference between regulatory depreciation expense and depreciation expense we record for financial reporting purposes. We earn a return on this asset and amortize the difference over the life of the related plant.


•	Debt reacquisition costs: Includes costs incurred to reacquire and refinance debt. These costs are amortized over the term of the new debt. We do not earn a return on this asset.

•

Treasury yield hedges: Represents the effective portion of losses on treasury yield hedge transactions. This amount will be amortized to interest expense over the term of the related debt. See Note 4, "Financial and Derivative Instruments, Trading Securities, Energy Marketing and Risk Management—Derivative Instruments—Cash Flow Hedges," for additional information regarding our treasury yield hedge transactions. We do not earn a return on this asset.


•	Asset retirement obligations: Represents amounts associated with our AROs as discussed in Note 14, "Asset Retirement Obligations." We recover these amounts over the life of the related plant. We do not earn a return on this asset.


•	Ad valorem tax: Represents actual costs incurred for property taxes in excess of amounts collected in our prices. We expect to recover these amounts in our prices over a one-year period. We do not earn a return on this asset.


•	Energy efficiency program costs: We accumulate and defer for future recovery costs related to our various energy efficiency programs. We will amortize such costs over a one-year period. We do not earn a return on this asset.


•	Disallowed plant costs: In 1985, the Kansas Corporation Commission (KCC) disallowed certain costs associated with the original construction of Wolf Creek. In 1987, the KCC authorized KGE to recover these costs in prices over the useful life of Wolf Creek. We do not earn a return on this asset.


•	Wolf Creek outage: We defer the expenses associated with Wolf Creek's scheduled refueling and maintenance outages and amortize these expenses during the period between planned outages. We do not earn a return on this asset.


•	Storm costs: We accumulated and deferred for future recovery costs related to restoring our electric transmission and distribution systems from damages sustained during unusually damaging storms. We amortize these costs over periods ranging from three to five years and earn a return on a majority of this asset.

•

Retail energy cost adjustment: We are allowed to adjust our retail prices to reflect changes in the cost of fuel and purchased power needed to serve our customers. This item represents the actual cost of fuel consumed in producing electricity and the cost of purchased power in excess of the amounts we have collected from customers. We expect to recover in our prices this shortfall over a one-year period. We have two retail jurisdictions, each with a separate cost of fuel. For the reporting period, this resulted in us simultaneously reporting both a regulatory asset and a regulatory liability for this item. We do not earn a return on this asset.


•	Other regulatory assets: Includes various regulatory assets that individually are small in relation to the total regulatory asset balance. Other regulatory assets have various recovery periods. We do not earn a return on any of these assets.

Below we summarize the nature and period of amortization for each of the regulatory liabilities listed in the table above.


•	Removal costs: Represents amounts collected, but not yet spent, to dispose of plant assets that do not represent legal retirement obligations. This liability will be discharged as removal costs are incurred.


•	Deferred regulatory gain from sale leaseback: Represents the gain KGE recorded on the 1987 sale and leaseback of its 50% interest in La Cygne Generation Station (La Cygne) unit 2. We amortize the gain over the lease term.

•

Nuclear decommissioning: We have a legal obligation to decommission Wolf Creek at the end of its useful life. This amount represents the difference between the fair value of the assets held in a decommissioning trust and the fair value of our ARO. See Note 4, "Financial and Derivative Instruments, Trading Securities, Energy Marketing and Risk Management," Note 5, "Financial Investments" and Note 14, "Asset Retirement Obligations," for information regarding our nuclear decommissioning trust (NDT) and our ARO.


•	La Cygne dismantling costs: We are contractually obligated to dismantle a portion of La Cygne unit 2. This item represents amounts collected but not yet spent to dismantle this unit and the obligation will be discharged as we dismantle the unit.

•

Retail energy cost adjustment: We are allowed to adjust our retail prices to reflect changes in the cost of fuel and purchased power needed to serve our customers. We bill customers based on our estimated costs. This item represents the amount we collected from customers that was in excess of our actual cost of fuel and purchased power. We will refund to customers this excess recovery over a one-year period. We have two retail jurisdictions, each with a separate cost of fuel. For the reporting period, this resulted in us simultaneously reporting both a regulatory asset and a regulatory liability for this item.


•	Kansas tax credits: Represents Kansas tax credits on investments in utility plant. Amounts will be credited to customers subsequent to their realization over the remaining lives of the utility plant giving rise to the tax credits.


•	Other post-retirement benefits costs: Represents the amount of other post-retirement benefits expense recognized in setting our prices in excess of actual other post-retirement benefits expense. We amortize the amount over a five-year period.


•	Gain on sale of oil: We discontinued the use of a certain type of oil in our plants. As a result, we sold this oil inventory for a gain. This item represents the remaining portion of the gain that will be refunded to customers over a three-year period.


•	Fuel supply and electricity contracts: We use fair value accounting for some of our fuel supply and electricity contracts. This represents the non-cash net gain position on fuel supply and electricity contracts that are recorded at fair value. Under the RECA, fuel supply contract market gains accrue to the benefit of our customers.


•	Other regulatory liabilities: Includes various regulatory liabilities that individually are relatively small in relation to the total regulatory liability balance. Other regulatory liabilities will be credited over various periods.

KCC Proceedings

General and Abbreviated Rate Reviews

In April 2012, the KCC issued an order expected to increase our annual retail revenues by approximately $50.0 million. In addition, we revised our depreciation rates to reflect changes in the estimated useful lives of some of our depreciable assets. The change in estimate will decrease annual depreciation expense by $43.6 million. The new prices were effective shortly after having received the order. The KCC also approved our request to file an abbreviated rate review within 12 months of this order to update our prices to include capital costs related to environmental projects at La Cygne.

In January 2010, the KCC issued an order allowing us to adjust our prices to include costs associated with investments in natural gas and wind generation facilities. The new prices were effective in February 2010 and were expected to increase our annual retail revenues by approximately $17.1 million.

Environmental Costs

In August 2011, the KCC issued an order ruling that Kansas City Power & Light Company's (KCPL) decision to make environmental upgrades at La Cygne to comply with environmental regulations is prudent and the $1.2 billion project cost estimate is reasonable. We have a 50% interest in La Cygne and intervened in the proceeding. The KCC denied our request to collect our approximately $610.0 million share of the capital investment for the environmental upgrades through our environmental cost recovery rider (ECRR). However, as noted above, the KCC approved our request to file an abbreviated rate review to update our prices to include capital costs associated with the project.

We also make annual filings with the KCC to adjust our prices to include costs associated with investments in air quality equipment made during the prior year. In the most recent three years, the KCC issued orders related to such filings allowing us to increase our annual retail revenues by approximately:


•	$19.5 million effective in June 2012;


•	$10.4 million effective in June 2011; and


•	$13.8 million effective in June 2010.

Transmission Costs

We make annual filings with the KCC to adjust our prices to include updated transmission costs as reflected in our transmission formula rate discussed below. In the most recent three years, the KCC issued orders related to such filings allowing us to increase our annual retail revenues by approximately:


•	$36.7 million effective in April 2012;


•	$17.4 million effective in April 2011; and


•	$6.4 million effective in March 2010.

Energy Efficiency

We make annual filings with the KCC to adjust our prices to include previously deferred amounts associated with various energy efficiency programs. In the most recent three years, the KCC issued orders related to such filings allowing us to increase our annual retail revenues by approximately:


•	$1.1 million effective in October 2012;


•	$4.9 million effective in November 2011; and


•	$5.8 million effective in November 2010.

FERC Proceedings

In October of each year, we post an updated transmission formula rate that includes projected transmission capital expenditures and operating costs for the following year. This rate provides the basis for our annual request with the KCC to adjust our retail prices to include updated transmission costs as noted above. In the most recent three years, we posted our transmission formula rate which was expected to increase our annual transmission revenues by approximately:


•	$38.2 million effective in January 2012;


•	$15.9 million effective in January 2011; and


•	$16.8 million effective in January 2010.

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management

12 Months Ended

Dec. 31, 2012

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Abstract]

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management

FINANCIAL AND DERIVATIVE INSTRUMENTS, TRADING SECURITIES, ENERGY MARKETING AND RISK MANAGEMENT

Values of Financial and Derivative Instruments

GAAP establishes a hierarchal framework for disclosing the transparency of the inputs utilized in measuring assets and liabilities at fair value. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the classification of assets and liabilities within the fair value hierarchy levels. The three levels of the hierarchy and examples are as follows:


•	Level 1 - Quoted prices are available in active markets for identical assets or liabilities. The types of assets and liabilities included in level 1 are highly liquid and actively traded instruments with quoted prices, such as equities listed on public exchanges and exchange-traded futures contracts.

•

Level 2 - Pricing inputs are not quoted prices in active markets, but are either directly or indirectly observable. The types of assets and liabilities included in level 2 are typically measured at net asset value, comparable to actively traded securities or contracts, such as treasury securities with pricing interpolated from recent trades of similar securities, or priced with models using highly observable inputs, such as commodity options priced using observable forward prices and volatilities.


•	Level 3 - Significant inputs to pricing have little or no transparency. The types of assets and liabilities included in level 3 are those with inputs requiring significant management judgment or estimation, such as the complex and subjective models and forecasts used to determine the fair value of options, private equity and real estate securities and long-term electricity supply contracts.

We record cash and cash equivalents, short-term borrowings and variable rate debt on our consolidated balance sheets at cost, which approximates fair value. We measure the fair value of fixed rate debt, a level 2 measurement, based on quoted market prices for the same or similar issues or on the current rates offered for instruments of the same remaining maturities and redemption provisions. The recorded amount of accounts receivable and other current financial instruments approximates fair value.

All of our level 2 investments are held in investment funds that are measured at fair value using daily net asset values. In addition, we maintain certain level 3 investments in private equity and real estate securities that are also measured at fair value using net asset value, but require significant unobservable market information to measure the fair value of the underlying investments. The underlying investments in private equity are measured at fair value utilizing both market- and income-based models, public company comparables, investment cost or the value derived from subsequent financings. Adjustments are made when actual performance differs from expected performance; when market, economic or company-specific conditions change; and when other news or events have a material impact on the security. The underlying real estate investments are measured at fair value using a combination of market- and income-based models utilizing market discount rates, projected cash flows and the estimated value into perpetuity.

Energy marketing contracts can be exchange-traded or traded over-the-counter (OTC). Fair value measurements of exchange-traded contracts typically utilize quoted prices in active markets. OTC contracts are valued using market transactions and other market evidence whenever possible, including market-based inputs to models, model calibration to market clearing transactions or alternative pricing sources with reasonable levels of price transparency. Valuation models require a variety of inputs, including contractual terms, market prices, yield curves, credit curves, nonperformance risk, measures of volatility and correlations of such inputs. Certain OTC contracts trade in less liquid markets with limited pricing information and the determination of fair value for these derivatives is inherently more subjective. In these situations, estimates by management are a significant input. Our risk management department, which reports to the Chief Financial Officer, has established valuation processes and procedures to ensure that the valuation methodologies for energy marketing transactions are fair and consistent. Methodologies are periodically reviewed and tested to ensure they are representative of the current market dynamics. See

"-Recurring Fair Value Measurements" and "-Derivative Instruments" below for additional information.

We measure fair value based on information available as of the measurement date. The following table provides the carrying values and measured fair values of our fixed-rate debt.



	As of December 31, 2012				As of December 31, 2011
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In Thousands)
Fixed-rate debt	$	2,702,500	$	3,178,752	$	2,373,063	$	2,623,993
Fixed-rate debt of VIEs	247,624		275,341		275,738		306,027

Recurring Fair Value Measurements

The following table provides the amounts and their corresponding level of hierarchy for our assets and liabilities that are measured at fair value.



As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Energy Marketing Contracts	$	—	$	381	$	8,429	$	8,810
Nuclear Decommissioning Trust:
Domestic equity	—		56,157		4,899		61,056
International equity	—		30,041		—		30,041
Core bonds	—		28,350		—		28,350
High-yield bonds	—		8,782		—		8,782
Emerging market bonds	—		6,428		—		6,428
Combination debt/equity fund	—		8,194		—		8,194
Real estate securities	—		—		7,865		7,865
Cash equivalents	38		—		—		38
Total Nuclear Decommissioning Trust	38		137,952		12,764		150,754
Trading Securities:
Domestic equity	—		22,470		—		22,470
International equity	—		5,744		—		5,744
Core bonds	—		15,104		—		15,104
Cash equivalents	166		—		—		166
Total Trading Securities	166		43,318		—		43,484
Total Assets Measured at Fair Value	$	204	$	181,651	$	21,193	$	203,048

Liabilities:
Energy Marketing Contracts	$	—	$	105	$	1,367	$	1,472

As of December 31, 2011
Assets:
Energy Marketing Contracts	$	—	$	2,401	$	13,330	$	15,731
Nuclear Decommissioning Trust:
Domestic equity	—		53,186		3,931		57,117
International equity	—		22,307		—		22,307
Core bonds	—		20,171		—		20,171
High-yield bonds	—		10,969		—		10,969
Emerging market bonds	—		5,309		—		5,309
Combination debt/equity fund	—		7,251		—		7,251
Real estate securities	—		—		7,095		7,095
Cash equivalents	51		—		—		51
Total Nuclear Decommissioning Trust	51		119,193		11,026		130,270
Trading Securities:
Domestic equity	—		21,175		—		21,175
International equity	—		4,896		—		4,896
Core bonds	—		13,961		—		13,961
Cash equivalents	169		—		—		169
Total Trading Securities	169		40,032		—		40,201
Total Assets Measured at Fair Value	$	220	$	161,626	$	24,356	$	186,202

Liabilities:
Energy Marketing Contracts	$	—	$	2,475	$	3,878	$	6,353
Treasury Yield Hedges	—		34,025		—		34,025
Total Liabilities Measured at Fair Value	$	—	$	36,500	$	3,878	$	40,378

We do not offset the fair value of energy marketing contracts executed with the same counterparty. As of December 31, 2012, we had no right to reclaim cash collateral and had recorded $1.8 million for our obligation to return cash collateral. As of December 31, 2011, we had no right to reclaim cash collateral and had recorded $2.9 million for our obligation to return cash collateral.

The following table provides reconciliations of assets and liabilities measured at fair value using significant level 3 inputs for the years ended December 31, 2012 and 2011.



	Energy Marketing Contracts, net				Nuclear Decommissioning Trust									Net Balance
	Energy Marketing Contracts, net				Domestic Equity			High-yield Bonds			Real Estate Securities			Net Balance
	(In Thousands)
Balance as of December 31, 2011	$	9,452			$	3,931		$	—		$	7,095		$	20,478
Total realized and unrealized gains (losses) included in:
Earnings (a)	2,176				—			—			—			2,176
Regulatory assets	(696		)	(b)	—			—			—			(696		)
Regulatory liabilities	2,114			(b)	90			—			770			2,974
Purchases	(5,034		)		891			—			320			(3,823		)
Sales	(620		)		(13		)	—			(320		)	(953		)
Settlements	(330		)		—			—			—			(330		)
Balance as of December 31, 2012	$	7,062			$	4,899		$	—		$	7,865		$	19,826

Balance as of December 31, 2010	$	11,815			$	2,867		$	305		$	3,049		$	18,036
Total realized and unrealized gains (losses) included in:
Earnings (a)	603				—			—			—			603
Regulatory assets	(1,450		)	(b)	—			—			—			(1,450		)
Regulatory liabilities	2,993			(b)	479			—			670			4,142
Purchases	(6,145		)		608			—			3,455			(2,082		)
Sales	1,022				(23		)	(305		)	(79		)	615
Settlements	614				—			—			—			614
Balance as of December 31, 2011	$	9,452			$	3,931		$	—		$	7,095		$	20,478

_______________


(a)	Unrealized gains and losses included in earnings are reported in revenues.


(b)	Includes changes in the fair value of certain fuel supply and electricity contracts.

Portions of the gains and losses contributing to changes in net assets in the above table are unrealized. The following table summarizes the unrealized gains and losses we recorded on our consolidated financial statements during the years ended December 31, 2012 and 2011, attributed to level 3 assets and liabilities.



	Year Ended December 31, 2012
	Energy Marketing Contracts, net				Nuclear Decommissioning Trust
	Energy Marketing Contracts, net				Domestic Equity		Real Estate Securities		Net Balance
	(In Thousands)
Total unrealized gains (losses) included in:
Earnings (a)	$	(748	)		$	—	$	—	$	(748	)
Regulatory assets	(74		)	(b)	—		—		(74		)
Regulatory liabilities	332			(b)	77		451		860
Total	$	(490	)		$	77	$	451	$	38

	Year Ended December 31, 2011
Total unrealized gains (losses) included in:
Earnings (a)	$	(898	)		$	—	$	—	$	(898	)
Regulatory assets	(747		)	(b)	—		—		(747		)
Regulatory liabilities	1,736			(b)	456		591		2,783
Total	$	91			$	456	$	591	$	1,138

_______________

(a)Unrealized gains and losses included in earnings are reported in revenues.

(b)Includes changes in the fair value of certain fuel supply and electricity contracts.

Our level 3 investments require unobservable quantitative inputs to measure fair value. The following table summarizes the quantitative inputs and assumptions for our level 3 investments not measured at net asset value.



	Fair Value as of
	December 31, 2012				Valuation Methodology	Unobservable Inputs	Range of Inputs
	Assets		Liabilities		Valuation Methodology	Unobservable Inputs	Range of Inputs
	(In Thousands)
Electricity - Forwards	$	862	$	358	Discounted cash flow	Basis (MWh)	$0	to	$15
Gas - Forwards	—		74		Discounted cash flow	Basis (mmBtu)	$0	to	$0.25
Options	7,567		935		Discounted cash flow	Basis - Electricity (MWh)	$0	to	$15
						Basis - Gas (mmBtu)	$0	to	$0.25
					Option models	Volatility - Electricity	10%	to	75%
						Volatility - Gas	20%	to	35%
						Correlation	60%	to	90%
Total	$	8,429	$	1,367

Our fair value measurement of energy marketing contracts is sensitive to level 3 fair value inputs. Increases or decreases to one unobservable input may magnify or mitigate the impact of other inputs. Holding all other inputs constant, an increase (decrease) in a significant unobservable input would typically impact our fair value measurement as follows.



Significant Unobservable Input	Position	Impact on Fair Value Measurement
Basis	Purchase	Increase (decrease)
	Sell	Decrease (increase)
Volatility	Purchase Option	Increase (decrease)
	Sell Option	Decrease (increase)
Correlation	Purchase Option	Decrease (increase)
	Sell Option	Increase (decrease)

Some of our investments in the NDT and our trading securities portfolio are measured at net asset value, do not have readily determinable fair values and are either with investment companies or companies that follow accounting guidance consistent with investment companies. In certain situations these investments may have redemption restrictions. The following table provides additional information on these investments.



	As of December 31, 2012				As of December 31, 2011				As of December 31, 2012
	Fair Value		Unfunded Commitments		Fair Value		Unfunded Commitments		Redemption Frequency	Length of Settlement
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity	$	4,899	$	1,024	$	3,931	$	1,914	(a)	(a)
Real estate securities	7,865		—		7,095		—		Quarterly	80 days
Total Nuclear Decommissioning Trust	$	12,764	$	1,024	$	11,026	$	1,914

Trading Securities:
Domestic equity	$	22,470	$	—	$	21,175	$	—	Upon Notice	1 day
International equity	5,744		—		4,896		—		Upon Notice	1 day
Core bonds	15,104		—		13,961		—		Upon Notice	1 day
Total Trading Securities	43,318		—		40,032		—
Total	$	56,082	$	1,024	$	51,058	$	1,914

_______________


(a)	This investment is in two long-term private equity funds that do not permit early withdrawal. Our investments in these funds cannot be distributed until the underlying investments have been liquidated which may take years from the date of initial liquidation. One fund has begun making distributions and we expect the other to begin in 2013.

Nonrecurring Fair Value Measurements

We have recognized legal obligations associated with the disposal of long-lived assets that result from the acquisition, construction, development or normal operations of such assets. In 2012, we recorded $3.1 million of additional AROs. In 2011, we recorded $9.9 million of additional AROs to reflect revisions to the estimated cost to decommission Wolf Creek. We initially record AROs at fair value for the estimated cost to satisfy the retirement obligation.

We measure the fair value of AROs by estimating the cost to satisfy the retirement obligation then discounting that value at a risk- and inflation-adjusted rate. To determine the cost to satisfy the retirement obligation, experts reporting to the Chief Operating Officer must estimate the cost of basic inputs such as labor, energy, materials, timing and disposal and make assumptions on the method of disposal or decommissioning. Our estimates are validated with contractor estimates and when we satisfy other similar obligations. We estimate the cost to satisfy the 2012 ARO layer as of December 31, 2012, is approximately $3.1 million.

To determine the appropriate discount rate, we use observable inputs such as inflation rates, short and long-term yields for U.S. government securities and our nonperformance risk. Due to the significant unobservable inputs required in our measurement, we have determined that our fair value measurements of our AROs are level 3 in the fair value hierarchy. For additional information on our AROs, see Note 14, "Asset Retirement Obligations."

Derivative Instruments

Cash Flow Hedges

We entered into treasury yield hedge transactions to hedge our interest rate risk associated with a $125.0 million portion of a forcaseted issuance of fixed rate debt. These transactions were designated and qualified as cash flow hedges and measured at fair value by estimating the net present value of a series of payments using market-based models with observable inputs such as the spread between the 30-year U.S Treasury bill yield and the contracted, fixed yield. As a result of regulatory accounting treatment, we report the effective portion of the gains or losses on these derivative instruments as a regulatory liability or regulatory asset and amortize such amounts to interest expense over the term of the related debt. As of December 31, 2011, we had recorded $34.0 million in other current liabilities on our consolidated balance sheet to reflect the fair value of the treasury yield hedge transactions and $33.8 million in long-term regulatory assets to reflect the effective portion. We recorded $0.2 million of hedge ineffectiveness losses in interest expense on our consolidated statements of income for the year ended December 31, 2011. During the first quarter of 2012, we settled the treasury yield hedge transactions for a cost of $29.7 million, which will be amortized to interest expense over the 30-year term of the debt issued in March 2012. See Note 9, "Long-Term Debt" for additional information regarding the debt issuance. As of December 31, 2012, we had recorded $28.6 million as a regulatory asset.

Commodity Contracts

We engage in both financial and physical trading with the goal of managing our commodity price risk, enhancing system reliability and increasing profits. We trade electricity and other energy-related products using a variety of financial instruments, which may include futures contracts, options, swaps and physical commodity contracts.

We classify these commodity derivative instruments as other current and other long-term assets and liabilities on our consolidated balance sheets. We report energy marketing contracts representing unrealized gain positions as assets; energy marketing contracts representing unrealized loss positions are reported as liabilities. With the exception of certain fuel supply and electricity contracts, which we record as regulatory assets or regulatory liabilities, we include the change in the fair value of energy marketing contracts in revenues on our consolidated statements of income. The following table presents the fair value of commodity derivative instruments reflected on our consolidated balance sheets.



Commodity Derivatives Not Designated as Hedging Instruments as of December 31, 2012
Asset Derivatives			Liability Derivatives
Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
	(In Thousands)			(In Thousands)
Current assets:			Current liabilities:
Other	$	4,776	Other	$	1,472
Other assets:
Other	4,034
Total	$	8,810

Commodity Derivatives Not Designated as Hedging Instruments as of December 31, 2011
Asset Derivatives			Liability Derivatives
Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
	(In Thousands)			(In Thousands)
Current assets:			Current liabilities:
Other	$	8,180	Other	$	6,353
Other assets:
Other	7,551
Total	$	15,731

The following table presents how changes in the fair value of commodity derivative instruments increased (decreased) line items on our consolidated financial statements for the years ended December 31, 2012 and 2011.



	Year Ended December 31, 2012						Year Ended December 31, 2011
Location	Net Gain Recognized			Net Loss Recognized			Net Gain Recognized		Net Loss Recognized
	(In Thousands)
Revenues	$	6,200		$	—		$	1,569	$	—
Regulatory assets	(374		)	—			—		374
Regulatory liabilities	—			(1,790		)	—		(1,623		)

As of December 31, 2012 and 2011, we had under contract the following commodity derivatives.



		Net Quantity as of
	Unit of Measure	December 31, 2012	December 31, 2011
Electricity	MWh	1,955,497	1,834,253
Natural Gas	MMBtu	1,674,000	1,467,500

Net open positions exist, or are established, due to the origination of new transactions and our assessment of, and response to, changing market conditions. To the extent we have net open positions, we are exposed to the risk that changing market prices could have a material impact on our consolidated financial results.

Energy Marketing Activities

Within our energy trading portfolio, we may establish certain positions intended to economically hedge a portion of physical sale or purchase contracts and we may enter into certain positions attempting to take advantage of market trends and conditions. We use the term economic hedge to mean a strategy intended to manage risks of volatility in prices or rate movements on selected assets, liabilities or anticipated transactions by creating a relationship in which gains or losses on derivative instruments are expected to offset the losses or gains on the assets, liabilities or anticipated transactions exposed to such market risks.

Price Risk

We use various types of fuel, including coal, natural gas, uranium and diesel to operate our plants and also purchase power to meet customer demand. Our prices and consolidated financial results are exposed to market risks from commodity price changes for electricity and other energy-related products as well as from interest rates. Volatility in these markets impacts our costs of purchased power, costs of fuel for our generating plants and our participation in energy markets. We strive to manage our customers' and our exposure to these market risks through regulatory, operating and financing activities and, when we deem appropriate, we economically hedge a portion of these risks through the use of derivative financial instruments for non-trading purposes.

Interest Rate Risk

We have entered into numerous fixed and variable rate debt obligations. For details, see Note 9, "Long-Term Debt." We manage our interest rate risk related to these debt obligations by limiting our exposure to variable interest rate debt, diversifying maturity dates and entering into treasury yield hedge transactions. We may also use other financial derivative instruments such as interest rate swaps.

Credit Risk

In addition to commodity price risk, we are exposed to credit risks associated with the financial condition of counterparties, product location (basis) pricing differentials, physical liquidity constraints and other risks. Declines in the creditworthiness of our counterparties could have a material impact on our overall exposure to credit risk. We maintain credit policies with regard to our counterparties intended to reduce our overall credit risk exposure to a level we deem acceptable and include the right to offset derivative assets and liabilities by counterparty.

We have derivative instruments with commodity exchanges and other counterparties that do not contain objective credit-risk-related contingent features. However, certain of our derivative instruments contain collateral provisions subject to certain of our debt ratings. If such debt ratings were to decrease or fall below investment grade, the counterparties to the derivative instruments, pursuant to the provisions, could require collateralization on derivative instruments. The aggregate fair value of all derivative instruments with objective credit-risk-related contingent features that were in a liability position as of December 31, 2012 and 2011, was $0.8 million and $3.1 million, respectively, for which we had posted no collateral as of either date, including independent amounts. If all credit-risk-related contingent features underlying these agreements had been triggered as of December 31, 2012 and 2011, we would have been required to provide to our counterparties $0.1 million and $0.5 million, respectively, of additional collateral after taking into consideration the offsetting impact of derivative assets and net accounts receivable.

Financial Investments

12 Months Ended

Dec. 31, 2012

Investments [Abstract]

Financial Investments

FINANCIAL INVESTMENTS

We report our investments in equity and debt securities at fair value and use the specific identification method to determine their realized gains and losses. We classify these investments as either trading securities or available-for-sale securities as described below.

Trading Securities

We hold equity and debt investments which we classify as trading securities in a trust used to fund certain retirement benefit obligations of $30.0 million and $29.4 million as of December 31, 2012 and 2011, respectively. For additional information on our benefit obligations, see Note 11, "Employee Benefit Plans."

As of December 31, 2012 and 2011, we measured the fair value of trust assets at $43.5 million and $40.2 million, respectively. We include unrealized gains or losses on these securities in investment earnings on our consolidated statements of income. For the years ended December 31, 2012, 2011 and 2010, we recorded unrealized gains of $4.1 million, $0.3 million and $4.3 million, respectively.

Available-for-Sale Securities

We hold investments in equity, debt and real estate securities in a trust for the purpose of funding the decommissioning of Wolf Creek. We have classified these investments as available-for-sale and have recorded all such investments at their fair market value as of December 31, 2012 and 2011. As of December 31, 2012, the fair value of available-for-sale debt securities in the core, high-yield and emerging market bond funds was $43.6 million. As of December 31, 2012, the NDT did not have investments in debt securities outside of investment funds.

Using the specific identification method to determine cost, we realized gains on our available-for-sale securities of $0.6 million in 2012, $1.3 million in 2011 and $13.2 million in 2010. We record net realized and unrealized gains and losses in regulatory liabilities on our consolidated balance sheets. This reporting is consistent with the method we use to account for the decommissioning costs we recover in our prices. Gains or losses on assets in the trust fund are recorded as increases or decreases to regulatory liabilities and could result in lower or higher funding requirements for decommissioning costs, which we believe would be reflected in the prices paid by our customers.

The following table presents the cost, gross unrealized gains and losses, fair value and allocation of investments in the NDT fund as of December 31, 2012 and 2011.



			Gross Unrealized
Security Type	Cost		Gain		Loss			Fair Value		Allocation
	(Dollars In Thousands)
As of December 31, 2012
Domestic equity	$	53,598	$	7,458	$	—		$	61,056	41	%
International equity	28,248		1,793		—			30,041		20	%
Core bonds	27,309		1,041		—			28,350		19	%
High-yield bonds	8,022		760		—			8,782		6	%
Emerging market bonds	6,080		348		—			6,428		4	%
Combination debt/equity fund	8,074		120		—			8,194		5	%
Real estate securities	9,981		—		(2,116		)	7,865		5	%
Cash equivalents	38		—		—			38		<1%
Total	$	141,350	$	11,520	$	(2,116	)	$	150,754	100	%

As of December 31, 2011
Domestic equity	$	55,357	$	1,760	$	—		$	57,117	44	%
International equity	24,501		—		(2,194		)	22,307		17	%
Core bonds	19,771		400		—			20,171		16	%
High-yield bonds	11,046		—		(77		)	10,969		8	%
Emerging market bonds	5,301		8		—			5,309		4	%
Combination debt/equity fund	7,524		—		(273		)	7,251		6	%
Real estate securities	9,662		—		(2,567		)	7,095		5	%
Cash equivalents	51		—		—			51		<1%
Total	$	133,213	$	2,168	$	(5,111	)	$	130,270	100	%

The following table presents the fair value and the gross unrealized losses of the available-for-sale securities held in the NDT fund aggregated by investment category and the length of time that individual securities have been in a continuous unrealized loss position as of December 31, 2012 and 2011.



	Less than 12 Months					12 Months or Greater					Total
	Fair Value		Gross Unrealized Losses			Fair Value		Gross Unrealized Losses			Fair Value		Gross Unrealized Losses
	(In Thousands)
As of December 31, 2012
Real estate securities	$	—	$	—		$	7,865	$	(2,116	)	$	7,865	$	(2,116	)

As of December 31, 2011
International equity	$	22,307	$	(2,194	)	$	—	$	—		$	22,307	$	(2,194	)
High-yield bonds	10,969		(77		)	—		—			10,969		(77		)
Combination debt/equity fund	7,251		(273		)	—		—			7,251		(273		)
Real estate securities	—		—			7,095		(2,567		)	7,095		(2,567		)
Total	$	40,527	$	(2,544	)	$	7,095	$	(2,567	)	$	47,622	$	(5,111	)

Property, Plant And Equipment

12 Months Ended

Dec. 31, 2012

Public Utilities, Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT

The following is a summary of our property, plant and equipment balance.



	As of December 31,
	2012			2011
	(In Thousands)
Electric plant in service	$	9,389,192		$	8,703,278
Electric plant acquisition adjustment	802,318			802,318
Accumulated depreciation	(3,791,545		)	(3,703,372		)
	6,399,965			5,802,224
Construction work in progress	532,332			534,003
Nuclear fuel, net	81,468			75,695
Net property, plant and equipment	$	7,013,765		$	6,411,922

The following is a summary of property, plant and equipment of VIEs.



	As of December 31,
	2012			2011
	(In Thousands)
Electric plant of VIEs	$	543,548		$	543,548
Accumulated depreciation of VIEs	(221,573		)	(210,054		)
Net property, plant and equipment of VIEs	$	321,975		$	333,494

We revised our depreciation rates to reflect changes in the estimated useful lives of some of our assets. We recorded depreciation expense on property, plant and equipment of $247.8 million in 2012, $262.6 million in 2011 and $249.2 million in 2010. Approximately $9.8 million, $9.8 million and $9.7 million of depreciation expense in 2012, 2011 and 2010, respectively, was attributable to property, plant and equipment of VIEs.

Joint Ownership of Utility Plants

The entire disclosure for long-lived, physical assets that are used in the normal conduct of business to produce goods and services and not intended for resale. Examples include land, buildings, machinery and equipment, and other types of furniture and equipment including, but not limited to, office equipment, furniture and fixtures, and computer equipment and software. This disclosure may include property plant and equipment accounting policies and methodology, a schedule of property, plant and equipment gross, additions, deletions, transfers and other changes, depreciation, depletion and amortization expense, net, accumulated depreciation, depletion and amortization expense and useful lives, income statement disclosures, assets held for sale and public utility disclosures.

+ References+ Details

Joint Ownership of Utility Plants

12 Months Ended

Dec. 31, 2012

Regulated Operations [Abstract]

JOINT OWNERSHIP OF UTILITY PLANTS

Under joint ownership agreements with other utilities, we have undivided ownership interests in four electric generating stations. Energy generated and operating expenses are divided on the same basis as ownership with each owner reflecting its respective costs in its statements of income and each owner responsible for its own financing. Information relative to our ownership interests in these facilities as of December 31, 2012, is shown in the table below.



Plant	In-Service Dates	Investment		Accumulated Depreciation		Construction Work in Progress		Net MW	Ownership Percentage
		(Dollars in Thousands)
La Cygne unit 1 (a)	June 1973	$	331,964	$	156,722	$	185,875	368	50
JEC unit 1 (a)	July 1978	528,478		196,511		80,217		661	92
JEC unit 2 (a)	May 1980	498,929		182,444		121		658	92
JEC unit 3 (a)	May 1983	703,393		282,481		1,000		664	92
Wolf Creek (b)	Sept. 1985	1,524,831		756,218		99,357		547	47
State Line (c)	June 2001	114,093		49,099		34		201	40
Total		$	3,701,688	$	1,623,475	$	366,604	3,099

_______________


(a)	Jointly owned with KCPL. Our 8% leasehold interest in JEC that is consolidated as a VIE is reflected in the net megawatts (MW) and ownership percentage provided above, but not in the other amounts in the table.


(b)	Jointly owned with KCPL and Kansas Electric Power Cooperative, Inc.

We include in operating expenses on our consolidated statements of income our share of operating expenses of the above plants. Our share of fuel expense for the above plants is generally based on the amount of power we take from the respective plants. Our share of other transactions associated with the plants is included in the appropriate classification on our consolidated financial statements.

In addition, we also consolidate a VIE that holds our 50% leasehold interest in La Cygne unit 2, which represents 343 MW of net capacity. The VIE's investment in the 50% interest was $392.1 million and accumulated depreciation was $180.2 million as of December 31, 2012. We include these amounts in property, plant and equipment of variable interest entities, net on our consolidated balance sheets. See Note 17, "Variable Interest Entities," for additional information about VIEs.

Short-Term Debt

12 Months Ended

Dec. 31, 2012

Debt Disclosure [Abstract]

Short-Term Debt

SHORT-TERM DEBT

In 2011 Westar Energy entered into a commercial paper program pursuant to which it may issue commercial paper up to a maximum aggregate amount outstanding at any one time of $1.0 billion. This program is supported by Westar Energy's revolving credit facilities described below. Maturities of commercial paper issuances may not exceed 365 days from the date of issuance and proceeds from such issuances will be used to temporarily fund capital expenditures, to repay borrowings under Westar Energy's revolving credit facilities, for working capital and/or for other general corporate purposes. As of December 31, 2012, Westar Energy had issued $339.2 million of commercial paper. Westar Energy had no commercial paper outstanding as of December 31, 2011.

In September 2011, Westar Energy refinanced its existing $730.0 million revolving credit facility with a new facility in the same amount. The commitments under the new facility terminate in September 2016. As long as there is no default under the facility, Westar Energy may extend the facility up to an additional two years and may increase the aggregate amount of borrowings under the facility to $1.0 billion, both subject to lender participation. All borrowings under the facility are secured by KGE first mortgage bonds. As of December 31, 2012, no amounts had been borrowed and $13.8 million of letters of credit had been issued under this revolving credit facility. As of December 31, 2011, $286.3 million had been borrowed and an additional $12.2 million of letters of credit had been issued under this revolving credit facility.

In February 2011, Westar Energy entered into a revolving credit facility with a syndicate of banks for $270.0 million. In February 2013, Westar Energy extended this facility by one year. This facility now terminates in February 2016. As long as there is no default under the facility, Westar Energy may extend the facility one additional year and may increase the aggregate amount of borrowings under the facility to $400.0 million, both subject to lender participation. All borrowings under the facility are secured by KGE first mortgage bonds. As of December 31, 2012 and 2011, Westar Energy had no borrowed amounts or letters of credit outstanding under this revolving credit facility.

In addition, total combined borrowings under Westar Energy's commercial paper program and revolving credit facilities may not exceed $1.0 billion at any given time. The weighted average interest rate on short-term borrowings was 0.46% and 1.49% as of December 31, 2012 and 2011, respectively. Additional information regarding our short-term debt is as follows.



	As of December 31,
	2012			2011
	(Dollars in Thousands)

Weighted average short-term debt outstanding during the year	$	298,907		$	362,946
Weighted daily average interest rates during the year, excluding fees	0.55		%	0.82		%

Our interest expense on short-term debt was $3.2 million in 2012, $3.9 million in 2011 and $1.9 million in 2010.

Long-term Debt, Unclassified [Abstract]

The entire disclosure for short-term debt.

+ References+ Details

Long-Term Debt

12 Months Ended

Dec. 31, 2012

Long-term Debt

LONG-TERM DEBT

Outstanding Debt

The following table summarizes our long-term debt outstanding.



	As of December 31,
	2012			2011
	(In Thousands)
Westar Energy
First mortgage bond series:
6.00% due 2014	$	250,000		$	250,000
5.15% due 2017	125,000			125,000
5.95% due 2035	125,000			125,000
5.10% due 2020	250,000			250,000
5.875% due 2036	150,000			150,000
6.10% due 2047	—			150,000
8.625% due 2018	300,000			300,000
4.125% due 2042	550,000			—
	1,750,000			1,350,000
Pollution control bond series:
Variable due 2032, 0.32% as of December 31, 2012; 0.22% as of December 31, 2011	45,000			45,000
Variable due 2032, 0.26% as of December 31, 2012; 0.24% as of December 31, 2011	30,500			30,500
5.00% due 2033	—			57,245
	75,500			132,745

KGE
First mortgage bond series:
6.53% due 2037	175,000			175,000
6.15% due 2023	50,000			50,000
6.64% due 2038	100,000			100,000
6.70% due 2019	300,000			300,000
	625,000			625,000
Pollution control bond series:
5.10% due 2023	—			13,318
Variable due 2027, 0.26% as of December 31, 2012; 0.28% as of December 31, 2011	21,940			21,940
5.30% due 2031	108,600			108,600
5.30% due 2031	18,900			18,900
Variable due 2032, 0.26% as of December 31, 2012; 0.28% as of December 31, 2011	14,500			14,500
Variable due 2032, 0.26% as of December 31, 2012; 0.28% as of December 31, 2011	10,000			10,000
4.85% due 2031	50,000			50,000
5.60% due 2031	50,000			50,000
6.00% due 2031	50,000			50,000
5.00% due 2031	50,000			50,000
	373,940			387,258

Total long-term debt	2,824,440			2,495,003
Unamortized debt discount (a)	(5,169		)	(3,894		)
Long-term debt due within one year	—			—
Long-term debt, net	$	2,819,271		$	2,491,109

Variable Interest Entities
7.77% due 2012 (b)	$	—		$	2,583
6.99% due 2014 (b)	866			2,094
5.92 % due 2019 (b)	17,630			22,748
5.647% due 2021 (b)	229,128			248,313
Total long-term debt of variable interest entities	247,624			275,738
Unamortized debt premium (a)	1,061			1,659
Long-term debt of variable interest entities due within one year	(25,942		)	(28,114		)
Long-term debt of variable interest entities, net	$	222,743		$	249,283

_______________

(a) We amortize debt discounts and premiums to interest expense over the term of the respective issues.

(b) Portions of our payments related to this debt reduce the principal balances each year until maturity.

The Westar Energy and KGE mortgages each contain provisions restricting the amount of first mortgage bonds that could be issued by each entity. We must comply with such restrictions prior to the issuance of additional first mortgage bonds or other secured indebtedness.

The amount of Westar Energy first mortgage bonds authorized by its Mortgage and Deed of Trust, dated July 1, 1939, as supplemented, is subject to certain limitations as described below. The amount of KGE first mortgage bonds authorized by the KGE Mortgage and Deed of Trust, dated April 1, 1940, as supplemented and amended, is limited to a maximum of $3.5 billion, unless amended further. First mortgage bonds are secured by utility assets. Amounts of additional bonds that may be issued are subject to property, earnings and certain restrictive provisions, except in connection with certain refundings, of each mortgage. As of December 31, 2012, approximately $830.0 million principal amount of additional first mortgage bonds could be issued under the most restrictive provisions in Westar Energy's mortgage, except in connection with certain refundings. As of December 31, 2012, approximately $870.0 million principal amount of additional KGE first mortgage bonds could be issued under the most restrictive provisions in KGE's mortgage.

As of December 31, 2012, we had $121.9 million of variable rate, tax-exempt bonds. While the interest rates for these bonds have been extremely low, we continue to monitor the credit markets and evaluate our options with respect to these bonds.

In May 2012, Westar Energy issued $300.0 million principal amount of first mortgage bonds at a discount yielding 4.157%, bearing stated interest at 4.125% and maturing in March 2042. These bonds constitute a further issuance of a series of bonds initially issued in March 2012 in the principal amount of $250.0 million, at a discount yielding 4.13%, bearing stated interest at 4.125% and maturing in March 2042. Proceeds from these issuances of $541.4 million were used to repay short-term debt, which was used to purchase capital equipment, to redeem bonds, and for working capital and general corporate purposes.

In May 2012, Westar Energy redeemed $150.0 million aggregate principal amount of 6.10% first mortgage bonds. Additionally, in March 2012 Westar Energy redeemed $57.2 million aggregate principal amount of 5.00% pollution control bonds and KGE redeemed $13.3 million aggregate principal amount of 5.10% pollution control bonds. The bonds were redeemed using short-term debt.

Debt Covenants

Some of our debt instruments contain restrictions that require us to maintain leverage ratios as defined in the credit agreements. We calculate these ratios in accordance with the agreements and they are used to determine compliance with our various debt covenants. We were in compliance with these covenants as of December 31, 2012.

Maturities

The principal amounts of our long-term debt maturities as of December 31, 2012, are as follows.



Year	Long-term debt		Long-term debt of VIEs
	(In Thousands)
2013	$	—	$	25,942
2014	250,000		27,479
2015	—		27,933
2016	—		28,309
2017	125,000		26,842
Thereafter	2,449,440		111,119
Total maturities	$	2,824,440	$	247,624

Interest expense on long-term debt was $145.6 million in 2012, $142.6 million in 2011 and $144.1 million in 2010. Interest expense on long-term debt of VIEs was $15.1 million in 2012, $16.8 million in 2011 and $18.7 million in 2010.

Taxes

12 Months Ended

Dec. 31, 2012

Income Tax Disclosure [Abstract]

Taxes

TAXES

Income tax expense is comprised of the following components.



	Year Ended December 31,
	2012			2011			2010
	(In Thousands)
Income Tax Expense (Benefit):
Current income taxes:
Federal	$	(691	)	$	(8,575	)	$	(32,107	)
State	579			196			(3,030		)
Deferred income taxes:
Federal	102,960			93,089			102,568
State	26,300			21,337			20,305
Investment tax credit amortization	(3,012		)	(2,703		)	(2,704		)
Income tax expense	$	126,136		$	103,344		$	85,032

Deferred tax assets and liabilities are reflected on our consolidated balance sheets as follows.



	As of December 31,
	2012		2011
	(In Thousands)
Other current liabilities (assets)	$	8,654	$	(394	)
Non-current deferred tax liabilities	1,197,837		1,110,463
Deferred tax liabilities	$	1,206,491	$	1,110,069

The tax effect of the temporary differences and carryforwards that comprise our deferred tax assets and deferred tax liabilities are summarized in the following table.



	As of December 31,
	2012		2011
	(In Thousands)
Deferred tax assets:
Tax credit carryforward (a)	$	199,160	$	159,163
Deferred employee benefit costs	191,997		202,687
Net operating loss carryforward (b)	111,869		84,365
Deferred state income taxes	55,577		42,209
Deferred regulatory gain on sale-leaseback	40,543		42,962
Alternative minimum tax carryforward (c)	36,471		36,471
Deferred compensation	28,319		28,286
Accrued liabilities	15,969		16,912
Disallowed costs	12,083		12,717
Capital loss carryforward (d)	11,509		12,554
Other	20,897		13,031
Total gross deferred tax assets	724,394		651,357
Less: Valuation allowance (e)	13,812		13,712
Deferred tax assets	$	710,582	$	637,645

Deferred tax liabilities:
Accelerated depreciation	$	1,255,892	$	1,088,727
Deferred employee benefit costs	191,997		202,687
Acquisition premium	179,920		187,934
Amounts due from customers for future income taxes, net	169,091		168,804
Deferred state income taxes	50,134		39,512
Pension expense tracker	22,437		14,600
Debt reacquisition costs	22,313		21,683
Storm costs	4,373		10,176
Other	20,916		13,591
Total deferred tax liabilities	$	1,917,073	$	1,747,714

Net deferred tax liabilities	$	1,206,491	$	1,110,069

_______________

(a)

Based on filed tax returns and amounts expected to be reported in current year tax returns (December 31, 2012), we had available federal general business tax credits of $39.3 million and state investment tax credits of $159.8 million. The federal general business tax credits were primarily generated from affordable housing partnerships in which we sold the majority of our interests in 2001. These tax credits expire beginning in 2020 and ending in 2032. The state investment tax credits expire beginning in 2013 and ending in 2028. As we do not expect to realize sufficient state taxable income in 2013, a valuation allowance of $1.3 million has been established for the state investment tax credits that expire in 2013 (see item (e) below).


(b)	As of December 31, 2012, we had a federal net operating loss carryforward of $276.9 million, which is available to offset federal taxable income. The net operating losses will expire beginning in 2030 and ending in 2032.


(c)	As of December 31, 2012, we had available an alternative minimum tax credit carryforward of $36.5 million, which has an unlimited carryforward period.


(d)	As of December 31, 2012, we had an unused capital loss carryforward of $29.1 million that is available to offset future capital gains. The capital losses will expire beginning in 2013 and ending in 2016.

(e)

As we do not expect to realize any significant capital gains in the future, we have established a valuation allowance of $11.5 million. In addition, we have established a valuation allowance of $2.3 million for certain deferred tax assets related to the write-down of other investments and state investment tax credits. The total valuation allowance related to the deferred tax assets was $13.8 million as of December 31, 2012, and $13.7 million as of December 31, 2011.

In accordance with various orders, we have reduced our prices to reflect the income tax benefits associated with certain accelerated income tax deductions. We believe it is probable that the net future increases in income taxes payable will be recovered from customers when these temporary income tax benefits reverse. We have recorded a regulatory asset for these amounts. We also have recorded a regulatory liability for our obligation to reduce the prices charged to customers for deferred income taxes recovered from customers at corporate income tax rates higher than current income tax rates. The price reduction will occur as the temporary differences resulting in the excess deferred income tax liabilities reverse. The income tax-related regulatory assets and liabilities as well as unamortized investment tax credits are also temporary differences for which deferred income taxes have been provided. The net deferred income tax liability related to these temporary differences is classified above as amounts due from customers for future income taxes, net.

Our effective income tax rates are computed by dividing total federal and state income taxes by the sum of such taxes and net income. The difference between the effective income tax rates and the federal statutory income tax rates are as follows.



	Year Ended December 31,
	2012		2011		2010
Statutory federal income tax rate	35.0	%	35.0	%	35.0	%
Effect of:
Corporate-owned life insurance policies	(4.9	)	(4.5	)	(6.1	)
State income taxes	4.3		4.1		3.8
Production tax credits	(2.4	)	(2.9	)	(3.4	)
Flow through depreciation for plant-related differences	1.4		1.8		2.6
AFUDC equity	(1.0	)	(0.6	)	(0.4	)
Amortization of federal investment tax credits	(0.7	)	(0.8	)	(0.9	)
Capital loss utilization	(0.3	)	(0.5	)	(0.7	)
Liability for unrecognized income tax benefits	0.2		—		(0.2	)
Other	(0.7	)	(1.2	)	(0.7	)
Effective income tax rate	30.9	%	30.4	%	29.0	%

We file income tax returns in the U.S. federal jurisdiction as well as various state and foreign jurisdictions. The income tax returns we file will likely be audited by the Internal Revenue Service (IRS) or other tax authorities. With few exceptions, the statute of limitations with respect to U.S. federal, state and local, or non-U.S. income tax examinations by tax authorities remains open for tax year 2008 and forward.

In the first and second quarters of 2011, the IRS completed its separate examinations of our federal income tax returns filed for tax years 2008 and 2009, respectively, without significant changes.

In May 2012, the IRS commenced an examination of our 2010 federal income tax return and the amended federal income tax returns we filed for years 2007, 2008 and 2009. The examination was completed in January 2013 and resulted in a refund which is subject to formal review and approval by the IRS and the Joint Committee on Taxation of the U.S. Congress. The examination results will not have a significant impact on our consolidated statements of income or cash flows. We believe that it is reasonably possible that the administrative reviews will be completed in 2013.

The liability for unrecognized income tax benefits decreased from $2.5 million at December 31, 2011, to $1.2 million at December 31, 2012. The net decrease in the liability for unrecognized income tax benefits resulted from the reversal of a liability for unrecognized income tax benefits related to the capitalization of plant expenditures. The reversal was based on additional IRS guidance regarding deduction and capitalization of expenditures related to tangible property. We do not expect significant changes in the liability for unrecognized income tax benefits in the next 12 months. A reconciliation of the beginning and ending amounts of unrecognized income tax benefits is as follows:



	2012			2011			2010
	(In Thousands)
Liability for unrecognized income tax benefits as of January 1	$	2,483		$	1,888		$	8,357
Additions based on tax positions related to the current year	373			967			608
Additions for tax positions of prior years	—			939			2,323
Reductions for tax positions of prior years	(1,637		)	(563		)	(1,241		)
Settlements	—			(748		)	(8,159		)
Liability for unrecognized income tax benefits as of December 31	$	1,219		$	2,483		$	1,888

The liability for unrecognized income tax benefits, as disclosed above, is net of reductions to deferred tax assets for tax loss and credit carryforwards of $0.3 million, $0.2 million and $1.0 million as of December 31, 2012, 2011 and 2010, respectively. The amounts of unrecognized income tax benefits that, if recognized, would favorably impact our effective income tax rate, were $2.0 million, $1.2 million and $1.3 million (net of tax) as of December 31, 2012, 2011 and 2010, respectively.

Interest related to income tax uncertainties is classified as interest expense and accrued interest liability. During 2011 and 2010, we reversed interest expense previously recorded for income tax uncertainties of $0.2 million and $1.0 million, respectively. As of December 31, 2012 and 2011, we had $0.2 million accrued for interest on our liability related to unrecognized income tax benefits. We accrued no penalties at either December 31, 2012, or December 31, 2011.

As of December 31, 2012 and 2011, we had recorded $1.5 million for probable assessments of taxes other than income taxes.

The entire disclosure for income taxes. Disclosures may 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.

Compensation and Retirement Disclosure [Abstract]

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

-Topic 740

-SubTopic 10

-Section 50

-Paragraph 15

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-Name Accounting Standards Codification

-Topic 235

-SubTopic 10

-Section S99

-Paragraph 1

-Subparagraph (SX 210.4-08.(h))

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-Name Regulation S-X (SX)

-Number 210

-Section 08

-Paragraph h

-Article 4

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-Name Accounting Standards Codification

-Topic 740

-SubTopic 10

-Section 50

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-Name Accounting Standards Codification

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-Section 50

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-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 109

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef

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-Name Statement of Financial Accounting Standard (FAS)

-Number 109

-Paragraph 43, 44, 45, 46, 47, 48, 49

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Employee Benefit Plans

12 Months Ended

Dec. 31, 2012

Employee Benefit Plans

EMPLOYEE BENEFIT PLANS

Pension and Post-Retirement Benefit Plans

We maintain a qualified non-contributory defined benefit pension plan covering substantially all of our employees. For the majority of our employees, pension benefits are based on years of service and an employee's compensation during the 60 highest paid consecutive months out of 120 before retirement. Non-union employees hired after December 31, 2001, and union employees hired after December 31, 2011, are covered by the same defined benefit pension plan; however, their benefits are derived from a cash balance account formula. We also maintain a non-qualified Executive Salary Continuation Plan for the benefit of certain current and retired executive officers. With the exception of one current executive officer, we have discontinued accruing any future benefits under this non-qualified plan.

The amount we contribute to our pension plan for future periods is not yet known, however, we expect to fund our pension plan each year at least to a level equal to current year pension expense. We must also meet minimum funding requirements under the Employee Retirement Income Security Act, as amended by the Pension Protection Act. We may contribute additional amounts from time to time as deemed appropriate.

In addition to providing pension benefits, we provide certain post-retirement health care and life insurance benefits for substantially all retired employees. We accrue and recover in our prices the costs of post-retirement benefits during an employee's years of service. We fund the portion of net periodic costs for post-retirement benefits included in our prices.

As a co-owner of Wolf Creek, KGE is indirectly responsible for 47% of the liabilities and expenses associated with the Wolf Creek pension and post-retirement benefit plans. See Note 12, "Wolf Creek Employee Benefit Plans," for information about Wolf Creek's benefit plans.

The following tables summarize the status of our pension and post-retirement benefit plans.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	876,308		$	747,460		$	150,078		$	137,759
Service cost	19,556			16,076			2,057			1,803
Interest cost	39,576			40,045			6,298			6,793
Plan participants’ contributions	—			—			2,987			3,390
Benefits paid (a)	(60,229		)	(31,107		)	(9,799		)	(10,114		)
Actuarial losses (gains)	53,497			94,161			943			5,246
Amendments	—			—			—			4,451
Other (b)	—			9,673			—			750
Benefit obligation, end of year (c)	$	928,708		$	876,308		$	152,564		$	150,078

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	481,077		$	432,233		$	91,858		$	86,984
Actual return on plan assets	67,328			27,819			10,673			(174		)
Employer contributions	56,700			50,000			10,803			10,793
Plan participants’ contributions	—			—			2,845			3,244
Benefits paid (a)	(57,174		)	(28,975		)	(9,386		)	(9,739		)
Other (b)	—			—			—			750
Fair value of plan assets, end of year	$	547,931		$	481,077		$	106,793		$	91,858

Funded status, end of year	$	(380,777	)	$	(395,231	)	$	(45,771	)	$	(58,220	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(2,870	)	$	(2,741	)	$	(298	)	$	(115	)
Noncurrent liability	(377,907		)	(392,490		)	(45,473		)	(58,105		)
Net amount recognized	$	(380,777	)	$	(395,231	)	$	(45,771	)	$	(58,220	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	383,365		$	397,691		$	12,436		$	18,178
Prior service cost	3,994			4,606			16,467			18,991
Transition obligation	—			—			325			4,236
Net amount recognized	$	387,359		$	402,297		$	29,228		$	41,405

_______________


(a)	In 2012 certain former employees received a one-time lump sum payment of their pension benefits totaling $26.1 million.


(b)	As of December 31, 2011, Other includes the $9.7 million reclassification of a contractual obligation related to the legal settlement with a former executive officer and $0.8 million of proceeds received as a result of the Early Retiree Reinsurance Program.

(c)

As of December 31, 2012 and 2011, pension benefits include non-qualified benefit obligations of $30.0 million and $29.4 million, respectively, which are funded by a trust containing assets of $43.5 million and $40.2 million, respectively, classified as trading securities as discussed in Notes 4 and 5, "Financial and Derivative Instruments, Trading Securities, Energy marketing and Risk Management" and "Financial Investments," respectively.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	928,708		$	876,308		$	—		$	—
Fair value of plan assets	547,931			481,077			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	806,888		$	750,263		—			—
Fair value of plan assets	547,931			481,077			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	—			—			$	152,564		$	150,078
Fair value of plan assets	—			—			106,793			91,858

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	4.13		%	4.50		%	3.99		%	4.25		%
Compensation rate increase	4.00		%	4.00		%	—			—

We use a measurement date of December 31 for our pension and post-retirement benefit plans. The discount rate used to determine the current year pension obligation and the following year's pension expense is based on a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality, non-callable corporate bonds that generate sufficient cash flow to provide for the projected benefit payments of the plan. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plan's projected benefit payments discounted at this rate with the market value of the bonds selected.

We amortize prior service cost (benefit) on a straight-line basis over the average future service of the active employees (plan participants) benefiting under the plan at the time of the amendment. We amortize the net actuarial gain or loss on a straight-line basis over the average future service of active plan participants benefiting under the plan without application of an amortization corridor. The KCC allows us to us to record a regulatory asset or liability to track the cumulative difference between current year pension and post-retirement benefits expense and the amount of such expense recognized in setting our prices. We accumulate such regulatory asset or liability between general rate reviews and amortize the accumulated amount as part of resetting our base prices. Following is additional information regarding our pension and post-retirement benefit plans.



	Pension Benefits									Post-retirement Benefits
Year Ended December 31,	2012			2011			2010			2012			2011			2010
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	19,556		$	16,076		$	13,926		$	2,057		$	1,803		$	1,526
Interest cost	39,576			40,045			39,391			6,298			6,793			7,083
Expected return on plan assets	(32,283		)	(31,087		)	(38,384		)	(5,491		)	(5,002		)	(5,197		)
Amortization of unrecognized:
Transition obligation, net	—			—			—			3,912			3,911			3,912
Prior service costs	612			1,213			2,729			2,524			2,524			2,154
Actuarial loss/(gain), net	32,778			23,659			17,183			1,503			702			321
Net periodic cost before regulatory adjustment	60,239			49,906			34,845			10,803			10,731			9,799
Regulatory adjustment (a)	(6,523		)	(22,098		)	(12,167		)	23			1,344			1,868
Net periodic cost	$	53,716		$	27,808		$	22,678		$	10,826		$	12,075		$	11,667

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	18,451		$	97,429		$	65,690		$	(4,239	)	$	10,421		$	3,298
Amortization of actuarial (loss)/gain	(32,778		)	(23,659		)	(17,183		)	(1,503		)	(702		)	(321		)
Current year prior service cost	—			—			676			—			4,451			—
Amortization of prior service costs	(612		)	(1,213		)	(2,729		)	(2,524		)	(2,524		)	(2,154		)
Amortization of transition obligation	—			—			—			(3,912		)	(3,911		)	(3,912		)
Total recognized in regulatory assets	$	(14,939	)	$	72,557		$	46,454		$	(12,178	)	$	7,735		$	(3,089	)

Total recognized in net periodic cost and regulatory assets	$	38,777		$	100,365		$	69,132		$	(1,352	)	$	19,810		$	8,578

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost (Benefit):
Discount rate	4.50		%	5.35		%	5.95		%	4.25		%	5.00		%	5.65		%
Expected long-term return on plan assets	6.50		%	6.50		%	8.25		%	6.00		%	6.00		%	7.75		%
Compensation rate increase	4.00		%	4.00		%	4.00		%	—			—			—

_______________


(a)	The regulatory adjustment represents the difference between current period pension or post-retirement benefit expense and the amount of such expense recognized in setting our prices.

We estimate that we will amortize the following amounts from regulatory assets into net periodic cost in 2013.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss	$	33,914	$	1,125
Prior service cost	601		2,524
Transition obligation	—		325
Total	$	34,515	$	3,974

We base the expected long-term rate of return on plan assets on historical and projected rates of return for current and planned asset classes in the plans' investment portfolios. We select assumed projected rates of return for each asset class after analyzing long-term historical experience and future expectations of the volatility of the various asset classes. Based on target asset allocations for each asset class, we develop an overall expected rate of return for the portfolios, adjusted for historical and expected experience of active portfolio management results compared to benchmark returns and for the effect of expenses paid from plan assets.

For measurement purposes, the assumed annual health care cost growth rates were as follows.



	As of December 31,
	2012	2011
Health care cost trend rate assumed for next year	8.0%	8.0%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.0%	5.0%

Year that the rate reaches the ultimate trend rate	2019	2018

The health care cost trend rate affects the projected benefit obligation. A 1% change in assumed health care cost growth rates would have effects shown in the following table.



	One-Percentage- Point Increase		One-Percentage- Point Decrease
	(In Thousands)
Effect on total of service and interest cost	$	67	$	(64	)
Effect on post-retirement benefit obligation	1,489		(1,384		)

Plan Assets

We manage pension and post-retirement benefit plan assets in a prudent manner with regard to preserving principal while providing reasonable returns. We have adopted a long-term investment horizon such that the chances and duration of investment losses are carefully weighed against the long-term potential for appreciation of assets. Part of our strategy includes managing interest rate sensitivity of plan assets relative to the associated liabilities. The primary objective of the pension plan is to provide a source of retirement income for its participants and beneficiaries, and the primary financial objective of the plan is to improve its funded status. The primary objective of the post-retirement benefit plan is growth in assets and preservation of principal, while minimizing interim volatility, to meet anticipated claims of plan participants. We delegate the management of our pension and post-retirement benefit plan assets to independent investment advisors who hire and dismiss investment managers based upon various factors. The investment advisors strive to diversify investments across asset classes, sectors and manager styles to minimize the risk of large losses, based upon objectives and risk tolerance specified by management, which include allowable and/or prohibited investment types. We measure and monitor investment risk on an ongoing basis through quarterly investment portfolio reviews and annual liability measurements.

As noted above, we have established certain prohibited investments for our pension and post-retirement benefit plans. Such prohibited investments include loans to the company or its officers and directors as well as investments in the company's debt or equity securities, except as may occur indirectly through investments in diversified mutual funds. In addition, to reduce concentration of risk, the pension plan will not invest in any fund that holds more than 25% of its total assets to be invested in the securities of one or more issuers conducting their principal business activities in the same industry. This restriction does not apply to investments in securities issued or guaranteed by the U.S. government or its agencies.

The target allocations for our pension plan assets are about 44% to debt securities, 42% to equity securities and the remaining 14% to other investments such as real estate securities, hedge funds and private equity investments. Our investments in equity include investment funds with underlying investments in domestic and foreign large-, mid- and small-cap companies, derivatives related to such holdings, private equity investments including late-stage venture investments and other investments. Our investments in debt include core and high-yield bonds. Core bonds are comprised of investment funds with underlying investments in investment grade debt securities of corporate entities, obligations of U.S. and foreign governments and their agencies, and other debt securities. High-yield bonds include investment funds with underlying investments in non-investment grade debt securities of corporate entities, obligations of foreign governments and their agencies, private debt securities and other debt securities. Real estate securities consist primarily of funds invested in core real estate throughout the U.S. while alternative funds invest in wide ranging investments including equity and debt securities of domestic and foreign corporations, debt securities issued by U.S. and foreign governments and their agencies, structured debt, warrants, exchange-traded funds, derivative instruments, private investment funds and other investments.

The target allocations for our post-retirement benefit plan assets are 65% to equity securities and 35% to debt securities. Our investments in equity securities include investment funds with underlying investments primarily in domestic and foreign large-, mid- and small-cap companies. Our investments in debt securities include a core bond fund with underlying investments in investment grade debt securities of domestic and foreign corporate entities, obligations of U.S. and foreign governments and their agencies, private placement securities and other investments.

Similar to other assets measured at fair value, GAAP establishes a hierarchal framework for disclosing the transparency of the inputs utilized in measuring pension and post-retirement benefit plan assets at fair value. From time to time, the pension and post-retirement benefits trusts may buy and sell investments resulting in changes within the hierarchy. See Note 4, "Financial and Derivative Instruments, Trading Securities, Energy Marketing and Risk Management," for a description of the hierarchal framework.

All level 2 pension investments are held in investment funds that are measured at fair value using daily net asset values as reported by the trustee, except for $35.6 million as of December 31, 2012, invested directly in long-term U.S. Treasury securities. We also maintain certain level 3 investments in private equity, real estate securities and alternative funds that require significant unobservable market information to measure the fair value of the investments. The fair value of private equity investments is measured by utilizing both market- and income-based models, public company comparables, at cost or at the value derived from subsequent financings. Adjustments are made when actual performance differs from expected performance; when market, economic or company-specific conditions change; and when other news or events have a material impact on the security. To measure the fair value of real estate securities we use a combination of market- and income-based models utilizing market discount rates, projected cash flows and the estimated value into perpetuity. Alternative funds are measured at fair value using net asset values as reported by the alternative fund managers. Since the underlying assets in alternative funds vary widely various methods are required, often utilizing significant management judgment.

The following table provides the fair value of our pension plan assets and the corresponding level of hierarchy as of December 31, 2012 and 2011.



As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	129,501	$	18,493	$	147,994
International equity	—		67,743		—		67,743
Core bonds	—		178,784		—		178,784
High-yield bonds	—		19,070		—		19,070
Emerging market bonds	—		14,276		—		14,276
Combination debt/equity fund	—		50,750		—		50,750
Real estate securities	—		—		20,927		20,927
Alternative funds	—		—		45,535		45,535
Cash equivalents	—		2,852		—		2,852
Total Assets Measured at Fair Value	$	—	$	462,976	$	84,955	$	547,931

As of December 31, 2011
Assets:
Domestic equity	$	—	$	121,364	$	15,375	$	136,739
International equity	—		53,943		—		53,943
Core bonds	—		142,700		—		142,700
High-yield bonds	—		38,380		—		38,380
Combination debt/equity fund	—		47,151		—		47,151
Real estate securities	—		—		18,848		18,848
Alternative funds	—		—		40,716		40,716
Cash equivalents	—		2,600		—		2,600
Total Assets Measured at Fair Value	$	—	$	406,138	$	74,939	$	481,077

The following table provides a reconciliation of pension plan assets measured at fair value using significant level 3 inputs for the years ended December 31, 2012 and 2011.



	Domestic Equity			High-yield Bonds			Real Estate Securities			Alternative Funds			Total
	(In Thousands)
Balance as of December 31, 2011	$	15,375		$	—		$	18,848		$	40,716		$	74,939
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	(25		)	—			2,296			4,819			7,090
Relating to assets sold during the period	53			—			(27		)	—			26
Purchases, issuances and settlements, net	3,090			—			(190		)	—			2,900
Balance as of December 31, 2012	$	18,493		$	—		$	20,927		$	45,535		$	84,955

Balance as of December 31, 2010	$	11,575		$	1,200		$	16,411		$	25,764		$	54,950
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	1,910			—			2,652			(48		)	4,514
Relating to assets sold during the period	—			—			(49		)	—			(49		)
Purchases, issuances and settlements, net	1,890			(1,200		)	(166		)	15,000			15,524
Balance as of December 31, 2011	$	15,375		$	—		$	18,848		$	40,716		$	74,939

The following table provides the fair value of our post-retirement benefit plan assets and the corresponding level of hierarchy as of December 31, 2012 and 2011.



As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	55,441	$	—	$	55,441
International equity	—		14,037		—		14,037
Core bonds	—		36,738		—		36,738
Cash equivalents	—		577		—		577
Total Assets Measured at Fair Value	$	—	$	106,793	$	—	$	106,793

As of December 31, 2011

Assets:
Domestic equity	$	—	$	47,411	$	—	$	47,411
International equity	—		11,500		—		11,500
Core bonds	—		32,192		—		32,192
Cash equivalents	—		755		—		755
Total Assets Measured at Fair Value	$	—	$	91,858	$	—	$	91,858

Cash Flows

The following table shows the expected cash flows for our pension and post-retirement benefit plans for future years.



Expected Cash Flows	Pension Benefits						Post-retirement Benefits
	To/(From) Trust			(From) Company Assets			To/(From) Trust			(From) Company Assets
	(In Millions)
Expected contributions:
2013	$	30.0					$	6.0

Expected benefit payments:
2013	$	(31.3	)	$	(2.9	)	$	(7.9	)	$	(0.3	)
2014	(33.3		)	(2.8		)	(8.3		)	(0.3		)
2015	(35.3		)	(2.8		)	(8.8		)	(0.3		)
2016	(38.0		)	(2.8		)	(9.1		)	(0.3		)
2017	(41.1		)	(2.8		)	(9.5		)	(0.3		)
2018 - 2022	(247.1		)	(13.0		)	(49.6		)	(1.2		)

Savings Plans

We maintain a qualified 401(k) savings plan in which most of our employees participate. We match employees' contributions in cash up to specified maximum limits. Our contributions to the plans are deposited with a trustee and invested at the direction of plan participants into one or more of the investment alternatives we provide under the plan. Our contributions totaled $7.1 million in 2012, $7.0 million in 2011 and $7.4 million in 2010.

Stock-Based Compensation Plans

We have a long-term incentive and share award plan (LTISA Plan), which is a stock-based compensation plan in which employees and directors are eligible for awards. The LTISA Plan was implemented as a means to attract, retain and motivate employees and directors. Under the LTISA Plan, we may grant awards in the form of stock options, dividend equivalents, share appreciation rights, RSUs, performance shares and performance share units to plan participants. In May 2011, Westar Energy shareholders approved an increase in the number of shares of common stock that may be granted under the LTISA Plan to 8.25 million shares from 5.0 million shares. As of December 31, 2012, awards of approximately 4.8 million shares of common stock had been made under the plan.

All stock-based compensation is measured at the grant date based on the fair value of the award and is recognized as an expense in the consolidated statement of income over the requisite service period. The requisite service periods range from one to ten years. The table below shows compensation expense and income tax benefits related to stock-based compensation arrangements that are included in our net income.



	Year Ended December 31,
	2012		2011		2010
	(In Thousands)
Compensation expense	$	7,203	$	8,367	$	11,321
Income tax benefits related to stock-based compensation arrangements	2,849		3,309		4,481

We use RSU awards for our stock-based compensation awards. RSU awards are grants that entitle the holder to receive shares of common stock as the awards vest. These RSU awards are defined as nonvested shares and do not include restrictions once the awards have vested. In 2011, outstanding RSUs with only service requirements previously awarded to our former chief executive officer that were subject to forfeiture were modified to provide for the vesting upon his retirement in July 2011 of a prorated number of the RSUs based on the number of days from the grant date of the RSUs to his retirement date. In addition, outstanding RSUs with performance measures previously awarded to our former chief executive officer were modified to provide for the vesting on the scheduled vesting date, subject to the satisfaction of the applicable performance criteria, of a prorated number of the target RSUs based on the number of days from the grant date of the RSUs to his retirement date. We recorded compensation expense of $2.8 million in 2011 related to these modifications.

RSU awards with only service requirements vest solely upon the passage of time. We measure the fair value of these RSU awards based on the market price of the underlying common stock as of the grant date. RSU awards with only service conditions that have a graded vesting schedule are recognized as an expense in the consolidated statement of income on a straight-line basis over the requisite service period for the entire award. Nonforfeitable dividend equivalents, or the rights to receive cash equal to the value of dividends paid on Westar Energy's common stock, are paid on these RSUs during the vesting period.

RSU awards with performance measures vest upon expiration of the award term. The number of shares of common stock awarded upon vesting will vary from 0% to 200% of the RSU award, with performance tied to our total shareholder return relative to the total shareholder return of our peer group. We measure the fair value of these RSU awards using a Monte Carlo simulation technique that uses the closing stock price at the valuation date and incorporates assumptions for inputs of the expected volatility and risk-free interest rates. Expected volatility is based on historical volatility over three years using daily stock price observations. The risk-free interest rate is based on treasury constant maturity yields as reported by the Federal Reserve and the length of the performance period. For the 2012 valuation, inputs for expected volatility ranged from 17.6% to 33.6% and the risk-free interest rate was approximately 0.4%. For the 2011 valuation, inputs for expected volatility and risk-free interest rates ranged from 24.5% to 28.5% and 0.1% to 1.3%, respectively. For these RSU awards, dividend equivalents accumulate over the vesting period and are paid in cash based on the number of shares of common stock awarded upon vesting.

During the years ended December 31, 2012, 2011 and 2010, our RSU activity for awards with only service requirements was as follows:



	As of December 31,
	2012				2011				2010
	Shares		Weighted- Average Grant Date Fair Value		Shares		Weighted- Average Grant Date Fair Value		Shares		Weighted- Average Grant Date Fair Value
	(Shares In Thousands)
Nonvested balance, beginning of year	368.5		$	23.83	600.4		$	21.50	368.8		$	21.98
Granted	131.0		27.82		284.1		26.30		366.4		22.14
Vested	(127.8	)	23.34		(187.3	)	23.50		(118.1	)	24.81
Forfeited	(20.6	)	24.40		(328.7	)	24.37		(16.7	)	22.32
Nonvested balance, end of year	351.1		25.47		368.5		23.83		600.4		21.50

Total unrecognized compensation cost related to RSU awards with only service requirements was $4.2 million as of December 31, 2012. We expect to recognize these costs over a remaining weighted-average period of 1.7 years. The total fair value of RSUs with only service requirements that vested during the years ended December 31, 2012, 2011 and 2010, was $3.7 million, $4.8 million and $2.7 million, respectively.

During the years ended December 31, 2012, 2011 and 2010, our RSU activity for awards with performance measures was as follows:



	As of December 31,
	2012				2011				2010
	Shares		Weighted- Average Grant Date Fair Value		Shares		Weighted- Average Grant Date Fair Value		Shares		Weighted- Average Grant Date Fair Value
	(Shares In Thousands)
Nonvested balance, beginning of year	324.2		$	28.31	348.4		$	24.98	—		$	—
Granted	122.3		28.84		244.4		31.26		366.0		24.96
Vested	(88.2	)	25.46		(119.5	)	24.12		(4.5	)	23.32
Forfeited	(18.2	)	29.00		(149.1	)	28.72		(13.1	)	24.99
Nonvested balance, end of year	340.1		29.20		324.2		28.31		348.4		24.98

As of December 31, 2012 and 2011, total unrecognized compensation cost related to RSU awards with performance measures was $3.5 million and $3.3 million, respectively. We expect to recognize these costs over a remaining weighted-average period of 1.7 years. The total fair value of RSUs with performance measures that vested during the years ended December 31, 2012 and 2011, was $3.6 million. No performance RSUs vested in 2010.

Stock options granted between 1998 and 2001 are completely vested and have expired. There were no options exercised and all remaining options were forfeited during the year ended December 31, 2010. We currently have no plans to issue new stock option awards.

Another component of the LTISA Plan is the Executive Stock for Compensation program under which, in the past, eligible employees were entitled to receive deferred common stock in lieu of current cash compensation. Although this plan was discontinued in 2001, dividends will continue to be paid to plan participants on their outstanding plan balance until distribution. Plan participants were awarded 666 shares of common stock for dividends in 2012, 4,757 shares in 2011 and 6,627 shares in 2010. Participants received common stock distributions of 1,461 shares in 2012, 67,426 shares in 2011 and 1,198 shares in 2010.

Income tax benefits resulting from income tax deductions in excess of the related compensation cost recognized in the financial statements is classified as cash flows from financing activities in the consolidated statements of cash flows.

The entire disclosure for pension and other postretirement benefits.

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

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+ Details

Wolf Creek Employee Benefit Plans

12 Months Ended

Dec. 31, 2012

Wolf Creek Employee Benefit Plans

WOLF CREEK EMPLOYEE BENEFIT PLANS

Pension and Post-retirement Benefit Plans

As a co-owner of Wolf Creek, KGE is indirectly responsible for 47% of the liabilities and expenses associated with the Wolf Creek pension and post-retirement benefit plans. KGE accrues its 47% share of Wolf Creek's cost of pension and post-retirement benefits during the years an employee provides service. The following tables summarize the status of KGE's 47% share of the Wolf Creek pension and post-retirement benefit plans.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	161,396		$	131,460		$	10,129		$	10,144
Service cost	6,062			4,957			191			165
Interest cost	7,537			7,370			411			458
Plan participants’ contributions	—			—			608			614
Benefits paid (a)	(8,569		)	(3,033		)	(988		)	(979		)
Actuarial losses (gains)	9,815			20,642			669			(360		)
Amendments	650			—			—			—
Other (b)	—			—			—			87
Benefit obligation, end of year	$	176,891		$	161,396		$	11,020		$	10,129

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	80,727		$	76,086		$	4		$	—
Actual return on plan assets	11,764			(2,578		)	—			—
Employer contributions	13,887			10,009			389			369
Plan participants' contributions	—			—			608			614
Benefits paid	(8,327		)	(2,790		)	(988		)	(979		)
Fair value of plan assets, end of year	$	98,051		$	80,727		$	13		$	4

Funded status, end of year	$	(78,840	)	$	(80,669	)	$	(11,007	)	$	(10,125	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(243	)	$	(243	)	$	(625	)	$	(609	)
Noncurrent liability	(78,597		)	(80,426		)	(10,382		)	(9,516		)
Net amount recognized	$	(78,840	)	$	(80,669	)	$	(11,007	)	$	(10,125	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	64,535		$	65,273		$	3,643		$	3,208
Prior service cost	675			31			—			—
Transition obligation	—			—			1			58
Net amount recognized	$	65,210		$	65,304		$	3,644		$	3,266

_______________


(a)	In 2012 certain former employees received a one-time lump sum payment of their pension benefits. Our share of the payment totaled $4.9 million.


(b)	Includes proceeds received as a result of the Early Retiree Reinsurance Program.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	176,891		$	161,396		$	—		$	—
Fair value of plan assets	98,051			80,727			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	141,722		$	128,633		$	—		$	—
Fair value of plan assets	98,051			80,727			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	$	—		$	—		$	11,020		$	10,129
Fair value of plan assets	—			—			13			4

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	4.16		%	4.55		%	3.78		%	4.10		%
Compensation rate increase	4.00		%	4.00		%	—			—

Wolf Creek uses a measurement date of December 31 for its pension and post-retirement benefit plans. The discount rate used to determine the current year pension obligation and the following year's pension expense is based on a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality, non-callable corporate bonds that generate sufficient cash flow to provide for the projected benefit payments of the plan. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plan's projected benefit payments discounted at this rate with the market value of the bonds selected.

The prior service cost (benefit) is amortized on a straight-line basis over the average future service of the active employees (plan participants) benefiting under the plan at the time of the amendment. The net actuarial gain or loss is amortized on a straight-line basis over the average future service of active plan participants benefiting under the plan without application of an amortization corridor. Following is additional information regarding KGE's 47% share of the Wolf Creek pension and other post-retirement benefit plans.



	Pension Benefits									Post-retirement Benefits
Year Ended December 31,	2012			2011			2010			2012			2011			2010
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	6,062		$	4,957		$	4,144		$	191		$	165		$	179
Interest cost	7,537			7,370			6,941			411			458			519
Expected return on plan assets	(6,577		)	(5,904		)	(5,453		)	—			—			—
Amortization of unrecognized:
Transition obligation, net	—			52			57			57			58			58
Prior service costs	6			16			29			—			—			—
Actuarial loss, net	5,366			3,586			2,636			234			227			276
Net periodic cost before regulatory adjustment	12,394			10,077			8,354			893			908			1,032
Regulatory adjustment (a)	(1,776		)	(2,546		)	(1,498		)	—			—			—
Net periodic cost	$	10,618		$	7,531		$	6,856		$	893		$	908		$	1,032

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	4,629		$	29,124		$	7,514		$	669		$	(360	)	$	363
Amortization of actuarial loss	(5,366		)	(3,586		)	(2,636		)	(234		)	(227		)	(276		)
Current year prior service cost	650			—			—			—			—			—
Amortization of prior service cost	(6		)	(16		)	(29		)	—			—			—
Amortization of transition obligation	—			(52		)	(57		)	(57		)	(58		)	(58		)
Total recognized in regulatory assets	$	(93	)	$	25,470		$	4,792		$	378		$	(645	)	$	29

Total recognized in net periodic cost and regulatory assets	$	10,525		$	33,001		$	11,648		$	1,271		$	263		$	1,061

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.55		%	5.45		%	6.05		%	4.10		%	4.90		%	5.50		%
Expected long-term return on plan assets	7.50		%	7.50		%	8.00		%	—			—			—
Compensation rate increase	4.00		%	4.00		%	4.00		%	—			—			—

_______________


(a)	The regulatory adjustment represents the difference between current period pension or post-retirement benefit expense and the amount of such expense recognized in setting our prices.

We estimate that we will amortize the following amounts from regulatory assets into net periodic cost in 2013.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss	$	5,421	$	264
Prior service cost	58		—
Transition obligation	—		1
Total	$	5,479	$	265

The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the plans' investment portfolios. Assumed projected rates of return for each asset class were selected after analyzing long-term historical experience and future expectations of the volatility of the various asset classes. Based on target asset allocations for each asset class, the overall expected rate of return for the portfolios was developed, adjusted for historical and expected experience of active portfolio management results compared to benchmark returns and for the effect of expenses paid from plan assets.

For measurement purposes, the assumed annual health care cost growth rates were as follows.



	As of December 31,
	2012		2011
Health care cost trend rate assumed for next year	8.0	%	8.0	%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.0	%	5.0	%

Year that the rate reaches the ultimate trend rate	2019		2018

The health care cost trend rate affects the projected benefit obligation. A 1% change in assumed health care cost growth rates would have effects shown in the following table.



	One-Percentage- Point Increase			One-Percentage- Point Decrease
	(In Thousands)
Effect on total of service and interest cost	$	(10	)	$	10
Effect on post-retirement benefit obligation	(129		)	128

Plan Assets

In 2012 Wolf Creek changed its investment advisor resulting in the sale of its then existing levels 1, 2 and 3 investments and the purchase of other level 2 and 3 investments. Its pension and post-retirement plan investment strategy is to manage assets in a prudent manner with regard to preserving principal while providing reasonable returns. It has adopted a long-term investment horizon such that the chances and duration of investment losses are carefully weighed against the long-term potential for appreciation of assets. Part of its strategy includes managing interest rate sensitivity of plan assets relative to the associated liabilities. The primary objective of the pension plan is to provide a source of retirement income for its participants and beneficiaries, and the primary financial objective of the plan is to improve its funded status. The primary objective of the post-retirement benefit plan is growth in assets and preservation of principal, while minimizing interim volatility, to meet anticipated claims of plan participants. Wolf Creek delegates the management of its pension and post-retirement benefit plan assets to independent investment advisors who hire and dismiss investment managers based upon various factors. The investment advisors strive to diversify investments across asset classes, sectors and manager styles to minimize the risk of large losses, based upon objectives and risk tolerance specified by Wolf Creek, which include allowable and/or prohibited investment types. It measures and monitors investment risk on an ongoing basis through quarterly investment portfolio reviews and annual liability measurements.

The target allocations for Wolf Creek's pension plan assets are 31% to international equity securities, 25% to domestic equity securities, 25% to debt securities, 10% to real estate securities, 5% to commodity investments and 4% to other investments. The investments in both international and domestic equity include investments in large-, mid- and small-cap companies, private equity funds and investment funds with underlying investments similar to those previously mentioned. The investments in debt include core and high-yield bonds. Core bonds include funds invested in investment grade debt securities of corporate entities, obligations of U.S. and foreign governments and their agencies, and private debt securities. High-yield bonds include a fund with underlying investments in non-investment grade debt securities of corporate entities, private placements and bank debt. Real estate securities include funds invested in commercial and residential real estate properties while commodity investments include funds invested in commodity-related instruments.

All of Wolf Creek's pension plan assets are recorded at fair value using daily net asset values as reported by the trustee. However, level 3 investments in real estate funds and alternative funds are invested in underlying investments that are illiquid and require significant judgment when measuring them at fair value using market- and income-based models. Significant unobservable inputs for underlying real estate investments include estimated market discount rates, projected cash flows and estimated value into perpetuity. Alternative funds invest in a wide range of investments typically with low correlations to traditional investments.

Similar to other assets measured at fair value, GAAP establishes a hierarchal framework for disclosing the transparency of the inputs utilized in measuring pension and post-retirement benefit plan assets at fair value. From time to time, the Wolf Creek pension trust may buy and sell investments resulting in changes within the hierarchy. See Note 4, "Financial and Derivative Instruments, Trading Securities, Energy Marketing and Risk Management," for a description of the hierarchal framework.

The following table provides the fair value of KGE's 47% share of Wolf Creek's pension plan assets and the corresponding level of hierarchy as of December 31, 2012 and 2011.



As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	24,305	$	—	$	24,305
International equity	—		30,484		—		30,484
Core bonds	—		24,763		—		24,763
Real estate securities	—		4,972		4,541		9,513
Commodities	—		4,789		—		4,789
Alternative investments	—		—		3,900		3,900
Cash equivalents	—		297		—		297
Total Assets Measured at Fair Value	$	—	$	89,610	$	8,441	$	98,051

As of December 31, 2011
Assets:
Domestic equity	$	30,753	$	—	$	—	$	30,753
International equity	9,953		8,070		—		18,023
Core bonds	—		17,877		—		17,877
High-yield bonds	4,102		—		—		4,102
Real estate securities	—		—		3,630		3,630
Commodities	—		4,377		—		4,377
Cash equivalents	—		1,965		—		1,965
Total Assets Measured at Fair Value	$	44,808	$	32,289	$	3,630	$	80,727

The following table provides a reconciliation of KGE's 47% share of Wolf Creek's pension plan assets measured at fair value using significant level 3 inputs for the years ended December 31, 2012 and 2011.




	Real Estate Securities			Alternative Investments		Total
	(In Thousands)
Balance as of December 31, 2011	$	3,630		$	—	$	3,630
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	(411		)	23		(388		)
Relating to assets sold during the period	755			—		755
Purchases, issuances and settlements, net	567			3,877		4,444
Balance as of December 31, 2012	$	4,541		$	3,900	$	8,441

Balance as of December 31, 2010	$	3,160		$	—	$	3,160
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	500			—		500
Relating to assets sold during the period	2			—		2
Purchases, issuances and settlements, net	(32		)	—		(32		)
Balance as of December 31, 2011	$	3,630		$	—	$	3,630

Cash Flows

The following table shows our expected cash flows for KGE's 47% share of Wolf Creek's pension and post-retirement benefit plans for future years.



Expected Cash Flows	Pension Benefits						Post-retirement Benefits
	To/(From) Trust			(From) Company Assets			To/(From) Trust			(From) Company Assets
	(In Millions)
Expected contributions:
2013	$	9.4					$	0.6

Expected benefit payments:
2013	$	(3.7	)	$	(0.2	)	$	(0.6	)	$	—
2014	(4.3		)	(0.2		)	(0.7		)	—
2015	(5.0		)	(0.2		)	(0.7		)	—
2016	(5.8		)	(0.2		)	(0.8		)	—
2017	(6.7		)	(0.2		)	(0.8		)	—
2018 - 2022	(46.9		)	(0.9		)	(4.5		)	—

Savings Plan

Wolf Creek maintains a qualified 401(k) savings plan in which most of its employees participate. They match employees' contributions in cash up to specified maximum limits. Wolf Creek's contributions to the plan are deposited with a trustee and invested at the direction of plan participants into one or more of the investment alternatives provided under the plan. KGE's portion of the expense associated with Wolf Creek's matching contributions was $1.3 million in 2012, $1.3 million in 2011 and $1.1 million in 2010.

Commitments And Contingencies

12 Months Ended

Dec. 31, 2012

Commitments and Contingencies Disclosure [Abstract]

Commitments And Contingencies

COMMITMENTS AND CONTINGENCIES

Purchase Orders and Contracts

As part of our ongoing operations and capital expenditure program, we have purchase orders and contracts, excluding fuel and transmission, which are discussed below under "—Fuel, Purchased Power and Transmission Commitments," that had an unexpended balance of approximately $588.3 million as of December 31, 2012, of which $278.1 million had been committed. These commitments relate to purchase obligations issued and outstanding at year-end.

The yearly detail of the aggregate amount of required payments as of December 31, 2012, was as follows.



	Committed Amount
	(In Thousands)
2013	$	159,546
2014	72,573
2015	29,271
Thereafter	16,727
Total amount committed	$	278,117

Federal Clean Air Act

We must comply with the federal Clean Air Act, state laws and implementing federal and state regulations that impose, among other things, limitations on emissions generated from our operations, including sulfur dioxide (SO₂), particulate matter (PM), nitrogen oxides (NOx), carbon monoxide (CO), mercury and acid gases.

Emissions from our generating facilities, including PM, SO₂ and NOx, have been determined by regulation to reduce visibility by causing or contributing to regional haze. Under federal laws, such as the Clean Air Visibility Rule, and pursuant to an agreement with the Kansas Department of Health and Environment (KDHE) and the Environmental Protection Agency (EPA), we are required to install, operate and maintain controls to reduce emissions found to cause or contribute to regional haze.

Under the federal Clean Air Act, the EPA sets National Ambient Air Quality Standards (NAAQS) for certain emissions considered harmful to public health and the environment, including PM, NOx, CO and SO₂, which result from fossil fuel combustion. Areas meeting the NAAQS are designated attainment areas while those that do not meet the NAAQS are considered nonattainment areas. Each state must develop a plan to bring nonattainment areas into compliance with the NAAQS. NAAQS must be reviewed by the EPA at five-year intervals. KDHE proposed to designate portions of the Kansas City area nonattainment for the eight-hour ozone standard, which has the potential to impact our operations. The EPA has not acted on KDHE's proposed designation of the Kansas City area and it is uncertain when, or if, such a designation might occur. The Wichita area also exceeded the eight-hour ozone standard and could be designated nonattainment in the future potentially impacting our operations.

In December 2012, the EPA strengthened an existing NAAQS for PM. The EPA anticipates making initial attainment/nonattainment designations under this rule by the end of 2014. We are currently evaluating the rule, however, we cannot at this time predict the impact it may have on our operations or consolidated financial results, but it could be material.

In 2010, the EPA strengthened the NAAQS for both NOx and SO₂. We continue to communicate with our regulators regarding these standards and are currently evaluating what impact this could have on our operations. If we are required to install additional equipment to control emissions at our facilities, the revised NAAQS could have a material impact on our operations and consolidated financial results.

Environmental Projects

We will continue to make significant capital and operating expenditures at our power plants to reduce regulated emissions. The amount of these expenditures could change materially depending on the timing and nature of required investments, the specific outcomes resulting from existing regulations, new regulations, legislation and the manner in which we operate the plants. In addition to the capital investment, in the event we install new equipment, such equipment may cause us to incur significant increases in annual operating and maintenance expense and may reduce the net production, reliability and availability of the plants. The degree to which we will need to reduce emissions and the timing of when such emissions controls may be required is uncertain. Additionally, our ability to access capital markets and the availability of materials, equipment and contractors may affect the timing and ultimate amount of such capital investments.

In comparison to a general rate review, the ECRR reduces the amount of time it takes to begin collecting in retail prices the costs associated with capital expenditures for qualifying environmental improvements. We are not allowed to use the ECRR to collect cost associated with our approximately $610.0 million share of the projected capital investment associated with the $1.2 billion of environmental upgrades at La Cygne. We therefore must file for a general review of our rates or an abbreviated rate review with the KCC in order to collect these costs. As previously discussed, the KCC approved our request to file an abbreviated rate review within 12 months of the April 2012 order to update our prices to include capital costs related to environmental projects at La Cygne. To change our prices to collect increased operating and maintenance costs, we must file a general rate review with the KCC.

Air Emissions

The operation of power plants results in emissions of mercury, acid gases and other air toxics. In 2011, the EPA published Mercury and Air Toxics Standards for power plants, which replaces the prior federal Clean Air Mercury Rule and requires significant reductions in mercury, acid gases and other emissions. Companies impacted by the new standards will have up to three years, or four years with approval from a state environmental regulatory agency, and in certain limited circumstances up to five years, to comply. We have obtained approval from our state environmental regulatory agency and expect to be compliant with the new standards within four years. We continue to evaluate the new standards and believe that our related investment will be less than $16.0 million.

In mid 2011, the EPA finalized the Cross-State Air Pollution Rule (CSAPR) requiring 28 states, including Kansas, Missouri and Oklahoma, to further reduce power plant emissions of SO₂ and NOx. Under CSAPR, reductions in annual SO₂ and NOx emissions were required to begin January 2012, with further reductions required beginning January 2014. The EPA also published a final supplemental rule to CSAPR later in 2011 requiring five states, including Missouri and Oklahoma, to make summertime reductions in NOx emissions beginning in May 2012. Although Kansas was included in the original proposed rule, the final supplemental rule instead called for the EPA to revisit Kansas' status once Kansas submitted an ozone state implementation plan. In August 2012, the U.S. Court of Appeals for the District of Columbia Circuit vacated CSAPR and remanded the rule to the EPA to promulgate a replacement. In October 2012, the EPA filed a petition with the court requesting a rehearing before the full court. In January 2013, the court issued orders declining to rehear the case. We cannot at this time predict how the EPA may proceed with rulemaking; however, based on our current and planned environmental controls, if the regulations were to be reinstated or replaced, either in part or in whole, we do not believe the impact on our operations and consolidated financial results would be material.

Greenhouse Gases

Under regulations known as the Tailoring Rule, the EPA is regulating greenhouse gas (GHG) emissions from certain stationary sources. The regulations are being implemented pursuant to two federal Clean Air Act programs which impose recordkeeping and monitoring requirements and also mandate the implementation of best available control technology (BACT) for projects that cause a significant increase in GHG emissions (defined to be more than 75,000 tons or more per year or 100,000 tons or more per year, depending on various factors). The EPA has issued guidance on what BACT entails for the control of GHGs and individual states are now required to determine what controls are required for facilities within their jurisdiction on a case-by-case basis. We cannot at this time determine the impact of these regulations on our operations and consolidated financial results, but we believe the cost of compliance with the regulations could be material.

Renewable Energy Standard

Kansas law mandates that we maintain a minimum amount of renewable energy sources. Through 2015 net renewable generation capacity must be 10% of the average peak demand for the three prior years, subject to limited exceptions. This requirement increases to 15% for years 2016 through 2019 and 20% for 2020 and thereafter. In 2012, we began purchasing under 20-year supply contracts the renewable energy produced from approximately 370 MW of additional wind generation, which, together with existing facilities, supply contracts and renewable energy credits, will allow us to satisfy the net renewable generation requirement through 2015 and contribute toward meeting the increased requirements beginning in 2016. If we are unable to meet future requirements, our operations and consolidated financial results could be adversely impacted.

EPA Consent Decree

As part of a 2010 settlement of a lawsuit filed by the Department of Justice on behalf of the EPA, we are installing selective catalytic reduction (SCR) equipment on one of three JEC coal units by the end of 2014, which we estimate will cost approximately $240.0 million. The settlement also required that we determine whether we needed to install additional SCR equipment on another JEC unit or if we can meet agreed upon plant-wide NOx emissions reduction limits using other controls. We have informed the EPA that we believe we can meet the terms of the settlement by installing less expensive NOx reduction equipment rather than additional SCR equipment. We plan to complete these projects in 2014 and recover the costs to install these systems through our ECRR, but such recovery remains subject to the approval of our regulators.

FERC Investigation

The Federal Energy Regulatory Commission (FERC) opened a non-public investigation of our use of transmission service between July 2006 and February 2008. In May 2009, FERC staff alleged that we improperly used secondary network transmission service to facilitate off-system wholesale power sales in violation of applicable FERC orders and Southwest Power Pool (SPP) tariffs and that we received $14.3 million of unjust profits through such activities. Based on our response to these allegations, FERC staff substantially revised downward its preliminary conclusions to allege that we received $0.9 million of unjust profits and failed to pay $0.8 million to the SPP for transmission service. As of December 31, 2012 and 2011, we had recorded a liability of $1.6 million and $0.5 million, respectively, related to the potential settlement of this investigation and the risks of litigating this matter to a final outcome. We settled with FERC in January 2013 resulting in payments totaling $1.6 million.

Nuclear Decommissioning

Nuclear decommissioning is a nuclear industry term for the permanent shutdown of a nuclear power plant and the removal of radioactive components in accordance with Nuclear Regulatory Commission (NRC) requirements. The NRC will terminate a plant's license and release the property for unrestricted use when a company has reduced the residual radioactivity of a nuclear plant to a level mandated by the NRC. The NRC requires companies with nuclear plants to prepare formal financial plans to fund nuclear decommissioning. These plans are designed so that sufficient funds required for nuclear decommissioning will be accumulated prior to the expiration of the license of the related nuclear power plant. Wolf Creek files a nuclear decommissioning site study with the KCC every three years.

The KCC reviews nuclear decommissioning plans in two phases. Phase one is the approval of the revised nuclear decommissioning study including the estimated costs to decommission the plant. Phase two involves the review and approval of a funding schedule prepared by the owner of the plant detailing how it plans to fund the future-year dollar amount of its pro rata share of the decommissioning costs.

In 2011 we revised the nuclear decommissioning study. Based on the study, our share of decommissioning costs, including decontamination, dismantling and site restoration, is estimated to be $296.2 million. This amount compares to the prior site study estimate of $279.0 million. The site study cost estimate represents the estimate to decommission Wolf Creek as of the site study year. The actual nuclear decommissioning costs may vary from the estimates because of changes in regulations and technologies as well as changes in costs for labor, materials and equipment.

We are allowed to recover nuclear decommissioning costs in our prices over a period equal to the operating license of Wolf Creek, which is through 2045. The NRC requires that funds sufficient to meet nuclear decommissioning obligations be held in a trust. We believe that the KCC approved funding level will also be sufficient to meet the NRC requirement. Our consolidated financial results would be materially affected if we were not allowed to recover in our prices the full amount of the funding requirement.

We recovered in our prices and deposited in an external trust fund for nuclear decommissioning approximately $3.2 million in 2012, $3.2 million in 2011 and $3.1 million in 2010. We record our investment in the NDT fund at fair value, which approximated $150.8 million and $130.3 million as of December 31, 2012 and 2011, respectively.

Storage of Spent Nuclear Fuel

Under the Nuclear Waste Policy Act of 1982, the Department of Energy (DOE) is responsible for the permanent disposal of spent nuclear fuel. Wolf Creek pays into a federal Nuclear Waste Fund administered by the DOE a quarterly fee for the future disposal of spent nuclear fuel. Our share of the fee, calculated as one tenth of a cent for each kilowatt-hour of net nuclear generation delivered to customers, was $3.6 million in 2012, $3.1 million in 2011 and $4.0 million in 2010. We include these costs in fuel and purchased power expense on our consolidated statements of income.

In 2010, the DOE filed a motion with the NRC to withdraw its then pending application to construct a national repository for the disposal of spent nuclear fuel and high-level radioactive waste at Yucca Mountain, Nevada. An NRC board denied the DOE's motion to withdraw its application and the DOE appealed that decision to the full NRC. In 2011, the NRC issued an evenly split decision on the appeal and also ordered the licensing board to close out its work on the DOE's application by the end of 2011 due to a lack of funding. These agency actions prompted the States of Washington and South Carolina, and a county in South Carolina, to file a lawsuit in a federal Court of Appeals asking the court to compel the NRC to resume its license review and to issue a decision on the license application. In August 2012, the court ordered the parties to report to it, no later than December 14, 2012 (later extended to January 4, 2013), whether Congress had provided funding for the NRC to proceed on the license application. By that date, Congress had not yet provided funding, and the parties filed their respective status reports and arguments on whether or not the court should order the NRC to resume its license review. The court has not yet acted on the pending request. 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. We 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.

Wolf Creek disposes of most of its low-level radioactive waste at an existing third-party repository in Utah, which we expect will remain available to Wolf Creek. Wolf Creek also contracts with a waste processor to process, take title and dispose in another state most of the remainder of Wolf Creek's low-level radioactive waste. Should on-site waste storage be needed in the future, Wolf Creek has storage capacity on site adequate for about four years of plant operations and believes it will be able to expand that storage capacity if needed.

Nuclear Insurance

We maintain nuclear insurance for Wolf Creek in four areas: liability, worker radiation, property and accidental outage. These policies contain certain industry standard exclusions, including, but not limited to, ordinary wear and tear and war. The nuclear liability program subscribed to by members of the nuclear power generating industry no longer include industry aggregate limits for non-certified acts, as defined by the Terrorism Risk Insurance Act, of terrorism-related losses. An industry aggregate limit of $3.2 billion plus any reinsurance recoverable by Nuclear Electric Insurance Limited (NEIL), our insurance provider, exists for property claims, including accidental outage power costs, for acts of terrorism affecting Wolf Creek or any other nuclear energy facility property policy within 12 months from the date of the first act. These limits are the maximum amount to be paid to members who sustain losses or damages from these types of terrorist acts. In addition, we may be required to participate in industry-wide retrospective assessment programs as discussed below.

Nuclear Liability Insurance

Pursuant to the Price-Anderson Act, which has been reauthorized through December 31, 2025, by the Energy Policy Act of 2005, we are required to insure against public liability claims resulting from nuclear incidents to the full limit of public liability, which is currently approximately $12.6 billion. This limit of liability consists of the maximum available commercial insurance of $375.0 million and the remaining $12.2 billion is provided through mandatory participation in an industry-wide retrospective assessment program. Under this retrospective assessment program, the owners of Wolf Creek are jointly and severally subject to an assessment of up to $117.5 million (our share is $55.2 million), payable at no more than $17.5 million (our share is $8.2 million) per incident per year per reactor. Both the total and yearly assessment is subject to an inflation adjustment based on the Consumer Price Index and applicable premium taxes. This assessment also applies in excess of our worker radiation claims insurance. The next inflation adjustment is scheduled for 2013. In addition, Congress could impose additional revenue-raising measures to pay claims.

Nuclear Property Insurance

The owners of Wolf Creek carry decontamination liability, premature nuclear decommissioning liability and property damage insurance for Wolf Creek totaling approximately $2.8 billion (our share is $1.3 billion). This insurance is provided by NEIL. In the event of an accident, insurance proceeds must first be used for reactor stabilization and site decontamination in accordance with a plan mandated by the NRC. Our share of any remaining proceeds can be used to pay for property damage, decontamination expenses or, if certain requirements are met, including nuclear decommissioning the plant, toward a shortfall in the NDT fund.

Accidental Nuclear Outage Insurance

The owners also carry additional insurance with NEIL to cover costs of replacement power and other extra expenses incurred during a prolonged outage resulting from accidental property damage at Wolf Creek. If significant losses were incurred at any of the nuclear plants insured under the NEIL policies, the owners of Wolf Creek may be subject to retrospective assessments under the current policies of approximately $30.2 million (our share is $14.2 million).

Although we maintain various insurance policies to provide coverage for potential losses and liabilities resulting from an accident or an extended outage, our insurance coverage may not be adequate to cover the costs that could result from a catastrophic accident or extended outage at Wolf Creek. Any substantial losses not covered by insurance, to the extent not recoverable in our prices, would have a material effect on our consolidated financial results.

Fuel, Purchased Power and Transmission Commitments

To supply a portion of the fuel requirements for our power plants, the owners of Wolf Creek have entered into various contracts to obtain nuclear fuel and we have entered into various contracts to obtain coal and natural gas. Some of these contracts contain provisions for price escalation and minimum purchase commitments. As of December 31, 2012, our share of Wolf Creek's nuclear fuel commitments was approximately $42.2 million for uranium concentrates expiring in 2017, $6.3 million for conversion expiring in 2017, $106.3 million for enrichment expiring in 2025 and $36.0 million for fabrication expiring in 2023.

As of December 31, 2012, our coal and coal transportation contract commitments under the remaining terms of the contracts were approximately $648.2 million. The contracts are for plants that we operate and expire at various times through 2021.

As of December 31, 2012, our natural gas transportation contract commitments under the remaining terms of the contracts were approximately $129.0 million. The natural gas transportation contracts provide firm service to several of our natural gas burning facilities and expire at various times through 2030.

We have purchase power agreements with the owners of four separate wind generation facilities with installed design capacities of 515 MW. The agreements expire in 2028 through 2032. Each of the agreements provide for our receipt and purchase of energy produced at a fixed price per unit of output. We estimate that our annual cost of energy purchased from these wind generation facilities will be approximately $68.2 million beginning in 2013.

We have acquired rights to transmit a total of 306 MW of power. Agreements providing transmission capacity for approximately 200 MW expire in 2016 while the remaining 106 MW expire in 2022. As of December 31, 2012, we are committed to spend approximately $34.3 million over the remaining terms of these agreements.

The entire disclosure for commitments and contingencies.

Asset Retirement Obligation [Abstract]

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Asset Retirement Obligations

12 Months Ended

Dec. 31, 2012

Asset Retirement Obligations

ASSET RETIREMENT OBLIGATIONS

Legal Liability

We have recognized legal obligations associated with the disposal of long-lived assets that result from the acquisition, construction, development or normal operation of such assets. The recording of AROs for regulated operations has no income statement impact due to the deferral of the adjustments through the establishment of a regulatory asset.

We initially recorded AROs at fair value for the estimated cost to decommission Wolf Creek (KGE's 47% share), retire our wind generation facilities, dispose of asbestos insulating material at our power plants, remediate ash disposal ponds and dispose of polychlorinated biphenyl (PCB)-contaminated oil.

The following table summarizes our legal AROs included on our consolidated balance sheets in long-term liabilities.



	As of December 31,
	2012			2011
	(In Thousands)
Beginning ARO	$	142,508		$	125,999
Liabilities settled	(1,389		)	(1,027		)
Accretion expense	8,454			7,623
Increase in nuclear decommissioning ARO liability	—			9,913
Revisions in estimated cash flows	3,075			—
Ending ARO	$	152,648		$	142,508

As discussed in Note 13, "Commitments and Contingencies—Nuclear Decommissioning," Wolf Creek filed a nuclear decommissioning study with the KCC in 2011. As a result of the study, we recorded a $9.9 million increase in our ARO to reflect revisions to the estimated costs to decommission Wolf Creek.

Conditional ARO refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. We determined that our conditional AROs include the retirement of our wind generation facilities, disposal of asbestos insulating material at our power plants, the remediation of ash disposal ponds and the disposal of PCB-contaminated oil.

We have an obligation to retire our wind generation facilities and remove the foundations. The ARO related to our wind generation facilities was determined based upon the date each wind generation facility was placed into service.

The amount of the retirement obligation related to asbestos disposal was recorded as of 1990, the date when the EPA published the "National Emission Standards for Hazardous Air Pollutants: Asbestos NESHAP Revision; Final Rule."

We operate, as permitted by the state of Kansas, ash landfills at several of our power plants. The retirement obligation for the ash landfills was determined based upon the date each landfill was originally placed in service.

PCB-contaminated oil is contained within company electrical equipment, primarily transformers. The PCB retirement obligation was determined based upon the PCB regulations that originally became effective in 1978.

Non-Legal Liability - Cost of Removal

We collect in our prices the costs to dispose of plant assets that do not represent legal retirement obligations. As of December 31, 2012 and 2011, we had $129.0 million and $82.3 million, respectively, in amounts collected, but not yet spent, for removal costs classified as a regulatory liability.

Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]

The entire disclosure for an asset retirement obligation and the associated long-lived asset. An asset retirement obligation is a legal obligation associated with the disposal or retirement from service 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.

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Common and Preferred Stock

12 Months Ended

Dec. 31, 2012

Common and Preferred Stock

COMMON AND PREFERRED STOCK

Common Stock

General

In May 2011, Westar Energy shareholders approved an amendment to its Restated Articles of Incorporation to increase the number of shares of common stock authorized to be issued from 150.0 million to 275.0 million. As of December 31, 2012 and 2011, Westar Energy had issued 126.5 million shares and 125.7 million shares, respectively.

Westar Energy has a direct stock purchase plan (DSPP). Shares of common stock sold pursuant to the DSPP may be either original issue shares or shares purchased in the open market. During 2012, 2011 and 2010, Westar Energy issued 0.8 million shares, 0.8 million shares and 0.7 million shares, respectively, through the DSPP and other stock-based plans operated under the LTISA Plan. As of December 31, 2012 and 2011, a total of 1.5 million shares and 2.0 million shares, respectively, were available under the DSPP registration statement.

Issuances

In April 2010, Westar Energy entered into a three-year Sales Agency Financing Agreement and forward sale agreement with a bank. The maximum amount that Westar Energy may offer and sell under the agreements is the lesser of an aggregate of $500.0 million or approximately 22.0 million shares, subject to adjustment for share splits, share combinations and share dividends. Under the terms of the Sales Agency Financing Agreement, Westar Energy may offer and sell shares of its common stock from time to time through the broker dealer subsidiary, as agent. The broker dealer receives a commission equal to 1% of the sales price of all shares sold under the agreement. In addition, under the terms of the Sales Agency Financing Agreement and forward sale agreement, Westar Energy may from time to time enter into one or more forward sale transactions with the bank, as forward purchaser, and the bank will borrow shares of Westar Energy's common stock from third parties and sell them through its broker dealer. Westar Energy must settle the forward sale transactions within 18 months of the date each transaction is entered. In 2011 and 2010, Westar Energy entered into and settled forward sale transactions with respect to an aggregate of approximately 5.4 million shares of common stock for proceeds of approximately $118.3 million. During 2012, Westar Energy entered into additional forward sale transactions with respect to an aggregate of approximately 1.8 million shares of common stock. Assuming physical share settlement of these forward sale transactions as of December 31, 2012, Westar Energy would have received aggregate proceeds of approximately $48.1 million based on a forward price of $27.45 per share.

In November 2010, Westar Energy entered into a separate forward sale agreement with a bank. Under the terms of the agreement, the bank, as forward seller, borrowed 7.5 million shares of Westar Energy's common stock from third parties and sold them to a group of underwriters for $25.54 per share. Under an over-allotment option included in the agreement, the underwriters purchased approximately 1.0 million additional shares for $25.54 per share, increasing the total number of shares under the forward sale agreement to approximately 8.5 million shares. The underwriters received a commission equal to 3.5% of the sales price of all shares sold under the agreement. In November 2011, Westar Energy delivered approximately 8.5 million shares of common stock for proceeds of approximately $197.3 million as complete settlement of this forward sale agreement.

Westar Energy used the proceeds from the issuance of common stock to repay short-term borrowings, with such borrowed amounts principally related to investments in capital equipment, as well as for working capital and general corporate purposes.

Preferred Stock Redemption

In May 2012, Westar Energy provided an irrevocable notice of redemption to holders of all of Westar Energy's preferred shares. Accordingly, we reduced preferred equity to zero, recognized the obligation to redeem the preferred shares as a liability and recognized the redemption premium as a preferred stock dividend. Payment was due to holders of the preferred shares effective July 1, 2012. The table below shows the redemption amounts for all series of preferred stock.



Rate	Shares	Principal Outstanding		Call Price	Premium		Total Cost to Redeem
(Dollars in Thousands)
4.50%	121,613	$	12,161	108.0%	$	973	$	13,134
4.25%	54,970	5,497		101.5%	82		5,579
5.00%	37,780	3,778		102.0%	76		3,854
	214,363	$	21,436		$	1,131	$	22,567

Tabular disclosure of an entity's stock, including par or stated value per share, number and dollar amount of share subscriptions, shares authorized, shares issued, shares outstanding, number and dollar amount of shares held in an employee trust, dividend per share, total dividends, share conversion features, par value plus additional paid in capital, the value of treasury stock and other information necessary to a fair presentation, and EPS information. Stock by class includes common, convertible, and preferred stocks which are not redeemable or redeemable solely at the option of the issuer. Includes preferred stock with redemption features that are solely within the control of the issuer and mandatorily redeemable stock if redemption is required to occur only upon liquidation or termination of the reporting entity. If more than one issue is outstanding, state the title of each issue and the corresponding dollar amount; dollar amount of any shares subscribed but unissued and the deduction of subscriptions receivable there from; number of shares authorized, issued, and outstanding.

Variable Interest Entities [Abstract]

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Variable Interest Entities

12 Months Ended

Dec. 31, 2012

Variable Interest Entities Disclosure [Text Block]

VARIABLE INTEREST ENTITIES

In determining the primary beneficiary of a VIE, we assess the entity's purpose and design, including the nature of the entity's activities and the risks that the entity was designed to create and pass through to its variable interest holders. A reporting enterprise is deemed to be the primary beneficiary of a VIE if it has (a) the power to direct the activities of the VIE that most significantly impact the VIE's economic performance and (b) the obligation to absorb losses or right to receive benefits from the VIE that could potentially be significant to the VIE. Accounting guidance effective January 1, 2010, requires the primary beneficiary of a VIE to consolidate the VIE. The trusts holding our 8% interest in JEC, our 50% interest in La Cygne unit 2 and railcars we use to transport coal to some of our power plants are VIEs of which we are the primary beneficiary.

We assess all entities with which we become involved to determine whether such entities are VIEs and, if so, whether or not we are the primary beneficiary of the entities. We also continuously assess whether we are the primary beneficiary of the VIEs with which we are involved. Prospective changes in facts and circumstances may cause us to reconsider our determination as it relates to the identification of the primary beneficiary.

8% Interest in Jeffrey Energy Center

Under an agreement that expires in January 2019, we lease an 8% interest in JEC from a trust. The trust was financed with an equity contribution from an owner participant and debt issued by the trust. The trust was created specifically to purchase the 8% interest in JEC and lease it to a third party, and does not hold any other assets. We meet the requirements to be considered the primary beneficiary of the trust. In determining the primary beneficiary of the trust, we concluded that the activities of the trust that most significantly impact its economic performance and that we have the power to direct include (1) the operation and maintenance of the 8% interest in JEC, (2) our ability to exercise a purchase option at the end of the agreement at the lesser of fair value or a fixed amount and (3) our option to require refinancing of the trust's debt. We have the potential to receive benefits from the trust that could potentially be significant if the fair value of the 8% interest in JEC at the end of the agreement is greater than the fixed amount. The possibility of lower interest rates upon refinancing the debt also creates the potential for us to receive significant benefits.

50% Interest in La Cygne Unit 2

Under an agreement that expires in September 2029, KGE entered into a sale-leaseback transaction with a trust under which the trust purchased KGE's 50% interest in La Cygne unit 2 and subsequently leased it back to KGE. The trust was financed with an equity contribution from an owner participant and debt issued by the trust. The trust was created specifically to purchase the 50% interest in La Cygne unit 2 and lease it back to KGE, and does not hold any other assets. We meet the requirements to be considered the primary beneficiary of the trust. In determining the primary beneficiary of the trust, we concluded that the activities of the trust that most significantly impact its economic performance and that we have the power to direct include (1) the operation and maintenance of the 50% interest in La Cygne unit 2, (2) our ability to exercise a purchase option at the end of the agreement at the lesser of fair value or a fixed amount and (3) our option to require refinancing of the trust's debt. We have the potential to receive benefits from the trust that could potentially be significant if the fair value of the 50% interest in La Cygne unit 2 at the end of the agreement is greater than the fixed amount. The possibility of lower interest rates upon refinancing the debt also creates the potential for us to receive significant benefits.

Railcars

Under two separate agreements that expire in May 2013 and November 2014, we lease railcars from trusts to transport coal to some of our power plants. The trusts were financed with equity contributions from owner participants and debt issued by the trusts. The trusts were created specifically to purchase the railcars and lease them to us, and do not hold any other assets. We meet the requirements to be considered the primary beneficiary of the trusts. In determining the primary beneficiary of the trusts, we concluded that the activities of the trusts that most significantly impact their economic performance and that we have the power to direct include the operation, maintenance and repair of the railcars and our ability to exercise a purchase option at the end of the agreements at the lesser of fair value or a fixed amount. We have the potential to receive benefits from the trusts that could potentially be significant if the fair value of the railcars at the end of the agreements is greater than the fixed amounts. Our agreements with these trusts also include renewal options during which time we would pay a fixed amount of rent. We have the potential to receive benefits from the trusts during the renewal periods if the fixed amount of rent is less than the amount we would be required to pay under a new agreement.

Financial Statement Impact

We have recorded the following assets and liabilities on our consolidated balance sheets related to the VIEs described above.



	As of December 31,
	2012		2011
	(In Thousands)
Assets:
Property, plant and equipment of variable interest entities, net	$	321,975	$	333,494
Regulatory assets (a)	5,810		4,915

Liabilities:
Current maturities of long-term debt of variable interest entities	$	25,942	$	28,114
Accrued interest (b)	3,948		4,448
Long-term debt of variable interest entities, net	222,743		249,283

_______________

(a) Included in long-term regulatory assets on our consolidated balance sheets.

(b) Included in accrued interest on our consolidated balance sheets.

All of the liabilities noted in the table above relate to the purchase of the property, plant and equipment. The assets of the VIEs can be used only to settle obligations of the VIEs and the VIEs' debt holders have no recourse to our general credit. We have not provided financial or other support to the VIEs and are not required to provide such support. We did not record any gain or loss upon initial consolidation of the VIEs.

Leases

12 Months Ended

Dec. 31, 2012

Leases [Abstract]

Leases

LEASES

Operating Leases

We lease office buildings, computer equipment, vehicles, railcars and other property and equipment. These leases have various terms and expiration dates ranging from one to 20 years.

In determining lease expense, we recognize the effects of scheduled rent increases on a straight-line basis over the minimum lease term. Rental expense and estimated future commitments under operating leases are as follows.



Year Ended December 31,	Total Operating Leases
	(In Thousands)
Rental expense:
2010	$	15,464
2011	17,577
2012	17,080

Future commitments:
2013	$	14,453
2014	12,550
2015	10,142
2016	8,390
2017	6,694
Thereafter	18,049
Total future commitments	$	70,278

Capital Leases

We identify capital leases based on defined criteria. For both vehicles and computer equipment, new leases are signed each month based on the terms of master lease agreements. The lease term for vehicles is from two to eight years depending on the type of vehicle. Computer equipment has a lease term of three to five years.

In 2012, we signed an agreement to lease electrical facilities that connect a wind generating facility to the transmission system. The agreement extends through August 2032, at which time it may be extended or we may exercise an option to purchase the line. The terms of the agreement meet the criteria of a capital lease; therefore, we recorded an $8.3 million capital lease.

In 2011, FERC issued an order approving a power supply agreement. The agreement extends through May 2039 and the terms meet the criteria to be classified as a capital lease. Accordingly, we recorded a $40.0 million capital lease in 2011.

Assets recorded under capital leases, including the 2012 and 2011 leases described above presented as generation plant, are listed below.



	As of December 31,
	2012			2011
	(In Thousands)
Vehicles	$	12,594		$	14,241
Computer equipment	1,423			1,720
Generation plant	48,346			40,048
Accumulated amortization	(6,928		)	(6,485		)
Total capital leases	$	55,435		$	49,524

Capital leases are treated as operating leases for rate making purposes. Minimum annual rental payments, excluding administrative costs such as property taxes, insurance and maintenance, under capital leases are listed below.



Year Ended December 31,	Total Capital Leases
	(In Thousands)
2013	$	6,538
2014	6,363
2015	5,840
2016	5,087
2017	4,708
Thereafter	76,800
	105,336
Amounts representing imputed interest	(48,461		)
Present value of net minimum lease payments under capital leases	56,875
Less: Current portion	3,066
Total long-term obligation under capital leases	$	53,809

Quarterly Financial Information Disclosure [Abstract]

The entire disclosure for lessee entity's leasing arrangements including, but not limited to, all of the following: (a.) The basis on which contingent rental payments are determined, (b.) The existence and terms of renewal or purchase options and escalation clauses, (c.) Restrictions imposed by lease agreements, such as those concerning dividends, additional debt, and further leasing.

+ References+ Details

Quarterly Results (Unaudited)

12 Months Ended

Dec. 31, 2012

Quarterly Results (Unaudited)

QUARTERLY RESULTS (UNAUDITED)

Our business is seasonal in nature and, in our opinion, comparisons between the quarters of a year do not give a true indication of overall trends and changes in operations.



2012	First		Second		Third		Fourth
	(In Thousands, Except Per Share Amounts)

Revenues (a)	$	475,677	$	566,262	$	695,758	$	523,772
Net income (a)	29,237		64,462		141,067		47,695
Net income attributable to common stock (a)	27,282		61,361		139,281		45,607

Per Share Data (a):

Basic:
Earnings available	$	0.21	$	0.48	$	1.10	$	0.36

Diluted:
Earnings available	$	0.21	$	0.48	$	1.09	$	0.36

Cash dividend declared per common share	$	0.33	$	0.33	$	0.33	$	0.33
Market price per common share:
High	$	29.13	$	30.17	$	33.04	$	30.29
Low	$	27.12	$	26.80	$	28.96	$	27.33

_______________


(a)	Items are computed independently for each of the periods presented and the sum of the quarterly amounts may not equal the total for the year.



2011	First		Second		Third		Fourth
	(In Thousands, Except Per Share Amounts)

Revenues (a)	$	481,720	$	524,892	$	678,152	$	486,228
Net income (a)	32,957		45,525		136,392		21,306
Net income attributable to common stock (a)	31,342		43,887		134,708		19,335

Per Share Data (a):

Basic:
Earnings available	$	0.27	$	0.38	$	1.15	$	0.16

Diluted:
Earnings available	$	0.27	$	0.38	$	1.14	$	0.16

Cash dividend declared per common share	$	0.32	$	0.32	$	0.32	$	0.32
Market price per common share:
High	$	26.60	$	27.98	$	27.29	$	29.05
Low	$	25.05	$	25.58	$	22.63	$	25.02

_______________


(a)	Items are computed independently for each of the periods presented and the sum of the quarterly amounts may not equal the total for the year.

Valuation and Qualifying Accounts [Abstract]

The entire disclosure for the quarterly financial data in the annual financial statements. The disclosure may include a tabular presentation of financial information for each fiscal quarter for the current and previous year, including revenues, gross profit, income or loss before extraordinary items and earnings per share data. It also includes an indication if the information in the note is unaudited, comments on the aggregate effect of year-end adjustments, and an explanation of matters or transactions that affect comparability or are pertinent to an understanding of the information furnished.

+ References+ Details

Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2012

Valuation and Qualifying Accounts

WESTAR ENERGY, INC.

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS



Description	Balance at Beginning of Period		Charged to Costs and Expenses		Deductions (a)			Balance at End of Period
	(In Thousands)
Year ended December 31, 2010
Allowances deducted from assets for doubtful accounts	$	5,231	$	8,337	$	(7,839	)	$	5,729

Year ended December 31, 2011
Allowances deducted from assets for doubtful accounts	$	5,729	$	8,774	$	(7,119	)	$	7,384

Year ended December 31, 2012
Allowances deducted from assets for doubtful accounts	$	7,384	$	6,617	$	(9,085	)	$	4,916

_______________


(a)	Result from write-offs of accounts receivable.

Summary Of Significant Accounting Policies (Policy)

12 Months Ended

Dec. 31, 2012

Principles Of Consolidation

Principles of Consolidation

Use Of Management's Estimates

Use of Management's Estimates

Regulatory Accounting

Cash And Cash Equivalents

Cash and Cash Equivalents

We consider investments that are highly liquid and have maturities of three months or less when purchased to be cash equivalents.

Restricted Cash

Pursuant to Westar Energy's Articles of Incorporation, Westar Energy deposited cash in a separate bank account to effect the redemption of all of Westar Energy's preferred stock in 2012.

Fuel Inventory And Supplies

Fuel Inventory and Supplies

We state fuel inventory and supplies at average cost.

Property, Plant And Equipment

Property, Plant and Equipment



	Year Ended December 31,
	2012		2011			2010
	(Dollars In Thousands)
Borrowed funds	$	10,399	$	5,589		$	4,295
Equity funds	11,706		5,550			3,104
Total	$	22,105	$	11,139		$	7,399
Average AFUDC Rates	5.0%		3.6		%	2.6		%

Allowance For Funds Used During Construction

AFUDC represents the allowed cost of capital used to finance utility construction activity. We compute AFUDC by applying a composite rate to qualified construction work in progress. We credit other income (for equity funds) and interest expense (for borrowed funds) for the amount of AFUDC capitalized as construction cost on the accompanying consolidated statements of income

Depreciation

Depreciable lives of property, plant and equipment are as follows.



	Years
Fossil fuel generating facilities	6	to	78
Nuclear fuel generating facility	33	to	71
Wind generating facilities	19	to	20
Transmission facilities	15	to	75
Distribution facilities	15	to	70
Other	5	to	30

Nuclear Fuel

Cash Surrender Value of Life Insurance

We recorded on our consolidated balance sheets in other long-term assets the following amounts related to corporate-owned life insurance policies.



	As of December 31,
	2012			2011
	(In Thousands)
Cash surrender value of policies	$	1,370,788		$	1,345,443
Borrowings against policies	(1,241,343		)	(1,208,389		)
Corporate-owned life insurance, net	$	129,445		$	137,054

Revenue Recognition

Electricity Sales

Energy Marketing Contracts

Allowance For Doubtful Accounts

Allowance for Doubtful Accounts

Income Taxes

Sales Tax

We account for the collection and remittance of sales tax on a net basis. As a result, we do not reflect sales tax in our consolidated statements of income.

Earnings Per Share

The following table reconciles our basic and diluted EPS from net income.



	Year Ended December 31,
	2012		2011		2010
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	282,462	$	236,180	$	208,624
Less: Net income attributable to noncontrolling interests	7,316		5,941		4,728
Net income attributable to Westar Energy, Inc.	275,146		230,239		203,896
Less: Preferred dividends	1,616		970		970
Net income allocated to RSUs	778		772		1,259
Net income allocated to common stock	$	272,752	$	228,497	$	201,667

Weighted average equivalent common shares outstanding – basic	126,711,869		116,890,552		111,629,292
Effect of dilutive securities:
RSUs	97,757		188,025		140,077
Forward sale agreements	89,160		1,211,645		245,496
Employee stock options	—		—		59
Weighted average equivalent common shares outstanding – diluted (a)	126,898,786		118,290,222		112,014,924

Earnings per common share, basic	$	2.15	$	1.95	$	1.81
Earnings per common share, diluted	$	2.15	$	1.93	$	1.80

_______________


(a)	For the years ended December 31, 2012, 2011 and 2010, we had no antidilutive shares.

Supplemental Cash Flow Information



	Year Ended December 31,
	2012			2011			2010
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	143,564		$	145,570		$	145,463
Interest on financing activities of VIEs	16,214			18,167			20,191
Income taxes, net of refunds	(4,378		)	(17,519		)	(34,980		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	89,354			105,435			64,423
Property, plant and equipment additions of VIEs	—			—			356,964
Jeffrey Energy Center (JEC) 8% leasehold interest	—			—			(108,706		)
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	12,803			15,103			18,777
Debt of VIEs	—			—			337,951
Capital lease for JEC 8% leasehold interest	—			—			(106,423		)
Assets acquired through capital leases	10,683			43,011			910

Summary Of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2012

Fuel Inventory and Supplies

Following are the balances for fuel inventory and supplies stated separately.



	As of December 31,
	2012		2011
	(In Thousands)
Fuel inventory	$	94,664	$	86,408
Supplies	154,352		142,710
Total	$	249,016	$	229,118

Allowance For Funds Used During Construction

We credit other income (for equity funds) and interest expense (for borrowed funds) for the amount of AFUDC capitalized as construction cost on the accompanying consolidated statements of income as follows:



	Year Ended December 31,
	2012		2011			2010
	(Dollars In Thousands)
Borrowed funds	$	10,399	$	5,589		$	4,295
Equity funds	11,706		5,550			3,104
Total	$	22,105	$	11,139		$	7,399
Average AFUDC Rates	5.0%		3.6		%	2.6		%

Depreciable Lives of Property, Plant and Equipment

Depreciable lives of property, plant and equipment are as follows.



	Years
Fossil fuel generating facilities	6	to	78
Nuclear fuel generating facility	33	to	71
Wind generating facilities	19	to	20
Transmission facilities	15	to	75
Distribution facilities	15	to	70
Other	5	to	30

Cash Surrender Value of Life Insurance

We recorded on our consolidated balance sheets in other long-term assets the following amounts related to corporate-owned life insurance policies.



	As of December 31,
	2012			2011
	(In Thousands)
Cash surrender value of policies	$	1,370,788		$	1,345,443
Borrowings against policies	(1,241,343		)	(1,208,389		)
Corporate-owned life insurance, net	$	129,445		$	137,054

Reconciliation Of Basic And Diluted Earnings Per Share

The following table reconciles our basic and diluted EPS from net income.



	Year Ended December 31,
	2012		2011		2010
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	282,462	$	236,180	$	208,624
Less: Net income attributable to noncontrolling interests	7,316		5,941		4,728
Net income attributable to Westar Energy, Inc.	275,146		230,239		203,896
Less: Preferred dividends	1,616		970		970
Net income allocated to RSUs	778		772		1,259
Net income allocated to common stock	$	272,752	$	228,497	$	201,667

Weighted average equivalent common shares outstanding – basic	126,711,869		116,890,552		111,629,292
Effect of dilutive securities:
RSUs	97,757		188,025		140,077
Forward sale agreements	89,160		1,211,645		245,496
Employee stock options	—		—		59
Weighted average equivalent common shares outstanding – diluted (a)	126,898,786		118,290,222		112,014,924

Earnings per common share, basic	$	2.15	$	1.95	$	1.81
Earnings per common share, diluted	$	2.15	$	1.93	$	1.80

_______________


(a)	For the years ended December 31, 2012, 2011 and 2010, we had no antidilutive shares.

Supplemental Cash Flow Information



	Year Ended December 31,
	2012			2011			2010
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	143,564		$	145,570		$	145,463
Interest on financing activities of VIEs	16,214			18,167			20,191
Income taxes, net of refunds	(4,378		)	(17,519		)	(34,980		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	89,354			105,435			64,423
Property, plant and equipment additions of VIEs	—			—			356,964
Jeffrey Energy Center (JEC) 8% leasehold interest	—			—			(108,706		)
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	12,803			15,103			18,777
Debt of VIEs	—			—			337,951
Capital lease for JEC 8% leasehold interest	—			—			(106,423		)
Assets acquired through capital leases	10,683			43,011			910

Schedule Of Regulatory Assets And Liabilities [Table Text Block]

Tabular disclosure of the useful life and salvage value of long-lived, physical assets that are used in the normal conduct of business to produce goods and services and not intended for resale. Examples include land, buildings, machinery and equipment, and other types of furniture and equipment including, but not limited to, office equipment, furniture and fixtures, and computer equipment and software.

+ References+ Details

Rate Matters And Regulation (Tables)

12 Months Ended

Dec. 31, 2012

Regulated Operations [Abstract]

Regulatory assets and liabilities reflected on our consolidated balance sheets are as follows.



	As of December 31,
	2012		2011
	(In Thousands)
Regulatory Assets:
Deferred employee benefit costs	$	542,174	$	560,915
Amounts due from customers for future income taxes, net	169,091		168,804
Depreciation	73,672		76,298
Debt reacquisition costs	67,721		66,856
Treasury yield hedges	28,573		33,753
Asset retirement obligations	22,633		22,196
Ad valorem tax	21,812		6,622
Energy efficiency program costs	18,835		16,521
Disallowed plant costs	16,106		16,236
Wolf Creek outage	14,143		25,033
Storm costs	11,076		25,747
Retail energy cost adjustment	4,262		19,587
Other regulatory assets	12,574		7,522
Total regulatory assets	$	1,002,672	$	1,046,090

Regulatory Liabilities:
Removal costs	$	128,971	$	82,338
Deferred regulatory gain from sale leaseback	92,046		97,541
Nuclear decommissioning	25,937		12,544
La Cygne dismantling costs	18,093		15,680
Retail energy cost adjustment	16,595		25,225
Kansas tax credits	10,781		8,497
Other post-retirement benefits costs	10,722		11,125
Gain on sale of oil	6,219		5,822
Fuel supply and electricity contracts	4,387		6,177
Other regulatory liabilities	9,424		6,438
Total regulatory liabilities	$	323,175	$	271,387

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Tables)

12 Months Ended

Dec. 31, 2012

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Abstract]

Carrying Values And Fair Values Of Financial Instruments

The following table provides the carrying values and measured fair values of our fixed-rate debt.



	As of December 31, 2012				As of December 31, 2011
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In Thousands)
Fixed-rate debt	$	2,702,500	$	3,178,752	$	2,373,063	$	2,623,993
Fixed-rate debt of VIEs	247,624		275,341		275,738		306,027

Fair Value Of Assets And Liabilities

The following table provides the amounts and their corresponding level of hierarchy for our assets and liabilities that are measured at fair value.



As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Energy Marketing Contracts	$	—	$	381	$	8,429	$	8,810
Nuclear Decommissioning Trust:
Domestic equity	—		56,157		4,899		61,056
International equity	—		30,041		—		30,041
Core bonds	—		28,350		—		28,350
High-yield bonds	—		8,782		—		8,782
Emerging market bonds	—		6,428		—		6,428
Combination debt/equity fund	—		8,194		—		8,194
Real estate securities	—		—		7,865		7,865
Cash equivalents	38		—		—		38
Total Nuclear Decommissioning Trust	38		137,952		12,764		150,754
Trading Securities:
Domestic equity	—		22,470		—		22,470
International equity	—		5,744		—		5,744
Core bonds	—		15,104		—		15,104
Cash equivalents	166		—		—		166
Total Trading Securities	166		43,318		—		43,484
Total Assets Measured at Fair Value	$	204	$	181,651	$	21,193	$	203,048

Liabilities:
Energy Marketing Contracts	$	—	$	105	$	1,367	$	1,472

As of December 31, 2011
Assets:
Energy Marketing Contracts	$	—	$	2,401	$	13,330	$	15,731
Nuclear Decommissioning Trust:
Domestic equity	—		53,186		3,931		57,117
International equity	—		22,307		—		22,307
Core bonds	—		20,171		—		20,171
High-yield bonds	—		10,969		—		10,969
Emerging market bonds	—		5,309		—		5,309
Combination debt/equity fund	—		7,251		—		7,251
Real estate securities	—		—		7,095		7,095
Cash equivalents	51		—		—		51
Total Nuclear Decommissioning Trust	51		119,193		11,026		130,270
Trading Securities:
Domestic equity	—		21,175		—		21,175
International equity	—		4,896		—		4,896
Core bonds	—		13,961		—		13,961
Cash equivalents	169		—		—		169
Total Trading Securities	169		40,032		—		40,201
Total Assets Measured at Fair Value	$	220	$	161,626	$	24,356	$	186,202

Liabilities:
Energy Marketing Contracts	$	—	$	2,475	$	3,878	$	6,353
Treasury Yield Hedges	—		34,025		—		34,025
Total Liabilities Measured at Fair Value	$	—	$	36,500	$	3,878	$	40,378

Reconciliations Of Assets And Liabilities At Fair Value

The following table provides reconciliations of assets and liabilities measured at fair value using significant level 3 inputs for the years ended December 31, 2012 and 2011.



	Energy Marketing Contracts, net				Nuclear Decommissioning Trust									Net Balance
	Energy Marketing Contracts, net				Domestic Equity			High-yield Bonds			Real Estate Securities			Net Balance
	(In Thousands)
Balance as of December 31, 2011	$	9,452			$	3,931		$	—		$	7,095		$	20,478
Total realized and unrealized gains (losses) included in:
Earnings (a)	2,176				—			—			—			2,176
Regulatory assets	(696		)	(b)	—			—			—			(696		)
Regulatory liabilities	2,114			(b)	90			—			770			2,974
Purchases	(5,034		)		891			—			320			(3,823		)
Sales	(620		)		(13		)	—			(320		)	(953		)
Settlements	(330		)		—			—			—			(330		)
Balance as of December 31, 2012	$	7,062			$	4,899		$	—		$	7,865		$	19,826

Balance as of December 31, 2010	$	11,815			$	2,867		$	305		$	3,049		$	18,036
Total realized and unrealized gains (losses) included in:
Earnings (a)	603				—			—			—			603
Regulatory assets	(1,450		)	(b)	—			—			—			(1,450		)
Regulatory liabilities	2,993			(b)	479			—			670			4,142
Purchases	(6,145		)		608			—			3,455			(2,082		)
Sales	1,022				(23		)	(305		)	(79		)	615
Settlements	614				—			—			—			614
Balance as of December 31, 2011	$	9,452			$	3,931		$	—		$	7,095		$	20,478

Unrealized Gains And Losses On Financial Statements

The following table summarizes the unrealized gains and losses we recorded on our consolidated financial statements during the years ended December 31, 2012 and 2011, attributed to level 3 assets and liabilities.



	Year Ended December 31, 2012
	Energy Marketing Contracts, net				Nuclear Decommissioning Trust
	Energy Marketing Contracts, net				Domestic Equity		Real Estate Securities		Net Balance
	(In Thousands)
Total unrealized gains (losses) included in:
Earnings (a)	$	(748	)		$	—	$	—	$	(748	)
Regulatory assets	(74		)	(b)	—		—		(74		)
Regulatory liabilities	332			(b)	77		451		860
Total	$	(490	)		$	77	$	451	$	38

	Year Ended December 31, 2011
Total unrealized gains (losses) included in:
Earnings (a)	$	(898	)		$	—	$	—	$	(898	)
Regulatory assets	(747		)	(b)	—		—		(747		)
Regulatory liabilities	1,736			(b)	456		591		2,783
Total	$	91			$	456	$	591	$	1,138

Fair Value Inputs Quantitative Information

The following table summarizes the quantitative inputs and assumptions for our level 3 investments not measured at net asset value.



	Fair Value as of
	December 31, 2012				Valuation Methodology	Unobservable Inputs	Range of Inputs
	Assets		Liabilities		Valuation Methodology	Unobservable Inputs	Range of Inputs
	(In Thousands)
Electricity - Forwards	$	862	$	358	Discounted cash flow	Basis (MWh)	$0	to	$15
Gas - Forwards	—		74		Discounted cash flow	Basis (mmBtu)	$0	to	$0.25
Options	7,567		935		Discounted cash flow	Basis - Electricity (MWh)	$0	to	$15
						Basis - Gas (mmBtu)	$0	to	$0.25
					Option models	Volatility - Electricity	10%	to	75%
						Volatility - Gas	20%	to	35%
						Correlation	60%	to	90%
Total	$	8,429	$	1,367

Investments In Financial Instruments

The following table provides additional information on these investments.



	As of December 31, 2012				As of December 31, 2011				As of December 31, 2012
	Fair Value		Unfunded Commitments		Fair Value		Unfunded Commitments		Redemption Frequency	Length of Settlement
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity	$	4,899	$	1,024	$	3,931	$	1,914	(a)	(a)
Real estate securities	7,865		—		7,095		—		Quarterly	80 days
Total Nuclear Decommissioning Trust	$	12,764	$	1,024	$	11,026	$	1,914

Trading Securities:
Domestic equity	$	22,470	$	—	$	21,175	$	—	Upon Notice	1 day
International equity	5,744		—		4,896		—		Upon Notice	1 day
Core bonds	15,104		—		13,961		—		Upon Notice	1 day
Total Trading Securities	43,318		—		40,032		—
Total	$	56,082	$	1,024	$	51,058	$	1,914

Fair Value Of Commodity Derivative Instruments

The following table presents the fair value of commodity derivative instruments reflected on our consolidated balance sheets.



Commodity Derivatives Not Designated as Hedging Instruments as of December 31, 2012
Asset Derivatives			Liability Derivatives
Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
	(In Thousands)			(In Thousands)
Current assets:			Current liabilities:
Other	$	4,776	Other	$	1,472
Other assets:
Other	4,034
Total	$	8,810

Commodity Derivatives Not Designated as Hedging Instruments as of December 31, 2011
Asset Derivatives			Liability Derivatives
Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
	(In Thousands)			(In Thousands)
Current assets:			Current liabilities:
Other	$	8,180	Other	$	6,353
Other assets:
Other	7,551
Total	$	15,731

Changes In The Fair Value Of Commodity Derivative Instruments



	Year Ended December 31, 2012						Year Ended December 31, 2011
Location	Net Gain Recognized			Net Loss Recognized			Net Gain Recognized		Net Loss Recognized
	(In Thousands)
Revenues	$	6,200		$	—		$	1,569	$	—
Regulatory assets	(374		)	—			—		374
Regulatory liabilities	—			(1,790		)	—		(1,623		)

Energy Related Products Contracts

As of December 31, 2012 and 2011, we had under contract the following commodity derivatives.



		Net Quantity as of
	Unit of Measure	December 31, 2012	December 31, 2011
Electricity	MWh	1,955,497	1,834,253
Natural Gas	MMBtu	1,674,000	1,467,500

Financial Investments (Tables)

12 Months Ended

Dec. 31, 2012

Investments [Abstract]

Cost And Fair Value Of Available-For-Sale Securities

The following table presents the cost, gross unrealized gains and losses, fair value and allocation of investments in the NDT fund as of December 31, 2012 and 2011.



			Gross Unrealized
Security Type	Cost		Gain		Loss			Fair Value		Allocation
	(Dollars In Thousands)
As of December 31, 2012
Domestic equity	$	53,598	$	7,458	$	—		$	61,056	41	%
International equity	28,248		1,793		—			30,041		20	%
Core bonds	27,309		1,041		—			28,350		19	%
High-yield bonds	8,022		760		—			8,782		6	%
Emerging market bonds	6,080		348		—			6,428		4	%
Combination debt/equity fund	8,074		120		—			8,194		5	%
Real estate securities	9,981		—		(2,116		)	7,865		5	%
Cash equivalents	38		—		—			38		<1%
Total	$	141,350	$	11,520	$	(2,116	)	$	150,754	100	%

As of December 31, 2011
Domestic equity	$	55,357	$	1,760	$	—		$	57,117	44	%
International equity	24,501		—		(2,194		)	22,307		17	%
Core bonds	19,771		400		—			20,171		16	%
High-yield bonds	11,046		—		(77		)	10,969		8	%
Emerging market bonds	5,301		8		—			5,309		4	%
Combination debt/equity fund	7,524		—		(273		)	7,251		6	%
Real estate securities	9,662		—		(2,567		)	7,095		5	%
Cash equivalents	51		—		—			51		<1%
Total	$	133,213	$	2,168	$	(5,111	)	$	130,270	100	%

Fair Value And Gross Unrealized Losses Of Available-For-Sale Securities



	Less than 12 Months					12 Months or Greater					Total
	Fair Value		Gross Unrealized Losses			Fair Value		Gross Unrealized Losses			Fair Value		Gross Unrealized Losses
	(In Thousands)
As of December 31, 2012
Real estate securities	$	—	$	—		$	7,865	$	(2,116	)	$	7,865	$	(2,116	)

As of December 31, 2011
International equity	$	22,307	$	(2,194	)	$	—	$	—		$	22,307	$	(2,194	)
High-yield bonds	10,969		(77		)	—		—			10,969		(77		)
Combination debt/equity fund	7,251		(273		)	—		—			7,251		(273		)
Real estate securities	—		—			7,095		(2,567		)	7,095		(2,567		)
Total	$	40,527	$	(2,544	)	$	7,095	$	(2,567	)	$	47,622	$	(5,111	)

Property, Plant And Equipment (Tables)

12 Months Ended

Dec. 31, 2012

Public Utility, Property, Plant and Equipment [Line Items]

Schedule of Public Utility Property, Plant, and Equipment

The following is a summary of our property, plant and equipment balance.



	As of December 31,
	2012			2011
	(In Thousands)
Electric plant in service	$	9,389,192		$	8,703,278
Electric plant acquisition adjustment	802,318			802,318
Accumulated depreciation	(3,791,545		)	(3,703,372		)
	6,399,965			5,802,224
Construction work in progress	532,332			534,003
Nuclear fuel, net	81,468			75,695
Net property, plant and equipment	$	7,013,765		$	6,411,922

Variable Interest Entity [Member]

Public Utility, Property, Plant and Equipment [Line Items]

Schedule of Public Utility Property, Plant, and Equipment

The following is a summary of property, plant and equipment of VIEs.



	As of December 31,
	2012			2011
	(In Thousands)
Electric plant of VIEs	$	543,548		$	543,548
Accumulated depreciation of VIEs	(221,573		)	(210,054		)
Net property, plant and equipment of VIEs	$	321,975		$	333,494

Joint Ownership of Utility Plants Joint Ownership of Utility Plants (Tables)

12 Months Ended

Dec. 31, 2012

Jointly Owned Utility Plant, Net Ownership Amount [Abstract]

Schedule of Jointly Owned Utility Plants

Information relative to our ownership interests in these facilities as of December 31, 2012, is shown in the table below.



Plant	In-Service Dates	Investment		Accumulated Depreciation		Construction Work in Progress		Net MW	Ownership Percentage
		(Dollars in Thousands)
La Cygne unit 1 (a)	June 1973	$	331,964	$	156,722	$	185,875	368	50
JEC unit 1 (a)	July 1978	528,478		196,511		80,217		661	92
JEC unit 2 (a)	May 1980	498,929		182,444		121		658	92
JEC unit 3 (a)	May 1983	703,393		282,481		1,000		664	92
Wolf Creek (b)	Sept. 1985	1,524,831		756,218		99,357		547	47
State Line (c)	June 2001	114,093		49,099		34		201	40
Total		$	3,701,688	$	1,623,475	$	366,604	3,099

_______________


(a)	Jointly owned with KCPL. Our 8% leasehold interest in JEC that is consolidated as a VIE is reflected in the net megawatts (MW) and ownership percentage provided above, but not in the other amounts in the table.


(b)	Jointly owned with KCPL and Kansas Electric Power Cooperative, Inc.

Short-term Debt Additional Information

Tabular disclosure of proportionate interests in jointly owned utility plants. Includes the amount of plants in service, the accumulated provision for depreciation (if available), the amount of plants under construction, and the proportionate share. The amounts presented may be further subdivided to show amounts applicable to plant subcategories (for example, production, transmission, distribution). Includes statements that the amounts represent the utility's share in each joint plant and that it must provide its own financing. Information concerning two or more generating plants on the same site may be combined. States that the utility's share of direct expenses of the joint plants is included in the corresponding operating expenses on its income statement (for example, fuel, maintenance of plant, other operating expense). If the share of direct expenses is charged to purchased power, then disclose the amount so charged and the proportionate amounts charged to specific operating expenses on the records maintained for the joint plants.

+ References+ Details

Short-Term Debt (Tables)

12 Months Ended

Dec. 31, 2012

Debt Disclosure [Abstract]

Additional information regarding our short-term debt is as follows.



	As of December 31,
	2012			2011
	(Dollars in Thousands)

Weighted average short-term debt outstanding during the year	$	298,907		$	362,946
Weighted daily average interest rates during the year, excluding fees	0.55		%	0.82		%

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2012

Long-term Debt, Unclassified [Abstract]

Long-term Debt Outstanding

The following table summarizes our long-term debt outstanding.



	As of December 31,
	2012			2011
	(In Thousands)
Westar Energy
First mortgage bond series:
6.00% due 2014	$	250,000		$	250,000
5.15% due 2017	125,000			125,000
5.95% due 2035	125,000			125,000
5.10% due 2020	250,000			250,000
5.875% due 2036	150,000			150,000
6.10% due 2047	—			150,000
8.625% due 2018	300,000			300,000
4.125% due 2042	550,000			—
	1,750,000			1,350,000
Pollution control bond series:
Variable due 2032, 0.32% as of December 31, 2012; 0.22% as of December 31, 2011	45,000			45,000
Variable due 2032, 0.26% as of December 31, 2012; 0.24% as of December 31, 2011	30,500			30,500
5.00% due 2033	—			57,245
	75,500			132,745

KGE
First mortgage bond series:
6.53% due 2037	175,000			175,000
6.15% due 2023	50,000			50,000
6.64% due 2038	100,000			100,000
6.70% due 2019	300,000			300,000
	625,000			625,000
Pollution control bond series:
5.10% due 2023	—			13,318
Variable due 2027, 0.26% as of December 31, 2012; 0.28% as of December 31, 2011	21,940			21,940
5.30% due 2031	108,600			108,600
5.30% due 2031	18,900			18,900
Variable due 2032, 0.26% as of December 31, 2012; 0.28% as of December 31, 2011	14,500			14,500
Variable due 2032, 0.26% as of December 31, 2012; 0.28% as of December 31, 2011	10,000			10,000
4.85% due 2031	50,000			50,000
5.60% due 2031	50,000			50,000
6.00% due 2031	50,000			50,000
5.00% due 2031	50,000			50,000
	373,940			387,258

Total long-term debt	2,824,440			2,495,003
Unamortized debt discount (a)	(5,169		)	(3,894		)
Long-term debt due within one year	—			—
Long-term debt, net	$	2,819,271		$	2,491,109

Variable Interest Entities
7.77% due 2012 (b)	$	—		$	2,583
6.99% due 2014 (b)	866			2,094
5.92 % due 2019 (b)	17,630			22,748
5.647% due 2021 (b)	229,128			248,313
Total long-term debt of variable interest entities	247,624			275,738
Unamortized debt premium (a)	1,061			1,659
Long-term debt of variable interest entities due within one year	(25,942		)	(28,114		)
Long-term debt of variable interest entities, net	$	222,743		$	249,283

_______________

(a) We amortize debt discounts and premiums to interest expense over the term of the respective issues.

(b) Portions of our payments related to this debt reduce the principal balances each year until maturity.

Schedule of Maturities of Long-term Debt

The principal amounts of our long-term debt maturities as of December 31, 2012, are as follows.



Year	Long-term debt		Long-term debt of VIEs
	(In Thousands)
2013	$	—	$	25,942
2014	250,000		27,479
2015	—		27,933
2016	—		28,309
2017	125,000		26,842
Thereafter	2,449,440		111,119
Total maturities	$	2,824,440	$	247,624

Tabular disclosure of 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 entity, if longer.

Income Tax Expense Components

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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+ Details

Taxes (Tables)

12 Months Ended

Dec. 31, 2012

Income Tax Disclosure [Abstract]

Income tax expense is comprised of the following components.



	Year Ended December 31,
	2012			2011			2010
	(In Thousands)
Income Tax Expense (Benefit):
Current income taxes:
Federal	$	(691	)	$	(8,575	)	$	(32,107	)
State	579			196			(3,030		)
Deferred income taxes:
Federal	102,960			93,089			102,568
State	26,300			21,337			20,305
Investment tax credit amortization	(3,012		)	(2,703		)	(2,704		)
Income tax expense	$	126,136		$	103,344		$	85,032

Deferred Tax Assets and Liabilities

Deferred tax assets and liabilities are reflected on our consolidated balance sheets as follows.



	As of December 31,
	2012		2011
	(In Thousands)
Other current liabilities (assets)	$	8,654	$	(394	)
Non-current deferred tax liabilities	1,197,837		1,110,463
Deferred tax liabilities	$	1,206,491	$	1,110,069

The tax effect of the temporary differences and carryforwards that comprise our deferred tax assets and deferred tax liabilities are summarized in the following table.



	As of December 31,
	2012		2011
	(In Thousands)
Deferred tax assets:
Tax credit carryforward (a)	$	199,160	$	159,163
Deferred employee benefit costs	191,997		202,687
Net operating loss carryforward (b)	111,869		84,365
Deferred state income taxes	55,577		42,209
Deferred regulatory gain on sale-leaseback	40,543		42,962
Alternative minimum tax carryforward (c)	36,471		36,471
Deferred compensation	28,319		28,286
Accrued liabilities	15,969		16,912
Disallowed costs	12,083		12,717
Capital loss carryforward (d)	11,509		12,554
Other	20,897		13,031
Total gross deferred tax assets	724,394		651,357
Less: Valuation allowance (e)	13,812		13,712
Deferred tax assets	$	710,582	$	637,645

Deferred tax liabilities:
Accelerated depreciation	$	1,255,892	$	1,088,727
Deferred employee benefit costs	191,997		202,687
Acquisition premium	179,920		187,934
Amounts due from customers for future income taxes, net	169,091		168,804
Deferred state income taxes	50,134		39,512
Pension expense tracker	22,437		14,600
Debt reacquisition costs	22,313		21,683
Storm costs	4,373		10,176
Other	20,916		13,591
Total deferred tax liabilities	$	1,917,073	$	1,747,714

Net deferred tax liabilities	$	1,206,491	$	1,110,069

_______________

(a)


(b)	As of December 31, 2012, we had a federal net operating loss carryforward of $276.9 million, which is available to offset federal taxable income. The net operating losses will expire beginning in 2030 and ending in 2032.


(c)	As of December 31, 2012, we had available an alternative minimum tax credit carryforward of $36.5 million, which has an unlimited carryforward period.


(d)	As of December 31, 2012, we had an unused capital loss carryforward of $29.1 million that is available to offset future capital gains. The capital losses will expire beginning in 2013 and ending in 2016.

(e)

Effective Income Tax Rate Reconciliation

The difference between the effective income tax rates and the federal statutory income tax rates are as follows.



	Year Ended December 31,
	2012		2011		2010
Statutory federal income tax rate	35.0	%	35.0	%	35.0	%
Effect of:
Corporate-owned life insurance policies	(4.9	)	(4.5	)	(6.1	)
State income taxes	4.3		4.1		3.8
Production tax credits	(2.4	)	(2.9	)	(3.4	)
Flow through depreciation for plant-related differences	1.4		1.8		2.6
AFUDC equity	(1.0	)	(0.6	)	(0.4	)
Amortization of federal investment tax credits	(0.7	)	(0.8	)	(0.9	)
Capital loss utilization	(0.3	)	(0.5	)	(0.7	)
Liability for unrecognized income tax benefits	0.2		—		(0.2	)
Other	(0.7	)	(1.2	)	(0.7	)
Effective income tax rate	30.9	%	30.4	%	29.0	%

Unrecognized Income Tax Benefits Reconciliation

A reconciliation of the beginning and ending amounts of unrecognized income tax benefits is as follows:



	2012			2011			2010
	(In Thousands)
Liability for unrecognized income tax benefits as of January 1	$	2,483		$	1,888		$	8,357
Additions based on tax positions related to the current year	373			967			608
Additions for tax positions of prior years	—			939			2,323
Reductions for tax positions of prior years	(1,637		)	(563		)	(1,241		)
Settlements	—			(748		)	(8,159		)
Liability for unrecognized income tax benefits as of December 31	$	1,219		$	2,483		$	1,888

Tabular disclosure of 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.

+ References+ Details

Employee Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2012

Schedule Of Benefit Obligation Fair Value Of Plan Assets And Amounts Recognized In Balance Sheet

The following tables summarize the status of our pension and post-retirement benefit plans.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	876,308		$	747,460		$	150,078		$	137,759
Service cost	19,556			16,076			2,057			1,803
Interest cost	39,576			40,045			6,298			6,793
Plan participants’ contributions	—			—			2,987			3,390
Benefits paid (a)	(60,229		)	(31,107		)	(9,799		)	(10,114		)
Actuarial losses (gains)	53,497			94,161			943			5,246
Amendments	—			—			—			4,451
Other (b)	—			9,673			—			750
Benefit obligation, end of year (c)	$	928,708		$	876,308		$	152,564		$	150,078

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	481,077		$	432,233		$	91,858		$	86,984
Actual return on plan assets	67,328			27,819			10,673			(174		)
Employer contributions	56,700			50,000			10,803			10,793
Plan participants’ contributions	—			—			2,845			3,244
Benefits paid (a)	(57,174		)	(28,975		)	(9,386		)	(9,739		)
Other (b)	—			—			—			750
Fair value of plan assets, end of year	$	547,931		$	481,077		$	106,793		$	91,858

Funded status, end of year	$	(380,777	)	$	(395,231	)	$	(45,771	)	$	(58,220	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(2,870	)	$	(2,741	)	$	(298	)	$	(115	)
Noncurrent liability	(377,907		)	(392,490		)	(45,473		)	(58,105		)
Net amount recognized	$	(380,777	)	$	(395,231	)	$	(45,771	)	$	(58,220	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	383,365		$	397,691		$	12,436		$	18,178
Prior service cost	3,994			4,606			16,467			18,991
Transition obligation	—			—			325			4,236
Net amount recognized	$	387,359		$	402,297		$	29,228		$	41,405

_______________


(a)	In 2012 certain former employees received a one-time lump sum payment of their pension benefits totaling $26.1 million.


(b)	As of December 31, 2011, Other includes the $9.7 million reclassification of a contractual obligation related to the legal settlement with a former executive officer and $0.8 million of proceeds received as a result of the Early Retiree Reinsurance Program.

(c)

Schedule Of Benefit Obligations In Excess Of Fair Value Of Plan Assets And Assumptions Used For Benefit Obligation



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	928,708		$	876,308		$	—		$	—
Fair value of plan assets	547,931			481,077			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	806,888		$	750,263		—			—
Fair value of plan assets	547,931			481,077			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	—			—			$	152,564		$	150,078
Fair value of plan assets	—			—			106,793			91,858

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	4.13		%	4.50		%	3.99		%	4.25		%
Compensation rate increase	4.00		%	4.00		%	—			—

Schedule Of Net Benefit Costs And Assumptions Used For Net Periodic Cost

Following is additional information regarding our pension and post-retirement benefit plans.



	Pension Benefits									Post-retirement Benefits
Year Ended December 31,	2012			2011			2010			2012			2011			2010
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	19,556		$	16,076		$	13,926		$	2,057		$	1,803		$	1,526
Interest cost	39,576			40,045			39,391			6,298			6,793			7,083
Expected return on plan assets	(32,283		)	(31,087		)	(38,384		)	(5,491		)	(5,002		)	(5,197		)
Amortization of unrecognized:
Transition obligation, net	—			—			—			3,912			3,911			3,912
Prior service costs	612			1,213			2,729			2,524			2,524			2,154
Actuarial loss/(gain), net	32,778			23,659			17,183			1,503			702			321
Net periodic cost before regulatory adjustment	60,239			49,906			34,845			10,803			10,731			9,799
Regulatory adjustment (a)	(6,523		)	(22,098		)	(12,167		)	23			1,344			1,868
Net periodic cost	$	53,716		$	27,808		$	22,678		$	10,826		$	12,075		$	11,667

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	18,451		$	97,429		$	65,690		$	(4,239	)	$	10,421		$	3,298
Amortization of actuarial (loss)/gain	(32,778		)	(23,659		)	(17,183		)	(1,503		)	(702		)	(321		)
Current year prior service cost	—			—			676			—			4,451			—
Amortization of prior service costs	(612		)	(1,213		)	(2,729		)	(2,524		)	(2,524		)	(2,154		)
Amortization of transition obligation	—			—			—			(3,912		)	(3,911		)	(3,912		)
Total recognized in regulatory assets	$	(14,939	)	$	72,557		$	46,454		$	(12,178	)	$	7,735		$	(3,089	)

Total recognized in net periodic cost and regulatory assets	$	38,777		$	100,365		$	69,132		$	(1,352	)	$	19,810		$	8,578

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost (Benefit):
Discount rate	4.50		%	5.35		%	5.95		%	4.25		%	5.00		%	5.65		%
Expected long-term return on plan assets	6.50		%	6.50		%	8.25		%	6.00		%	6.00		%	7.75		%
Compensation rate increase	4.00		%	4.00		%	4.00		%	—			—			—

_______________


(a)	The regulatory adjustment represents the difference between current period pension or post-retirement benefit expense and the amount of such expense recognized in setting our prices.

Schedule Of Amounts To Be Amortized From Regulatory Assets To Net Periodic Cost

We estimate that we will amortize the following amounts from regulatory assets into net periodic cost in 2013.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss	$	33,914	$	1,125
Prior service cost	601		2,524
Transition obligation	—		325
Total	$	34,515	$	3,974

Schedule of Health Care Cost Trend Rates

For measurement purposes, the assumed annual health care cost growth rates were as follows.



	As of December 31,
	2012	2011
Health care cost trend rate assumed for next year	8.0%	8.0%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.0%	5.0%

Year that the rate reaches the ultimate trend rate	2019	2018

Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates

The health care cost trend rate affects the projected benefit obligation. A 1% change in assumed health care cost growth rates would have effects shown in the following table.



	One-Percentage- Point Increase		One-Percentage- Point Decrease
	(In Thousands)
Effect on total of service and interest cost	$	67	$	(64	)
Effect on post-retirement benefit obligation	1,489		(1,384		)

Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets

The following table provides a reconciliation of pension plan assets measured at fair value using significant level 3 inputs for the years ended December 31, 2012 and 2011.



	Domestic Equity			High-yield Bonds			Real Estate Securities			Alternative Funds			Total
	(In Thousands)
Balance as of December 31, 2011	$	15,375		$	—		$	18,848		$	40,716		$	74,939
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	(25		)	—			2,296			4,819			7,090
Relating to assets sold during the period	53			—			(27		)	—			26
Purchases, issuances and settlements, net	3,090			—			(190		)	—			2,900
Balance as of December 31, 2012	$	18,493		$	—		$	20,927		$	45,535		$	84,955

Balance as of December 31, 2010	$	11,575		$	1,200		$	16,411		$	25,764		$	54,950
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	1,910			—			2,652			(48		)	4,514
Relating to assets sold during the period	—			—			(49		)	—			(49		)
Purchases, issuances and settlements, net	1,890			(1,200		)	(166		)	15,000			15,524
Balance as of December 31, 2011	$	15,375		$	—		$	18,848		$	40,716		$	74,939

Schedule of Expected Benefit Payments

Cash Flows

The following table shows the expected cash flows for our pension and post-retirement benefit plans for future years.



Expected Cash Flows	Pension Benefits						Post-retirement Benefits
	To/(From) Trust			(From) Company Assets			To/(From) Trust			(From) Company Assets
	(In Millions)
Expected contributions:
2013	$	30.0					$	6.0

Expected benefit payments:
2013	$	(31.3	)	$	(2.9	)	$	(7.9	)	$	(0.3	)
2014	(33.3		)	(2.8		)	(8.3		)	(0.3		)
2015	(35.3		)	(2.8		)	(8.8		)	(0.3		)
2016	(38.0		)	(2.8		)	(9.1		)	(0.3		)
2017	(41.1		)	(2.8		)	(9.5		)	(0.3		)
2018 - 2022	(247.1		)	(13.0		)	(49.6		)	(1.2		)

Schedule of Compensation Expense and Income Tax Benefits Related to Stock Compensation Arrangements

The table below shows compensation expense and income tax benefits related to stock-based compensation arrangements that are included in our net income.



	Year Ended December 31,
	2012		2011		2010
	(In Thousands)
Compensation expense	$	7,203	$	8,367	$	11,321
Income tax benefits related to stock-based compensation arrangements	2,849		3,309		4,481

Other Postretirement Benefit Plans, Defined Benefit [Member]

Schedule of Allocation of Plan Assets

The following table provides the fair value of our post-retirement benefit plan assets and the corresponding level of hierarchy as of December 31, 2012 and 2011.



As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	55,441	$	—	$	55,441
International equity	—		14,037		—		14,037
Core bonds	—		36,738		—		36,738
Cash equivalents	—		577		—		577
Total Assets Measured at Fair Value	$	—	$	106,793	$	—	$	106,793

As of December 31, 2011

Assets:
Domestic equity	$	—	$	47,411	$	—	$	47,411
International equity	—		11,500		—		11,500
Core bonds	—		32,192		—		32,192
Cash equivalents	—		755		—		755
Total Assets Measured at Fair Value	$	—	$	91,858	$	—	$	91,858

Pension Benefits [Member]

Schedule of Allocation of Plan Assets

The following table provides the fair value of our pension plan assets and the corresponding level of hierarchy as of December 31, 2012 and 2011.



As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	129,501	$	18,493	$	147,994
International equity	—		67,743		—		67,743
Core bonds	—		178,784		—		178,784
High-yield bonds	—		19,070		—		19,070
Emerging market bonds	—		14,276		—		14,276
Combination debt/equity fund	—		50,750		—		50,750
Real estate securities	—		—		20,927		20,927
Alternative funds	—		—		45,535		45,535
Cash equivalents	—		2,852		—		2,852
Total Assets Measured at Fair Value	$	—	$	462,976	$	84,955	$	547,931

As of December 31, 2011
Assets:
Domestic equity	$	—	$	121,364	$	15,375	$	136,739
International equity	—		53,943		—		53,943
Core bonds	—		142,700		—		142,700
High-yield bonds	—		38,380		—		38,380
Combination debt/equity fund	—		47,151		—		47,151
Real estate securities	—		—		18,848		18,848
Alternative funds	—		—		40,716		40,716
Cash equivalents	—		2,600		—		2,600
Total Assets Measured at Fair Value	$	—	$	406,138	$	74,939	$	481,077

RSU Awards With Performance Measures [Member]

Schedule of Share-based Compensation, Restricted Stock Units Award Activity

During the years ended December 31, 2012, 2011 and 2010, our RSU activity for awards with performance measures was as follows:



	As of December 31,
	2012				2011				2010
	Shares		Weighted- Average Grant Date Fair Value		Shares		Weighted- Average Grant Date Fair Value		Shares		Weighted- Average Grant Date Fair Value
	(Shares In Thousands)
Nonvested balance, beginning of year	324.2		$	28.31	348.4		$	24.98	—		$	—
Granted	122.3		28.84		244.4		31.26		366.0		24.96
Vested	(88.2	)	25.46		(119.5	)	24.12		(4.5	)	23.32
Forfeited	(18.2	)	29.00		(149.1	)	28.72		(13.1	)	24.99
Nonvested balance, end of year	340.1		29.20		324.2		28.31		348.4		24.98

RSU Awards With Only Service Requirements [Member]

Schedule of Share-based Compensation, Restricted Stock Units Award Activity

During the years ended December 31, 2012, 2011 and 2010, our RSU activity for awards with only service requirements was as follows:



	As of December 31,
	2012				2011				2010
	Shares		Weighted- Average Grant Date Fair Value		Shares		Weighted- Average Grant Date Fair Value		Shares		Weighted- Average Grant Date Fair Value
	(Shares In Thousands)
Nonvested balance, beginning of year	368.5		$	23.83	600.4		$	21.50	368.8		$	21.98
Granted	131.0		27.82		284.1		26.30		366.4		22.14
Vested	(127.8	)	23.34		(187.3	)	23.50		(118.1	)	24.81
Forfeited	(20.6	)	24.40		(328.7	)	24.37		(16.7	)	22.32
Nonvested balance, end of year	351.1		25.47		368.5		23.83		600.4		21.50

Wolf Creek Employee Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2012

Wolf Creek Interim Pension And Post-Retirement Benefit Disclosure [Line Items]

Schedule Of Benefit Obligation Fair Value Of Plan Assets And Amounts Recognized In Balance Sheet

The following tables summarize the status of our pension and post-retirement benefit plans.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	876,308		$	747,460		$	150,078		$	137,759
Service cost	19,556			16,076			2,057			1,803
Interest cost	39,576			40,045			6,298			6,793
Plan participants’ contributions	—			—			2,987			3,390
Benefits paid (a)	(60,229		)	(31,107		)	(9,799		)	(10,114		)
Actuarial losses (gains)	53,497			94,161			943			5,246
Amendments	—			—			—			4,451
Other (b)	—			9,673			—			750
Benefit obligation, end of year (c)	$	928,708		$	876,308		$	152,564		$	150,078

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	481,077		$	432,233		$	91,858		$	86,984
Actual return on plan assets	67,328			27,819			10,673			(174		)
Employer contributions	56,700			50,000			10,803			10,793
Plan participants’ contributions	—			—			2,845			3,244
Benefits paid (a)	(57,174		)	(28,975		)	(9,386		)	(9,739		)
Other (b)	—			—			—			750
Fair value of plan assets, end of year	$	547,931		$	481,077		$	106,793		$	91,858

Funded status, end of year	$	(380,777	)	$	(395,231	)	$	(45,771	)	$	(58,220	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(2,870	)	$	(2,741	)	$	(298	)	$	(115	)
Noncurrent liability	(377,907		)	(392,490		)	(45,473		)	(58,105		)
Net amount recognized	$	(380,777	)	$	(395,231	)	$	(45,771	)	$	(58,220	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	383,365		$	397,691		$	12,436		$	18,178
Prior service cost	3,994			4,606			16,467			18,991
Transition obligation	—			—			325			4,236
Net amount recognized	$	387,359		$	402,297		$	29,228		$	41,405

_______________


(a)	In 2012 certain former employees received a one-time lump sum payment of their pension benefits totaling $26.1 million.


(b)	As of December 31, 2011, Other includes the $9.7 million reclassification of a contractual obligation related to the legal settlement with a former executive officer and $0.8 million of proceeds received as a result of the Early Retiree Reinsurance Program.

(c)

Schedule Of Benefit Obligations In Excess Of Fair Value Of Plan Assets And Assumptions Used For Benefit Obligation



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	928,708		$	876,308		$	—		$	—
Fair value of plan assets	547,931			481,077			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	806,888		$	750,263		—			—
Fair value of plan assets	547,931			481,077			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	—			—			$	152,564		$	150,078
Fair value of plan assets	—			—			106,793			91,858

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	4.13		%	4.50		%	3.99		%	4.25		%
Compensation rate increase	4.00		%	4.00		%	—			—

Schedule Of Net Benefit Costs And Assumptions Used For Net Periodic Cost

Following is additional information regarding our pension and post-retirement benefit plans.



	Pension Benefits									Post-retirement Benefits
Year Ended December 31,	2012			2011			2010			2012			2011			2010
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	19,556		$	16,076		$	13,926		$	2,057		$	1,803		$	1,526
Interest cost	39,576			40,045			39,391			6,298			6,793			7,083
Expected return on plan assets	(32,283		)	(31,087		)	(38,384		)	(5,491		)	(5,002		)	(5,197		)
Amortization of unrecognized:
Transition obligation, net	—			—			—			3,912			3,911			3,912
Prior service costs	612			1,213			2,729			2,524			2,524			2,154
Actuarial loss/(gain), net	32,778			23,659			17,183			1,503			702			321
Net periodic cost before regulatory adjustment	60,239			49,906			34,845			10,803			10,731			9,799
Regulatory adjustment (a)	(6,523		)	(22,098		)	(12,167		)	23			1,344			1,868
Net periodic cost	$	53,716		$	27,808		$	22,678		$	10,826		$	12,075		$	11,667

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	18,451		$	97,429		$	65,690		$	(4,239	)	$	10,421		$	3,298
Amortization of actuarial (loss)/gain	(32,778		)	(23,659		)	(17,183		)	(1,503		)	(702		)	(321		)
Current year prior service cost	—			—			676			—			4,451			—
Amortization of prior service costs	(612		)	(1,213		)	(2,729		)	(2,524		)	(2,524		)	(2,154		)
Amortization of transition obligation	—			—			—			(3,912		)	(3,911		)	(3,912		)
Total recognized in regulatory assets	$	(14,939	)	$	72,557		$	46,454		$	(12,178	)	$	7,735		$	(3,089	)

Total recognized in net periodic cost and regulatory assets	$	38,777		$	100,365		$	69,132		$	(1,352	)	$	19,810		$	8,578

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost (Benefit):
Discount rate	4.50		%	5.35		%	5.95		%	4.25		%	5.00		%	5.65		%
Expected long-term return on plan assets	6.50		%	6.50		%	8.25		%	6.00		%	6.00		%	7.75		%
Compensation rate increase	4.00		%	4.00		%	4.00		%	—			—			—

_______________


(a)	The regulatory adjustment represents the difference between current period pension or post-retirement benefit expense and the amount of such expense recognized in setting our prices.

Schedule Of Amounts To Be Amortized From Regulatory Assets To Net Periodic Cost

We estimate that we will amortize the following amounts from regulatory assets into net periodic cost in 2013.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss	$	33,914	$	1,125
Prior service cost	601		2,524
Transition obligation	—		325
Total	$	34,515	$	3,974

Schedule of Health Care Cost Trend Rates

For measurement purposes, the assumed annual health care cost growth rates were as follows.



	As of December 31,
	2012	2011
Health care cost trend rate assumed for next year	8.0%	8.0%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.0%	5.0%

Year that the rate reaches the ultimate trend rate	2019	2018

Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates

The health care cost trend rate affects the projected benefit obligation. A 1% change in assumed health care cost growth rates would have effects shown in the following table.



	One-Percentage- Point Increase		One-Percentage- Point Decrease
	(In Thousands)
Effect on total of service and interest cost	$	67	$	(64	)
Effect on post-retirement benefit obligation	1,489		(1,384		)

Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets

The following table provides a reconciliation of pension plan assets measured at fair value using significant level 3 inputs for the years ended December 31, 2012 and 2011.



	Domestic Equity			High-yield Bonds			Real Estate Securities			Alternative Funds			Total
	(In Thousands)
Balance as of December 31, 2011	$	15,375		$	—		$	18,848		$	40,716		$	74,939
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	(25		)	—			2,296			4,819			7,090
Relating to assets sold during the period	53			—			(27		)	—			26
Purchases, issuances and settlements, net	3,090			—			(190		)	—			2,900
Balance as of December 31, 2012	$	18,493		$	—		$	20,927		$	45,535		$	84,955

Balance as of December 31, 2010	$	11,575		$	1,200		$	16,411		$	25,764		$	54,950
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	1,910			—			2,652			(48		)	4,514
Relating to assets sold during the period	—			—			(49		)	—			(49		)
Purchases, issuances and settlements, net	1,890			(1,200		)	(166		)	15,000			15,524
Balance as of December 31, 2011	$	15,375		$	—		$	18,848		$	40,716		$	74,939

Schedule of Expected Benefit Payments

Cash Flows

The following table shows the expected cash flows for our pension and post-retirement benefit plans for future years.



Expected Cash Flows	Pension Benefits						Post-retirement Benefits
	To/(From) Trust			(From) Company Assets			To/(From) Trust			(From) Company Assets
	(In Millions)
Expected contributions:
2013	$	30.0					$	6.0

Expected benefit payments:
2013	$	(31.3	)	$	(2.9	)	$	(7.9	)	$	(0.3	)
2014	(33.3		)	(2.8		)	(8.3		)	(0.3		)
2015	(35.3		)	(2.8		)	(8.8		)	(0.3		)
2016	(38.0		)	(2.8		)	(9.1		)	(0.3		)
2017	(41.1		)	(2.8		)	(9.5		)	(0.3		)
2018 - 2022	(247.1		)	(13.0		)	(49.6		)	(1.2		)

Wolf Creek [Member]

Wolf Creek Interim Pension And Post-Retirement Benefit Disclosure [Line Items]

Schedule Of Benefit Obligation Fair Value Of Plan Assets And Amounts Recognized In Balance Sheet

The following tables summarize the status of KGE's 47% share of the Wolf Creek pension and post-retirement benefit plans.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	161,396		$	131,460		$	10,129		$	10,144
Service cost	6,062			4,957			191			165
Interest cost	7,537			7,370			411			458
Plan participants’ contributions	—			—			608			614
Benefits paid (a)	(8,569		)	(3,033		)	(988		)	(979		)
Actuarial losses (gains)	9,815			20,642			669			(360		)
Amendments	650			—			—			—
Other (b)	—			—			—			87
Benefit obligation, end of year	$	176,891		$	161,396		$	11,020		$	10,129

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	80,727		$	76,086		$	4		$	—
Actual return on plan assets	11,764			(2,578		)	—			—
Employer contributions	13,887			10,009			389			369
Plan participants' contributions	—			—			608			614
Benefits paid	(8,327		)	(2,790		)	(988		)	(979		)
Fair value of plan assets, end of year	$	98,051		$	80,727		$	13		$	4

Funded status, end of year	$	(78,840	)	$	(80,669	)	$	(11,007	)	$	(10,125	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(243	)	$	(243	)	$	(625	)	$	(609	)
Noncurrent liability	(78,597		)	(80,426		)	(10,382		)	(9,516		)
Net amount recognized	$	(78,840	)	$	(80,669	)	$	(11,007	)	$	(10,125	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	64,535		$	65,273		$	3,643		$	3,208
Prior service cost	675			31			—			—
Transition obligation	—			—			1			58
Net amount recognized	$	65,210		$	65,304		$	3,644		$	3,266

_______________


(a)	In 2012 certain former employees received a one-time lump sum payment of their pension benefits. Our share of the payment totaled $4.9 million.


(b)	Includes proceeds received as a result of the Early Retiree Reinsurance Program.

Schedule Of Benefit Obligations In Excess Of Fair Value Of Plan Assets And Assumptions Used For Benefit Obligation



	Pension Benefits						Post-retirement Benefits
As of December 31,	2012			2011			2012			2011
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	176,891		$	161,396		$	—		$	—
Fair value of plan assets	98,051			80,727			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	141,722		$	128,633		$	—		$	—
Fair value of plan assets	98,051			80,727			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	$	—		$	—		$	11,020		$	10,129
Fair value of plan assets	—			—			13			4

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	4.16		%	4.55		%	3.78		%	4.10		%
Compensation rate increase	4.00		%	4.00		%	—			—

Schedule Of Net Benefit Costs And Assumptions Used For Net Periodic Cost

Following is additional information regarding KGE's 47% share of the Wolf Creek pension and other post-retirement benefit plans.



	Pension Benefits									Post-retirement Benefits
Year Ended December 31,	2012			2011			2010			2012			2011			2010
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	6,062		$	4,957		$	4,144		$	191		$	165		$	179
Interest cost	7,537			7,370			6,941			411			458			519
Expected return on plan assets	(6,577		)	(5,904		)	(5,453		)	—			—			—
Amortization of unrecognized:
Transition obligation, net	—			52			57			57			58			58
Prior service costs	6			16			29			—			—			—
Actuarial loss, net	5,366			3,586			2,636			234			227			276
Net periodic cost before regulatory adjustment	12,394			10,077			8,354			893			908			1,032
Regulatory adjustment (a)	(1,776		)	(2,546		)	(1,498		)	—			—			—
Net periodic cost	$	10,618		$	7,531		$	6,856		$	893		$	908		$	1,032

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	4,629		$	29,124		$	7,514		$	669		$	(360	)	$	363
Amortization of actuarial loss	(5,366		)	(3,586		)	(2,636		)	(234		)	(227		)	(276		)
Current year prior service cost	650			—			—			—			—			—
Amortization of prior service cost	(6		)	(16		)	(29		)	—			—			—
Amortization of transition obligation	—			(52		)	(57		)	(57		)	(58		)	(58		)
Total recognized in regulatory assets	$	(93	)	$	25,470		$	4,792		$	378		$	(645	)	$	29

Total recognized in net periodic cost and regulatory assets	$	10,525		$	33,001		$	11,648		$	1,271		$	263		$	1,061

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.55		%	5.45		%	6.05		%	4.10		%	4.90		%	5.50		%
Expected long-term return on plan assets	7.50		%	7.50		%	8.00		%	—			—			—
Compensation rate increase	4.00		%	4.00		%	4.00		%	—			—			—

Schedule Of Amounts To Be Amortized From Regulatory Assets To Net Periodic Cost

We estimate that we will amortize the following amounts from regulatory assets into net periodic cost in 2013.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss	$	5,421	$	264
Prior service cost	58		—
Transition obligation	—		1
Total	$	5,479	$	265

Schedule of Health Care Cost Trend Rates

For measurement purposes, the assumed annual health care cost growth rates were as follows.



	As of December 31,
	2012		2011
Health care cost trend rate assumed for next year	8.0	%	8.0	%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.0	%	5.0	%

Year that the rate reaches the ultimate trend rate	2019		2018

Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates

The health care cost trend rate affects the projected benefit obligation. A 1% change in assumed health care cost growth rates would have effects shown in the following table.



	One-Percentage- Point Increase			One-Percentage- Point Decrease
	(In Thousands)
Effect on total of service and interest cost	$	(10	)	$	10
Effect on post-retirement benefit obligation	(129		)	128

Schedule of Allocation of Plan Assets

The following table provides the fair value of KGE's 47% share of Wolf Creek's pension plan assets and the corresponding level of hierarchy as of December 31, 2012 and 2011.



As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	24,305	$	—	$	24,305
International equity	—		30,484		—		30,484
Core bonds	—		24,763		—		24,763
Real estate securities	—		4,972		4,541		9,513
Commodities	—		4,789		—		4,789
Alternative investments	—		—		3,900		3,900
Cash equivalents	—		297		—		297
Total Assets Measured at Fair Value	$	—	$	89,610	$	8,441	$	98,051

As of December 31, 2011
Assets:
Domestic equity	$	30,753	$	—	$	—	$	30,753
International equity	9,953		8,070		—		18,023
Core bonds	—		17,877		—		17,877
High-yield bonds	4,102		—		—		4,102
Real estate securities	—		—		3,630		3,630
Commodities	—		4,377		—		4,377
Cash equivalents	—		1,965		—		1,965
Total Assets Measured at Fair Value	$	44,808	$	32,289	$	3,630	$	80,727

Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets




	Real Estate Securities			Alternative Investments		Total
	(In Thousands)
Balance as of December 31, 2011	$	3,630		$	—	$	3,630
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	(411		)	23		(388		)
Relating to assets sold during the period	755			—		755
Purchases, issuances and settlements, net	567			3,877		4,444
Balance as of December 31, 2012	$	4,541		$	3,900	$	8,441

Balance as of December 31, 2010	$	3,160		$	—	$	3,160
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	500			—		500
Relating to assets sold during the period	2			—		2
Purchases, issuances and settlements, net	(32		)	—		(32		)
Balance as of December 31, 2011	$	3,630		$	—	$	3,630

Schedule of Expected Benefit Payments

The following table shows our expected cash flows for KGE's 47% share of Wolf Creek's pension and post-retirement benefit plans for future years.



Expected Cash Flows	Pension Benefits						Post-retirement Benefits
	To/(From) Trust			(From) Company Assets			To/(From) Trust			(From) Company Assets
	(In Millions)
Expected contributions:
2013	$	9.4					$	0.6

Expected benefit payments:
2013	$	(3.7	)	$	(0.2	)	$	(0.6	)	$	—
2014	(4.3		)	(0.2		)	(0.7		)	—
2015	(5.0		)	(0.2		)	(0.7		)	—
2016	(5.8		)	(0.2		)	(0.8		)	—
2017	(6.7		)	(0.2		)	(0.8		)	—
2018 - 2022	(46.9		)	(0.9		)	(4.5		)	—

Variable Interest Entities (Tables)

12 Months Ended

Dec. 31, 2012

Variable Interest Entities [Abstract]

Assets And Liabilities In Relation To VIEs

We have recorded the following assets and liabilities on our consolidated balance sheets related to the VIEs described above.



	As of December 31,
	2012		2011
	(In Thousands)
Assets:
Property, plant and equipment of variable interest entities, net	$	321,975	$	333,494
Regulatory assets (a)	5,810		4,915

Liabilities:
Current maturities of long-term debt of variable interest entities	$	25,942	$	28,114
Accrued interest (b)	3,948		4,448
Long-term debt of variable interest entities, net	222,743		249,283

_______________

(a) Included in long-term regulatory assets on our consolidated balance sheets.

(b) Included in accrued interest on our consolidated balance sheets.

Tabular disclosure of the significant judgments and assumptions made in determining whether a variable interest (as defined) held by the entity requires the variable interest entity (VIE) (as defined) to be consolidated and (or) disclose information about its involvement with the VIE, individually or in aggregate (as applicable); the nature of restrictions, if any, on the consolidated VIE's assets and on the settlement of its liabilities reported by an entity in its statement of financial position, including the carrying amounts of such assets and liabilities; the nature of, and changes in, the risks associated with involvement in the VIE; how involvement with the VIE affects the entity's financial position, financial performance, and cash flows; the lack of recourse if creditors (or beneficial interest holders) of the consolidated VIE have no recourse to the general credit of the primary beneficiary (if applicable); the terms of arrangements, giving consideration to both explicit arrangements and implicit variable interests, if any, that could require the entity to provide financial support to the VIE, including events or circumstances that could expose the entity to a loss; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; the significant factors considered and judgments made in determining that the power to direct the activities of a VIE that most significantly impact the VIE's economic performance are shared (as defined); the carrying amounts and classification of assets and liabilities of the VIE included in the statement of financial position; the entity's maximum exposure to loss, if any, as a result of its involvement with the VIE, including how the maximum exposure is determined and significant sources of the entity's exposure to the VIE; a comparison of the carrying amounts of the assets and liabilities and the entity's maximum exposure to loss; information about any liquidity arrangements, guarantees, and (or) other commitments by third parties that may affect the fair value or risk of the entity's variable interest in the VIE; whether or not the entity has provided financial support or other support (explicitly or implicitly) to the VIE that it was not previously contractually required to provide or whether the entity intends to provide that support, including the type and amount of the support and the primary reasons for providing the support; and supplemental information the entity determines necessary to provide.

Operating Leases, Minimum Annual Rental Payments

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-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 167

-Paragraph 22E

-Appendix D

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-URI http://asc.fasb.org/extlink&oid=6528138

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+ Details

Leases (Tables)

12 Months Ended

Dec. 31, 2012

Leases [Abstract]

Rental expense and estimated future commitments under operating leases are as follows.



Year Ended December 31,	Total Operating Leases
	(In Thousands)
Rental expense:
2010	$	15,464
2011	17,577
2012	17,080

Future commitments:
2013	$	14,453
2014	12,550
2015	10,142
2016	8,390
2017	6,694
Thereafter	18,049
Total future commitments	$	70,278

Assets Recorded Under Capital Leases

Assets recorded under capital leases, including the 2012 and 2011 leases described above presented as generation plant, are listed below.



	As of December 31,
	2012			2011
	(In Thousands)
Vehicles	$	12,594		$	14,241
Computer equipment	1,423			1,720
Generation plant	48,346			40,048
Accumulated amortization	(6,928		)	(6,485		)
Total capital leases	$	55,435		$	49,524

Capital Leases, Minimum Annual Rental Payments

Minimum annual rental payments, excluding administrative costs such as property taxes, insurance and maintenance, under capital leases are listed below.



Year Ended December 31,	Total Capital Leases
	(In Thousands)
2013	$	6,538
2014	6,363
2015	5,840
2016	5,087
2017	4,708
Thereafter	76,800
	105,336
Amounts representing imputed interest	(48,461		)
Present value of net minimum lease payments under capital leases	56,875
Less: Current portion	3,066
Total long-term obligation under capital leases	$	53,809

Quarterly Results (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2012

Quarterly Financial Information Disclosure [Abstract]

Schedule of Quarterly Financial Information

Our business is seasonal in nature and, in our opinion, comparisons between the quarters of a year do not give a true indication of overall trends and changes in operations.



2012	First		Second		Third		Fourth
	(In Thousands, Except Per Share Amounts)

Revenues (a)	$	475,677	$	566,262	$	695,758	$	523,772
Net income (a)	29,237		64,462		141,067		47,695
Net income attributable to common stock (a)	27,282		61,361		139,281		45,607

Per Share Data (a):

Basic:
Earnings available	$	0.21	$	0.48	$	1.10	$	0.36

Diluted:
Earnings available	$	0.21	$	0.48	$	1.09	$	0.36

Cash dividend declared per common share	$	0.33	$	0.33	$	0.33	$	0.33
Market price per common share:
High	$	29.13	$	30.17	$	33.04	$	30.29
Low	$	27.12	$	26.80	$	28.96	$	27.33

_______________


(a)	Items are computed independently for each of the periods presented and the sum of the quarterly amounts may not equal the total for the year.



2011	First		Second		Third		Fourth
	(In Thousands, Except Per Share Amounts)

Revenues (a)	$	481,720	$	524,892	$	678,152	$	486,228
Net income (a)	32,957		45,525		136,392		21,306
Net income attributable to common stock (a)	31,342		43,887		134,708		19,335

Per Share Data (a):

Basic:
Earnings available	$	0.27	$	0.38	$	1.15	$	0.16

Diluted:
Earnings available	$	0.27	$	0.38	$	1.14	$	0.16

Cash dividend declared per common share	$	0.32	$	0.32	$	0.32	$	0.32
Market price per common share:
High	$	26.60	$	27.98	$	27.29	$	29.05
Low	$	25.05	$	25.58	$	22.63	$	25.02

_______________


(a)	Items are computed independently for each of the periods presented and the sum of the quarterly amounts may not equal the total for the yea

Summary Of Significant Accounting Policies (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Property, Plant and Equipment [Line Items]
Average annual composite basis group depreciation rates	2.60%	3.00%	2.90%
Unbilled revenue	$ 62,500,000	$ 54,000,000
Gain on sale of non-utility investment	0	(7,246,000)	0
Nuclear Fuel [Member]
Property, Plant and Equipment [Line Items]
Accumulated amortization	69,200,000	44,800,000
Nuclear fuel charged to fuel and purchased power expense	$ 28,300,000	$ 24,600,000	$ 29,200,000

Summary Of Significant Accounting Policies (Allowance For Funds Used During Construction) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Accounting Policies [Abstract]
Borrowed funds	$ 10,399	$ 5,589	$ 4,295
Equity funds	11,706	5,550	3,104
Total	$ 22,105	$ 11,139	$ 7,399
Average AFUDC rates	5.00%	3.60%	2.60%

Total increase in earnings in the period representing the cost of equity (based on assumed rate of return) and/or borrowed funds (based on interest rate) used to finance construction of regulated assets, which is expected to be recovered through rate adjustments.

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+ Details

Summary Of Significant Accounting Policies (Depreciable Lives of PP&E) (Details)	12 Months Ended
	Dec. 31, 2012
Minimum [Member]
Depreciable Lives [Line Items]
Transmission facilities, estimated useful life	15
Distribution facilities, estimated useful life	15
Other property, plant and equipment, estimated useful life	5
Maximum [Member]
Depreciable Lives [Line Items]
Transmission facilities, estimated useful life	75
Distribution facilities, estimated useful life	70
Other property, plant and equipment, estimated useful life	30
Fossil Fuel Plant [Member] \| Minimum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	6
Fossil Fuel Plant [Member] \| Maximum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	78
Nuclear Plant [Member] \| Minimum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	33
Nuclear Plant [Member] \| Maximum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	71
Other Plant in Service [Member] \| Minimum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	19
Other Plant in Service [Member] \| Maximum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	20

Summary Of Significant Accounting Policies (Cash Surrender Value of Life Insurance) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Accounting Policies [Abstract]
Cash surrender value of policies	$ 1,370,788	$ 1,345,443
Borrowings against policies	(1,241,343)	(1,208,389)
Corporate-owned life insurance, net	$ 129,445	$ 137,054

Carrying amount as of the balance sheet date of amounts which could be received based on the terms of the insurance contract upon surrendering life policies owned by the entity.

+ References+ Details

This item represents the amount that could be realized under a life insurance contract or contracts owned by the Entity as of the date of the statement of financial position. Such Entity-owned life insurance policies are commonly known as corporate-owned life insurance (COLI) or bank-owned life insurance (BOLI).

+ References+ Details

Summary Of Significant Accounting Policies (Reconciliation Of Basic And Diluted EPS) (Details) (USD $)
In Thousands, except Share data, unless otherwise specified

3 Months Ended

12 Months Ended

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Less: Net income attributable to noncontrolling interests

Net income

$ 282,462

$ 236,180

$ 208,624

7,316

5,941

4,728

Net income attributable to Westar Energy, Inc.

275,146

230,239

203,896

Less: Preferred dividends

1,616

970

Net income allocated to RSUs

778

772

1,259

Net income allocated to common stock

$ 272,752

$ 228,497

$ 201,667

Weighted average equivalent common shares outstanding - basic

126,711,869

116,890,552

111,629,292

RSUs

97,757

188,025

140,077

Forward sale agreements

89,160

1,211,645

245,496

Employee stock options

Weighted average equivalent common shares outstanding - diluted

126,898,786

118,290,222

112,014,924

Basic earnings per common share

$ 0.36

$ 1.10

^[1]

$ 0.48

$ 0.21

$ 0.16

$ 1.15

^[1]

$ 0.38

$ 0.27

$ 2.15

$ 1.95

$ 1.81

Diluted earnings per common share

$ 0.36

$ 1.09

^[1]

$ 0.48

$ 0.21

$ 0.16

$ 1.14

^[1]

$ 0.38

$ 0.27

$ 2.15

$ 1.93

$ 1.80

Antidilutive shares

[1]	(a)Items are computed independently for each of the periods presented and the sum of the quarterly amounts may not equal the total for the year.

Summary Of Significant Accounting Policies (Supplemental Cash Flow Information) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Cash Paid For (Received From)
Interest on financing activities	$ 143,564	$ 145,570	$ 145,463
Income taxes, net of refunds	(4,378)	(17,519)	(34,980)
Noncash Investing and Financing Transactions
Property, plant and equipment additions	89,354	105,435	64,423
Jeffrey Energy Center (JEC) 8% leasehold interest	0	0	(108,706)
Issuance of common stock for reinvested dividends and compensation plans	12,803	15,103	18,777
Capital lease for JEC 8% leasehold interest	0	0	(106,423)
Assets acquired through capital leases	10,683	43,011	910
Variable Interest Entity, Primary Beneficiary [Member]
Cash Paid For (Received From)
Interest on financing activities	16,214	18,167	20,191
Noncash Investing and Financing Transactions
Property, plant and equipment additions	0	0	356,964
Debt of VIEs	$ 0	$ 0	$ 337,951

Rate Matters And Regulation (Regulatory Assets and Liabilities) (Details) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	$ 1,002,672,000	$ 1,046,090,000
Regulatory Liabilities	323,175,000	271,387,000
Removal Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	128,971,000	82,338,000
Deferred Regulatory Gain From Sale Leaseback [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	92,046,000	97,541,000
Nuclear Decommissioning [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	25,937,000	12,544,000
La Cygne Dismantling Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	18,093,000	15,680,000
Retail Energy Cost Adjustment [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	16,595,000	25,225,000
Kansas Tax Credits [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	10,781,000	8,497,000
Other Post-retirement Benefit Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	10,722,000	11,125,000
Gain on Sale of Oil [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	6,219,000	5,822,000
Fuel Supply and Electricity Contracts [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	4,387,000	6,177,000
Other Regulatory Liabilities [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	9,424,000	6,438,000
Other Pension Plans, Postretirement or Supplemental Plans, Defined Benefit [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	485,500,000
Pension Cost [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	56,700,000
Deferred Employee Benefit Costs Amortization Expense, Next Twelve Months	9,800,000
Deferred Employee Benefit Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	542,174,000	560,915,000
Deferred Employee Benefit Costs Amortization Expense, Next Twelve Months	44,200,000
Amounts Due From Customers For Future Income Taxes, Net [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	169,091,000	168,804,000
Depreciation [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	73,672,000	76,298,000
Debt Reacquisition Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	67,721,000	66,856,000
Asset Retirement Obligation [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	22,633,000	22,196,000
Ad Valorem Tax [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	21,812,000	6,622,000
Energy Efficiency Program Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	18,835,000	16,521,000
Disallowed Plant Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	16,106,000	16,236,000
Wolf Creek Outage [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	14,143,000	25,033,000
Storm Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	11,076,000	25,747,000
Retail Energy Cost Adjustment [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	4,262,000	19,587,000
Other Regulatory Assets [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	12,574,000	7,522,000
Cash Flow Hedging [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	$ 28,573,000	$ 33,753,000

Rate Matters And Regulation (Narrative) (Details) (USD $)	0 Months Ended			12 Months Ended											12 Months Ended						12 Months Ended
	Oct. 15, 2011	Oct. 15, 2010	Oct. 15, 2009	Dec. 31, 2012	Oct. 31, 2012	Sep. 27, 2012	May 29, 2012	Apr. 18, 2012	Dec. 30, 2011	Oct. 27, 2011	May 27, 2011	Oct. 29, 2010	Jun. 11, 2010	May 25, 2010	Dec. 31, 2012 La Cygne Generating Station [Member]	Dec. 31, 2012 Retail Energy Cost Adjustment [Member] Y	Dec. 31, 2012 Other Post-retirement Benefit Costs [Member] Y	Dec. 31, 2012 Gain on Sale of Oil [Member] Y	Dec. 31, 2012 Pension Cost [Member] Y	Dec. 31, 2012 Deferred Employee Benefit Costs [Member]	Dec. 31, 2012 Ad Valorem Tax [Member] Y	Dec. 31, 2012 Energy Efficiency Program Costs [Member] Y	Dec. 31, 2012 Storm Costs [Member] Minimum [Member] Y	Dec. 31, 2012 Storm Costs [Member] Maximum [Member] Y	Dec. 31, 2012 Retail Energy Cost Adjustment [Member] Y	Jan. 27, 2010 Abbreviated Rate Review, Period Two [Member]
Regulatory Assets and Liabilities [Line Items]
Deferred Employee Benefit Costs Amortization Expense, Next Twelve Months																			$ 9,800,000	$ 44,200,000
Regulatory Asset, Amortization Period																			5		1	1	3	5	1
Ownership Percentage															50.00%
Regulatory Liability, Amortization Period																1	5	3
Expected Increase In Annual Retail Revenues								50,000,000																		17,100,000
Change in Depreciation Estimate								43,600,000
Environmental Upgrades of Jointly Owned Utility Plant				1,200,000,000
Entity Share of Environmental Upgrades of Jointly Owned Plant				610,000,000
Estimated Increase In Annual Retail Revenues For Environmental Costs							19,500,000				10,400,000			13,800,000
Estimated Increase In Annual Retail Revenues For Transmission Costs						36,700,000			17,400,000				6,400,000
Estimated Increase In Annual Retail Revenues For Energy Efficiency Costs					1,100,000					4,900,000		5,800,000
Estimated Increase In Annual Transmission Revenues	$ 38,200,000	$ 15,900,000	$ 16,800,000

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Narrative) (Details) (USD $)	12 Months Ended			0 Months Ended					12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Jul. 21, 2010	Jan. 20, 2012 Cash Flow Hedging [Member]	Dec. 31, 2012 Cash Flow Hedging [Member]	Dec. 31, 2011 Cash Flow Hedging [Member]	Dec. 31, 2011 Other Current Liabilities [Member]	Dec. 31, 2012 Asset Retirement Obligation [Member]	Dec. 31, 2012 Wolf Creek [Member]	Dec. 31, 2011 Wolf Creek [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Right to reclaim cash collateral	$ 0	$ 0
Obligation to return cash collateral	1,800,000	2,900,000
Revised ARO estimate	3,075,000	0							0	9,913,000
Fair Value Inputs, Cost Estimate								3,100,000
Notional amount			125,000,000
Interest rate cash flow hedge liability at fair value							34,000,000
Long-term regulatory assets	887,777,000	922,272,000
Interest rate cash flow hedge ineffectiveness		200,000
Interest rate cash flow hedge settlement cost				29,700,000
Regulatory Assets	1,002,672,000	1,046,090,000			28,573,000	33,753,000
Aggregate fair value of derivative instruments with credit-risk-related contingent features	800,000	3,100,000
Aggregate fair value of collateral already posted	0	0
Aggregate fair value additional collateral	$ 100,000	$ 500,000

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Carrying Values And Fair Values Of Financial Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Debt Instrument [Line Items]
Carrying Value	$ 2,824,440	$ 2,495,003
Fixed Rate Debt Member
Debt Instrument [Line Items]
Carrying Value	2,702,500	2,373,063
Fair Value	3,178,752	2,623,993
Fixed Rate Debt Of Variable Interest Entities [Member]
Debt Instrument [Line Items]
Carrying Value	247,624	275,738
Fair Value	$ 275,341	$ 306,027

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.

+ References+ Details

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Fair Value Of Assets And Liabilities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Energy Marketing Contracts, Assets	$ 8,810	$ 15,731
Total Nuclear Decommissioning Trust	150,754	130,270
Total Trading Securities, Assets	43,484	40,201
Total Assets Measured at Fair Value	203,048	186,202
Total Liabilities Measured at Fair Value		40,378
Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	38	51
Total Trading Securities, Assets	166	169
Total Assets Measured at Fair Value	204	220
Total Liabilities Measured at Fair Value		0
Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	137,952	119,193
Total Trading Securities, Assets	43,318	40,032
Total Assets Measured at Fair Value	181,651	161,626
Total Liabilities Measured at Fair Value		36,500
Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	12,764	11,026
Total Trading Securities, Assets	0	0
Total Assets Measured at Fair Value	21,193	24,356
Total Liabilities Measured at Fair Value		3,878
Energy Marketing Contracts [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Energy Marketing Contracts, Assets	8,810	15,731
Energy Marketing Contracts, Liabilities	1,472	6,353
Energy Marketing Contracts [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Energy Marketing Contracts, Assets	0	0
Energy Marketing Contracts, Liabilities	0	0
Energy Marketing Contracts [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Energy Marketing Contracts, Assets	381	2,401
Energy Marketing Contracts, Liabilities	105	2,475
Energy Marketing Contracts [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Energy Marketing Contracts, Assets	8,429	13,330
Energy Marketing Contracts, Liabilities	1,367	3,878
Treasury Yield Hedges [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Treasury Yield Hedges		34,025
Treasury Yield Hedges [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Treasury Yield Hedges		0
Treasury Yield Hedges [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Treasury Yield Hedges		34,025
Treasury Yield Hedges [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Treasury Yield Hedges		0
Domestic Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	61,056	57,117
Total Trading Securities, Assets	22,470	21,175
Domestic Equity [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Total Trading Securities, Assets	0	0
Domestic Equity [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	56,157	53,186
Total Trading Securities, Assets	22,470	21,175
Domestic Equity [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	4,899	3,931
Total Trading Securities, Assets	0	0
International Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	30,041	22,307
Total Trading Securities, Assets	5,744	4,896
International Equity [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Total Trading Securities, Assets	0	0
International Equity [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	30,041	22,307
Total Trading Securities, Assets	5,744	4,896
International Equity [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Total Trading Securities, Assets	0	0
Core Bonds [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	28,350	20,171
Total Trading Securities, Assets	15,104	13,961
Core Bonds [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Total Trading Securities, Assets	0	0
Core Bonds [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	28,350	20,171
Total Trading Securities, Assets	15,104	13,961
Core Bonds [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Total Trading Securities, Assets	0	0
High-Yield Bonds [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	8,782	10,969
High-Yield Bonds [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
High-Yield Bonds [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	8,782	10,969
High-Yield Bonds [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Emerging Market Bonds [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	6,428	5,309
Emerging Market Bonds [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Emerging Market Bonds [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	6,428	5,309
Emerging Market Bonds [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Combination Debt and Equity Fund [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	8,194	7,251
Combination Debt and Equity Fund [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Combination Debt and Equity Fund [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	8,194	7,251
Combination Debt and Equity Fund [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Real Estate Securities [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	7,865	7,095
Real Estate Securities [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Real Estate Securities [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Real Estate Securities [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	7,865	7,095
Cash Equivalents [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	38	51
Total Trading Securities, Assets	166	169
Cash Equivalents [Member] \| Level 1 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	38	51
Total Trading Securities, Assets	166	169
Cash Equivalents [Member] \| Level 2 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Total Trading Securities, Assets	0	0
Cash Equivalents [Member] \| Fair Value, Inputs, Level 3 [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	0	0
Total Trading Securities, Assets	$ 0	$ 0

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

This element represents the portion of the balance sheet assertion valued at fair value by the entity whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. This item represents Trading Securities which consist of all investments in certain debt and equity securities that are bought and held principally for the purpose of selling them in the near term (thus held for only a short period of time) or for which an entity has elected the fair value option. Trading generally reflects active and frequent buying and selling, and trading securities are generally used with the objective of generating profits on short-term differences in price, but this category of investments may also include items which are not intended to be sold in the near term or for which the fair value option has been elected.

+ References+ Details

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Reconciliations Of Assets And Liabilities At Fair Value) (Details) (USD $)
In Thousands, unless otherwise specified

12 Months Ended

Dec. 31, 2012

Dec. 31, 2011

$ 20,478

$ 18,036

2,176

^[1]

603

^[1]

(696)

(1,450)

2,974

4,142

(3,823)

(2,082)

(953)

(615)

(330)

(614)

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

19,826

20,478

Energy Marketing Contracts, Net [Member]

9,452

11,815

2,176

^[1]

603

^[1]

(696)

^[2]

(1,450)

^[2]

2,114

^[2]

2,993

^[2]

(5,034)

(6,145)

(620)

(1,022)

(330)

(614)

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

7,062

9,452

Domestic Equity [Member]

3,931

2,867

^[2]

^[1]

479

(891)

(608)

(13)

(23)

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

4,899

3,931

High-Yield Bonds [Member]

305

^[1]

(305)

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

Real Estate Securities [Member]

7,095

3,049

^[1]

770

670

(320)

(3,455)

(320)

(79)

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

$ 7,865

$ 7,095

[1]	Unrealized gains and losses included in earnings are reported in revenues.
[2]	Includes changes in the fair value of certain fuel supply and electricity contracts.

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Unrealized Gains And Losses On Financial Statements) (Details) (USD $)
In Thousands, unless otherwise specified

12 Months Ended

Dec. 31, 2012

Dec. 31, 2011

$ (748)

^[1]

$ (898)

^[1]

(74)

(747)

860

2,783

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

1,138

Energy Marketing Contracts, Net [Member]

(748)

^[1]

(898)

^[1]

(74)

^[2]

(747)

^[2]

332

^[2]

1,736

^[2]

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

(490)

Domestic Equity [Member]

^[1]

456

Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]

456

Real Estate Securities [Member]

^[1]

451

591

$ 451

$ 591

[1]	Unrealized gains and losses included in earnings are reported in revenues.
[2]	Includes changes in the fair value of certain fuel supply and electricity contracts.

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Fair Value Inputs Quantitative Information) (Details) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Energy Marketing Contracts, Assets	$ 8,810,000	$ 15,731,000
Forward Contracts Electricity [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Energy Marketing Contracts, Assets	862,000
Energy Marketing Contracts, Liabilities	358,000
Forward Contracts Gas [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Energy Marketing Contracts, Assets	0
Energy Marketing Contracts, Liabilities	74,000
Options Held [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Energy Marketing Contracts, Assets	7,567,000
Energy Marketing Contracts, Liabilities	935,000
Energy Marketing Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Energy Marketing Contracts, Assets	8,810,000	15,731,000
Energy Marketing Contracts, Liabilities	1,472,000	6,353,000
Energy Marketing Contracts [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Energy Marketing Contracts, Assets	8,429,000	13,330,000
Energy Marketing Contracts, Liabilities	1,367,000	3,878,000
Fair Value Inputs, Discounted Cash Flow [Member] \| Minimum [Member] \| Forward Contracts Electricity [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Basis	0
Fair Value Inputs, Discounted Cash Flow [Member] \| Minimum [Member] \| Forward Contracts Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Basis	0
Fair Value Inputs, Discounted Cash Flow [Member] \| Minimum [Member] \| Option Contracts Electricity [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Basis	0
Fair Value Inputs, Discounted Cash Flow [Member] \| Minimum [Member] \| Option Contracts Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Basis	0
Fair Value Inputs, Discounted Cash Flow [Member] \| Maximum [Member] \| Forward Contracts Electricity [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Basis	15
Fair Value Inputs, Discounted Cash Flow [Member] \| Maximum [Member] \| Forward Contracts Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Basis	0.25
Fair Value Inputs, Discounted Cash Flow [Member] \| Maximum [Member] \| Option Contracts Electricity [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Basis	15
Fair Value Inputs, Discounted Cash Flow [Member] \| Maximum [Member] \| Option Contracts Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Basis	$ 0.25
Fair Value Inputs, Option Models [Member] \| Minimum [Member] \| Option Contracts Electricity [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Volatility	10.00%
Fair Value Inputs, Option Models [Member] \| Minimum [Member] \| Option Contracts Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Volatility	20.00%
Fair Value Inputs, Option Models [Member] \| Minimum [Member] \| Options Held [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Correlation	60.00%
Fair Value Inputs, Option Models [Member] \| Maximum [Member] \| Option Contracts Electricity [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Volatility	75.00%
Fair Value Inputs, Option Models [Member] \| Maximum [Member] \| Option Contracts Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Volatility	35.00%
Fair Value Inputs, Option Models [Member] \| Maximum [Member] \| Options Held [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Inputs Correlation	90.00%

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Investments In Financial Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	$ 150,754	$ 130,270
Total Trading Securities, Assets	43,484	40,201
Total	203,048	186,202
Domestic Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	61,056	57,117
Total Trading Securities, Assets	22,470	21,175
International Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	30,041	22,307
Total Trading Securities, Assets	5,744	4,896
Core Bonds [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	28,350	20,171
Total Trading Securities, Assets	15,104	13,961
Real Estate Securities [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	7,865	7,095
Fair Value [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	12,764	11,026
Total Trading Securities, Assets	43,318	40,032
Total	56,082	51,058
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	1,024	1,914
Fair Value [Member] \| Domestic Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	4,899	3,931
Total Trading Securities, Assets	22,470	21,175
Fair Value [Member] \| International Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Trading Securities, Assets	5,744	4,896
Fair Value [Member] \| Core Bonds [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Trading Securities, Assets	15,104	13,961
Fair Value [Member] \| Real Estate Securities [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Total Nuclear Decommissioning Trust	7,865	7,095
Decommissioning Trust Assets [Member] \| Fair Value [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	1,024	1,914
Decommissioning Trust Assets [Member] \| Fair Value [Member] \| Domestic Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	1,024	1,914
Decommissioning Trust Assets [Member] \| Fair Value [Member] \| Real Estate Securities [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	0	0
Trading Securities [Member] \| Fair Value [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	0	0
Trading Securities [Member] \| Fair Value [Member] \| Domestic Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	0	0
Trading Securities [Member] \| Fair Value [Member] \| International Equity [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	0	0
Trading Securities [Member] \| Fair Value [Member] \| Core Bonds [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	$ 0	$ 0

+ References+ Details

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Fair Value Of Commodity Derivative Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Derivative instruments not designated as hedging instruments, energy marketing contracts, assets	$ 8,810	$ 15,731
Energy Marketing Contracts [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Derivative instruments not designated as hedging instruments, energy marketing contracts, assets	8,810	15,731
Derivative instruments not designated as hedging instruments, energy marketing contracts, liabilities	1,472	6,353
Current Assets [Member] \| Energy Marketing Contracts [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Derivative instruments not designated as hedging instruments, energy marketing contracts, assets	4,776	8,180
Other Assets [Member] \| Energy Marketing Contracts [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Derivative instruments not designated as hedging instruments, energy marketing contracts, assets	4,034	7,551
Current Liabilities [Member] \| Energy Marketing Contracts [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Derivative instruments not designated as hedging instruments, energy marketing contracts, liabilities	$ 1,472	$ 6,353

Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management (Changes In The Fair Value Of Commodity Derivative Instruments) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Revenues Increase [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Revenues increase, net gain recognized	$ 6,200	$ 1,569
Revenues Decrease [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Revenues decrease, net loss recognized	0	0
Regulatory Assets Increase [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Regulatory assets increase, net loss recognized	0	374
Regulatory Assets Decrease [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Regulatory assets decrease, net gain recognized	(374)	0
Regulatory Liabilities Increase [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Regulatory liabilities increase, net gain recognized	0	0
Regulatory Liabilities Decrease [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Regulatory liabilities decrease, net loss recognized	$ (1,790)	$ (1,623)

Financial Investments (Narrative) (Details) (USD $)	12 Months Ended
Financial Investments (Narrative) (Details) (USD $)	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule of Available-for-sale Securities [Line Items]
Total Trading Securities, Assets	$ 43,484,000	$ 40,201,000
Unrealized gains (losses) on trading securities	4,100,000	300,000	4,300,000
Fair value of the debt securities in the NDT fund	43,600,000
Realized gains (losses) on available-for-sale-securities	600,000	1,300,000	13,200,000
Supplemental Employee Retirement Plans, Defined Benefit [Member]
Schedule of Available-for-sale Securities [Line Items]
Benefit obligation for certain retirement benefits	$ 30,000,000	$ 29,400,000

Amount of debt securities categorized neither as held-to-maturity nor trading.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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Reference 2: http://www.xbrl.org/2003/role/presentationRef

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Reference 3: http://www.xbrl.org/2003/role/presentationRef

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Reference 4: http://www.xbrl.org/2003/role/presentationRef

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Reference 5: http://www.xbrl.org/2003/role/presentationRef

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-Paragraph 22

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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Reference 8: http://www.xbrl.org/2003/role/presentationRef

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Reference 9: http://www.xbrl.org/2003/role/presentationRef

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

1) For defined benefit pension plans, the benefit obligation is the projected benefit obligation, which is the actuarial present value as of a date of all benefits attributed by the pension benefit formula to employee service rendered prior to that date. 2) For other postretirement defined benefit plans, the benefit obligation is the accumulated postretirement benefit obligation, which is the actuarial present value of benefits attributed to employee service rendered to a particular date.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 132R

-Paragraph 5

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 715

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-Glossary Projected Benefit Obligation

-URI http://asc.fasb.org/extlink&oid=6522206

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-Glossary Accumulated Postretirement Benefit Obligation

-URI http://asc.fasb.org/extlink&oid=6503904

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Reference 6: http://www.xbrl.org/2003/role/presentationRef

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+ Details

+ References+ Details

The net change in the difference between the fair value and the carrying value, or in the comparative fair values, of trading securities held at each balance sheet date, that was included in earnings for the period. Trading securities are bought and held principally for the purpose of selling them in the near term (thus held for only a short period of time) and the change in net unrealized holding gain (loss) is included in earnings for the period.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

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Reference 2: http://www.xbrl.org/2003/role/presentationRef

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-Paragraph 12

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef

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-Paragraph 2

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-Glossary Trading Securities

-URI http://asc.fasb.org/extlink&oid=6526789

Reference 5: http://www.xbrl.org/2003/role/presentationRef

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+ Details

Financial Investments (Cost And Fair Value Of Available-For-Sale Securities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Schedule of Available-for-sale Securities [Line Items]
Cost	$ 141,350	$ 133,213
Gross Unrealized Gain	11,520	2,168
Gross Unrealized Loss	(2,116)	(5,111)
Fair Value	150,754	130,270
Allocation	100.00%	100.00%
Domestic Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	53,598	55,357
Gross Unrealized Gain	7,458	1,760
Gross Unrealized Loss	0	0
Fair Value	61,056	57,117
Allocation	41.00%	44.00%
International Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	28,248	24,501
Gross Unrealized Gain	1,793	0
Gross Unrealized Loss	0	(2,194)
Fair Value	30,041	22,307
Allocation	20.00%	17.00%
Core Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	27,309	19,771
Gross Unrealized Gain	1,041	400
Gross Unrealized Loss	0	0
Fair Value	28,350	20,171
Allocation	19.00%	16.00%
High-Yield Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	8,022	11,046
Gross Unrealized Gain	760	0
Gross Unrealized Loss	0	(77)
Fair Value	8,782	10,969
Allocation	6.00%	8.00%
Emerging Market Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	6,080	5,301
Gross Unrealized Gain	348	8
Gross Unrealized Loss	0	0
Fair Value	6,428	5,309
Allocation	4.00%	4.00%
Combination Debt and Equity Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	8,074	7,524
Gross Unrealized Gain	120	0
Gross Unrealized Loss	0	(273)
Fair Value	8,194	7,251
Allocation	5.00%	6.00%
Real Estate Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	9,981	9,662
Gross Unrealized Gain	0	0
Gross Unrealized Loss	(2,116)	(2,567)
Fair Value	7,865	7,095
Allocation	5.00%	5.00%
Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	38	51
Gross Unrealized Gain	0	0
Gross Unrealized Loss	0	0
Fair Value	$ 38	$ 51

This item represents the cost of debt and equity securities, which are categorized neither as held-to-maturity nor trading, net of adjustments including accretion, amortization, collection of cash, previous other-than-temporary impairments recognized in earnings (less any cumulative-effect adjustments recognized, as defined), and fair value hedge accounting adjustments, if any.

+ References+ Details

This element represents the portion of the balance sheet assertion valued at fair value by the entity whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. This item represents Available-for-sale Securities which consist of all investments in certain debt and equity securities neither classified as trading or held-to-maturity securities. A debt security represents a creditor relationship with an enterprise. Debt securities include, among other items, US Treasury securities, US government securities, municipal securities, corporate bonds, convertible debt, commercial paper, and all securitized debt instruments. An equity security represents an ownership interest in an enterprise or the right to acquire or dispose of an ownership interest in an enterprise at fixed or determinable prices. Equity securities include, among other things, common stock, certain preferred stock, warrant rights, call options, and put options, but do not include convertible debt. An entity may opt to provide the reader with additional narrative text to better understand the nature of investments in debt and equity securities which are categorized as Available-for-sale.

+ References+ Details

This item represents the gross unrealized gains for securities, at a point in time, which are categorized neither as held-to-maturity nor trading securities.

+ References+ Details

Financial Investments (Fair Value And Gross Unrealized Losses Of Available-For-Sale Securities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months		$ 40,527
Gross Unrealized Losses, Less than 12 Months		(2,544)
Fair Value, 12 Months or Greater		7,095
Gross Unrealized Losses, 12 Months or Greater		(2,567)
Fair Value, Total		47,622
Gross Unrealized Losses, Total		(5,111)
Real Estate Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	0	0
Gross Unrealized Losses, Less than 12 Months	0	0
Fair Value, 12 Months or Greater	7,865	7,095
Gross Unrealized Losses, 12 Months or Greater	(2,116)	(2,567)
Fair Value, Total	7,865	7,095
Gross Unrealized Losses, Total	(2,116)	(2,567)
International Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months		22,307
Gross Unrealized Losses, Less than 12 Months		(2,194)
Fair Value, 12 Months or Greater		0
Gross Unrealized Losses, 12 Months or Greater		0
Fair Value, Total		22,307
Gross Unrealized Losses, Total		(2,194)
High-Yield Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months		10,969
Gross Unrealized Losses, Less than 12 Months		(77)
Fair Value, 12 Months or Greater		0
Gross Unrealized Losses, 12 Months or Greater		0
Fair Value, Total		10,969
Gross Unrealized Losses, Total		(77)
Combination Debt/Equity Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months		7,251
Gross Unrealized Losses, Less than 12 Months		(273)
Fair Value, 12 Months or Greater		0
Gross Unrealized Losses, 12 Months or Greater		0
Fair Value, Total		7,251
Gross Unrealized Losses, Total		$ (273)

This item represents the aggregate fair value of investments in debt and equity securities in an unrealized loss position which are categorized neither as held-to-maturity nor trading securities.

+ References+ Details

This item represents the aggregate fair value of investments in debt and equity securities categorized neither as held-to-maturity nor trading securities that have been in a continuous unrealized loss position for less than twelve months.

+ References+ Details

+ References+ Details

Property, Plant And Equipment (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Public Utility, Property, Plant and Equipment [Line Items]
Electric plant in service	$ 9,389,192	$ 8,703,278
Electric plant acquisition adjustment	(802,318)	(802,318)
Accumulated depreciation	(3,791,545)	(3,703,372)
Electric plant, net	6,399,965	5,802,224
Construction work in progress	532,332	534,003
Nuclear fuel, net	81,468	75,695
Property, plant and equipment, net	7,013,765	6,411,922
Variable Interest Entity [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Electric plant in service	543,548	543,548
Accumulated depreciation	(221,573)	(210,054)
Property, plant and equipment, net	$ 321,975	$ 333,494

Amount, net of accumulated depreciation, depletion and amortization, of long-lived physical assets used in the normal conduct of business and not intended for resale. Examples include, but are not limited to, land, buildings, machinery and equipment, office equipment, furniture and fixtures, and computer equipment.

+ References+ Details

Property, Plant And Equipment (Depreciation) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation	$ 247.8	$ 262.6	$ 249.2
Variable Interest Entity [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation	$ 9.8	$ 9.8	$ 9.7

Jointly Owned Utility Plant, Net Ownership Amount [Abstract]

The amount of expense recognized in the current period that reflects the allocation of the cost of tangible assets over the assets' useful lives. Includes production and non-production related depreciation.

+ References+ Details

Joint Ownership of Utility Plants Joint Ownership of Utility Plants (Details) (USD $)

12 Months Ended

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

La Cygne unit 1 [Member]

Dec. 31, 2012

JEC unit 1 [Member]

Dec. 31, 2012

JEC unit 2 [Member]

Dec. 31, 2012

JEC unit 3 [Member]

Dec. 31, 2012

Wolf Creek [Member]

Dec. 31, 2012

State Line [Member]

Dec. 31, 2012

La Cygne unit 2 [Member]

Dec. 31, 2012

La Cygne Generating Station [Member]

Dec. 31, 2012

Jeffrey Energy Center [Member]

Dec. 31, 2012

Variable Interest Entity, Primary Beneficiary [Member]

Dec. 31, 2011

Variable Interest Entity, Primary Beneficiary [Member]

Dec. 31, 2012

Variable Interest Entity, Primary Beneficiary [Member]

La Cygne Generating Station [Member]

Investment

$ 3,701,688,000

$ 331,964,000

^[1]

$ 528,478,000

^[1]

$ 498,929,000

^[1]

$ 703,393,000

^[1]

$ 1,524,831,000

^[2]

$ 114,093,000

^[3]

Accumulated Depreciation

1,623,475,000

156,722,000

^[1]

196,511,000

^[1]

182,444,000

^[1]

282,481,000

^[1]

756,218,000

^[2]

49,099,000

^[3]

Construction Work in Progress

366,604,000

185,875,000

^[1]

80,217,000

^[1]

121,000

^[1]

1,000,000

^[1]

99,357,000

^[2]

34,000

^[3]

Net Capacity, in MW

3,099

368

^[3]

661

^[3]

658

^[3]

664

^[3]

547

^[3]

201

^[3]

343

^[3]

Ownership Percentage

47.00%

50.00%

^[1]

92.00%

^[1]

92.00%

^[1]

92.00%

^[1]

47.00%

^[2]

40.00%

^[3]

Variable Interest Entity Percentage of Asset Held

50.00%

8.00%

VIE Investment in Property, Plant and Equipment

392,100,000

Accumulated Depreciation on VIE Investment in Property, Plant and Equipment

$ 3,791,545,000

$ 3,703,372,000

$ 221,573,000

$ 210,054,000

$ 180,200,000

[1]	Jointly owned with KCPL. Our 8% leasehold interest in JEC that is consolidated as a VIE is reflected in the net megawatts (MW) and ownership percentage provided above, but not in the other amounts in the table.
[2]	Jointly owned with KCPL and Kansas Electric Power Cooperative, Inc.
[3]	Jointly owned with Empire District Electric Company.

Gross amount of long-lived physical assets used in the normal conduct of business and not intended for resale. Examples include, but are not limited to, land, buildings, machinery and equipment, office equipment, furniture and fixtures, and computer equipment.

+ References+ Details

Short-Term Debt (Details) (USD $)	12 Months Ended						12 Months Ended		0 Months Ended			0 Months Ended
Short-Term Debt (Details) (USD $)	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Feb. 12, 2013 Y	Dec. 31, 2012 Commercial Paper and Revolving LIne of Credit [Member]	Dec. 31, 2011 Commercial Paper and Revolving LIne of Credit [Member]	Dec. 31, 2012 Commercial Paper [Member] days	Dec. 31, 2011 Commercial Paper [Member]	Sep. 29, 2011 Revolving Credit Facility Lender One [Member] Y	Dec. 31, 2012 Revolving Credit Facility Lender One [Member]	Dec. 31, 2011 Revolving Credit Facility Lender One [Member]	Feb. 18, 2011 Revolving Credit Facility Lender Two [Member] Y	Dec. 31, 2012 Revolving Credit Facility Lender Two [Member]	Dec. 31, 2011 Revolving Credit Facility Lender Two [Member]
Short-term Debt [Line Items]
Short-Term Debt Maximum Borrowings					$ 1,000,000,000		$ 1,000,000,000
Commercial paper program, Maximim maturity period							365
Short-term debt amount outstanding	339,200,000	286,300,000					339,200,000	0
Secured revolving credit facility									730,000,000			270,000,000
Line of credit facility expiration date									Sep. 29, 2016			Feb. 18, 2016
Expected number of years for extending line of credit facility									2			1
Expected extended amount for line of credit									1,000,000,000			400,000,000
Period of credit facility extension				1
Secured revolving credit facility borrowed										0	286,300,000		0	0
Issued letters of credit										13,800,000	12,200,000		0	0
Weighted average interest rate					0.46%	1.49%
Weighted average amount outstanding	298,907,000	362,946,000
Weighted daily average interest rate, excluding fees	0.55%	0.82%
Interest expense on short-term debt	$ 3,200,000	$ 3,900,000	$ 1,900,000

Long-Term Debt (Details) (USD $)
In Thousands, unless otherwise specified

Dec. 31, 2012

May 17, 2012

Mar. 01, 2012

Dec. 31, 2011

Long-term debt due within one year

$ 2,824,440

$ 2,495,003

Unamortized debt discount, Net

(5,169)

^[1]

(3,894)

^[1]

2,819,271

2,491,109

Westar Energy [Member] | Secured Debt [Member]

1,750,000

1,350,000

75,500

132,745

Westar Energy [Member] | Secured Debt [Member] | 6.00% First Mortgage Bonds Due 2014 [Member]

250,000

Westar Energy [Member] | Secured Debt [Member] | 5.15% First Mortgage Bonds Due 2017 [Member]

125,000

Westar Energy [Member] | Secured Debt [Member] | 5.95% First Mortgage Bonds Due 2035 [Member]

125,000

Westar Energy [Member] | Secured Debt [Member] | 5.10% First Mortgage Bonds Due 2020 [Member]

250,000

Westar Energy [Member] | Secured Debt [Member] | 5.875% First Mortgage Bonds Due 2036 [Member]

150,000

Westar Energy [Member] | Secured Debt [Member] | 6.10% First Mortgage Bonds Due 2047 [Member]

150,000

Westar Energy [Member] | Secured Debt [Member] | 8.625% First Mortgage Bonds Due 2018 [Member]

300,000

Westar Energy [Member] | Secured Debt [Member] | 4.125% First Mortgage Bonds Due 2042 [Member]

550,000

300,000

250,000

Westar Energy [Member] | Secured Debt [Member] | Pollution Control Bonds Variable Due 2032 [Member]

45,000

Westar Energy [Member] | Secured Debt [Member] | Pollution Control Bonds Variable Due 2032 [Member]

30,500

Westar Energy [Member] | Secured Debt [Member] | 5.00% Pollution Control Bonds Due 2033 [Member]

57,245

KGE [Member] | Secured Debt [Member]

625,000

373,940

387,258

KGE [Member] | Secured Debt [Member] | 6.53% First Mortgage Bonds Due 2037 [Member]

175,000

KGE [Member] | Secured Debt [Member] | 6.15% First Mortgage Bonds Due 2023 [Member]

50,000

KGE [Member] | Secured Debt [Member] | 6.64% First Mortgage Bonds Due 2038 [Member]

100,000

KGE [Member] | Secured Debt [Member] | 6.70% First Mortgage Bonds Due 2019 [Member]

300,000

KGE [Member] | Secured Debt [Member] | 5.10% Pollution Control Bonds Due 2023 [Member]

13,318

KGE [Member] | Secured Debt [Member] | Pollution Control Bonds Variable Due 2027 [Member]

21,940

KGE [Member] | Secured Debt [Member] | 5.30% Pollution Control Bonds Due 2031 [Member]

108,600

KGE [Member] | Secured Debt [Member] | 5.30% Pollution Control Bonds Due 2031 [Member]

18,900

KGE [Member] | Secured Debt [Member] | Pollution Control Bonds Variable Due 2032 [Member]

14,500

KGE [Member] | Secured Debt [Member] | Pollution Control Bonds Variable Due 2032 [Member]

10,000

KGE [Member] | Secured Debt [Member] | 4.85% Pollution Control Bonds Due 2031 [Member]

50,000

KGE [Member] | Secured Debt [Member] | 5.60% Pollution Control Bonds Due 2031 [Member]

50,000

KGE [Member] | Secured Debt [Member] | 6.00% Pollution Control Bonds Due 2031 [Member]

50,000

KGE [Member] | Secured Debt [Member] | 5.00% Pollution Control Bonds Due 2031 [Member]

50,000

Variable Interest Entity [Member]

Long-term debt due within one year

247,624

275,738

(25,942)

(28,114)

Unamortized debt discount, Net

1,061

^[1]

1,659

^[1]

222,743

249,283

Variable Interest Entity [Member] | Variable Interest Entity 7.77% due 2012 [Member]

^[2]

2,583

^[2]

Variable Interest Entity [Member] | Variable Interest Entity 6.99% due 2014 [Member]

866

^[2]

2,094

^[2]

Variable Interest Entity [Member] | Variable Interest Entity 5.92% due 2019 [Member]

17,630

^[2]

22,748

^[2]

Variable Interest Entity [Member] | Variable Interest Entity 5.647% due 2021 [Member]

$ 229,128

^[2]

$ 248,313

^[2]

[1]	We amortize debt discounts and premiums to interest expense over the term of the respective issues.
[2]	Portions of our payments related to this debt reduce the principal balances each year until maturity.

+ References+ Details

The amount of debt discount (net of debt premium) 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

-Publisher FASB

-Name Accounting Standards Codification

-Topic 835

-SubTopic 30

-Section 45

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Reference 2: http://www.xbrl.org/2003/role/presentationRef

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Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher AICPA

-Name Accounting Principles Board Opinion (APB)

-Number 21

-Paragraph 16

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

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Reference 6: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

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Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher AICPA

-Name Accounting Principles Board Opinion (APB)

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Represents the current and noncurrent portions of a debt security issued by a state, certain agencies or authorities, a local government, or development corporation to finance the construction of air- or water-pollution control facilities or sewage or solid waste disposal facilities pursuant to federal law. The bonds are backed by the credit of the beneficiary of the financing rather than the credit of the issuer.

+ References+ Details

Long-term Debt Maturities (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012
Debt Instrument [Line Items]
2013	$ 0
2014	250,000
2015	0
2016	0
2017	125,000
Thereafter	2,449,440
Variable Interest Entity, Primary Beneficiary [Member]
Debt Instrument [Line Items]
2013	25,942
2014	27,479
2015	27,933
2016	28,309
2017	26,842
Thereafter	$ 111,119

Long-term Debt (Narrative) (Details) (USD $)	12 Months Ended									0 Months Ended								0 Months Ended			0 Months Ended
Long-term Debt (Narrative) (Details) (USD $)	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2012 Variable Interest Entity [Member]	Dec. 31, 2011 Variable Interest Entity [Member]	Dec. 31, 2010 Variable Interest Entity [Member]	Dec. 31, 2012 KGE [Member] First Mortgage Bond Series [Member]	Dec. 31, 2012 KGE [Member] Secured Debt [Member]	Dec. 31, 2011 KGE [Member] Secured Debt [Member]	Mar. 30, 2012 KGE [Member] Pollution Control Bond Series [Member] 5.10% Pollution Control Bonds Due 2023 [Member]	Dec. 31, 2012 Westar Energy [Member] First Mortgage Bond Series [Member]	Dec. 31, 2012 Westar Energy [Member] Secured Debt [Member]	Dec. 31, 2011 Westar Energy [Member] Secured Debt [Member]	Dec. 31, 2012 Westar Energy [Member] Secured Debt [Member] Debt Instrument Twenty-Nine [Member]	May 17, 2012 Westar Energy [Member] Secured Debt [Member] Debt Instrument Twenty-Nine [Member]	Mar. 01, 2012 Westar Energy [Member] Secured Debt [Member] Debt Instrument Twenty-Nine [Member]	Dec. 31, 2011 Westar Energy [Member] Secured Debt [Member] Debt Instrument Twenty-Nine [Member]	May 15, 2012 Westar Energy [Member] Secured Debt [Member] 6.10% First Mortgage Bonds Due 2047 [Member]	Dec. 31, 2012 Westar Energy [Member] Secured Debt [Member] 6.10% First Mortgage Bonds Due 2047 [Member]	Dec. 31, 2011 Westar Energy [Member] Secured Debt [Member] 6.10% First Mortgage Bonds Due 2047 [Member]	Mar. 30, 2012 Westar Energy [Member] Pollution Control Bond Series [Member] 5.00% Pollution Control Bonds Due 2033 [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity							$ 3,500,000,000
Remaining Borrowing Capacity							870,000,000				830,000,000
Variable Rate Tax-Exempt Bonds	121,900,000
Long-term debt	2,824,440,000	2,495,003,000		247,624,000	275,738,000			625,000,000	625,000,000			1,750,000,000	1,350,000,000	550,000,000	300,000,000	250,000,000	0		0	150,000,000
Stated interest percentage										5.10%					0.00%	4.125%		6.10%			5.00%
Bond discount yield percentage															4.157%	4.13%
Net proceeds	541,374,000	0	0
Repayments of Long-term Debt	(220,563,000)	(371,000)	(1,695,000)	(28,114,000)	(30,159,000)	(28,610,000)				(13,300,000)								(150,000,000)			(57,200,000)
Interest expense on long-term debt	$ 145,600,000	$ 142,600,000	$ 144,100,000	$ 15,100,000	$ 16,800,000	$ 18,700,000

Taxes (Components of Income Tax Expense) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Current income taxes:
Federal	$ (691)	$ (8,575)	$ (32,107)
State	579	196	(3,030)
Deferred income taxes:
Federal	102,960	93,089	102,568
State	26,300	21,337	20,305
Investment tax credit amortization	(3,012)	(2,703)	(2,704)
Income tax expense	$ 126,136	$ 103,344	$ 85,032

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 or Loss from continuing operations.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 740

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-Paragraph 1

-Subparagraph (SAB TOPIC 6.I.7)

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Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Glossary Current Tax Expense (or Benefit)

-URI http://asc.fasb.org/extlink&oid=6509736

Reference 3: http://www.xbrl.org/2003/role/presentationRef

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-Publisher FASB

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Reference 6: http://www.xbrl.org/2003/role/presentationRef

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Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

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+ Details

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 or Loss from continuing operations.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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Reference 2: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

-Glossary Current Tax Expense (or Benefit)

-URI http://asc.fasb.org/extlink&oid=6509736

Reference 3: http://www.xbrl.org/2003/role/presentationRef

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-Subparagraph (a)

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef

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-Name Regulation S-X (SX)

-Number 210

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

The component of total income tax expense for the period comprised of the increase (decrease) 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

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Reference 3: http://www.xbrl.org/2003/role/presentationRef

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-Name Regulation S-X (SX)

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Reference 4: http://www.xbrl.org/2003/role/presentationRef

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-Number Topic 6

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Reference 5: http://www.xbrl.org/2003/role/presentationRef

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-Glossary Deferred Tax Expense (or Benefit)

-URI http://asc.fasb.org/extlink&oid=6510177

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-Name Statement of Financial Accounting Standard (FAS)

-Number 109

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+ Details

The component of total income tax expense for the period comprised of the increase (decrease) 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

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-Name Regulation S-X (SX)

-Number 210

-Section 08

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Reference 4: http://www.xbrl.org/2003/role/presentationRef

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-Number Topic 6

-Section I

-Subsection 7

Reference 5: http://www.xbrl.org/2003/role/presentationRef

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-Glossary Deferred Tax Expense (or Benefit)

-URI http://asc.fasb.org/extlink&oid=6510177

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+ Details

The sum of the current income tax expense or benefit and the deferred income tax expense or benefit pertaining to pretax Income or Loss from continuing operations; income tax expense or benefit may include interest and penalties on tax uncertainties based on the entity's accounting policy.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 235

-SubTopic 10

-Section S99

-Paragraph 1

-Subparagraph (SX 210.4-08.(h))

-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 08

-Paragraph h

-Article 4

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 740

-SubTopic 10

-Section 50

-Paragraph 10

-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32672-109319

Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 740

-SubTopic 10

-Section 50

-Paragraph 9

-Subparagraph (a),(b)

-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 740

-SubTopic 10

-Section 45

-Paragraph 25

-URI http://asc.fasb.org/extlink&oid=21917399&loc=d3e32247-109318

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 109

-Paragraph 45, 46

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name FASB Interpretation (FIN)

-Number 48

-Paragraph 15, 16, 19

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Taxes (Deferred Tax Assets and Liabilities in Balance Sheet) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Income Tax Disclosure [Abstract]
Other current liabilities (assets)	$ 8,654	$ (394)
Non-current deferred tax liabilities	1,197,837	1,110,463
Net deferred tax liabilities	$ 1,206,491	$ 1,110,069

Amount after allocation of valuation allowances of deferred tax asset attributable to deductible temporary differences and carryforwards, net of deferred tax liability attributable to taxable temporary differences expected to be realized or consumed within one year or operating cycle, if longer.

+ References+ Details

+ References+ Details

Taxes (Schedule of Deferred Tax Assets and Liabilities) (Details) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Deferred tax assets:
Business tax credit carryforward	$ 199,160,000	$ 159,163,000
Deferred employee benefit costs	191,997,000	202,687,000
Net operating loss carryforward	111,869,000	84,365,000
Deferred state income taxes	55,577,000	42,209,000
Deferred regulatory gain on sale-leaseback	40,543,000	42,962,000
Alternative minimum tax carryforward	36,471,000	36,471,000
Deferred compensation	28,319,000	28,286,000
Accrued liabilities	15,969,000	16,912,000
Disallowed costs	12,083,000	12,717,000
Capital loss carryforward	11,509,000	12,554,000
Other	20,897,000	13,031,000
Total gross deferred tax assets	724,394,000	651,357,000
Less: Valuation allowance	13,812,000	13,712,000
Deferred tax assets	710,582,000	637,645,000
Deferred tax liabilities:
Accelerated depreciation	1,255,892,000	1,088,727,000
Deferred employee benefit costs	191,997,000	202,687,000
Acquisition premium	179,920,000	187,934,000
Amounts due from customers for future income taxes, net	169,091,000	168,804,000
Deferred state income taxes	50,134,000	39,512,000
Pension expense tracker	22,437,000	14,600,000
Debt reacquisition costs	22,313,000	21,683,000
Storm costs	4,373,000	10,176,000
Other	20,916,000	13,591,000
Total deferred tax liabilities	1,917,073,000	1,747,714,000
Net deferred tax liabilities	1,206,491,000	1,110,069,000
Capital loss carryforwards	29,100,000
Deferred Tax Asset, State Investment Tax Credits [Member]
Deferred tax assets:
Less: Valuation allowance	1,300,000
Deferred Tax Asset, Capital Loss [Member]
Deferred tax assets:
Less: Valuation allowance	11,500,000
Deferred Tax Asset, Loss on Other Investments [Member]
Deferred tax assets:
Less: Valuation allowance	2,300,000
Internal Revenue Service (IRS) [Member]
Deferred tax assets:
Business tax credit carryforward	39,300,000
Deferred tax liabilities:
Operating Loss Carryforwards	276,900,000
State and Local Jurisdiction [Member]
Deferred tax assets:
Business tax credit carryforward	$ 159,800,000

Taxes (Effective Income Tax Reconciliation) (Details)	12 Months Ended
Taxes (Effective Income Tax Reconciliation) (Details)	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Effective Income Tax Rate
Statutory federal income tax rate	35.00%	35.00%	35.00%
Corporate-owned life insurance policies	(4.90%)	(4.50%)	(6.10%)
State income taxes	4.30%	4.10%	3.80%
Production tax credits	(2.40%)	(2.90%)	(3.40%)
Accelerated depreciation flow through and amortization	1.40%	1.80%	2.60%
AFUDC equity	(1.00%)	(0.60%)	(0.40%)
Amortization of federal investment tax credits	(0.70%)	(0.80%)	(0.90%)
Capital loss utilization	(0.30%)	(0.50%)	(0.70%)
Liability for unrecognized income tax benefits	0.20%	0.00%	(0.20%)
Other	(0.70%)	(1.20%)	(0.70%)
Effective income tax rate	30.90%	30.40%	29.00%

Taxes (Unrecognized Tax Benefits) (Details) (USD $)	12 Months Ended
Taxes (Unrecognized Tax Benefits) (Details) (USD $)	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized income tax benefits at January 1	$ 2,483,000	$ 1,888,000	$ 8,357,000
Additions based on tax positions related to the current year	373,000	967,000	608,000
Additions for tax positions of prior years	0	939,000	2,323,000
Reductions for tax positions of prior years	(1,637,000)	(563,000)	(1,241,000)
Settlements	0	(748,000)	(8,159,000)
Unrecognized income tax benefits at December 31	1,219,000	2,483,000	1,888,000
Tax loss and credit carryforwards	300,000	200,000	1,000,000
The amounts of unrecognized income tax benefits that, if recognized, would favorably impact our effective income tax rate	2,000,000	1,200,000	1,300,000
Reversal of interest expense previously recorded for income tax uncertainties		200,000	1,000,000
Accrued interest related to unrecognized income tax benefits	200,000	200,000
Penalties accrued	0	0
Taxes other than income taxes	$ 1,500,000	$ 1,500,000

Employee Benefit Plans (Funded Status) (Details) (USD $)
In Thousands, unless otherwise specified

12 Months Ended

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Total Trading Securities, Assets

$ 43,484

$ 40,201

Pension Benefits [Member]

876,308

747,460

19,556

16,076

13,926

39,576

40,045

39,391

60,229

31,107

53,497

94,161

^[1]

9,673

^[1]

928,708

876,308

747,460

481,077

432,233

67,328

27,819

56,700

50,000

57,174

28,975

^[1]

547,931

481,077

432,233

Amounts Recognized in the Balance Sheets Consist of:

(380,777)

(395,231)

(2,870)

(2,741)

(377,907)

(392,490)

Amounts Recognized in Regulatory Assets Consist of:

(380,777)

(395,231)

383,365

397,691

3,994

4,606

387,359

402,297

Other Postretirement Benefit Plans, Defined Benefit [Member]

150,078

137,759

2,057

1,803

1,526

6,298

6,793

7,083

2,987

3,390

9,799

10,114

943

5,246

4,451

^[1]

750

^[1]

152,564

150,078

137,759

91,858

86,984

10,673

(174)

10,803

10,793

(2,845)

(3,244)

9,386

9,739

^[1]

750

^[1]

106,793

91,858

86,984

Amounts Recognized in the Balance Sheets Consist of:

(45,771)

(58,220)

(298)

(115)

(45,473)

(58,105)

Amounts Recognized in Regulatory Assets Consist of:

(45,771)

(58,220)

12,436

18,178

16,467

18,991

325

4,236

29,228

41,405

Supplemental Employee Retirement Plans, Defined Benefit [Member]

30,000

29,400

OneTimeBenefitPayment [Member] | Pension Benefits [Member]

$ 26,100

[1]

(a)In 2012 certain former employees received a one-time lump sum payment of their pension benefits totaling $26.1 million.(b) As of December 31, 2011, Other includes the $9.7 million reclassification of a contractual obligation related to the legal settlement with a former executive officer and $0.8 million of proceeds received as a result of the Early Retiree Reinsurance Program.(c)As of December 31, 2012 and 2011, pension benefits include non-qualified benefit obligations of $30.0 million and $29.4 million, respectively, which are funded by a trust containing assets of $43.5 million and $40.2 million, respectively, classified as trading securities as discussed in Notes 4 and 5, "Financial and Derivative Instruments, Trading Securities, Energy marketing and Risk Management" and "Financial Investments," respectively.

Employee Benefit Plans (Plans With a Projected Benefit Obligation and Accumulated Benefit Obligation in Excess of Plan Assets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 928,708	$ 876,308
Fair value of plan assets	547,931	481,077
Accumulated benefit obligation	806,888	750,263
Fair value of plan assets	547,931	481,077
Discount rate	4.13%	4.50%
Compensation rate increase	4.00%	4.00%
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	152,564	150,078
Fair value of plan assets	$ 106,793	$ 91,858
Discount rate	3.99%	4.25%
Compensation rate increase	0.00%	0.00%

If aggregate disclosures are presented, the aggregate pension accumulated benefit obligation for pension plans with accumulated benefit obligations in excess of plan assets as of the measurement date of each statement of financial position presented.

+ References+ Details

If aggregate disclosures are presented, the aggregate fair value of plan assets for pension plans with accumulated benefit obligations in excess of plan assets as of the measurement date of each statement of financial position presented.

+ References+ Details

Employee Benefit Plans (Net Periodic Costs And Other Changes Recognized in Regulatory Assets) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Components of Net Periodic Cost (Benefit):
Service cost	$ 19,556	$ 16,076	$ 13,926
Interest cost	39,576	40,045	39,391
Expected return on plan assets	(32,283)	(31,087)	(38,384)
Transition obligation, net	0	0	0
Prior service costs	612	1,213	2,729
Actuarial loss/(gain), net	32,778	23,659	17,183
Net periodic cost before regulatory adjustment	60,239	49,906	34,845
Regulatory adjustment	(6,523)	(22,098)	(12,167)
Net periodic cost	53,716	27,808	22,678
Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	18,451	97,429	65,690
Amortization of actuarial (loss)/gain	(32,778)	(23,659)	(17,183)
Current year prior service cost	0	0	676
Amortization of prior service costs	(612)	(1,213)	(2,729)
Amortization of transition obligation	0	0	0
Total recognized in regulatory assets	(14,939)	72,557	46,454
Total recognized in net periodic cost and regulatory assets	38,777	100,365	69,132
Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.50%	5.35%	5.95%
Expected long-term return on plan assets	6.50%	6.50%	8.25%
Compensation rate increase	4.00%	4.00%	4.00%
Other Postretirement Benefit Plans, Defined Benefit [Member]
Components of Net Periodic Cost (Benefit):
Service cost	2,057	1,803	1,526
Interest cost	6,298	6,793	7,083
Expected return on plan assets	(5,491)	(5,002)	(5,197)
Transition obligation, net	3,912	3,911	3,912
Prior service costs	2,524	2,524	2,154
Actuarial loss/(gain), net	1,503	702	321
Net periodic cost before regulatory adjustment	10,803	10,731	9,799
Regulatory adjustment	23	1,344	1,868
Net periodic cost	10,826	12,075	11,667
Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	(4,239)	10,421	3,298
Amortization of actuarial (loss)/gain	(1,503)	(702)	(321)
Current year prior service cost	0	4,451	0
Amortization of prior service costs	(2,524)	(2,524)	(2,154)
Amortization of transition obligation	(3,912)	(3,911)	(3,912)
Total recognized in regulatory assets	(12,178)	7,735	(3,089)
Total recognized in net periodic cost and regulatory assets	$ (1,352)	$ 19,810	$ 8,578
Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.25%	5.00%	5.65%
Expected long-term return on plan assets	6.00%	6.00%	7.75%
Compensation rate increase	0.00%	0.00%	0.00%

Employee Benefit Plans (Estimated Amounts From Regulatory Assets Into Net Periodic Cost) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Change in Regulatory Assets, Reclassification, Pension and Other Postretirement Benefit Plans, Net Gain (Loss) Recognized in Net Periodic Benefit Cost	$ 33,914
Estimated Future Change in Regulatory Assets, Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost (Credit) Recognized in Net Periodic Benefit Cost	(601)
Estimated Future Change in Regulatory Assets, Reclassification, Pension and Other Postretirement Benefit Plans, Net Transition Asset (Obligation), Recognized in Net Periodic Benefit Cost	0
Total	34,515
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Change in Regulatory Assets, Reclassification, Pension and Other Postretirement Benefit Plans, Net Gain (Loss) Recognized in Net Periodic Benefit Cost	1,125
Estimated Future Change in Regulatory Assets, Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost (Credit) Recognized in Net Periodic Benefit Cost	(2,524)
Estimated Future Change in Regulatory Assets, Reclassification, Pension and Other Postretirement Benefit Plans, Net Transition Asset (Obligation), Recognized in Net Periodic Benefit Cost	325
Total	$ 3,974

Employee Benefit Plans (Assumed Annual Health Care Cost Growth Rates) (Details)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	8.00%	8.00%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	5.00%	5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	2019	2018

The assumed health care cost trend rate for the next year used to measure the expected cost of benefits covered by the plan (gross eligible charges). This is based upon the annual rate of change in the cost of health care benefits currently provided by the postretirement benefit plan, due to factors other than changes in the composition of the plan population by age and dependency status.

+ References+ Details

Employee Benefit Plans (One Percentage Change In Assumed Health Care Cost Growth Rates Effects) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components	$ 67
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	(64)
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	1,489
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	$ (1,384)

Employee Benefit Plans (Fair Value of Plan Assets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 547,931	$ 481,077	$ 432,233
Pension Plans, Defined Benefit [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	462,976	406,138
Pension Plans, Defined Benefit [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	84,955	74,939
Pension Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	147,994	136,739
Pension Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	129,501	121,364
Pension Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	18,493	15,375
Pension Plans, Defined Benefit [Member] \| International Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	67,743	53,943
Pension Plans, Defined Benefit [Member] \| International Equity Securities [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| International Equity Securities [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	67,743	53,943
Pension Plans, Defined Benefit [Member] \| International Equity Securities [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Core Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	178,784	142,700
Pension Plans, Defined Benefit [Member] \| Core Bonds [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Core Bonds [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	178,784	142,700
Pension Plans, Defined Benefit [Member] \| Core Bonds [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| High-Yield Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	19,070	38,380
Pension Plans, Defined Benefit [Member] \| High-Yield Bonds [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| High-Yield Bonds [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	19,070	38,380
Pension Plans, Defined Benefit [Member] \| High-Yield Bonds [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Emerging Market Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	14,276
Pension Plans, Defined Benefit [Member] \| Emerging Market Bonds [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0
Pension Plans, Defined Benefit [Member] \| Emerging Market Bonds [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	14,276
Pension Plans, Defined Benefit [Member] \| Emerging Market Bonds [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0
Pension Plans, Defined Benefit [Member] \| Combination Debt Equity Fund Member
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	50,750	47,151
Pension Plans, Defined Benefit [Member] \| Combination Debt Equity Fund Member \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Combination Debt Equity Fund Member \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	50,750	47,151
Pension Plans, Defined Benefit [Member] \| Combination Debt Equity Fund Member \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	20,927	18,848
Pension Plans, Defined Benefit [Member] \| Real Estate [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Real Estate [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Real Estate [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	20,927	18,848
Pension Plans, Defined Benefit [Member] \| Alternative Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	45,535	40,716
Pension Plans, Defined Benefit [Member] \| Alternative Funds [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Alternative Funds [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Alternative Funds [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	45,535	40,716
Pension Plans, Defined Benefit [Member] \| Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	2,852	2,600
Pension Plans, Defined Benefit [Member] \| Cash Equivalents [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Pension Plans, Defined Benefit [Member] \| Cash Equivalents [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	2,852	2,600
Pension Plans, Defined Benefit [Member] \| Cash Equivalents [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	106,793	91,858	86,984
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	106,793	91,858
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	55,441	47,411
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	55,441	47,411
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| International Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	14,037	11,500
Other Postretirement Benefit Plans, Defined Benefit [Member] \| International Equity Securities [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| International Equity Securities [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	14,037	11,500
Other Postretirement Benefit Plans, Defined Benefit [Member] \| International Equity Securities [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Core Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	36,738	32,192
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Core Bonds [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Core Bonds [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	36,738	32,192
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Core Bonds [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	577	755
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Cash Equivalents [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Cash Equivalents [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	577	755
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Cash Equivalents [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 0	$ 0

Assets, usually stocks, bonds, and other investments, that have been segregated and restricted (usually in a trust) to provide benefits, at their fair value as of the measurement date. Plan assets include amounts contributed by the employer (and by employees for a contributory plan) and amounts earned from investing the contributions, less benefits paid. If a plan has liabilities other than for benefits, those non-benefit obligations may be considered as reductions of plan assets.

+ References+ Details

Employee Benefit Plans (Changes in Level 3 Plan Assets Measured at Fair Value on a Recurring Basis) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 19,826	$ 20,478	$ 18,036
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	84,955	74,939	54,950
Defined Benefit Plan, Actual Return on Plan Assets Still Held	(7,090)	(4,514)
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	(26)	(49)
Purchases, issuances and settlements, net	2,900	15,524
Domestic Equity Securities [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	18,493	15,375	11,575
Defined Benefit Plan, Actual Return on Plan Assets Still Held	(25)	(1,910)
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	(53)	0
Purchases, issuances and settlements, net	3,090	1,890
High-Yield Bonds [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0	0	1,200
Defined Benefit Plan, Actual Return on Plan Assets Still Held	0	0
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	0	0
Purchases, issuances and settlements, net	0	(1,200)
Real Estate [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	20,927	18,848	16,411
Defined Benefit Plan, Actual Return on Plan Assets Still Held	(2,296)	(2,652)
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	(27)	(49)
Purchases, issuances and settlements, net	(190)	(166)
Alternative Funds [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	45,535	40,716	25,764
Defined Benefit Plan, Actual Return on Plan Assets Still Held	(4,819)	(48)
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	0	0
Purchases, issuances and settlements, net	$ 0	$ 15,000

Employee Benefit Plans (Expected Cash Flows Related To Pension and Post-Retirement Benefit Plans) (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012
Plan Trust [Member] \| Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2013	$ 30.0
2013	(31.3)
2014	(33.3)
2015	(35.3)
2016	(38.0)
2017	(41.1)
2018 - 2022	(247.1)
Plan Trust [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
2013	6.0
2013	(7.9)
2014	(8.3)
2015	(8.8)
2016	(9.1)
2017	(9.5)
2018 - 2022	(49.6)
Company Assets [Member] \| Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2013	(2.9)
2014	(2.8)
2015	(2.8)
2016	(2.8)
2017	(2.8)
2018 - 2022	(13.0)
Company Assets [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
2013	(0.3)
2014	(0.3)
2015	(0.3)
2016	(0.3)
2017	(0.3)
2018 - 2022	$ (1.2)

Employee Benefit Plans (Compensation expense and income tax benefits related to stock-based compensation arrangements included in net income) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Allocated Share-based Compensation Expense	$ 7,203	$ 8,367	$ 11,321
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	$ 2,849	$ 3,309	$ 4,481

Represents the expense recognized during the period arising from equity-based compensation arrangements (for example, shares of stock, unit, stock options or other equity instruments) with employees, directors and certain consultants qualifying for treatment as employees.

+ References+ Details

Employee Benefit Plans (RSU activity for awards) (Details) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
RSU Awards With Only Service Requirements [Member]
Defined Benefit Plan Disclosure [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Total Fair Value	$ 3,700,000	$ 4,800,000	$ 2,700,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested balance, beginning of year	368,500	600,400	368,800
Granted	131,000	284,100	366,400
Vested	(127,800)	(187,300)	(118,100)
Forfeited	(20,600)	(328,700)	(16,700)
Nonvested balance, end of year	351,100	368,500	600,400
Weighted Average Grant Date Fair Value, beginning of year	$ 23.83	$ 21.50	$ 21.98
Grants in Period, Weighted Average Grant Date Fair Value	$ 27.82	$ 26.30	$ 22.14
Vested in Period, Weighted Average Grant Date Fair Value	$ 23.34	$ 23.50	$ 24.81
Forfeited in Period, Weighted Average Grant Date Fair Value	$ 24.40	$ 24.37	$ 22.32
Weighted Average Grant Date Fair Value, end of year	$ 25.47	$ 23.83	$ 21.50
RSU Awards With Performance Measures [Member]
Defined Benefit Plan Disclosure [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Total Fair Value	$ 3,600,000	$ 3,600,000	$ 0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested balance, beginning of year	324,200	348,400	0
Granted	122,300	244,400	366,000
Vested	(88,200)	(119,500)	(4,500)
Forfeited	(18,200)	(149,100)	(13,100)
Nonvested balance, end of year	340,100	324,200	348,400
Weighted Average Grant Date Fair Value, beginning of year	$ 28.31	$ 24.98	$ 0.00
Grants in Period, Weighted Average Grant Date Fair Value	$ 28.84	$ 31.26	$ 24.96
Vested in Period, Weighted Average Grant Date Fair Value	$ 25.46	$ 24.12	$ 23.32
Forfeited in Period, Weighted Average Grant Date Fair Value	$ 29.00	$ 28.72	$ 24.99
Weighted Average Grant Date Fair Value, end of year	$ 29.20	$ 28.31	$ 24.98

Employee Benefit Plans (Textual) (Details) (USD $)

12 Months Ended

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2012

Level 2 [Member]

Dec. 31, 2011

Level 2 [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Dec. 31, 2011

Pension Plans, Defined Benefit [Member]

Dec. 31, 2010

Pension Plans, Defined Benefit [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2011

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2010

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2012

Supplemental Employee Retirement Plans, Defined Benefit [Member]

Dec. 31, 2011

Supplemental Employee Retirement Plans, Defined Benefit [Member]

Dec. 31, 2012

KGE [Member]

Dec. 31, 2012

Debt Securities [Member]

Pension Plans, Defined Benefit [Member]

Dec. 31, 2012

Debt Securities [Member]

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2012

Equity Securities [Member]

Pension Plans, Defined Benefit [Member]

Dec. 31, 2012

Equity Securities [Member]

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2012

Other Investments [Member]

Pension Plans, Defined Benefit [Member]

Dec. 31, 2010

Stock Options [Member]

Dec. 31, 2012

Long Term Incentive and Share Award [Member]

May 19, 2011

Long Term Incentive and Share Award [Member]

May 18, 2011

Long Term Incentive and Share Award [Member]

Dec. 31, 2012

Long Term Incentive and Share Award Plan Executive Stock For Compensation Program [Member]

Dec. 31, 2011

Long Term Incentive and Share Award Plan Executive Stock For Compensation Program [Member]

Dec. 31, 2010

Long Term Incentive and Share Award Plan Executive Stock For Compensation Program [Member]

Dec. 31, 2012

RSU Awards With Performance Measures [Member]

Dec. 31, 2011

RSU Awards With Performance Measures [Member]

Dec. 31, 2010

RSU Awards With Performance Measures [Member]

Dec. 31, 2012

RSU Awards With Only Service Requirements [Member]

Dec. 31, 2011

RSU Awards With Only Service Requirements [Member]

Dec. 31, 2010

RSU Awards With Only Service Requirements [Member]

Dec. 31, 2012

OneTimeBenefitPayment [Member]

Pension Plans, Defined Benefit [Member]

Subsidiary Interest in Defined Benefit Plans

47.00%

Defined Benefit Plan, Benefit Obligation Other

$ 60,229,000

$ 31,107,000

$ 9,799,000

$ 10,114,000

$ 26,100,000

^[1]

9,673,000

^[1]

750,000

^[1]

Benefit obligation for certain retirement benefits

928,708,000

876,308,000

747,460,000

152,564,000

150,078,000

137,759,000

30,000,000

29,400,000

Total Trading Securities, Assets

43,484,000

40,201,000

43,318,000

40,032,000

Defined Benefit Plan Target Allocation Percentage Of Assets Of Any One Industry

25.00%

Target Defined Benefit Plan Asset Allocations

44.00%

35.00%

42.00%

65.00%

14.00%

US Government Securities, at Carrying Value

35,600,000

401k Savings Plan Matching Contributions

7,100,000

7,000,000

7,400,000

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized

^[1]

750,000

^[1]

8,250,000

5,000,000

Share-based Compensation Arrangement by Share-based Payment Award, Shares Awarded

4,800,000

Share-based Compensation Arrangement by Share-based Payment Award, Plan Modification, Incremental Compensation Cost

2,800,000

Percentage of RSU Award, Minimum

0.00%

Percentage of RSU Award, Maximum

200.00%

Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate, Minimum

17.60%

24.50%

Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate, Maximum

33.60%

28.50%

Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate, Minimum

0.40%

0.10%

Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate, Maximum

1.30%

Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized

3,500,000

3,300,000

4,200,000

Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition

1 year 8 months 13 days

Share-based Compensation Award Fair Value, Vested During Period

$ 3,600,000

$ 0

$ 3,700,000

$ 4,800,000

$ 2,700,000

Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period

Common Stock Dividends, Shares

666

4,757

6,627

Common stock, shares issued

126,503,638

125,698,396

1,461

67,426

1,198

[1]

Wolf Creek Employee Benefit Plans (Funded Status) (Details) (USD $)
In Thousands, unless otherwise specified

12 Months Ended

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Wolf Creek [Member]

$ 98,051

$ 80,727

Pension Benefits [Member]

876,308

747,460

19,556

16,076

13,926

39,576

40,045

39,391

(60,229)

(31,107)

53,497

94,161

^[1]

9,673

^[1]

928,708

876,308

747,460

481,077

432,233

67,328

27,819

56,700

50,000

57,174

28,975

547,931

481,077

432,233

Amounts Recognized in the Balance Sheet Consist of:

(380,777)

(395,231)

(2,870)

(2,741)

(377,907)

(392,490)

Amounts Recognized in Regulatory Assets Consist of:

(380,777)

(395,231)

383,365

397,691

3,994

4,606

387,359

402,297

Pension Benefits [Member] | Wolf Creek [Member]

161,396

131,460

6,062

4,957

4,144

7,537

7,370

6,941

(8,569)

(3,033)

9,815

20,642

650

^[1]

176,891

161,396

131,460

80,727

76,086

11,764

(2,578)

13,887

10,009

(8,327)

(2,790)

98,051

80,727

76,086

Amounts Recognized in the Balance Sheet Consist of:

(78,840)

(80,669)

(243)

(78,597)

(80,426)

Amounts Recognized in Regulatory Assets Consist of:

(78,840)

(80,669)

64,535

65,273

675

65,210

65,304

Other Postretirement Benefit Plans, Defined Benefit [Member]

150,078

137,759

2,057

1,803

1,526

6,298

6,793

7,083

2,987

3,390

(9,799)

(10,114)

943

5,246

4,451

^[1]

750

^[1]

152,564

150,078

137,759

91,858

86,984

10,673

(174)

10,803

10,793

2,845

3,244

9,386

9,739

106,793

91,858

86,984

Amounts Recognized in the Balance Sheet Consist of:

(45,771)

(58,220)

(298)

(115)

(45,473)

(58,105)

Amounts Recognized in Regulatory Assets Consist of:

(45,771)

(58,220)

12,436

18,178

16,467

18,991

325

4,236

29,228

41,405

Other Postretirement Benefit Plans, Defined Benefit [Member] | Wolf Creek [Member]

10,129

10,144

191

165

179

411

458

519

608

614

(988)

(979)

669

(360)

^[1]

11,020

10,129

10,144

389

369

608

614

(988)

(979)

Amounts Recognized in the Balance Sheet Consist of:

(11,007)

(10,125)

(625)

(609)

(10,382)

(9,516)

Amounts Recognized in Regulatory Assets Consist of:

(11,007)

(10,125)

3,643

3,208

3,644

3,266

OneTimeBenefitPayment [Member] | Pension Benefits [Member]

(26,100)

OneTimeBenefitPayment [Member] | Pension Benefits [Member] | Wolf Creek [Member]

$ (4,900)

[1]

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (Plans With a Projected Benefit Obligation and Accumulated Benefit Obligation in Excess of Plan Assets) (Details) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 928,708	$ 876,308
Fair value of plan assets	547,931	481,077
Accumulated benefit obligation	806,888	750,263
Fair value of plan assets	547,931	481,077
Discount rate	4.13%	4.50%
Compensation rate increase	4.00%	4.00%
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	152,564	150,078
Fair value of plan assets	106,793	91,858
Discount rate	3.99%	4.25%
Compensation rate increase	0.00%	0.00%
Wolf Creek [Member] \| Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	176,891	161,396
Fair value of plan assets	98,051	80,727
Accumulated benefit obligation	141,722	128,633
Fair value of plan assets	98,051	80,727
Discount rate	4.16%	4.55%
Compensation rate increase	4.00%	4.00%
Wolf Creek [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	11,020	10,129
Fair value of plan assets	$ 13	$ 4
Discount rate	3.78%	4.10%
Compensation rate increase	0.00%	0.00%

+ References+ Details

+ References+ Details

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (Net Periodic Costs And Other Changes Recognized in Regulatory Assets) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Components of Net Periodic Cost (Benefit):
Service cost	$ 19,556	$ 16,076	$ 13,926
Interest cost	39,576	40,045	39,391
Expected return on plan assets	(32,283)	(31,087)	(38,384)
Transition obligation, net	0	0	0
Prior service costs	612	1,213	2,729
Actuarial loss, net	32,778	23,659	17,183
Net periodic cost before regulatory adjustment	60,239	49,906	34,845
Regulatory adjustment	(6,523)	(22,098)	(12,167)
Net periodic cost	53,716	27,808	22,678
Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	18,451	97,429	65,690
Amortization of actuarial loss	(32,778)	(23,659)	(17,183)
Current year prior service cost	0	0	676
Amortization of prior service costs	(612)	(1,213)	(2,729)
Amortization of transition obligation	0	0	0
Total recognized in regulatory assets	(14,939)	72,557	46,454
Total recognized in net periodic cost and regulatory assets	38,777	100,365	69,132
Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.50%	5.35%	5.95%
Expected long-term return on plan assets	6.50%	6.50%	8.25%
Compensation rate increase	4.00%	4.00%	4.00%
Pension Benefits [Member] \| Wolf Creek [Member]
Components of Net Periodic Cost (Benefit):
Service cost	6,062	4,957	4,144
Interest cost	7,537	7,370	6,941
Expected return on plan assets	(6,577)	(5,904)	(5,453)
Transition obligation, net	0	52	57
Prior service costs	6	16	29
Actuarial loss, net	5,366	3,586	2,636
Net periodic cost before regulatory adjustment	12,394	10,077	8,354
Regulatory adjustment	(1,776)	(2,546)	(1,498)
Net periodic cost	10,618	7,531	6,856
Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	4,629	29,124	7,514
Amortization of actuarial loss	(5,366)	(3,586)	(2,636)
Current year prior service cost	650	0	0
Amortization of prior service costs	(6)	(16)	(29)
Amortization of transition obligation	0	(52)	(57)
Total recognized in regulatory assets	(93)	25,470	4,792
Total recognized in net periodic cost and regulatory assets	10,525	33,001	11,648
Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.55%	5.45%	6.05%
Expected long-term return on plan assets	7.50%	7.50%	8.00%
Compensation rate increase	4.00%	4.00%	4.00%
Other Postretirement Benefit Plans, Defined Benefit [Member]
Components of Net Periodic Cost (Benefit):
Service cost	2,057	1,803	1,526
Interest cost	6,298	6,793	7,083
Expected return on plan assets	(5,491)	(5,002)	(5,197)
Transition obligation, net	3,912	3,911	3,912
Prior service costs	2,524	2,524	2,154
Actuarial loss, net	1,503	702	321
Net periodic cost before regulatory adjustment	10,803	10,731	9,799
Regulatory adjustment	23	1,344	1,868
Net periodic cost	10,826	12,075	11,667
Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	(4,239)	10,421	3,298
Amortization of actuarial loss	(1,503)	(702)	(321)
Current year prior service cost	0	4,451	0
Amortization of prior service costs	(2,524)	(2,524)	(2,154)
Amortization of transition obligation	(3,912)	(3,911)	(3,912)
Total recognized in regulatory assets	(12,178)	7,735	(3,089)
Total recognized in net periodic cost and regulatory assets	(1,352)	19,810	8,578
Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.25%	5.00%	5.65%
Expected long-term return on plan assets	6.00%	6.00%	7.75%
Compensation rate increase	0.00%	0.00%	0.00%
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Wolf Creek [Member]
Components of Net Periodic Cost (Benefit):
Service cost	191	165	179
Interest cost	411	458	519
Expected return on plan assets	0	0	0
Transition obligation, net	57	58	58
Prior service costs	0	0	0
Actuarial loss, net	234	227	276
Net periodic cost before regulatory adjustment	893	908	1,032
Regulatory adjustment	0	0	0
Net periodic cost	893	908	1,032
Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	669	(360)	363
Amortization of actuarial loss	(234)	(227)	(276)
Current year prior service cost	0	0	0
Amortization of prior service costs	0	0	0
Amortization of transition obligation	(57)	(58)	(58)
Total recognized in regulatory assets	378	(645)	29
Total recognized in net periodic cost and regulatory assets	$ 1,271	$ 263	$ 1,061
Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.10%	4.90%	5.50%
Expected long-term return on plan assets	0.00%	0.00%	0.00%
Compensation rate increase	0.00%	0.00%	0.00%

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (Estimated Amounts From Regulatory Assets Into Net Periodic Cost) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012
Pension Benefits [Member]
Actuarial loss	$ (33,914)
Prior service cost	(601)
Transition obligation	0
Total	34,515
Pension Benefits [Member] \| Wolf Creek [Member]
Actuarial loss	5,421
Prior service cost	58
Transition obligation	0
Total	5,479
Other Postretirement Benefit Plans, Defined Benefit [Member]
Actuarial loss	(1,125)
Prior service cost	(2,524)
Transition obligation	(325)
Total	3,974
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Wolf Creek [Member]
Actuarial loss	264
Prior service cost	0
Transition obligation	1
Total	$ 265

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (Assumed Annual Health Care Cost Growth Rates) (Details)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Health care cost trend rate assumed for next year	8.00%	8.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2019	2018
Wolf Creek [Member]
Health care cost trend rate assumed for next year	8.00%	8.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2019	2018

+ References+ Details

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (One Percentage Change In Assumed Health Care Cost Growth Rates Effects) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012
Effect on total of service and interest cost from one-percentage-point increase	$ 67
Effect on total of service and interest cost from one-percentage-point decrease	(64)
Effect on post-retirement benefit obligation from one-percentage-point increase	1,489
Effect on post-retirement benefit obligation from one-percentage-point decrease	(1,384)
Wolf Creek [Member]
Effect on total of service and interest cost from one-percentage-point increase	(10)
Effect on total of service and interest cost from one-percentage-point decrease	10
Effect on post-retirement benefit obligation from one-percentage-point increase	(129)
Effect on post-retirement benefit obligation from one-percentage-point decrease	$ 128

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (Fair Value of Plan Assets) (Details) (Wolf Creek [Member], USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Fair value of pension plan assets	$ 98,051	$ 80,727
Level 1
Fair value of pension plan assets	0	44,808
Level 2
Fair value of pension plan assets	89,610	32,289
Level 3
Fair value of pension plan assets	8,441	3,630
Domestic Equity Securities [Member]
Fair value of pension plan assets	24,305	30,753
Domestic Equity Securities [Member] \| Level 1
Fair value of pension plan assets	0	30,753
Domestic Equity Securities [Member] \| Level 2
Fair value of pension plan assets	24,305	0
Domestic Equity Securities [Member] \| Level 3
Fair value of pension plan assets	0	0
International Equity Securities [Member]
Fair value of pension plan assets	30,484	18,023
International Equity Securities [Member] \| Level 1
Fair value of pension plan assets	0	9,953
International Equity Securities [Member] \| Level 2
Fair value of pension plan assets	30,484	8,070
International Equity Securities [Member] \| Level 3
Fair value of pension plan assets	0	0
Core Bonds [Member]
Fair value of pension plan assets	24,763	17,877
Core Bonds [Member] \| Level 1
Fair value of pension plan assets	0	0
Core Bonds [Member] \| Level 2
Fair value of pension plan assets	24,763	17,877
Core Bonds [Member] \| Level 3
Fair value of pension plan assets	0	0
High-yield bonds
Fair value of pension plan assets		4,102
High-yield bonds \| Level 1
Fair value of pension plan assets		4,102
High-yield bonds \| Level 2
Fair value of pension plan assets		0
High-yield bonds \| Level 3
Fair value of pension plan assets		0
Real Estate [Member]
Fair value of pension plan assets	9,513	3,630
Real Estate [Member] \| Level 1
Fair value of pension plan assets	0	0
Real Estate [Member] \| Level 2
Fair value of pension plan assets	4,972	0
Real Estate [Member] \| Level 3
Fair value of pension plan assets	4,541	3,630
Commodities [Member]
Fair value of pension plan assets	4,789	4,377
Commodities [Member] \| Level 1
Fair value of pension plan assets	0	0
Commodities [Member] \| Level 2
Fair value of pension plan assets	4,789	4,377
Commodities [Member] \| Level 3
Fair value of pension plan assets	0	0
Alternative Funds [Member]
Fair value of pension plan assets	3,900
Alternative Funds [Member] \| Level 1
Fair value of pension plan assets	0
Alternative Funds [Member] \| Level 2
Fair value of pension plan assets	0
Alternative Funds [Member] \| Level 3
Fair value of pension plan assets	3,900
Cash Equivalents [Member]
Fair value of pension plan assets	297	1,965
Cash Equivalents [Member] \| Level 1
Fair value of pension plan assets	0	0
Cash Equivalents [Member] \| Level 2
Fair value of pension plan assets	297	1,965
Cash Equivalents [Member] \| Level 3
Fair value of pension plan assets	$ 0	$ 0

+ References+ Details

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (Changes in Level 3 Plan Assets Measured at Fair Value on a Recurring Basis) (Details) (USD $) In Thousands, unless otherwise specified				12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2012 Level 3	Dec. 31, 2011 Level 3	Dec. 31, 2012 Level 3 Wolf Creek [Member]	Dec. 31, 2011 Level 3 Wolf Creek [Member]	Dec. 31, 2012 Real Estate [Member] Level 3	Dec. 31, 2011 Real Estate [Member] Level 3	Dec. 31, 2012 Real Estate [Member] Level 3 Wolf Creek [Member]	Dec. 31, 2011 Real Estate [Member] Level 3 Wolf Creek [Member]	Dec. 31, 2012 Alternative Funds [Member] Level 3	Dec. 31, 2011 Alternative Funds [Member] Level 3	Dec. 31, 2012 Alternative Funds [Member] Level 3 Wolf Creek [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at period start	$ 19,826	$ 20,478	$ 18,036	$ 74,939	$ 54,950	$ 3,630	$ 3,160	$ 18,848	$ 16,411	$ 3,630	$ 3,160	$ 40,716	$ 25,764	$ 0
Actual gain (loss) on plan assets relating to assets still held at the reporting date				(7,090)	(4,514)	(388)	(500)	(2,296)	(2,652)	(411)	(500)	(4,819)	(48)	(23)
Actual gain (loss) on plan assets relating to assets sold during the period				26	49	755	2	27	49	755	2	0	0	0
Purchases, issuances and settlements, net				2,900	15,524	4,444	(32)	(190)	(166)	567	(32)	0	15,000	3,877
Balance at period end	$ 19,826	$ 20,478	$ 18,036	$ 84,955	$ 74,939	$ 8,441	$ 3,630	$ 20,927	$ 18,848	$ 4,541	$ 3,630	$ 45,535	$ 40,716	$ 3,900

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (Expected Cash Flows Related To Pension and Post-Retirement Benefit Plans) (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012
Plan Trust [Member] \| Pension Benefits [Member]
Expected contributions:
2013	$ 30.0
Expected benefit payments:
2013	(31.3)
2014	(33.3)
2015	(35.3)
2016	(38.0)
2017	(41.1)
2018 - 2022	(247.1)
Plan Trust [Member] \| Pension Benefits [Member] \| Wolf Creek [Member]
Expected contributions:
2013	9.4
Expected benefit payments:
2013	(3.7)
2014	(4.3)
2015	(5.0)
2016	(5.8)
2017	(6.7)
2018 - 2022	(46.9)
Plan Trust [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Expected contributions:
2013	6.0
Expected benefit payments:
2013	(7.9)
2014	(8.3)
2015	(8.8)
2016	(9.1)
2017	(9.5)
2018 - 2022	(49.6)
Plan Trust [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member] \| Wolf Creek [Member]
Expected contributions:
2013	0.6
Expected benefit payments:
2013	(0.6)
2014	(0.7)
2015	(0.7)
2016	(0.8)
2017	(0.8)
2018 - 2022	(4.5)
Company Assets [Member] \| Pension Benefits [Member]
Expected benefit payments:
2013	(2.9)
2014	(2.8)
2015	(2.8)
2016	(2.8)
2017	(2.8)
2018 - 2022	(13.0)
Company Assets [Member] \| Pension Benefits [Member] \| Wolf Creek [Member]
Expected benefit payments:
2013	(0.2)
2014	(0.2)
2015	(0.2)
2016	(0.2)
2017	(0.2)
2018 - 2022	(0.9)
Company Assets [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Expected benefit payments:
2013	(0.3)
2014	(0.3)
2015	(0.3)
2016	(0.3)
2017	(0.3)
2018 - 2022	(1.2)
Company Assets [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member] \| Wolf Creek [Member]
Expected benefit payments:
2013	0
2014	0
2015	0
2016	0
2017	0
2018 - 2022	$ 0

Wolf Creek Employee Benefit Plans (Textual) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
401k Savings Plan Matching Contributions	$ 7.1	$ 7.0	$ 7.4
KGE [Member]
Subsidiary's interest, percentage	47.00%
Wolf Creek [Member]
401k Savings Plan Matching Contributions	$ 1.3	$ 1.3	$ 1.1
International Equity Securities [Member] \| Wolf Creek [Member]
Target Defined Benefit Plan Asset Allocations	31.00%
Domestic Equity Securities [Member] \| Wolf Creek [Member]
Target Defined Benefit Plan Asset Allocations	25.00%
Debt Securities [Member] \| Wolf Creek [Member]
Target Defined Benefit Plan Asset Allocations	25.00%
Real Estate [Member] \| Wolf Creek [Member]
Target Defined Benefit Plan Asset Allocations	10.00%
Commodity [Member] \| Wolf Creek [Member]
Target Defined Benefit Plan Asset Allocations	5.00%
Other Investments [Member] \| Wolf Creek [Member]
Target Defined Benefit Plan Asset Allocations	4.00%

Commitments And Contingencies (Details) (USD $)	12 Months Ended
Commitments And Contingencies (Details) (USD $)	Dec. 31, 2012 facilities MW Y phases States	Dec. 31, 2011	Dec. 31, 2010	Jan. 31, 2013
Commitments And Contingencies [Line Items]
Unexpended Commitments	$ 588,300,000
Aggregate Amount of Required Payments [Abstract]
2013	159,546,000
2014	72,573,000
2015	29,271,000
Thereafter	16,727,000
Total amount committed	278,117,000
Federal Clean Air Act [Abstract]
Review period interval by the EPA	5
Environmental Projects [Abstract]
Entity Share of Environmental Upgrades of Jointly Owned Plant	610,000,000
Environmental Upgrades of Jointly Owned Utility Plant	1,200,000,000
Air Emissions [Abstract]
Period to Comply With Regulations	4
Estimated Cost to Comply with Environmental Regulation	16,000,000
Number of States Required to Comply with Regulations	28
Number of States Required to Comply with Seasonal Regulations	5
Renewable Energy Standard [Abstract]
Supply agreement duration, years	20
Capacity of qualifying wind generation facilities	370
EPA Consent Decree [Abstract]
Estimate of cost of selective catalytic reduction equipment	240,000,000
FERC Investigation [Abstract]
Estimate of possible loss	1,600,000	500,000
Settlement consideration				1,600,000
Nuclear Decommissioning [Abstract]
Site study frequency	3
Number of nuclear decommissioning phases	2
Estimated decommissioning costs	296,200,000
Previously estimated decommissioning costs	279,000,000
Decommissioning fund deposits	3,200,000	3,200,000	3,100,000
Total Nuclear Decommissioning Trust	150,754,000	130,270,000
Fee for future disposal of spent nuclear fuel	3,600,000	3,100,000	4,000,000
Number of insurance types for nuclear insurance	4
Nuclear Insurance Industry Aggregate Limit	3,200,000,000
Nuclear Liability Insurance - Full Limit of Public Liability	12,600,000,000
Nuclear Liability Insurance - Maximum Available Commercial Insurance	375,000,000
Nuclear Liability Insurance - Industry-Wide Retrospective Assessment Program	12,200,000,000
Nuclear Liability Insurance - Owners' Insurance Amount Maximum	117,500,000
Nuclear Liability Insurance - Entity Share of Insurance Amount Maximum	55,200,000
Nuclear Liability Insurance - Owners' Insurance Amount, Per Incident	17,500,000
Nuclear Liability Insurance - Entity Share of Insurance Amount, Per Incident	8,200,000
Nuclear Liability Insurance - Owners' Property Insurance, Maximum	2,800,000,000
Nuclear Liability Insurance - Entity Share of Owners' Property Insurance, Maximum	1,300,000,000
Nuclear Liability Insurance - Owners' Accidental Nuclear Outage Insurance, Maximum	30,200,000
Nuclear Liability Insurance - Entity Share of Owners' Accidental Nuclear Outage Insurance, Maximum	14,200,000
Number of Wind Generation Facilities	4
Capacity of wind generation facilities, megawatts	515
Future wind energy purchase costs	68,200,000
Transmission Capacity per Contractual Obligations	306
Net Capacity, in MW	3,099
Cost of Transmission	34,300,000
2011 Through 2015 Generation Capacity Peak Demand [Member]
Renewable Energy Standard [Abstract]
Renewable energy generation capacity, percentage	10.00%
2016 Through 2019 Generation Capacity Peak Demand [Member]
Renewable Energy Standard [Abstract]
Renewable energy generation capacity, percentage	15.00%
2020 And Thereafter Generation Capacity Peak Demand [Member]
Renewable Energy Standard [Abstract]
Renewable energy generation capacity, percentage	20.00%
Potential GHG Emissions Restrictions 1 [Member]
Greenhouse Gases [Abstract]
GHG emission	75,000
Potential GHG Emissions Restrictions 2 [Member]
Greenhouse Gases [Abstract]
GHG emission	100,000
Preliminary Unjust Profits [Member]
FERC Investigation [Abstract]
Damages sought	14,300,000
Further Revised Unjust Profits [Member]
FERC Investigation [Abstract]
Damages sought	900,000
Revised Alleged Transmission Service Costs [Member]
FERC Investigation [Abstract]
Damages sought	800,000
Minimum [Member]
Air Emissions [Abstract]
Period to Comply With Regulations	3
Maximum [Member]
Air Emissions [Abstract]
Period to Comply With Regulations	5
Uranium Concentrates [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	42,200,000
Conversion [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	6,300,000
Enrichment [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	106,300,000
Fabrication [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	36,000,000
Coal and Coal Transportation [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	648,200,000
Natural Gas Transportation [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	$ 129,000,000
Transmission Service Agreements One [Member]
Nuclear Decommissioning [Abstract]
Net Capacity, in MW	200
Transmission Service Agreements Two [Member]
Nuclear Decommissioning [Abstract]
Net Capacity, in MW	106

Asset Retirement Obligations (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Regulatory Liabilities [Line Items]
KGE ownership share	47.00%
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning ARO	$ 142,508	$ 125,999
Liabilities settled	(1,389)	(1,027)
Accretion expense	8,454	7,623
Revised ARO estimate	3,075	0
Ending ARO	152,648	142,508
Regulatory liability - removal costs	323,175	271,387
Removal Costs [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Regulatory liability - removal costs	128,971	82,338
Wolf Creek [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Revised ARO estimate	$ 0	$ 9,913

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.

+ References+ Details

Amount of accretion expense recognized during the period that is associated with an asset retirement obligation. Accretion expense measures and incorporates changes due to the passage of time into the carrying amount of the liability.

+ References+ Details

Common and Preferred Stock (Common Stock Details) (USD $)	12 Months Ended						0 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2012 Forward Sale Agreement Entered In April 2010 [Member]	Dec. 31, 2011 Forward Sale Agreement Entered In April 2010 [Member]	Apr. 30, 2010 Forward Sale Agreement Entered In April 2010 [Member]	Nov. 17, 2011 Forward Sale Agreement Entered In November Two Thousand And Ten Member	Nov. 30, 2010 Forward Sale Agreement Entered In November Two Thousand And Ten Member	Nov. 30, 2010 Base Allotment [Member] Forward Sale Agreement Entered In November Two Thousand And Ten Member	Nov. 30, 2010 Over Allotment Option [Member] Forward Sale Agreement Entered In November Two Thousand And Ten Member	Dec. 31, 2012 Direct Stock Purchase Plan And Other Stock-Based Plans [Member]	Dec. 31, 2011 Direct Stock Purchase Plan And Other Stock-Based Plans [Member]	Dec. 31, 2010 Direct Stock Purchase Plan And Other Stock-Based Plans [Member]	Dec. 31, 2012 DSPP [Member]	Dec. 31, 2011 DSPP [Member]
Common Stock [Line Items]
Common stock, shares authorized	275,000,000	275,000,000	150,000,000
Common stock, shares issued	126,503,638	125,698,396			5,400,000		8,500,000				800,000	800,000	700,000
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant														1,500,000	2,000,000
Forward Sale Agreement, Maximum Amount Authorized						$ 500,000,000
Forward Sale Agreement, Maximum Shares Authorized						22,000,000
Commissions Paid, Percentage of Sales Price of Shares Sold						1.00%		3.50%
Proceeds from Issuance or Sale of Equity	6,996,000	294,942,000	54,651,000		118,300,000		197,300,000
Forward Contract Indexed to Issuer's Equity, Indexed Shares				1,800,000
Forward Contract Indexed to Issuer's Equity, Estimated Proceeds				$ 48,100,000
Average forward price of shares				$ 27.45
Shares Borrowed Under Forward Contracts								8,500,000	7,500,000	1,000,000
Shares Borrowed Under Forward Contracts, Price Per Share								$ 25.54

Common and Preferred Stock (Preferred Stock Details) (USD $) In Thousands, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Jun. 30, 2012	Dec. 31, 2011
Preferred Stock, Value, Issued	$ 0	$ 0	$ 21,436
Preferred stock, shares outstanding	0		214,363
Preferred Stock Redemption Premium	1,131
Total Cost to Redeem	22,567
Redeemable Preferred Stock Rate One [Member]
Preferred Stock, Value, Issued	12,161
Preferred Stock, Dividend Rate, Percentage	4.50%
Preferred stock, shares outstanding	121,613
Preferred Stock, Call Price	1.08
Preferred Stock Redemption Premium	973
Total Cost to Redeem	13,134
Redeemable Preferred Stock Rate Two [Member]
Preferred Stock, Value, Issued	5,497
Preferred Stock, Dividend Rate, Percentage	4.25%
Preferred stock, shares outstanding	54,970
Preferred Stock, Call Price	1.015
Preferred Stock Redemption Premium	82
Total Cost to Redeem	5,579
Redeemable Preferred Stock Rate Three [Member]
Preferred Stock, Value, Issued	3,778
Preferred Stock, Dividend Rate, Percentage	5.00%
Preferred stock, shares outstanding	37,780
Preferred Stock, Call Price	1.02
Preferred Stock Redemption Premium	76
Total Cost to Redeem	$ 3,854

Variable Interest Entity [Line Items]

Aggregate par or stated value of issued nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer). This item includes treasury stock repurchased by the entity. Note: elements for number of nonredeemable preferred shares, par value and other disclosure concepts are in another section within stockholders' equity.

+ References+ Details

Variable Interest Entities (Assets And Liabilities In Relation To VIEs) (Details) (USD $)
In Thousands, unless otherwise specified

Dec. 31, 2012

Dec. 31, 2011

Property, plant and equipment, net

$ 7,013,765

$ 6,411,922

Regulatory Assets

1,002,672

1,046,090

Current maturities of long-term debt

Accrued interest

77,891

77,437

Variable Interest Entity [Line Items]

2,819,271

2,491,109

Variable Interest Entity, Primary Beneficiary [Member]

Property, plant and equipment, net

321,975

333,494

Regulatory Assets

5,810

^[1]

4,915

^[1]

Current maturities of long-term debt

25,942

28,114

Accrued interest

3,948

4,448

$ 222,743

$ 249,283

[1]	(a) Included in long-term regulatory assets on our consolidated balance sheets.(b) Included in accrued interest on our consolidated balance sheets.

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).

+ References+ Details

+ References+ Details

Leases (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended						12 Months Ended				12 Months Ended
	Dec. 31, 2012 Minimum [Member]	Dec. 31, 2012 Maximum [Member]	Dec. 31, 2012 Generation Tie Line [Member]	Dec. 31, 2011 Power Supply Agreement [Member]	Dec. 31, 2012 Vehicles [Member]	Dec. 31, 2011 Vehicles [Member]	Dec. 31, 2012 Vehicles [Member] Minimum [Member] Y	Dec. 31, 2012 Vehicles [Member] Maximum [Member] Y	Dec. 31, 2012 Computer Equipment [Member]	Dec. 31, 2011 Computer Equipment [Member]	Dec. 31, 2012 Computer Equipment [Member] Minimum [Member] Y	Dec. 31, 2012 Computer Equipment [Member] Maximum [Member] Y
Leases [Line Items]
Lease term in years	1	20,000					2	8			3	5
Lease Expiration Date			Aug. 01, 2032	May 31, 2039
Capital leased assets gross			$ 8,300	$ 40,000	$ 12,594	$ 14,241			$ 1,423	$ 1,720

Property, plant, or equipment held under lease agreements classified as an asset.

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Leases Leases (Operating Leases, Minimum Annual Rental Payments) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Rental expense:
Rental expense	$ 17,080	$ 17,577	$ 15,464
Future commitments:
2013	14,453
2014	12,550
2015	10,142
2016	8,390
2017	6,694
Thereafter	18,049
Total future commitments	$ 70,278

Leases (Assets Recorded Under Capital Leases) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Leases [Line Items]
Accumulated amortization	$ (6,928)	$ (6,485)
Total capital leases	55,435	49,524
Vehicles [Member]
Leases [Line Items]
Capital leased assets gross	12,594	14,241
Computer Equipment [Member]
Leases [Line Items]
Capital leased assets gross	1,423	1,720
Generation Plant [Member]
Leases [Line Items]
Capital leased assets gross	$ 48,346	$ 40,048

Property, plant, or equipment held under lease agreements classified as an asset.

+ References+ Details

Net Income attributable to common stock

The total charge for the use of long-lived depreciable assets subject to a lease meeting the criteria for capitalization.

+ References+ Details

Leases (Capital Leases, Minimum Annual Rental Payments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012
Leases [Abstract]
2013	$ 6,538
2014	6,363
2015	5,840
2016	5,087
2017	4,708
Thereafter	76,800
Total future commitments	105,336
Amounts representing imputed interest	(48,461)
Present value of net minimum lease payments under capital leases	56,875
Less: current portion	3,066
Total long-term obligation under capital leases	$ 53,809

Quarterly Results (Unaudited) (Details) (USD $)
In Thousands, except Per Share data, unless otherwise specified

3 Months Ended

12 Months Ended

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Quarterly Results [Line Items]

Revenues

$ 523,772

$ 695,758

^[1]

$ 566,262

$ 475,677

$ 486,228

$ 678,152

^[1]

$ 524,892

$ 481,720

$ 2,261,470

$ 2,170,991

$ 2,056,171

Net income

47,695

141,067

^[1]

64,462

29,237

21,306

136,392

^[1]

45,525

32,957

282,462

236,180

208,624

$ 45,607

$ 139,281

^[1]

$ 61,361

$ 27,282

$ 19,335

$ 134,708

^[1]

$ 43,887

$ 31,342

$ 273,530

$ 229,269

$ 202,926

Basic: Earnings available

$ 0.36

$ 1.10

^[1]

$ 0.48

$ 0.21

$ 0.16

$ 1.15

^[1]

$ 0.38

$ 0.27

$ 2.15

$ 1.95

$ 1.81

Diluted: Earnings available

$ 0.36

$ 1.09

^[1]

$ 0.48

$ 0.21

$ 0.16

$ 1.14

^[1]

$ 0.38

$ 0.27

$ 2.15

$ 1.93

$ 1.80

Cash dividend declared per common share

$ 0.33

^[1]

$ 0.33

$ 0.32

^[1]

$ 0.32

$ 1.32

$ 1.28

$ 1.24

High [Member]

Quarterly Results [Line Items]

Market price per common share

$ 30.29

$ 33.04

^[1]

$ 30.17

$ 29.13

$ 29.05

$ 27.29

^[1]

$ 27.98

$ 26.60

Low [Member]

Quarterly Results [Line Items]

Market price per common share

$ 27.33

$ 28.96

^[1]

$ 26.80

$ 27.12

$ 25.02

$ 22.63

^[1]

$ 25.58

$ 25.05

[1]	(a)Items are computed independently for each of the periods presented and the sum of the quarterly amounts may not equal the total for the year.

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 128

-Paragraph 36, 37, 38

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Emerging Issues Task Force (EITF)

-Number 07-4

-Paragraph 4

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 50

-Paragraph 1

-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 225

-SubTopic 10

-Section S99

-Paragraph 2

-Subparagraph (SX 210.5-03.21)

-URI http://asc.fasb.org/extlink&oid=6880815&loc=d3e20235-122688

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 45

-Paragraph 2

-URI http://asc.fasb.org/extlink&oid=7655603&loc=d3e1252-109256

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 04

-Paragraph 18

-Article 7

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 03

-Paragraph 20

-Article 5

Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 04

-Paragraph 21

-Article 9

Reference 9: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 55

-Paragraph 52

-URI http://asc.fasb.org/extlink&oid=16381557&loc=d3e4984-109258

Reference 10: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 944

-SubTopic 225

-Section S99

-Paragraph 1

-Subparagraph (SX 210.7-04.19)

-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 11: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 942

-SubTopic 225

-Section S99

-Paragraph 1

-Subparagraph (SX 210.9-04.23)

-URI http://asc.fasb.org/extlink&oid=6879574&loc=d3e536633-122882

+ Details

The amount of net income (loss) for the period available to each share of common stock or common unit outstanding during the reporting period and to each share or unit that would have been outstanding assuming the issuance of common shares or units for all dilutive potential common shares or units outstanding during the reporting period.

+ References+ Details

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.