23,608

33,049

Total Current Assets

706,798

643,075

Nuclear decommissioning trust

7,551,916

7,013,765

OTHER ASSETS:

Regulatory assets

620,006

887,777

175,625

150,754

246,140

247,885

Total Other Assets

1,041,771

1,286,416

TOTAL ASSETS

9,597,111

9,265,231

CURRENT LIABILITIES:

250,000

Short-term debt

134,600

339,200

Accounts payable

233,351

180,825

Accrued dividends

43,604

41,743

Accrued taxes

69,742

58,624

80,457

77,891

Regulatory liabilities

35,982

37,557

Total Current Liabilities

80,184

84,359

955,399

846,141

LONG-TERM LIABILITIES:

Unamortized investment tax credits

2,968,958

2,819,271

Deferred income taxes

1,361,418

1,197,837

192,265

191,512

Regulatory liabilities

293,574

285,618

Accrued employee benefits

331,558

564,870

Asset retirement obligations

160,682

152,648

Total Long-Term Liabilities

69,924

74,336

5,573,181

5,508,835

COMMITMENTS AND CONTINGENCIES (See Notes 13 and 15)

Westar Energy, Inc. Shareholders' Equity:

Cumulative preferred stock, par value $100 per share; authorized 600,000 shares; issued and outstanding zero shares and 214,363 shares, respective to each date

21,436

Common stock, par value $5 per share; authorized 275,000,000 shares; issued and outstanding 126,503,748 shares and 125,698,396 shares, respective to each date

641,271

632,519

Paid-in capital

1,696,727

1,656,972

Retained earnings

724,776

606,649

Total Westar Energy, Inc. Shareholders' Equity

3,062,774

2,896,140

Noncontrolling Interests

5,757

14,115

Total Equity

3,068,531

2,910,255

TOTAL LIABILITIES AND EQUITY

9,597,111

9,265,231

Variable Interest Entity [Member]

CURRENT ASSETS:

296,626

321,975

CURRENT LIABILITIES:

27,479

25,942

3,472

^[1]

3,948

^[1]

LONG-TERM LIABILITIES:

$ 194,802

$ 222,743

[1]	Included in accrued interest on our consolidated balance sheets.

Consolidated Balance Sheets Parenthetical (Parentheticals) (USD $) In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Allowance for doubtful accounts receivable	$ 4,596	$ 4,916
Preferred stock, par value	$ 100	$ 100
Preferred stock, shares authorized	600,000	600,000
Preferred stock, shares issued	0	214,363
Preferred stock, shares outstanding	0	214,363
Common stock, par value	$ 5	$ 5
Common stock, shares authorized	275,000,000	275,000,000
Common stock, shares issued	128,254,229	126,503,748
Common stock, shares outstanding	128,254,229	126,503,748

Consolidated Statements Of Income (USD $) In Thousands, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
REVENUES	$ 2,370,654	$ 2,261,470	$ 2,170,991
OPERATING EXPENSES:
Fuel and purchased power	634,797	589,990	630,793
Network Transmission Cost	178,604	166,547	132,164
Operating and maintenance	359,060	342,055	332,989
Depreciation and amortization	272,593	270,464	285,322
Selling, general and administrative	224,133	226,012	184,695
Taxes, Miscellaneous	122,282	104,269	92,599
Total Operating Expenses	1,791,469	1,699,337	1,658,562
INCOME FROM OPERATIONS	579,185	562,133	512,429
OTHER INCOME (EXPENSE):
Investment earnings	10,056	7,411	9,301
Other income	35,609	35,378	8,652
Other expense	(18,099)	(19,987)	(18,398)
Total Other Income (Expense)	27,566	22,802	(445)
Interest expense	182,167	176,337	172,460
INCOME BEFORE INCOME TAXES	424,584	408,598	339,524
Income tax expense	123,721	126,136	103,344
NET INCOME	300,863	282,462	236,180
Less: Net income attributable to noncontrolling interests	8,343	7,316	5,941
NET INCOME ATTRIBUTABLE TO WESTAR ENERGY	292,520	275,146	230,239
Preferred dividends	0	1,616	970
NET INCOME ATTRIBUTABLE TO COMMON STOCK	$ 292,520	$ 273,530	$ 229,269
Basic earnings per common share	$ 2.29	$ 2.15	$ 1.95
Diluted earnings per common share	$ 2.27	$ 2.15	$ 1.93
AVERAGE EQUIVALENT COMMON SHARES OUTSTANDING	127,462,994	126,711,869	116,890,552
DIVIDENDS DECLARED PER COMMON SHARE	$ 1.36	$ 1.32	$ 1.28

Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net income	$ 300,863	$ 282,462	$ 236,180
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	272,593	270,464	285,322
Amortization of nuclear fuel	22,690	24,369	21,151
Amortization of deferred regulatory gain from sale-leaseback	(5,495)	(5,495)	(5,495)
Amortization of corporate-owned life insurance	15,149	28,792	25,650
Non-cash compensation	8,188	7,255	8,422
Net deferred income taxes and credits	123,307	126,248	111,723
Stock-based compensation excess tax benefits	(576)	(1,698)	(1,180)
Allowance for equity funds used during construction	(14,143)	(11,706)	(5,550)
Gain on sale of non-utility investment	0	0	(7,246)
Gain on settlement of contractual obligations with former officers	0	0	(22,039)
Changes in working capital items:
Accounts receivable	(24,649)	2,408	(1,638)
Fuel inventory and supplies	10,124	(19,227)	(21,485)
Prepaid expenses and other	(12,316)	(3,630)	(50,138)
Accounts payable	7,856	(19,161)	3,008
Accrued taxes	14,218	11,937	18,633
Other current liabilities	(52,829)	(105,169)	(107,012)
Changes in other assets	(4,167)	13,015	(10,167)
Changes in other liabilities	41,990	(1,758)	(15,443)
Cash Flows from Operating Activities	702,803	599,106	462,696
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Additions to property, plant and equipment	(780,098)	(810,209)	(697,451)
Purchase of securities within trusts	(66,668)	(20,473)	(49,737)
Sale of securities within trusts	81,994	21,604	47,534
Investment in corporate-owned life insurance	(17,724)	(18,404)	(19,214)
Proceeds from investment in corporate-owned life insurance	147,658	33,542	1,295
Proceeds from federal grant	876	4,775	8,561
Investment in affiliated company	(4,947)	(8,669)	(1,943)
Proceeds from sale of non-utility investment	0	0	9,246
Other investing activities	(2,992)	497	193
Cash Flows used in Investing Activities	(641,901)	(797,337)	(701,516)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Short-term debt, net	(205,241)	52,900	54,081
Proceeds from long-term debt	492,347	541,374	0
Retirements of long-term debt	(100,000)	(220,563)	(371)
Repayment of capital leases	(2,995)	(2,679)	(2,233)
Borrowings against cash surrender value of corporate-owned life insurance	59,565	67,791	67,562
Repayment of borrowings against cash surrender value of corporate-owned life insurance	(145,418)	(34,838)	(3,421)
Stock-based compensation excess tax benefits	576	1,698	1,180
Preferred stock redemption	0	(22,567)	0
Issuance of common stock	32,906	6,996	294,942
Distributions to shareholders of noncontrolling interests	(2,419)	(3,295)	(1,917)
Cash dividends paid	(162,904)	(158,182)	(138,233)
Proceeds from (Payments for) Other Financing Activities	(2,719)
Cash Flows from (used in) Financing Activities	(62,244)	200,521	241,431
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(1,342)	2,290	2,611
CASH AND CASH EQUIVALENTS:
Beginning of period	5,829	3,539	928
End of period	4,487	5,829	3,539
Variable Interest Entity [Member]
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Retirements of long-term debt	$ (25,942)	$ (28,114)	$ (30,159)

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, 2010	$ 2,410,373	$ 21,436	$ 560,640	$ 1,398,580	$ 423,647	$ 6,070
Beginning 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	294,942	0	64,756	230,186	0	0
Issuance of stock, shares		0	12,951,207
Issuance Of Stock For Comprensation And Reinvested Dividends, Shares			619,121
Issuance Of Stock For Compensation And Reinvested Dividends	7,427		3,096	4,331
Adjustments Related to Tax Withholding for Share-based Compensation	(3,141)			(3,141)
Preferred dividends	(970)	0	0	0	(970)	0
Dividends on common stock	(151,700)	0	0	0	(151,700)	0
Amortization of restricted stock	8,367			8,367
Stock compensation and tax benefit	(1,180)	0	0	(1,180)	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	6,996	0	1,212	5,784	0	0
Issuance of stock, shares		0	242,463
Issuance Of Stock For Comprensation And Reinvested Dividends, Shares			562,889
Issuance Of Stock For Compensation And Reinvested Dividends	9,089		2,815	6,274
Adjustments Related to Tax Withholding for Share-based Compensation	(3,490)			(3,490)
Stock redemption, shares		(214,363)
Stock redemption, value	(21,436)	(21,436)
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	7,203	0	0	7,203	0	0
Stock compensation and tax benefit	(1,698)	0	0	1,698	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
Net income	300,863	0	0	0	292,520	8,343
Issuance of stock, value	32,906	0	6,282	26,624	0	0
Issuance of stock, shares		0	1,256,391
Issuance Of Stock For Comprensation And Reinvested Dividends, Shares			494,090
Issuance Of Stock For Compensation And Reinvested Dividends	9,641		2,470	7,171
Adjustments Related to Tax Withholding for Share-based Compensation	(2,719)			(2,719)
Preferred dividends	0
Dividends on common stock	(174,393)	0	0	0	(174,393)	0
Amortization of restricted stock	8,103			8,103
Stock compensation and tax benefit	(576)			576
Noncontrolling Interest, Decrease from Deconsolidation	(14,282)					(14,282)
Distributions to shareholders of noncontrolling interests	(2,419)	0	0	0	0	(2,419)
Ending balance at Dec. 31, 2013	$ 3,068,531	$ 0	$ 641,271	$ 1,696,727	$ 724,776	$ 5,757
Ending balance, shares at Dec. 31, 2013		0	128,254,229

Description Of Business	12 Months Ended
Description Of Business	Dec. 31, 2013
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 693,000 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, 2013

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.

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,
	2013		2012
	(In Thousands)
Fuel inventory	$	78,368	$	94,664
Supplies	161,143		154,352
Total	$	239,511	$	249,016

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,
	2013		2012			2011
	(Dollars In Thousands)
Borrowed funds	$	11,706	$	10,399		$	5,589
Equity funds	14,143		11,706			5,550
Total	$	25,849	$	22,105		$	11,139
Average AFUDC Rates	4.8%		5.0		%	3.6		%

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 2.5% in 2013, 2.6% in 2012 and 3.0% in 2011.

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



	Years
Fossil fuel generating facilities	6	to	78
Nuclear fuel generating facility	55	to	71
Wind generating facilities	19	to	20
Transmission facilities	15	to	75
Distribution facilities	22	to	68
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 $46.2 million as of December 31, 2013, and $69.2 million as of December 31, 2012. The cost of nuclear fuel charged to fuel and purchased power expense was $26.5 million in 2013, $28.3 million in 2012 and $24.6 million in 2011.

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,
	2013			2012
	(In Thousands)
Cash surrender value of policies	$	1,289,457		$	1,370,788
Borrowings against policies	(1,156,341		)	(1,241,343		)
Corporate-owned life insurance, net	$	133,116		$	129,445

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

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 $60.1 million as of December 31, 2013, and $62.5 million as of December 31, 2012.

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 the extent capital losses, operating losses, or tax credits will be carried forward to future periods. 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 and RSUs with forfeitable rights to dividend equivalents. 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,
	2013		2012		2011
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	300,863	$	282,462	$	236,180
Less: Net income attributable to noncontrolling interests	8,343		7,316		5,941
Net income attributable to Westar Energy, Inc.	292,520		275,146		230,239
Less: Preferred dividends	—		1,616		970
Net income allocated to RSUs	810		778		772
Net income allocated to common stock	$	291,710	$	272,752	$	228,497

Weighted average equivalent common shares outstanding – basic	127,462,994		126,711,869		116,890,552
Effect of dilutive securities:
RSUs	17,195		97,757		188,025
Forward sale agreements	818,505		89,160		1,211,645
Weighted average equivalent common shares outstanding – diluted (a)	128,298,694		126,898,786		118,290,222

Earnings per common share, basic	$	2.29	$	2.15	$	1.95
Earnings per common share, diluted	$	2.27	$	2.15	$	1.93

_______________


(a)	For the years ended December 31, 2013, 2012 and 2011, we had no antidilutive shares.

Supplemental Cash Flow Information



	Year Ended December 31,
	2013			2012			2011
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	148,691		$	143,564		$	145,570
Interest on financing activities of VIEs	13,892			16,214			18,167
Income taxes, net of refunds	(11		)	(4,378		)	(17,519		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	127,544			89,354			105,435
Property, plant and equipment of VIEs	(14,282		)	—			—
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	9,641			9,089			7,427
Deconsolidation of VIEs	(14,282		)	—			—
Assets acquired through capital leases	334			10,683			43,011

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, 2013

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,
	2013		2012
	(In Thousands)
Regulatory Assets:
Deferred employee benefit costs	$	277,122	$	542,174
Amounts due from customers for future income taxes, net	163,742		169,091
Depreciation	71,047		73,672
Debt reacquisition costs	63,882		67,721
Ad valorem tax	34,492		21,812
Wolf Creek outage	29,026		14,143
Treasury yield hedges	27,594		28,573
Asset retirement obligations	23,555		22,633
Retail energy cost adjustment	22,138		4,262
Disallowed plant costs	15,964		16,106
Energy efficiency program costs	14,477		18,835
Storm costs	1,483		11,076
Other regulatory assets	10,892		12,574
Total regulatory assets	$	755,414	$	1,002,672

Regulatory Liabilities:
Removal costs	$	114,148	$	128,971
Deferred regulatory gain from sale leaseback	86,551		92,046
Nuclear decommissioning	43,272		25,937
La Cygne dismantling costs	20,505		18,093
Other post-retirement benefits costs	19,000		10,722
Retail energy cost adjustment	15,414		16,595
Kansas tax credits	11,076		10,781
Jurisdictional allowance for funds used during construction	7,893		4,457
Gain on sale of oil	4,278		6,219
Fuel supply and electricity contracts	2,635		4,387
Other regulatory liabilities	4,784		4,967
Total regulatory liabilities	$	329,556	$	323,175

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 $223.5 million for pension and post-retirement benefit obligations and $53.7 million for actual pension expense in excess of the amount of such expense recognized in setting our prices. The decrease from 2012 to 2013 is primarily attributable to the favorable increase in the funded status of our and Wolf Creek's pension and post-retirement plans. During 2014, we will amortize to expense approximately $24.9 million of the benefit obligations and approximately $9.8 million of the excess pension expense. As authorized in the April 2012 Kansas Corporation Commission (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.


•	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.


•	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.


•	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 Instruments and Trading Securities—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.

•

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.

•

Disallowed plant costs: Originally there was a decision to disallow certain costs related to the Wolf Creek plant. Subsequently, in 1987, the KCC revised its original conclusion and provided for recovery of an indirect disallowance with no return on investment. This regulatory asset represents the present value of the future expected revenues to be provided to recover these costs, net of the amounts amortized.


•	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.


•	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 will amortize the remaining costs over a two-year period and no longer 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 amount recorded for our ARO. See Note 4, "Financial Instruments and Trading Securities," 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.


•	Other post-retirement benefits costs: Includes $6.7 million for post-retirement obligations and $12.3 million 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.

•

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: This item 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.


•	Jurisdictional allowance for funds used during construction: This item represents AFUDC that is accrued subsequent to the time the associated construction charges are included in our rates and prior to the time the charges are placed in service. The AFUDC is amortized to depreciation expense over the useful life of the asset that is placed in service.


•	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 November 2013, the KCC issued an order allowing us to adjust our prices to include the additional investment in the La Cygne environmental upgrades, as discussed below, and to reflect cost reductions elsewhere. The new prices are expected to increase our annual retail revenues by approximately $30.7 million.

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.

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, we received an order regarding an abbreviated rate review to update our prices to include a portion of the 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:


•	$27.3 million effective in June 2013;


•	$19.5 million effective in June 2012; and


•	$10.4 million effective in June 2011.

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:


•	$11.8 million effective in March 2013;


•	$36.7 million effective in April 2012; and


•	$17.4 million effective in April 2011.

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 adjust our annual retail revenues by approximately:


•	$1.3 million decrease effective in November 2013;


•	$1.1 million increase effective in October 2012; and


•	$4.9 million increase effective in November 2011.

Property Tax Surcharge

We make annual filings with the KCC to adjust our prices to include the cost incurred for property taxes. In the most recent three years, the KCC issued orders related to such filings allowing us to increase our annual retail revenues by approximately:


•	$15.2 million effective in January 2013;


•	$5.9 million effective in January 2012; and


•	$0.7 million effective in January 2011.

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:


•	$12.2 million effective in January 2013;


•	$38.2 million effective in January 2012; and


•	$15.9 million effective in January 2011.

Financial Instruments and Trading Securities

12 Months Ended

Dec. 31, 2013

Financial And Derivative Instruments and Trading Securities [Abstract]

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

FINANCIAL INSTRUMENTS AND TRADING SECURITIES

Values of Financial and Derivative Instruments

GAAP establishes a hierarchical 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.

•

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.


•	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. Level 3 includes investments in private equity, real estate securities and other alternative investments, which are measured at net asset value.

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, alternative investments 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 alternative investments include collateralized debt obligations, mezzanine debt and a variety of other investments. The fair value of these investments is measured using a variety of primarily market-based models utilizing inputs such as security prices, maturity, call features, ratings and other developments related to specific securities. 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.

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, 2013				As of December 31, 2012
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In Thousands)
Fixed-rate debt	$	3,102,500	$	3,294,209	$	2,702,500	$	3,178,752
Fixed-rate debt of VIEs	221,682		241,241		247,624		275,341

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, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Nuclear Decommissioning Trust:
Domestic equity	$	—	$	49,957	$	5,817	$	55,774
International equity	—		31,816		—		31,816
Core bonds	—		18,107		—		18,107
High-yield bonds	—		12,902		—		12,902
Emerging market bonds	—		11,055		—		11,055
Other fixed income	—		4,690		—		4,690
Combination debt/equity/other fund	—		17,093		—		17,093
Alternative investments	—		—		15,675		15,675
Real estate securities	—		—		8,511		8,511
Cash equivalents	2		—		—		2
Total Nuclear Decommissioning Trust	2		145,620		30,003		175,625
Trading Securities: (a)
Domestic equity	—		18,075		—		18,075
International equity	—		4,519		—		4,519
Core bonds	—		12,166		—		12,166
Cash equivalents	166		—		—		166
Total Trading Securities	166		34,760		—		34,926
Total Assets Measured at Fair Value	$	168	$	180,380	$	30,003	$	210,551

As of December 31, 2012
Assets:
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	$	181,270	$	12,764	$	194,238

_______________


(a)	The decrease in the fair value of trading securities was due to withdrawing $15.3 million.

The following table provides reconciliations of assets and liabilities held in the NDT measured at fair value using significant level 3 inputs for the years ended December 31, 2013 and 2012.



	Domestic Equity			Alternative Investments		Real Estate Securities			Net Balance
	(In Thousands)
Balance as of December 31, 2012	$	4,899		$	—	$	7,865		$	12,764
Total realized and unrealized gains included in:
Regulatory liabilities	940			675		646			2,261
Purchases	341			15,000		287			15,628
Sales	(363		)	—		(287		)	(650		)
Balance as of December 31, 2013	$	5,817		$	15,675	$	8,511		$	30,003

Balance as of December 31, 2011	$	3,931		$	—	$	7,095		$	11,026
Total realized and unrealized gains included in:
Regulatory liabilities	90			—		770			860
Purchases	891			—		320			1,211
Sales	(13		)	—		(320		)	(333		)
Balance as of December 31, 2012	$	4,899		$	—	$	7,865		$	12,764

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 we recorded to regulatory liabilities on our consolidated financial statements during the years ended December 31, 2013 and 2012, attributed to level 3 assets and liabilities.



	Domestic Equity		Alternative Investments		Real Estate Securities		Net Balance
	(In Thousands)
Year ended December 31, 2013	$	577	$	675	$	359	$	1,611
Year ended December 31, 2012	77		—		451		528

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, 2013				As of December 31, 2012				As of December 31, 2013
	Fair Value		Unfunded Commitments		Fair Value		Unfunded Commitments		Redemption Frequency	Length of Settlement
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity	$	5,817	$	2,683	$	4,899	$	1,024	(a)	(a)
Alternative investments	15,675		—		—		—		(b)	(b)
Real estate securities	8,511		—		7,865		—		Quarterly	80 days
Total Nuclear Decommissioning Trust	$	30,003	$	2,683	$	12,764	$	1,024

Trading Securities:
Domestic equity	$	18,075	$	—	$	22,470	$	—	Upon Notice	1 day
International equity	4,519		—		5,744		—		Upon Notice	1 day
Core bonds	12,166		—		15,104		—		Upon Notice	1 day
Total Trading Securities	34,760		—		43,318		—
Total	$	64,763	$	2,683	$	56,082	$	1,024

_______________

(a)

This investment is in three 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 to make distributions and we expect the other to begin in 2014. Our initial investment in the third fund occurred in the 3rd quarter of 2013. This fund's term will be 15 years, subject to the General Partner's right to extend the term for up to three additional one-year periods.


(b)	This fund has an initial lock-up period of 24 months. Redemptions are allowed, on a quarterly basis, after 24 months at the sole discretion of the fund's board of directors. A 65-day notice of redemption is required. There is a holdback on final redemptions.

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 2013, we recorded no additional AROs. In 2012, we recorded $3.1 million of additional AROs. 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 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

In 2011, we entered into treasury yield hedge transactions to hedge our interest rate risk associated with a $125.0 million portion of a forecasted 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. 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, 2013 and 2012, we had recorded $27.6 million and $28.6 million, respectively, as a regulatory asset.

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.

Financial Investments

12 Months Ended

Dec. 31, 2013

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 $27.0 million and $30.0 million as of December 31, 2013 and 2012, respectively. For additional information on our benefit obligations, see Note 11, "Employee Benefit Plans."

As of December 31, 2013 and 2012, we measured the fair value of trust assets at $34.9 million and $43.5 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, 2013, 2012 and 2011, we recorded unrealized gains of $6.7 million, $4.1 million and $0.3 million, respectively.

Available-for-Sale Securities

We hold investments 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, 2013, and December 31, 2012. As of December 31, 2013, the fair value of available-for-sale bond funds was $46.8 million. The NDT did not have investments in debt securities outside of investment funds as of December 31, 2013.

Using the specific identification method to determine cost, we realized gains on our available-for-sale securities of $5.3 million in 2013, $0.6 million in 2012 and $1.3 million in 2011. 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, 2013 and 2012.



			Gross Unrealized
Security Type	Cost		Gain		Loss			Fair Value		Allocation
	(Dollars In Thousands)
As of December 31, 2013
Domestic equity	$	40,976	$	14,799	$	(1	)	$	55,774	32	%
International equity	26,581		5,266		(31		)	31,816		18	%
Core bonds	18,287		—		(180		)	18,107		10	%
High-yield bonds	12,275		627		—			12,902		7	%
Emerging market bonds	12,207		—		(1,152		)	11,055		6	%
Other fixed income	4,684		6		—			4,690		3	%
Combination debt/equity/other fund	14,964		2,380		(251		)	17,093		10	%
Alternative investments	15,000		675		—			15,675		9	%
Real estate securities	10,268		—		(1,757		)	8,511		5	%
Cash equivalents	2		—		—			2		<1%
Total	$	155,244	$	23,753	$	(3,372	)	$	175,625	100	%

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	%

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, 2013 and 2012.



	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, 2013
Domestic equity	$	59	$	(1	)	$	—	$	—		$	59	$	(1	)
International equity	6,244		(31		)	—		—			6,244		(31		)
Core bonds	18,107		(180		)	—		—			18,107		(180		)
Emerging market bonds	11,055		(1,152		)	—		—			11,055		(1,152		)
Combination debt/equity/other funds	6,283		(251		)	—		—			6,283		(251		)
Real estate securities	—		—			8,511		(1,757		)	8,511		(1,757		)
Total	$	41,748	$	(1,615	)	$	8,511	$	(1,757	)	$	50,259	$	(3,372	)

As of December 31, 2012
Real estate securities	$	—	$	—		$	7,865	$	(2,116	)	$	7,865	$	(2,116	)

Property, Plant And Equipment

12 Months Ended

Dec. 31, 2013

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,
	2013			2012
	(In Thousands)
Electric plant in service	$	9,753,787		$	9,389,192
Electric plant acquisition adjustment	802,318			802,318
Accumulated depreciation	(3,971,735		)	(3,791,545		)
	6,584,370			6,399,965
Construction work in progress	904,586			532,332
Nuclear fuel, net	62,960			81,468
Net property, plant and equipment	$	7,551,916		$	7,013,765

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



	As of December 31,
	2013			2012
	(In Thousands)
Electric plant of VIEs	$	513,793		$	543,548
Accumulated depreciation of VIEs	(217,167		)	(221,573		)
Net property, plant and equipment of VIEs	$	296,626		$	321,975

We revised our depreciation rates to reflect changes in the estimated useful lives of some of our assets in 2012. We recorded depreciation expense on property, plant and equipment of $249.9 million in 2013, $247.8 million in 2012 and $262.6 million in 2011. Approximately $9.7 million, $9.8 million and $9.8 million of depreciation expense in 2013, 2012 and 2011, respectively, was attributable to property, plant and equipment of VIEs.

Joint Ownership of Utility Plants

The entire disclosure for long-lived, physical assets used in the normal conduct of business and not intended for resale. Includes, but is not limited to, accounting policies and methodology, roll forwards, depreciation, depletion and amortization expense, including composite depreciation, accumulated depreciation, depletion and amortization expense, useful lives and method used, income statement disclosures, assets held for sale and public utility disclosures.

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Joint Ownership of Utility Plants

12 Months Ended

Dec. 31, 2013

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, 2013, 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	$	334,054	$	151,674	$	280,688	368	50
JEC unit 1 (a)	July 1978	530,407		194,944		166,073		661	92
JEC unit 2 (a)	May 1980	504,508		190,660		13,138		658	92
JEC unit 3 (a)	May 1983	713,937		296,278		1,906		664	92
Wolf Creek (b)	Sept. 1985	1,596,382		773,724		144,083		547	47
State Line (c)	June 2001	110,408		48,357		305		201	40
Total		$	3,789,696	$	1,655,637	$	606,193	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 341 MW of net capacity. The VIE's investment in the 50% interest was $392.1 million and accumulated depreciation was $187.4 million as of December 31, 2013. 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, 2013

Debt Disclosure [Abstract]

Short-Term Debt

SHORT-TERM DEBT

In July 2013 Westar Energy extended the term of its $730.0 million revolving credit facility to terminate in September 2017. As long as there is no default under the facility, Westar Energy may extend the facility up to an additional year 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, 2013, no amounts had been borrowed and $18.4 million of letters of credit had been issued under this revolving credit facility. As of December 31, 2012, none had been borrowed and $13.8 million of letters of credit had been issued under this revolving credit facility.

In 2011, Westar Energy entered into a revolving credit facility with a syndicate of banks for $270.0 million. In February 2014, Westar Energy extended the term of the $270.0 million revolving credit facility to February 2017, provided that $20.0 million of this facility will terminate in February 2016. As long as there is no default under the facility, Westar Energy may increase the aggregate amount of borrowings under the facility to $400.0 million, subject to lender participation. All borrowings under the facility are secured by KGE first mortgage bonds. As of December 31, 2013 and 2012, Westar Energy had no borrowed amounts or letters of credit outstanding under this revolving credit facility.

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. 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. Westar Energy had issued $134.6 million and $339.2 million of commercial paper as of December 31, 2013 and 2012, respectively.

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 outstanding as of December 31, 2013 and December 31, 2012, was 0.28% and 0.46%, respectively. Additional information regarding our short-term debt is as follows.



	As of December 31,
	2013			2012
	(Dollars in Thousands)
Weighted average short-term debt outstanding during the year	$	228,352		$	298,907
Weighted daily average interest rates during the year, excluding fees	0.39		%	0.55		%

Our interest expense on short-term debt was $2.4 million in 2013, $3.2 million in 2012 and $3.9 million in 2011.

Long-term Debt, Unclassified [Abstract]

The entire disclosure for short-term debt.

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Long-Term Debt

12 Months Ended

Dec. 31, 2013

Long-term Debt

LONG-TERM DEBT

Outstanding Debt

The following table summarizes our long-term debt outstanding.



	As of December 31,
	2013			2012
	(In Thousands)
Westar Energy
First mortgage bond series:
6.00% due 2014	$	250,000		$	250,000
5.15% due 2017	125,000			125,000
8.625% due 2018	300,000			300,000
5.10% due 2020	250,000			250,000
5.95% due 2035	125,000			125,000
5.875% due 2036	150,000			150,000
4.125% due 2042	550,000			550,000
4.10% due 2043	250,000			—
4.625% due 2043	250,000			—
	2,250,000			1,750,000
Pollution control bond series:
Variable due 2032, 0.12% as of December 31, 2013; 0.32% as of December 31, 2012	45,000			45,000
Variable due 2032, 0.12% as of December 31, 2013; 0.26% as of December 31, 2012	30,500			30,500
	75,500			75,500

KGE
First mortgage bond series:
6.70% due 2019	300,000			300,000
6.15% due 2023	50,000			50,000
6.53% due 2037	175,000			175,000
6.64% due 2038	100,000			100,000
	625,000			625,000
Pollution control bond series:
Variable due 2027, 0.10% as of December 31, 2013; 0.26% as of December 31, 2012	21,940			21,940
5.30% due 2031	108,600			108,600
5.30% due 2031	18,900			18,900
4.85% due 2031	50,000			50,000
5.60% due 2031	—			50,000
6.00% due 2031	—			50,000
5.00% due 2031	50,000			50,000
Variable due 2032, 0.10% as of December 31, 2013; 0.26% as of December 31, 2012	14,500			14,500
Variable due 2032, 0.10% as of December 31, 2013; 0.26% as of December 31, 2012	10,000			10,000
	273,940			373,940

Total long-term debt	3,224,440			2,824,440
Unamortized debt discount (a)	(5,482		)	(5,169		)
Long-term debt due within one year	(250,000		)	—
Long-term debt, net	$	2,968,958		$	2,819,271

Variable Interest Entities
6.99% due 2014 (b)	316			866
5.92 % due 2019 (b)	13,243			17,630
5.647% due 2021 (b)	208,123			229,128
Total long-term debt of variable interest entities	221,682			247,624
Unamortized debt premium (a)	599			1,061
Long-term debt of variable interest entities due within one year	(27,479		)	(25,942		)
Long-term debt of variable interest entities, net	$	194,802		$	222,743

_______________

(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, 2013, approximately $505.3 million principal amount of additional first mortgage bonds could be issued under the most restrictive provisions in Westar Energy's mortgage. As of December 31, 2013, approximately $1.1 billion principal amount of additional KGE first mortgage bonds could be issued under the most restrictive provisions in KGE's mortgage.

As of December 31, 2013, 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 August 2013, Westar Energy issued $250.0 million principal amount of first mortgage bonds bearing stated interest at 4.625% and maturing September 2043.

In June 2013, KGE redeemed two pollution control bond series with an aggregate principal amount of $100.0 million and stated interest rates at 5.60% and 6.00%.

In March 2013, Westar Energy issued $250.0 million principal amount of first mortgage bonds bearing stated interest at 4.10% and maturing April 2043.

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.

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.

Proceeds from issuances 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.

Maturities

The principal amounts of our long-term debt maturities as of December 31, 2013, are as follows.



Year	Long-term debt		Long-term debt of VIEs
	(In Thousands)
2014	$	250,000	$	27,479
2015	—		27,933
2016	—		28,309
2017	125,000		26,842
2018	300,000		28,538
Thereafter	2,549,440		82,581
Total maturities	$	3,224,440	$	221,682

Interest expense on long-term debt was $154.9 million in 2013, $145.6 million in 2012 and $142.6 million in 2011. Interest expense on long-term debt of VIEs was $13.0 million in 2013, $15.1 million in 2012 and $16.8 million in 2011.

Taxes

12 Months Ended

Dec. 31, 2013

Income Tax Disclosure [Abstract]

Taxes

TAXES

Income tax expense is comprised of the following components.



	Year Ended December 31,
	2013			2012			2011
	(In Thousands)
Income Tax Expense (Benefit):
Current income taxes:
Federal	$	135		$	(691	)	$	(8,575	)
State	279			579			196
Deferred income taxes:
Federal	102,030			102,960			93,089
State	24,443			26,300			21,337
Investment tax credit amortization	(3,166		)	(3,012		)	(2,703		)
Income tax expense	$	123,721		$	126,136		$	103,344

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



	As of December 31,
	2013		2012
	(In Thousands)
Current deferred tax assets	$	37,927	$	—
Other current liabilities	—		8,654
Non-current deferred tax liabilities	1,361,418		1,197,837
Net deferred tax liabilities	$	1,323,491	$	1,206,491

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,
	2013		2012
	(In Thousands)
Deferred tax assets:
Tax credit carryforward (a)	$	212,635	$	199,160
Net operating loss carryforward (b)	110,588		111,869
Deferred employee benefit costs	85,720		191,997
Deferred state income taxes	57,243		55,577
Deferred regulatory gain on sale-leaseback	38,124		40,543
Alternative minimum tax carryforward (c)	35,666		36,471
Deferred compensation	30,022		28,319
Accrued liabilities	17,396		15,969
Disallowed costs	11,453		12,083
LaCygne dismantling cost	8,110		7,156
Capital loss carryforward (d)	3,447		11,509
Other	20,058		13,741
Total gross deferred tax assets	630,462		724,394
Less: Valuation allowance (e)	3,504		13,812
Deferred tax assets	$	626,958	$	710,582

Deferred tax liabilities:
Accelerated depreciation	$	1,390,669	$	1,255,892
Acquisition premium	171,907		179,920
Amounts due from customers for future income taxes, net	163,742		169,091
Deferred employee benefit costs	85,720		191,997
Deferred state income taxes	51,504		50,134
Pension expense tracker	21,230		22,437
Storm costs	21,165		4,373
Debt reacquisition costs	19,985		22,313
Other	24,527		20,916
Total deferred tax liabilities	$	1,950,449	$	1,917,073

Net deferred tax liabilities	$	1,323,491	$	1,206,491

_______________

(a)

Based on filed tax returns and amounts expected to be reported in current year tax returns (December 31, 2013), we had available federal general business tax credits of $50.2 million and state investment tax credits of $162.4 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 2033. The state investment tax credits expire beginning in 2017 and ending in 2029.


(b)	As of December 31, 2013, we had a federal net operating loss carryforward of $277.6 million, which is available to offset federal taxable income. The net operating losses will expire beginning in 2031 and ending in 2032.


(c)	As of December 31, 2013, we had available an alternative minimum tax credit carryforward of $35.7 million, which has an unlimited carryforward period.


(d)	As of December 31, 2013, we had an unused capital loss carryforward of $8.7 million that is available to offset future capital gains. The capital losses will expire in 2016.


(e)	As we do not expect to realize any significant capital gains in the future, we have established a valuation allowance of $3.5 million. The total valuation allowance related to the deferred tax assets was $3.5 million as of December 31, 2013, and $13.8 million as of December 31, 2012.

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,
	2013		2012		2011
Statutory federal income tax rate	35.0	%	35.0	%	35.0	%
Effect of:
Corporate-owned life insurance policies	(5.4	)	(4.9	)	(4.5	)
State income taxes	3.8		4.3		4.1
Production tax credits	(2.3	)	(2.4	)	(2.9	)
Flow through depreciation for plant-related differences	2.2		1.4		1.8
AFUDC equity	(1.2	)	(1.0	)	(0.6	)
Capital loss utilization carryforward	(1.1	)	(0.3	)	(0.5	)
Amortization of federal investment tax credits	(0.7	)	(0.7	)	(0.8	)
Liability for unrecognized income tax benefits	0.1		0.2		—
Other	(1.3	)	(0.7	)	(1.2	)
Effective income tax rate	29.1	%	30.9	%	30.4	%

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.

The IRS has examined our federal income tax return filed for tax year 2010 and the amended federal income tax returns we filed for tax years 2007, 2008 and 2009. The examination results, which were approved by the Joint Committee on Taxation of the U.S. Congress and accepted by the IRS in April 2013, did not have a significant impact on our consolidated statements of income or cash flows.

On September 13, 2013, the IRS and United States Treasury Department released final regulations regarding the deduction and capitalization of expenditures related to tangible property, including the tax treatment of, among other things, materials and supplies and the determination of whether expenditures with respect to tangible property are a deductible repair or must be capitalized, and re-proposed regulations regarding dispositions of property under the Modified Accelerated Cost Recovery System. The regulations are generally effective for tax years beginning on or after January 1, 2014, but may be adopted in earlier years under certain circumstances. On January 24, 2014, the IRS issued transition guidance that provides the procedures for taxpayers to change their method of accounting to comply with the regulations. We intend to adopt the guidance effective January 1, 2014. We do not expect the adoption of the regulations to have a material impact on our consolidated financial statements.

The liability for unrecognized income tax benefits increased from $1.2 million at December 31, 2012, to $1.7 million at December 31, 2013. The net increase in the liability for unrecognized income tax benefits was largely attributable to tax positions taken with respect to the capitalization of plant related expenditures. 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:



	2013			2012			2011
	(In Thousands)
Liability for unrecognized income tax benefits as of January 1	$	1,219		$	2,483		$	1,888
Additions based on tax positions related to the current year	224			373			967
Additions for tax positions of prior years	325			—			939
Reductions for tax positions of prior years	(65		)	(1,637		)	(563		)
Settlements	—			—			(748		)
Liability for unrecognized income tax benefits as of December 31	$	1,703		$	1,219		$	2,483

The liability for unrecognized income tax benefits, as disclosed above, is net of reductions to deferred tax assets for credit carryforwards of $0.3 million and $0.2 million as of December 31, 2012 and 2011, respectively. There were no reductions to deferred tax assets for credit carryforwards as of December 31, 2013. The amounts of unrecognized income tax benefits that, if recognized, would favorably impact our effective income tax rate, were $2.4 million, $2.0 million and $1.2 million (net of tax) as of December 31, 2013, 2012 and 2011, respectively.

Interest related to income tax uncertainties is classified as interest expense and accrued interest liability. During 2013 and 2012 , we did not reverse any interest expense previously recorded for income tax uncertainties. During 2011, we reversed interest expense previously recorded for income tax uncertainties of $0.2 million. As of December 31, 2013 and 2012, 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, 2013 or 2012.

As of December 31, 2013 and 2012, we had recorded $1.5 million for probable assessments of taxes other than income taxes.

In July 2013, the FASB issued new accounting guidance on presenting an unrecognized tax benefit when a net operating loss carryforward exists. An unrecognized tax benefit should be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, similar tax loss, or a tax credit carryforward. To the extent a net operating loss carryforward is not available to settle any additional income taxes that would result from the disallowance of a tax position at the reporting date; the unrecognized tax benefit should be presented in the financial statements as a liability and should not be combined with deferred tax assets. The guidance is effective for fiscal years beginning after December 15, 2013. This guidance is not expected to have a material impact on our consolidated financial results.

Compensation and Retirement Disclosure [Abstract]

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.

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Employee Benefit Plans

12 Months Ended

Dec. 31, 2013

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 retired executive officers. 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 expect to fund our post-retirement plan each year at least to a level equal to current year post-retirement expense.

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,	2013			2012			2013			2012
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	928,708		$	876,308		$	152,564		$	150,078
Service cost	21,420			19,556			2,028			2,057
Interest cost	38,520			39,576			6,007			6,298
Plan participants’ contributions	—			—			2,961			2,987
Benefits paid (a)	(36,529		)	(60,229		)	(10,968		)	(9,799		)
Actuarial (gains) losses	(128,339		)	53,497			(19,531		)	943
Benefit obligation, end of year (b)	$	823,780		$	928,708		$	133,061		$	152,564

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	547,931		$	481,077		$	106,793		$	91,858
Actual return on plan assets	68,151			67,328			17,361			10,673
Employer contributions	27,500			56,700			5,318			10,803
Plan participants’ contributions	—			—			2,830			2,845
Benefits paid (a)	(33,765		)	(57,174		)	(10,536		)	(9,386		)
Fair value of plan assets, end of year	$	609,817		$	547,931		$	121,766		$	106,793

Funded status, end of year	$	(213,963	)	$	(380,777	)	$	(11,295	)	$	(45,771	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(2,740	)	$	(2,870	)	$	(242	)	$	(298	)
Noncurrent liability	(211,223		)	(377,907		)	(11,053		)	(45,473		)
Net amount recognized	$	(213,963	)	$	(380,777	)	$	(11,295	)	$	(45,771	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	186,365		$	383,365		$	(18,890	)	$	12,436
Prior service cost	3,393			3,994			13,942			16,467
Transition obligation	—			—			—			325
Net amount recognized	$	189,758		$	387,359		$	(4,948	)	$	29,228

_______________


(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, 2013 and 2012, pension benefits include non-qualified benefit obligations of $27.0 million and $30.0 million, respectively, which are funded by a trust containing assets of $34.9 million and $43.5 million, respectively, classified as trading securities. The assets in the aforementioned trust are not included in the table above. See Notes 4 and 5, "Financial Instruments and Trading Securities" and "Financial Investments," respectively, for additional information regarding these amounts.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2013			2012			2013			2012
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	823,780		$	928,708		$	—		$	—
Fair value of plan assets	609,817			547,931			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	732,150		$	806,888		—			—
Fair value of plan assets	609,817			547,931			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	—			—			$	133,061		$	152,564
Fair value of plan assets	—			—			121,766			106,793

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	5.07		%	4.13		%	4.88		%	3.99		%
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 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 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,	2013			2012			2011			2013			2012			2011
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	21,420		$	19,556		$	16,076		$	2,028		$	2,057		$	1,803
Interest cost	38,520			39,576			40,045			6,007			6,298			6,793
Expected return on plan assets	(33,405		)	(32,283		)	(31,087		)	(6,691		)	(5,491		)	(5,002		)
Amortization of unrecognized:
Transition obligation, net	—			—			—			325			3,912			3,911
Prior service costs	601			612			1,213			2,524			2,524			2,524
Actuarial loss, net	33,914			32,778			23,659			1,125			1,503			702
Net periodic cost before regulatory adjustment	61,050			60,239			49,906			5,318			10,803			10,731
Regulatory adjustment (a)	3,693			(6,523		)	(22,098		)	2,922			23			1,344
Net periodic cost	$	64,743		$	53,716		$	27,808		$	8,240		$	10,826		$	12,075

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	(163,086	)	$	18,451		$	97,429		$	(30,201	)	$	(4,239	)	$	10,421
Amortization of actuarial (loss)	(33,914		)	(32,778		)	(23,659		)	(1,125		)	(1,503		)	(702		)
Current year prior service cost	—			—			—			—			—			4,451
Amortization of prior service costs	(601		)	(612		)	(1,213		)	(2,525		)	(2,524		)	(2,524		)
Amortization of transition obligation	—			—			—			(325		)	(3,912		)	(3,911		)
Total recognized in regulatory assets	$	(197,601	)	$	(14,939	)	$	72,557		$	(34,176	)	$	(12,178	)	$	7,735

Total recognized in net periodic cost and regulatory assets	$	(132,858	)	$	38,777		$	100,365		$	(25,936	)	$	(1,352	)	$	19,810

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost (Benefit):
Discount rate	4.13		%	4.50		%	5.35		%	3.99		%	4.25		%	5.00		%
Expected long-term return on plan assets	6.50		%	6.50		%	6.50		%	6.00		%	6.00		%	6.00		%
Compensation rate increase	4.00		%	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 2014.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss (gain)	$	19,362	$	(742	)
Prior service cost	525		2,524
Total	$	19,887	$	1,782

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,
	2013	2012
Health care cost trend rate assumed for next year	7.5%	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	2019

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	$	153	$	(136	)
Effect on post-retirement benefit obligation	2,098		(1,901		)

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.

Target allocations for our pension plan assets are about 39% to debt securities, 39% to equity securities, 12% alternative investments such as real estate securities, hedge funds and private equity investments, and the remaining 10% to a fund which provides tactical portfolio overlay by investing in debt and equity securities. 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.

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 Instruments and Trading Securities," 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 $47.4 million as of December 31, 2013, invested directly in long-term U.S. Treasury securities. We also maintain certain level 3 investments in private equity, alternative investments 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 alternative investments include collateralized debt obligations, mezzanine debt and a variety of other investments. The fair value of these investments is measured using a variety of primarily market-based models utilizing inputs such as security prices, maturity, call features, ratings and other developments related to specific securities. 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.

The following table provides the fair value of our pension plan assets and the corresponding level of hierarchy as of December 31, 2013 and 2012.



As of December 31, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	161,272	$	22,488	$	183,760
International equity	—		75,872		—		75,872
Core bonds	—		191,506		—		191,506
High-yield bonds	—		20,796		—		20,796
Emerging market bonds	—		13,113		—		13,113
Combination debt/equity fund	—		58,336		—		58,336
Alternative investments	—		—		39,171		39,171
Real estate securities	—		—		24,022		24,022
Cash equivalents	—		3,241		—		3,241
Total Assets Measured at Fair Value	$	—	$	524,136	$	85,681	$	609,817

As of December 31, 2012
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
Alternative investments	—		—		45,535		45,535
Real estate securities	—		—		20,927		20,927
Cash equivalents	—		2,852		—		2,852
Total Assets Measured at Fair Value	$	—	$	462,976	$	84,955	$	547,931

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, 2013 and 2012.



	Domestic Equity			Alternative Funds			Real Estate Securities			Total
	(In Thousands)
Balance as of December 31, 2012	$	18,493		$	45,535		$	20,927		$	84,955
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	3,845			1,936			3,307			9,088
Relating to assets sold during the period	—			826			—			826
Purchases, issuances and settlements, net	150			(9,126		)	(212		)	(9,188		)
Balance as of December 31, 2013	$	22,488		$	39,171		$	24,022		$	85,681

Balance as of December 31, 2011	$	15,375		$	40,716		$	18,848		$	74,939
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	(25		)	4,819			2,296			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		$	45,535		$	20,927		$	84,955

The following table provides the fair value of our post-retirement benefit plan assets and the corresponding level of hierarchy as of December 31, 2013 and 2012.



As of December 31, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	64,080	$	—	$	64,080
International equity	—		16,018		—		16,018
Core bonds	—		41,092		—		41,092
Cash equivalents	—		576		—		576
Total Assets Measured at Fair Value	$	—	$	121,766	$	—	$	121,766

As of December 31, 2012

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

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:
2014	$	30.8					$	2.9

Expected benefit payments:
2014	$	(35.4	)	$	(2.8	)	$	(8.7	)	$	(0.2	)
2015	(36.9		)	(2.8		)	(9.1		)	(0.2		)
2016	(39.2		)	(2.8		)	(9.3		)	(0.2		)
2017	(41.5		)	(2.7		)	(9.6		)	(0.2		)
2018	(44.5		)	(2.7		)	(9.8		)	(0.2		)
2019 - 2023	(257.9		)	(12.8		)	(49.7		)	(1.0		)

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 plan 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 $6.9 million in 2013, $7.1 million in 2012 and $7.0 million in 2011.

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, 2013, awards of approximately 4.9 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,
	2013		2012		2011
	(In Thousands)
Compensation expense	$	8,121	$	7,203	$	8,367
Income tax benefits related to stock-based compensation arrangements	3,212		2,849		3,309

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 2013 valuation, inputs for expected volatility ranged from 15.0% to 23.5% and the risk-free interest rate was approximately 0.3%. 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 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, 2013, 2012 and 2011, our RSU activity for awards with only service requirements was as follows:



	As of December 31,
	2013				2012				2011
	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	351.1		$	25.47	368.5		$	23.83	600.4		$	21.50
Granted	139.6		31.06		131.0		27.82		284.1		26.30
Vested	(125.5	)	23.22		(127.8	)	23.34		(187.3	)	23.50
Forfeited	(12.7	)	28.35		(20.6	)	24.40		(328.7	)	24.37
Nonvested balance, end of year	352.5		28.38		351.1		25.47		368.5		23.83

Total unrecognized compensation cost related to RSU awards with only service requirements was $4.4 million as of December 31, 2013. 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, 2013, 2012 and 2011, was $3.7 million, $3.7 million and $4.8 million, respectively.

During the years ended December 31, 2013, 2012 and 2011, our RSU activity for awards with performance measures was as follows:



	As of December 31,
	2013				2012				2011
	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	340.1		$	29.20	324.2		$	28.31	348.4		$	24.98
Granted	134.4		31.54		122.3		28.84		244.4		31.26
Vested	(112.5	)	28.29		(88.2	)	25.46		(119.5	)	24.12
Forfeited	(11.9	)	30.45		(18.2	)	29.00		(149.1	)	28.72
Nonvested balance, end of year	350.1		30.35		340.1		29.20		324.2		28.31

As of December 31, 2013 and 2012, total unrecognized compensation cost related to RSU awards with performance measures was $4.0 million and $3.5 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, 2013, 2012 and 2011, was $2.3 million, $3.6 million and $3.6 million, respectively.

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 551 shares of common stock for dividends in 2013, 666 shares in 2012 and 4,757 shares in 2011. Participants received common stock distributions of 3,456 shares in 2013, 1,461 shares in 2012 and 67,426 shares in 2011.

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.

Wolf Creek Employee Benefit Plans

12 Months Ended

Dec. 31, 2013

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

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,	2013			2012			2013			2012
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	176,891		$	161,396		$	11,020		$	10,129
Service cost	6,835			6,062			206			191
Interest cost	7,562			7,537			413			411
Plan participants’ contributions	—			—			696			608
Benefits paid (a)	(4,349		)	(8,569		)	(1,022		)	(988		)
Actuarial (gains) losses	(24,119		)	9,815			(1,303		)	669
Amendments	—			650			—			—
Benefit obligation, end of year	$	162,820		$	176,891		$	10,010		$	11,020

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	98,051		$	80,727		$	13		$	4
Actual return on plan assets	13,166			11,764			—			—
Employer contributions	7,624			13,887			330			389
Plan participants' contributions	—			—			696			608
Benefits paid	(4,107		)	(8,327		)	(1,022		)	(988		)
Fair value of plan assets, end of year	$	114,734		$	98,051		$	17		$	13

Funded status, end of year	$	(48,086	)	$	(78,840	)	$	(9,993	)	$	(11,007	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(237	)	$	(243	)	$	(614	)	$	(625	)
Noncurrent liability	(47,849		)	(78,597		)	(9,379		)	(10,382		)
Net amount recognized	$	(48,086	)	$	(78,840	)	$	(9,993	)	$	(11,007	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	29,203		$	64,535		$	2,076		$	3,643
Prior service cost	617			675			—			—
Transition obligation	—			—			—			1
Net amount recognized	$	29,820		$	65,210		$	2,076		$	3,644

_______________


(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.



	Pension Benefits						Post-retirement Benefits
As of December 31,	2013			2012			2013			2012
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	162,820		$	176,891		$	—		$	—
Fair value of plan assets	114,734			98,051			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	137,459		$	141,722		$	—		$	—
Fair value of plan assets	114,734			98,051			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	$	—		$	—		$	10,010		$	11,020
Fair value of plan assets	—			—			16			13

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	5.11		%	4.16		%	4.70		%	3.78		%
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,	2013			2012			2011			2013			2012			2011
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	6,835		$	6,062		$	4,957		$	206		$	191		$	165
Interest cost	7,562			7,537			7,370			413			411			458
Expected return on plan assets	(7,373		)	(6,577		)	(5,904		)	—			—			—
Amortization of unrecognized:
Transition obligation, net	—			—			52			—			57			58
Prior service costs	58			6			16			—			—			—
Actuarial loss, net	5,421			5,366			3,586			265			234			227
Net periodic cost before regulatory adjustment	12,503			12,394			10,077			884			893			908
Regulatory adjustment (a)	(641		)	(1,776		)	(2,546		)	—			—			—
Net periodic cost	$	11,862		$	10,618		$	7,531		$	884		$	893		$	908

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	(29,911	)	$	4,629		$	29,124		$	(1,303	)	$	669		$	(360	)
Amortization of actuarial loss	(5,421		)	(5,366		)	(3,586		)	(265		)	(234		)	(227		)
Current year prior service cost	—			650			—			—			—			—
Amortization of prior service cost	(58		)	(6		)	(16		)	—			—			—
Amortization of transition obligation	—			—			(52		)	—			(57		)	(58		)
Total recognized in regulatory assets	$	(35,390	)	$	(93	)	$	25,470		$	(1,568	)	$	378		$	(645	)

Total recognized in net periodic cost and regulatory assets	$	(23,528	)	$	10,525		$	33,001		$	(684	)	$	1,271		$	263

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.16		%	4.55		%	5.45		%	3.78		%	4.10		%	4.90		%
Expected long-term return on plan assets	7.50		%	7.50		%	7.50		%	—			—			—
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 2014.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss	$	2,987	$	165
Prior service cost	58		—
Total	$	3,045	$	165

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,
	2013		2012
Health care cost trend rate assumed for next year	7.5	%	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		2019

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	$	(9	)	$	9
Effect on post-retirement benefit obligation	(102		)	97

Plan Assets

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 Instruments and Trading Securities," 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, 2013 and 2012.



As of December 31, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	30,599	$	—	$	30,599
International equity	—		36,868		—		36,868
Core bonds	—		26,926		—		26,926
Real estate securities	—		5,440		5,094		10,534
Commodities	—		5,245		—		5,245
Alternative investments	—		—		4,147		4,147
Cash equivalents	—		415		—		415
Total Assets Measured at Fair Value	$	—	$	105,493	$	9,241	$	114,734

As of December 31, 2012
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

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, 2013 and 2012.




	Real Estate Securities			Alternative Investments		Total
	(In Thousands)
Balance as of December 31, 2012	$	4,541		$	3,900	$	8,441
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	553			247		800
Balance as of December 31, 2013	$	5,094		$	4,147	$	9,241

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

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:
2014	$	5.4					$	0.6

Expected benefit payments:
2014	$	(4.6	)	$	(0.2	)	$	(0.6	)	$	—
2015	(5.3		)	(0.2		)	(0.7		)	—
2016	(6.1		)	(0.2		)	(0.8		)	—
2017	(7.0		)	(0.2		)	(0.8		)	—
2018	(7.8		)	(0.2		)	(0.8		)	—
2019 - 2022	(53.0		)	(1.3		)	(4.4		)	—

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 $1.4 million in 2013, $1.3 million in 2012 and $1.3 million in 2011.

Commitments And Contingencies

12 Months Ended

Dec. 31, 2013

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." 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, 2013, was as follows.



	Committed Amount
	(In Thousands)
2014	$	258,293
2015	20,653
2016	25,762
Thereafter	7,463
Total amount committed	$	312,171

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 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 two classes of PM, NOx (a precursor to ozone), 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 one class of PM. By the end of 2014, the EPA anticipates making final attainment/nonattainment designations under this rule and expects to issue a final implementation rule. We are currently evaluating the rule and the impact it may have on our operations or consolidated financial results.

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 approximately $610.0 million of the projected capital investment associated with the environmental upgrades at La Cygne. In November 2013, the KCC issued an order allowing us to adjust our prices to include the additional investment in the La Cygne environmental upgrades and to reflect cost reductions elsewhere. The new prices are expected to increase our annual retail revenues by approximately $30.7 million. For additional information regarding our abbreviated rate review, see Note 3, "Rate Matters and Regulation." 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 2012, the EPA's Mercury and Air Toxics Standards (MATS) for power plants became effective, replacing the prior federal Clean Air Mercury Rule (CAMR) and requiring significant reductions in mercury, acid gases and other emissions. We expect to be compliant with the new standards by April 2016 as approved by KDHE. We continue to evaluate the new standards and believe that our related investment will be approximately $17.0 million.

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 retail 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. With our agreement to purchase an additional 200 MW of installed design capacity from a wind generation facility beginning in late 2016, we expect to meet the increased requirements through 2020. 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 $230.0 million. We are installing less expensive NOx reduction equipment on the other two units to satisfy other terms of the settlement. 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, we had recorded a liability of $1.6 million 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 for $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 $2.9 million in 2013, $3.2 million in 2012 and $3.2 million in 2011. We record our investment in the NDT fund at fair value, which approximated $175.6 million and $150.8 million as of December 31, 2013 and 2012, 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 $3.0 million in 2013, $3.6 million in 2012 and $3.1 million in 2011. We include these costs in fuel and purchased power expense on our consolidated statements of income. As of November 2013, a federal court of appeals ruled that the DOE must stop collecting this fee.

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 2013, the court ordered the NRC to resume its review of the DOE's application. 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 liability, property, and business interruption insurance for Wolf Creek. These policies contain certain industry standard terms, conditions and exclusions, including, but not limited to, ordinary wear and tear and war. An industry aggregate limit of $3.2 billion plus any reinsurance, indemnity or any other source recoverable by Nuclear Electric Insurance Limited (NEIL), our property and business interruption insurance provider, exists for acts of terrorism affecting Wolf Creek or any other NEIL insured plant within 12 months from the date of the first act. The $3.2 billion maximum recovery limit is not applicable, however, in the event of a "certified act of terrorism" as defined in the Terrorism Risk Insurance Act of 2002, as amended by the Terrorism Risk Insurance Program Reauthorization Act of 2007. 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 current limit of public liability, approximately $13.6 billion. This limit of liability consists of the maximum available commercial insurance of $375.0 million and the remaining $13.2 billion is provided through mandatory participation in an industry-wide retrospective assessment program. In addition, Congress could impose additional revenue-raising measures to pay claims. Under this retrospective assessment program, the owners of Wolf Creek are jointly and severally subject to an assessment of up to $127.3 million (our share is $59.8 million), payable at no more than $19.0 million (our share is $8.9 million) per incident per year per reactor. Both the total and yearly assessment is subject to an inflationary adjustment every five years with the next adjustment in 2018.

Nuclear Property and Business Interruption 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. 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 or, if certain requirements are met, including decommissioning the plant, toward a shortfall in the NDT fund. 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, we may be subject to retrospective assessments under the current policies of approximately $34.4 million (our share is $16.1 million).

Accidental Nuclear Outage Insurance

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, 2013, our share of Wolf Creek's nuclear fuel commitments was approximately $41.3 million for uranium concentrates expiring in 2017, $6.1 million for conversion expiring in 2017, $109.0 million for enrichment expiring in 2025 and $41.1 million for fabrication expiring in 2023.

As of December 31, 2013, our coal and coal transportation contract commitments under the remaining terms of the contracts were approximately $900.6 million. The contracts are for plants that we operate and expire at various times through 2021.

As of December 31, 2013, our natural gas transportation contract commitments under the remaining terms of the contracts were approximately $117.2 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 five separate wind generation facilities with installed design capacities of 715 MW expiring in 2028 through 2036. Of the 715 MW under contract, 200 MW are associated with an agreement pursuant to which a generation provider is scheduled to deliver power beginning in 2016. 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.

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, 2013, we are committed to spend approximately $33.8 million over the remaining terms of these agreements.

Asset Retirement Obligation [Abstract]

The entire disclosure for commitments and contingencies.

+ References+ Details

Asset Retirement Obligations

12 Months Ended

Dec. 31, 2013

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,
	2013			2012
	(In Thousands)
Beginning ARO	$	152,648		$	142,508
Liabilities settled	(973		)	(1,389		)
Accretion expense	9,007			8,454
Revisions in estimated cash flows	—			3,075
Ending ARO	$	160,682		$	152,648

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, 2013 and 2012, we had $114.1 million and $129.0 million, respectively, in amounts collected, but not yet spent, for removal costs classified as a regulatory liability.

Common and Preferred Stock

12 Months Ended

Dec. 31, 2013

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

Common and Preferred Stock

COMMON AND PREFERRED STOCK

Common Stock

General

In 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, 2013 and 2012, Westar Energy had issued 128.3 million shares and 126.5 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 2013 and 2012, Westar Energy issued 0.7 million shares and 0.8 million shares, respectively, through the DSPP and other stock-based plans operated under the LTISA Plan. As of December 31, 2013 and 2012, a total of 2.0 million shares and 1.5 million shares, respectively, were available under the DSPP registration statement.

Issuances

In September 2013, Westar Energy entered into two forward sale agreements with two banks. Under the terms of the agreements, the banks, as forward sellers, borrowed 8.0 million shares of Westar Energy's common stock from third parties and sold them to a group of underwriters for $31.15 per share. Pursuant to over-allotment options granted to the underwriters, the underwriters purchased in October 2013, an additional 0.9 million shares from the banks as forward sellers, increasing the total number of shares under the forward sale agreements to approximately 8.9 million. The underwriters received a commission equal to 3.5% of the sales price of all shares sold under the agreement. Westar Energy is required to settle such transactions within 24 months.

In March 2013, Westar Energy entered into a new, three-year sales agency financing agreement and master forward sale confirmation with a bank, similar to the sales agency financing agreement and master forward sale confirmation entered into in April 2010. The maximum amount that Westar Energy may offer and sell under the March 2013 master agreements is the lesser of an aggregate of $500.0 million or approximately 25.0 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. In addition, under the terms of the March 2013 sales agency financing agreement and master forward sale confirmation, 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 agent. The agent receives a commission equal to 1% of the sales price of all shares sold under the agreements. Westar Energy must settle the forward sale transactions within 18 months of the date each transaction is entered. Under the terms of March 2013 agreements and April 2010 agreements, during the year ended December 31, 2013, Westar Energy entered into transactions with respect to an aggregate of approximately 2.5 million shares of common stock and settled 1.1 million shares that had a 2012 vintage. As of December 31, 2013, 3.1 million shares could have been settled. In February 2014, Westar Energy settled 0.3 million shares with a physical settlement amount of approximately $9.2 million.

Assuming physical share settlement of the approximately 12.1 million shares associated with all forward sale transactions as of December 31, 2013, Westar Energy would have received aggregate proceeds of approximately $358.3 million based on a weighted average forward price of $29.73 per share.

The forward sale transactions are entered into at market prices; therefore, the forward sale agreements have no initial fair value. Westar Energy does not receive any proceeds from the sale of common stock under the forward sale agreements until transactions are settled. Upon settlement, Westar Energy will record the forward sale agreements within equity. Except in specified circumstances or events that would require physical share settlement, Westar Energy is able to elect to settle any forward sale transactions by means of physical share, cash or net share settlement, and is also able to elect to settle the forward sale transactions in whole, or in part, earlier than the stated maturity dates. Currently, Westar Energy anticipates settling the forward sale transactions through physical share settlement. The shares under the forward sale agreements are initially priced when the transactions are entered into and are subject to certain fixed pricing adjustments during the term of the agreements. Accordingly, assuming physical share settlement, Westar Energy's net proceeds from the forward sale transactions will represent the prices established by the forward sale agreements applicable to the time periods in which physical settlement occurs.

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

Variable Interest Entities [Abstract]

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.

+ References

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+ Details

Variable Interest Entities

12 Months Ended

Dec. 31, 2013

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

We leased railcars from an unrelated trust to transport coal to some of our power plants. We consolidated the trust as a VIE until the agreement expired in May 2013. As a result of deconsolidating the trust, property, plant and equipment of VIEs, net, and noncontrolling interests decreased $14.3 million.

We also lease railcars from another unrelated trust under an agreement that expires in November 2014. 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 railcars and lease them to us, and does not hold any other assets. We meet the requirements to be considered the primary beneficiary of this 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 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 trust that could potentially be significant if the fair value of the railcars at the end of the agreements is greater than the fixed amount. Our agreement with this trust also includes renewal options during which time we would pay a fixed amount of rent. We have the potential to receive benefits from the trust during the renewal period 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,
	2013		2012
	(In Thousands)
Assets:
Property, plant and equipment of variable interest entities, net	$	296,626	$	321,975
Regulatory assets (a)	6,792		5,810

Liabilities:
Current maturities of long-term debt of variable interest entities	$	27,479	$	25,942
Accrued interest (b)	3,472		3,948
Long-term debt of variable interest entities, net	194,802		222,743

_______________

(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, 2013

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:
2011	$	17,577
2012	17,080
2013	16,484

Future commitments:
2014	$	14,384
2015	11,980
2016	10,232
2017	8,383
2018	5,248
Thereafter	15,361
Total future commitments	$	65,588

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.

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



	As of December 31,
	2013			2012
	(In Thousands)
Vehicles	$	12,141		$	12,594
Computer equipment	1,758			1,423
Generation plant	48,346			48,346
Accumulated amortization	(10,493		)	(6,928		)
Total capital leases	$	51,752		$	55,435

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)
2014	$	6,464
2015	5,891
2016	5,179
2017	4,711
2018	4,664
Thereafter	72,135
	99,044
Amounts representing imputed interest	(44,992		)
Present value of net minimum lease payments under capital leases	54,052
Less: Current portion	3,249
Total long-term obligation under capital leases	$	50,803

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, 2013

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.



2013	First		Second		Third		Fourth
	(In Thousands, Except Per Share Amounts)

Revenues (a)	$	546,212	$	569,589	$	694,974	$	559,878
Net income (a)	53,256		69,451		135,095		43,061
Net income attributable to Westar Energy, Inc. (a)	51,144		67,188		133,125		41,062

Per Share Data (a):

Basic:
Earnings available	$	0.40	$	0.53	$	1.04	$	0.32

Diluted:
Earnings available	$	0.40	$	0.52	$	1.04	$	0.32

Cash dividend declared per common share	$	0.34	$	0.34	$	0.34	$	0.34
Market price per common share:
High	$	33.35	$	34.96	$	34.31	$	32.56
Low	$	28.59	$	30.13	$	29.79	$	29.95

_______________


(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.



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.

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, 2013

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, 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

Year ended December 31, 2013
Allowances deducted from assets for doubtful accounts	$	4,916	$	7,039	$	(7,359	)	$	4,596

_______________


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

Summary Of Significant Accounting Policies (Policy)

12 Months Ended

Dec. 31, 2013

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.

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,
	2013		2012			2011
	(Dollars In Thousands)
Borrowed funds	$	11,706	$	10,399		$	5,589
Equity funds	14,143		11,706			5,550
Total	$	25,849	$	22,105		$	11,139
Average AFUDC Rates	4.8%		5.0		%	3.6		%

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	55	to	71
Wind generating facilities	19	to	20
Transmission facilities	15	to	75
Distribution facilities	22	to	68
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,
	2013			2012
	(In Thousands)
Cash surrender value of policies	$	1,289,457		$	1,370,788
Borrowings against policies	(1,156,341		)	(1,241,343		)
Corporate-owned life insurance, net	$	133,116		$	129,445

Revenue Recognition

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,
	2013		2012		2011
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	300,863	$	282,462	$	236,180
Less: Net income attributable to noncontrolling interests	8,343		7,316		5,941
Net income attributable to Westar Energy, Inc.	292,520		275,146		230,239
Less: Preferred dividends	—		1,616		970
Net income allocated to RSUs	810		778		772
Net income allocated to common stock	$	291,710	$	272,752	$	228,497

Weighted average equivalent common shares outstanding – basic	127,462,994		126,711,869		116,890,552
Effect of dilutive securities:
RSUs	17,195		97,757		188,025
Forward sale agreements	818,505		89,160		1,211,645
Weighted average equivalent common shares outstanding – diluted (a)	128,298,694		126,898,786		118,290,222

Earnings per common share, basic	$	2.29	$	2.15	$	1.95
Earnings per common share, diluted	$	2.27	$	2.15	$	1.93

_______________


(a)	For the years ended December 31, 2013, 2012 and 2011, we had no antidilutive shares.

Supplemental Cash Flow Information



	Year Ended December 31,
	2013			2012			2011
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	148,691		$	143,564		$	145,570
Interest on financing activities of VIEs	13,892			16,214			18,167
Income taxes, net of refunds	(11		)	(4,378		)	(17,519		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	127,544			89,354			105,435
Property, plant and equipment of VIEs	(14,282		)	—			—
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	9,641			9,089			7,427
Deconsolidation of VIEs	(14,282		)	—			—
Assets acquired through capital leases	334			10,683			43,011

Summary Of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2013

Fuel Inventory and Supplies

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



	As of December 31,
	2013		2012
	(In Thousands)
Fuel inventory	$	78,368	$	94,664
Supplies	161,143		154,352
Total	$	239,511	$	249,016

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,
	2013		2012			2011
	(Dollars In Thousands)
Borrowed funds	$	11,706	$	10,399		$	5,589
Equity funds	14,143		11,706			5,550
Total	$	25,849	$	22,105		$	11,139
Average AFUDC Rates	4.8%		5.0		%	3.6		%

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	55	to	71
Wind generating facilities	19	to	20
Transmission facilities	15	to	75
Distribution facilities	22	to	68
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,
	2013			2012
	(In Thousands)
Cash surrender value of policies	$	1,289,457		$	1,370,788
Borrowings against policies	(1,156,341		)	(1,241,343		)
Corporate-owned life insurance, net	$	133,116		$	129,445

Reconciliation Of Basic And Diluted Earnings Per Share

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



	Year Ended December 31,
	2013		2012		2011
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	300,863	$	282,462	$	236,180
Less: Net income attributable to noncontrolling interests	8,343		7,316		5,941
Net income attributable to Westar Energy, Inc.	292,520		275,146		230,239
Less: Preferred dividends	—		1,616		970
Net income allocated to RSUs	810		778		772
Net income allocated to common stock	$	291,710	$	272,752	$	228,497

Weighted average equivalent common shares outstanding – basic	127,462,994		126,711,869		116,890,552
Effect of dilutive securities:
RSUs	17,195		97,757		188,025
Forward sale agreements	818,505		89,160		1,211,645
Weighted average equivalent common shares outstanding – diluted (a)	128,298,694		126,898,786		118,290,222

Earnings per common share, basic	$	2.29	$	2.15	$	1.95
Earnings per common share, diluted	$	2.27	$	2.15	$	1.93

_______________


(a)	For the years ended December 31, 2013, 2012 and 2011, we had no antidilutive shares.

Supplemental Cash Flow Information



	Year Ended December 31,
	2013			2012			2011
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	148,691		$	143,564		$	145,570
Interest on financing activities of VIEs	13,892			16,214			18,167
Income taxes, net of refunds	(11		)	(4,378		)	(17,519		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	127,544			89,354			105,435
Property, plant and equipment of VIEs	(14,282		)	—			—
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	9,641			9,089			7,427
Deconsolidation of VIEs	(14,282		)	—			—
Assets acquired through capital leases	334			10,683			43,011

Rate Matters And Regulation (Tables)

12 Months Ended

Dec. 31, 2013

Regulated Operations [Abstract]

Schedule Of Regulatory Assets And Liabilities [Table Text Block]

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



	As of December 31,
	2013		2012
	(In Thousands)
Regulatory Assets:
Deferred employee benefit costs	$	277,122	$	542,174
Amounts due from customers for future income taxes, net	163,742		169,091
Depreciation	71,047		73,672
Debt reacquisition costs	63,882		67,721
Ad valorem tax	34,492		21,812
Wolf Creek outage	29,026		14,143
Treasury yield hedges	27,594		28,573
Asset retirement obligations	23,555		22,633
Retail energy cost adjustment	22,138		4,262
Disallowed plant costs	15,964		16,106
Energy efficiency program costs	14,477		18,835
Storm costs	1,483		11,076
Other regulatory assets	10,892		12,574
Total regulatory assets	$	755,414	$	1,002,672

Regulatory Liabilities:
Removal costs	$	114,148	$	128,971
Deferred regulatory gain from sale leaseback	86,551		92,046
Nuclear decommissioning	43,272		25,937
La Cygne dismantling costs	20,505		18,093
Other post-retirement benefits costs	19,000		10,722
Retail energy cost adjustment	15,414		16,595
Kansas tax credits	11,076		10,781
Jurisdictional allowance for funds used during construction	7,893		4,457
Gain on sale of oil	4,278		6,219
Fuel supply and electricity contracts	2,635		4,387
Other regulatory liabilities	4,784		4,967
Total regulatory liabilities	$	329,556	$	323,175

Financial Instruments and Trading Securities (Tables)

12 Months Ended

Dec. 31, 2013

Financial And Derivative Instruments and Trading Securities [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, 2013				As of December 31, 2012
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In Thousands)
Fixed-rate debt	$	3,102,500	$	3,294,209	$	2,702,500	$	3,178,752
Fixed-rate debt of VIEs	221,682		241,241		247,624		275,341

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, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Nuclear Decommissioning Trust:
Domestic equity	$	—	$	49,957	$	5,817	$	55,774
International equity	—		31,816		—		31,816
Core bonds	—		18,107		—		18,107
High-yield bonds	—		12,902		—		12,902
Emerging market bonds	—		11,055		—		11,055
Other fixed income	—		4,690		—		4,690
Combination debt/equity/other fund	—		17,093		—		17,093
Alternative investments	—		—		15,675		15,675
Real estate securities	—		—		8,511		8,511
Cash equivalents	2		—		—		2
Total Nuclear Decommissioning Trust	2		145,620		30,003		175,625
Trading Securities: (a)
Domestic equity	—		18,075		—		18,075
International equity	—		4,519		—		4,519
Core bonds	—		12,166		—		12,166
Cash equivalents	166		—		—		166
Total Trading Securities	166		34,760		—		34,926
Total Assets Measured at Fair Value	$	168	$	180,380	$	30,003	$	210,551

As of December 31, 2012
Assets:
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	$	181,270	$	12,764	$	194,238

_______________


(a)	The decrease in the fair value of trading securities was due to withdrawing $15.3 million.

Reconciliations Of Assets And Liabilities At Fair Value

The following table provides reconciliations of assets and liabilities held in the NDT measured at fair value using significant level 3 inputs for the years ended December 31, 2013 and 2012.



	Domestic Equity			Alternative Investments		Real Estate Securities			Net Balance
	(In Thousands)
Balance as of December 31, 2012	$	4,899		$	—	$	7,865		$	12,764
Total realized and unrealized gains included in:
Regulatory liabilities	940			675		646			2,261
Purchases	341			15,000		287			15,628
Sales	(363		)	—		(287		)	(650		)
Balance as of December 31, 2013	$	5,817		$	15,675	$	8,511		$	30,003

Balance as of December 31, 2011	$	3,931		$	—	$	7,095		$	11,026
Total realized and unrealized gains included in:
Regulatory liabilities	90			—		770			860
Purchases	891			—		320			1,211
Sales	(13		)	—		(320		)	(333		)
Balance as of December 31, 2012	$	4,899		$	—	$	7,865		$	12,764

Unrealized Gains And Losses On Financial Statements

The following table summarizes the unrealized gains we recorded to regulatory liabilities on our consolidated financial statements during the years ended December 31, 2013 and 2012, attributed to level 3 assets and liabilities.



	Domestic Equity		Alternative Investments		Real Estate Securities		Net Balance
	(In Thousands)
Year ended December 31, 2013	$	577	$	675	$	359	$	1,611
Year ended December 31, 2012	77		—		451		528

Investments In Financial Instruments

The following table provides additional information on these investments.



	As of December 31, 2013				As of December 31, 2012				As of December 31, 2013
	Fair Value		Unfunded Commitments		Fair Value		Unfunded Commitments		Redemption Frequency	Length of Settlement
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity	$	5,817	$	2,683	$	4,899	$	1,024	(a)	(a)
Alternative investments	15,675		—		—		—		(b)	(b)
Real estate securities	8,511		—		7,865		—		Quarterly	80 days
Total Nuclear Decommissioning Trust	$	30,003	$	2,683	$	12,764	$	1,024

Trading Securities:
Domestic equity	$	18,075	$	—	$	22,470	$	—	Upon Notice	1 day
International equity	4,519		—		5,744		—		Upon Notice	1 day
Core bonds	12,166		—		15,104		—		Upon Notice	1 day
Total Trading Securities	34,760		—		43,318		—
Total	$	64,763	$	2,683	$	56,082	$	1,024

_______________

(a)


(b)	This fund has an initial lock-up period of 24 months. Redemptions are allowed, on a quarterly basis, after 24 months at the sole discretion of the fund's board of directors. A 65-day notice of redemption is required. There is a holdback on final redemptions.

Tabular disclosure of the fair value measurement of assets using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (1) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets) and gains or losses recognized in other comprehensive income (loss), and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (2) purchases, sales, issues, and settlements (each type disclosed separately); and (3) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs), by class of asset.

+ References+ Details

Cost And Fair Value Of Available-For-Sale Securities

This item represents the disclosure regarding the investments in certain entities that calculate net asset value per share that enables users to understand the nature and risks of the investments and whether the investments are probable of being sold at amounts different from net asset value per share. Such disclosure may include (1) the fair value of the investments in the major category, and a description of the significant investment strategies of the investee(s) in the major category; (2) for each major category of investment that includes investments that can never be redeemed with the investees, but the reporting entity receives distributions through the liquidation of the underlying assets of the investees, the reporting entity's estimate of the period of time over which the underlying assets are expected to be liquidated by the investees; (3) the amount of the entity's unfunded commitments related to investments in the major category; (4) a general description of the terms and conditions upon which the investor may redeem investments in the major category; (5) the circumstances in which an otherwise redeemable investment in the major category might not be redeemable; (6) for those otherwise redeemable investments that are restricted from redemption as of the reporting entity's measurement date, the entity's best estimate of when the restriction from redemption might lapse; if an estimate cannot be made, the entity shall disclose that fact and how long the restriction has been in effect; (7) any other significant restriction on the ability to sell investments in the major category at the measurement date; (8) total fair value of held for sale investments and any remaining actions required to complete the sale when the reporting entity determines that it is probable that it will sell the investments for an amount different from net asset value per share; and (9) disclosure of an entity's plans to sell and any remaining actions required to complete the sale when the entity intends to sell a group of investments, but the individual investments to be sold have not been identified.

+ References+ Details

Financial Investments (Tables)

12 Months Ended

Dec. 31, 2013

Investments [Abstract]

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, 2013 and 2012.



			Gross Unrealized
Security Type	Cost		Gain		Loss			Fair Value		Allocation
	(Dollars In Thousands)
As of December 31, 2013
Domestic equity	$	40,976	$	14,799	$	(1	)	$	55,774	32	%
International equity	26,581		5,266		(31		)	31,816		18	%
Core bonds	18,287		—		(180		)	18,107		10	%
High-yield bonds	12,275		627		—			12,902		7	%
Emerging market bonds	12,207		—		(1,152		)	11,055		6	%
Other fixed income	4,684		6		—			4,690		3	%
Combination debt/equity/other fund	14,964		2,380		(251		)	17,093		10	%
Alternative investments	15,000		675		—			15,675		9	%
Real estate securities	10,268		—		(1,757		)	8,511		5	%
Cash equivalents	2		—		—			2		<1%
Total	$	155,244	$	23,753	$	(3,372	)	$	175,625	100	%

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	%

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, 2013
Domestic equity	$	59	$	(1	)	$	—	$	—		$	59	$	(1	)
International equity	6,244		(31		)	—		—			6,244		(31		)
Core bonds	18,107		(180		)	—		—			18,107		(180		)
Emerging market bonds	11,055		(1,152		)	—		—			11,055		(1,152		)
Combination debt/equity/other funds	6,283		(251		)	—		—			6,283		(251		)
Real estate securities	—		—			8,511		(1,757		)	8,511		(1,757		)
Total	$	41,748	$	(1,615	)	$	8,511	$	(1,757	)	$	50,259	$	(3,372	)

As of December 31, 2012
Real estate securities	$	—	$	—		$	7,865	$	(2,116	)	$	7,865	$	(2,116	)

Property, Plant And Equipment (Tables)

12 Months Ended

Dec. 31, 2013

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,
	2013			2012
	(In Thousands)
Electric plant in service	$	9,753,787		$	9,389,192
Electric plant acquisition adjustment	802,318			802,318
Accumulated depreciation	(3,971,735		)	(3,791,545		)
	6,584,370			6,399,965
Construction work in progress	904,586			532,332
Nuclear fuel, net	62,960			81,468
Net property, plant and equipment	$	7,551,916		$	7,013,765

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,
	2013			2012
	(In Thousands)
Electric plant of VIEs	$	513,793		$	543,548
Accumulated depreciation of VIEs	(217,167		)	(221,573		)
Net property, plant and equipment of VIEs	$	296,626		$	321,975

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

12 Months Ended

Dec. 31, 2013

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, 2013, 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	$	334,054	$	151,674	$	280,688	368	50
JEC unit 1 (a)	July 1978	530,407		194,944		166,073		661	92
JEC unit 2 (a)	May 1980	504,508		190,660		13,138		658	92
JEC unit 3 (a)	May 1983	713,937		296,278		1,906		664	92
Wolf Creek (b)	Sept. 1985	1,596,382		773,724		144,083		547	47
State Line (c)	June 2001	110,408		48,357		305		201	40
Total		$	3,789,696	$	1,655,637	$	606,193	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, 2013

Debt Disclosure [Abstract]

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



	As of December 31,
	2013			2012
	(Dollars in Thousands)
Weighted average short-term debt outstanding during the year	$	228,352		$	298,907
Weighted daily average interest rates during the year, excluding fees	0.39		%	0.55		%

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2013

Long-term Debt, Unclassified [Abstract]

Long-term Debt Outstanding

The following table summarizes our long-term debt outstanding.



	As of December 31,
	2013			2012
	(In Thousands)
Westar Energy
First mortgage bond series:
6.00% due 2014	$	250,000		$	250,000
5.15% due 2017	125,000			125,000
8.625% due 2018	300,000			300,000
5.10% due 2020	250,000			250,000
5.95% due 2035	125,000			125,000
5.875% due 2036	150,000			150,000
4.125% due 2042	550,000			550,000
4.10% due 2043	250,000			—
4.625% due 2043	250,000			—
	2,250,000			1,750,000
Pollution control bond series:
Variable due 2032, 0.12% as of December 31, 2013; 0.32% as of December 31, 2012	45,000			45,000
Variable due 2032, 0.12% as of December 31, 2013; 0.26% as of December 31, 2012	30,500			30,500
	75,500			75,500

KGE
First mortgage bond series:
6.70% due 2019	300,000			300,000
6.15% due 2023	50,000			50,000
6.53% due 2037	175,000			175,000
6.64% due 2038	100,000			100,000
	625,000			625,000
Pollution control bond series:
Variable due 2027, 0.10% as of December 31, 2013; 0.26% as of December 31, 2012	21,940			21,940
5.30% due 2031	108,600			108,600
5.30% due 2031	18,900			18,900
4.85% due 2031	50,000			50,000
5.60% due 2031	—			50,000
6.00% due 2031	—			50,000
5.00% due 2031	50,000			50,000
Variable due 2032, 0.10% as of December 31, 2013; 0.26% as of December 31, 2012	14,500			14,500
Variable due 2032, 0.10% as of December 31, 2013; 0.26% as of December 31, 2012	10,000			10,000
	273,940			373,940

Total long-term debt	3,224,440			2,824,440
Unamortized debt discount (a)	(5,482		)	(5,169		)
Long-term debt due within one year	(250,000		)	—
Long-term debt, net	$	2,968,958		$	2,819,271

Variable Interest Entities
6.99% due 2014 (b)	316			866
5.92 % due 2019 (b)	13,243			17,630
5.647% due 2021 (b)	208,123			229,128
Total long-term debt of variable interest entities	221,682			247,624
Unamortized debt premium (a)	599			1,061
Long-term debt of variable interest entities due within one year	(27,479		)	(25,942		)
Long-term debt of variable interest entities, net	$	194,802		$	222,743

_______________

(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, 2013, are as follows.



Year	Long-term debt		Long-term debt of VIEs
	(In Thousands)
2014	$	250,000	$	27,479
2015	—		27,933
2016	—		28,309
2017	125,000		26,842
2018	300,000		28,538
Thereafter	2,549,440		82,581
Total maturities	$	3,224,440	$	221,682

Income Tax Expense Components

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.

+ References

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

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-SubTopic 10

-Section S99

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-Subparagraph (SX 210.4-08.(e),(f))

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

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-Name Regulation S-X (SX)

-Number 210

-Section 02

-Paragraph 22

-Article 5

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

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-Name Accounting Standards Codification

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-Paragraph 1

-Subparagraph (SX 210.5-02.22)

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-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

+ Details

Taxes (Tables)

12 Months Ended

Dec. 31, 2013

Income Tax Disclosure [Abstract]

Income tax expense is comprised of the following components.



	Year Ended December 31,
	2013			2012			2011
	(In Thousands)
Income Tax Expense (Benefit):
Current income taxes:
Federal	$	135		$	(691	)	$	(8,575	)
State	279			579			196
Deferred income taxes:
Federal	102,030			102,960			93,089
State	24,443			26,300			21,337
Investment tax credit amortization	(3,166		)	(3,012		)	(2,703		)
Income tax expense	$	123,721		$	126,136		$	103,344

Deferred Tax Assets and Liabilities

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,
	2013		2012
	(In Thousands)
Deferred tax assets:
Tax credit carryforward (a)	$	212,635	$	199,160
Net operating loss carryforward (b)	110,588		111,869
Deferred employee benefit costs	85,720		191,997
Deferred state income taxes	57,243		55,577
Deferred regulatory gain on sale-leaseback	38,124		40,543
Alternative minimum tax carryforward (c)	35,666		36,471
Deferred compensation	30,022		28,319
Accrued liabilities	17,396		15,969
Disallowed costs	11,453		12,083
LaCygne dismantling cost	8,110		7,156
Capital loss carryforward (d)	3,447		11,509
Other	20,058		13,741
Total gross deferred tax assets	630,462		724,394
Less: Valuation allowance (e)	3,504		13,812
Deferred tax assets	$	626,958	$	710,582

Deferred tax liabilities:
Accelerated depreciation	$	1,390,669	$	1,255,892
Acquisition premium	171,907		179,920
Amounts due from customers for future income taxes, net	163,742		169,091
Deferred employee benefit costs	85,720		191,997
Deferred state income taxes	51,504		50,134
Pension expense tracker	21,230		22,437
Storm costs	21,165		4,373
Debt reacquisition costs	19,985		22,313
Other	24,527		20,916
Total deferred tax liabilities	$	1,950,449	$	1,917,073

Net deferred tax liabilities	$	1,323,491	$	1,206,491

_______________

(a)


(b)	As of December 31, 2013, we had a federal net operating loss carryforward of $277.6 million, which is available to offset federal taxable income. The net operating losses will expire beginning in 2031 and ending in 2032.


(c)	As of December 31, 2013, we had available an alternative minimum tax credit carryforward of $35.7 million, which has an unlimited carryforward period.


(d)	As of December 31, 2013, we had an unused capital loss carryforward of $8.7 million that is available to offset future capital gains. The capital losses will expire in 2016.


(e)	As we do not expect to realize any significant capital gains in the future, we have established a valuation allowance of $3.5 million. The total valuation allowance related to the deferred tax assets was $3.5 million as of December 31, 2013, and $13.8 million as of December 31, 2012.

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



	As of December 31,
	2013		2012
	(In Thousands)
Current deferred tax assets	$	37,927	$	—
Other current liabilities	—		8,654
Non-current deferred tax liabilities	1,361,418		1,197,837
Net deferred tax liabilities	$	1,323,491	$	1,206,491

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,
	2013		2012		2011
Statutory federal income tax rate	35.0	%	35.0	%	35.0	%
Effect of:
Corporate-owned life insurance policies	(5.4	)	(4.9	)	(4.5	)
State income taxes	3.8		4.3		4.1
Production tax credits	(2.3	)	(2.4	)	(2.9	)
Flow through depreciation for plant-related differences	2.2		1.4		1.8
AFUDC equity	(1.2	)	(1.0	)	(0.6	)
Capital loss utilization carryforward	(1.1	)	(0.3	)	(0.5	)
Amortization of federal investment tax credits	(0.7	)	(0.7	)	(0.8	)
Liability for unrecognized income tax benefits	0.1		0.2		—
Other	(1.3	)	(0.7	)	(1.2	)
Effective income tax rate	29.1	%	30.9	%	30.4	%

Unrecognized Income Tax Benefits Reconciliation

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



	2013			2012			2011
	(In Thousands)
Liability for unrecognized income tax benefits as of January 1	$	1,219		$	2,483		$	1,888
Additions based on tax positions related to the current year	224			373			967
Additions for tax positions of prior years	325			—			939
Reductions for tax positions of prior years	(65		)	(1,637		)	(563		)
Settlements	—			—			(748		)
Liability for unrecognized income tax benefits as of December 31	$	1,703		$	1,219		$	2,483

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, 2013

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,	2013			2012			2013			2012
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	928,708		$	876,308		$	152,564		$	150,078
Service cost	21,420			19,556			2,028			2,057
Interest cost	38,520			39,576			6,007			6,298
Plan participants’ contributions	—			—			2,961			2,987
Benefits paid (a)	(36,529		)	(60,229		)	(10,968		)	(9,799		)
Actuarial (gains) losses	(128,339		)	53,497			(19,531		)	943
Benefit obligation, end of year (b)	$	823,780		$	928,708		$	133,061		$	152,564

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	547,931		$	481,077		$	106,793		$	91,858
Actual return on plan assets	68,151			67,328			17,361			10,673
Employer contributions	27,500			56,700			5,318			10,803
Plan participants’ contributions	—			—			2,830			2,845
Benefits paid (a)	(33,765		)	(57,174		)	(10,536		)	(9,386		)
Fair value of plan assets, end of year	$	609,817		$	547,931		$	121,766		$	106,793

Funded status, end of year	$	(213,963	)	$	(380,777	)	$	(11,295	)	$	(45,771	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(2,740	)	$	(2,870	)	$	(242	)	$	(298	)
Noncurrent liability	(211,223		)	(377,907		)	(11,053		)	(45,473		)
Net amount recognized	$	(213,963	)	$	(380,777	)	$	(11,295	)	$	(45,771	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	186,365		$	383,365		$	(18,890	)	$	12,436
Prior service cost	3,393			3,994			13,942			16,467
Transition obligation	—			—			—			325
Net amount recognized	$	189,758		$	387,359		$	(4,948	)	$	29,228

_______________


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

(b)

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,	2013			2012			2013			2012
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	823,780		$	928,708		$	—		$	—
Fair value of plan assets	609,817			547,931			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	732,150		$	806,888		—			—
Fair value of plan assets	609,817			547,931			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	—			—			$	133,061		$	152,564
Fair value of plan assets	—			—			121,766			106,793

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	5.07		%	4.13		%	4.88		%	3.99		%
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,	2013			2012			2011			2013			2012			2011
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	21,420		$	19,556		$	16,076		$	2,028		$	2,057		$	1,803
Interest cost	38,520			39,576			40,045			6,007			6,298			6,793
Expected return on plan assets	(33,405		)	(32,283		)	(31,087		)	(6,691		)	(5,491		)	(5,002		)
Amortization of unrecognized:
Transition obligation, net	—			—			—			325			3,912			3,911
Prior service costs	601			612			1,213			2,524			2,524			2,524
Actuarial loss, net	33,914			32,778			23,659			1,125			1,503			702
Net periodic cost before regulatory adjustment	61,050			60,239			49,906			5,318			10,803			10,731
Regulatory adjustment (a)	3,693			(6,523		)	(22,098		)	2,922			23			1,344
Net periodic cost	$	64,743		$	53,716		$	27,808		$	8,240		$	10,826		$	12,075

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	(163,086	)	$	18,451		$	97,429		$	(30,201	)	$	(4,239	)	$	10,421
Amortization of actuarial (loss)	(33,914		)	(32,778		)	(23,659		)	(1,125		)	(1,503		)	(702		)
Current year prior service cost	—			—			—			—			—			4,451
Amortization of prior service costs	(601		)	(612		)	(1,213		)	(2,525		)	(2,524		)	(2,524		)
Amortization of transition obligation	—			—			—			(325		)	(3,912		)	(3,911		)
Total recognized in regulatory assets	$	(197,601	)	$	(14,939	)	$	72,557		$	(34,176	)	$	(12,178	)	$	7,735

Total recognized in net periodic cost and regulatory assets	$	(132,858	)	$	38,777		$	100,365		$	(25,936	)	$	(1,352	)	$	19,810

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost (Benefit):
Discount rate	4.13		%	4.50		%	5.35		%	3.99		%	4.25		%	5.00		%
Expected long-term return on plan assets	6.50		%	6.50		%	6.50		%	6.00		%	6.00		%	6.00		%
Compensation rate increase	4.00		%	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 2014.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss (gain)	$	19,362	$	(742	)
Prior service cost	525		2,524
Total	$	19,887	$	1,782

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,
	2013	2012
Health care cost trend rate assumed for next year	7.5%	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	2019

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	$	153	$	(136	)
Effect on post-retirement benefit obligation	2,098		(1,901		)

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, 2013 and 2012.



	Domestic Equity			Alternative Funds			Real Estate Securities			Total
	(In Thousands)
Balance as of December 31, 2012	$	18,493		$	45,535		$	20,927		$	84,955
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	3,845			1,936			3,307			9,088
Relating to assets sold during the period	—			826			—			826
Purchases, issuances and settlements, net	150			(9,126		)	(212		)	(9,188		)
Balance as of December 31, 2013	$	22,488		$	39,171		$	24,022		$	85,681

Balance as of December 31, 2011	$	15,375		$	40,716		$	18,848		$	74,939
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	(25		)	4,819			2,296			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		$	45,535		$	20,927		$	84,955

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:
2014	$	30.8					$	2.9

Expected benefit payments:
2014	$	(35.4	)	$	(2.8	)	$	(8.7	)	$	(0.2	)
2015	(36.9		)	(2.8		)	(9.1		)	(0.2		)
2016	(39.2		)	(2.8		)	(9.3		)	(0.2		)
2017	(41.5		)	(2.7		)	(9.6		)	(0.2		)
2018	(44.5		)	(2.7		)	(9.8		)	(0.2		)
2019 - 2023	(257.9		)	(12.8		)	(49.7		)	(1.0		)

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,
	2013		2012		2011
	(In Thousands)
Compensation expense	$	8,121	$	7,203	$	8,367
Income tax benefits related to stock-based compensation arrangements	3,212		2,849		3,309

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, 2013 and 2012.



As of December 31, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	64,080	$	—	$	64,080
International equity	—		16,018		—		16,018
Core bonds	—		41,092		—		41,092
Cash equivalents	—		576		—		576
Total Assets Measured at Fair Value	$	—	$	121,766	$	—	$	121,766

As of December 31, 2012

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

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, 2013 and 2012.



As of December 31, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	161,272	$	22,488	$	183,760
International equity	—		75,872		—		75,872
Core bonds	—		191,506		—		191,506
High-yield bonds	—		20,796		—		20,796
Emerging market bonds	—		13,113		—		13,113
Combination debt/equity fund	—		58,336		—		58,336
Alternative investments	—		—		39,171		39,171
Real estate securities	—		—		24,022		24,022
Cash equivalents	—		3,241		—		3,241
Total Assets Measured at Fair Value	$	—	$	524,136	$	85,681	$	609,817

As of December 31, 2012
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
Alternative investments	—		—		45,535		45,535
Real estate securities	—		—		20,927		20,927
Cash equivalents	—		2,852		—		2,852
Total Assets Measured at Fair Value	$	—	$	462,976	$	84,955	$	547,931

RSU Awards With Performance Measures [Member]

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

During the years ended December 31, 2013, 2012 and 2011, our RSU activity for awards with performance measures was as follows:



	As of December 31,
	2013				2012				2011
	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	340.1		$	29.20	324.2		$	28.31	348.4		$	24.98
Granted	134.4		31.54		122.3		28.84		244.4		31.26
Vested	(112.5	)	28.29		(88.2	)	25.46		(119.5	)	24.12
Forfeited	(11.9	)	30.45		(18.2	)	29.00		(149.1	)	28.72
Nonvested balance, end of year	350.1		30.35		340.1		29.20		324.2		28.31

RSU Awards With Only Service Requirements [Member]

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

During the years ended December 31, 2013, 2012 and 2011, our RSU activity for awards with only service requirements was as follows:



	As of December 31,
	2013				2012				2011
	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	351.1		$	25.47	368.5		$	23.83	600.4		$	21.50
Granted	139.6		31.06		131.0		27.82		284.1		26.30
Vested	(125.5	)	23.22		(127.8	)	23.34		(187.3	)	23.50
Forfeited	(12.7	)	28.35		(20.6	)	24.40		(328.7	)	24.37
Nonvested balance, end of year	352.5		28.38		351.1		25.47		368.5		23.83

Wolf Creek Employee Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2013

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,	2013			2012			2013			2012
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	928,708		$	876,308		$	152,564		$	150,078
Service cost	21,420			19,556			2,028			2,057
Interest cost	38,520			39,576			6,007			6,298
Plan participants’ contributions	—			—			2,961			2,987
Benefits paid (a)	(36,529		)	(60,229		)	(10,968		)	(9,799		)
Actuarial (gains) losses	(128,339		)	53,497			(19,531		)	943
Benefit obligation, end of year (b)	$	823,780		$	928,708		$	133,061		$	152,564

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	547,931		$	481,077		$	106,793		$	91,858
Actual return on plan assets	68,151			67,328			17,361			10,673
Employer contributions	27,500			56,700			5,318			10,803
Plan participants’ contributions	—			—			2,830			2,845
Benefits paid (a)	(33,765		)	(57,174		)	(10,536		)	(9,386		)
Fair value of plan assets, end of year	$	609,817		$	547,931		$	121,766		$	106,793

Funded status, end of year	$	(213,963	)	$	(380,777	)	$	(11,295	)	$	(45,771	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(2,740	)	$	(2,870	)	$	(242	)	$	(298	)
Noncurrent liability	(211,223		)	(377,907		)	(11,053		)	(45,473		)
Net amount recognized	$	(213,963	)	$	(380,777	)	$	(11,295	)	$	(45,771	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	186,365		$	383,365		$	(18,890	)	$	12,436
Prior service cost	3,393			3,994			13,942			16,467
Transition obligation	—			—			—			325
Net amount recognized	$	189,758		$	387,359		$	(4,948	)	$	29,228

_______________


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

(b)

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,	2013			2012			2013			2012
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	823,780		$	928,708		$	—		$	—
Fair value of plan assets	609,817			547,931			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	732,150		$	806,888		—			—
Fair value of plan assets	609,817			547,931			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	—			—			$	133,061		$	152,564
Fair value of plan assets	—			—			121,766			106,793

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	5.07		%	4.13		%	4.88		%	3.99		%
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,	2013			2012			2011			2013			2012			2011
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	21,420		$	19,556		$	16,076		$	2,028		$	2,057		$	1,803
Interest cost	38,520			39,576			40,045			6,007			6,298			6,793
Expected return on plan assets	(33,405		)	(32,283		)	(31,087		)	(6,691		)	(5,491		)	(5,002		)
Amortization of unrecognized:
Transition obligation, net	—			—			—			325			3,912			3,911
Prior service costs	601			612			1,213			2,524			2,524			2,524
Actuarial loss, net	33,914			32,778			23,659			1,125			1,503			702
Net periodic cost before regulatory adjustment	61,050			60,239			49,906			5,318			10,803			10,731
Regulatory adjustment (a)	3,693			(6,523		)	(22,098		)	2,922			23			1,344
Net periodic cost	$	64,743		$	53,716		$	27,808		$	8,240		$	10,826		$	12,075

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	(163,086	)	$	18,451		$	97,429		$	(30,201	)	$	(4,239	)	$	10,421
Amortization of actuarial (loss)	(33,914		)	(32,778		)	(23,659		)	(1,125		)	(1,503		)	(702		)
Current year prior service cost	—			—			—			—			—			4,451
Amortization of prior service costs	(601		)	(612		)	(1,213		)	(2,525		)	(2,524		)	(2,524		)
Amortization of transition obligation	—			—			—			(325		)	(3,912		)	(3,911		)
Total recognized in regulatory assets	$	(197,601	)	$	(14,939	)	$	72,557		$	(34,176	)	$	(12,178	)	$	7,735

Total recognized in net periodic cost and regulatory assets	$	(132,858	)	$	38,777		$	100,365		$	(25,936	)	$	(1,352	)	$	19,810

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost (Benefit):
Discount rate	4.13		%	4.50		%	5.35		%	3.99		%	4.25		%	5.00		%
Expected long-term return on plan assets	6.50		%	6.50		%	6.50		%	6.00		%	6.00		%	6.00		%
Compensation rate increase	4.00		%	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 2014.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss (gain)	$	19,362	$	(742	)
Prior service cost	525		2,524
Total	$	19,887	$	1,782

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,
	2013	2012
Health care cost trend rate assumed for next year	7.5%	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	2019

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	$	153	$	(136	)
Effect on post-retirement benefit obligation	2,098		(1,901		)

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, 2013 and 2012.



	Domestic Equity			Alternative Funds			Real Estate Securities			Total
	(In Thousands)
Balance as of December 31, 2012	$	18,493		$	45,535		$	20,927		$	84,955
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	3,845			1,936			3,307			9,088
Relating to assets sold during the period	—			826			—			826
Purchases, issuances and settlements, net	150			(9,126		)	(212		)	(9,188		)
Balance as of December 31, 2013	$	22,488		$	39,171		$	24,022		$	85,681

Balance as of December 31, 2011	$	15,375		$	40,716		$	18,848		$	74,939
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	(25		)	4,819			2,296			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		$	45,535		$	20,927		$	84,955

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:
2014	$	30.8					$	2.9

Expected benefit payments:
2014	$	(35.4	)	$	(2.8	)	$	(8.7	)	$	(0.2	)
2015	(36.9		)	(2.8		)	(9.1		)	(0.2		)
2016	(39.2		)	(2.8		)	(9.3		)	(0.2		)
2017	(41.5		)	(2.7		)	(9.6		)	(0.2		)
2018	(44.5		)	(2.7		)	(9.8		)	(0.2		)
2019 - 2023	(257.9		)	(12.8		)	(49.7		)	(1.0		)

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,	2013			2012			2013			2012
	(In Thousands)
Change in Benefit Obligation:
Benefit obligation, beginning of year	$	176,891		$	161,396		$	11,020		$	10,129
Service cost	6,835			6,062			206			191
Interest cost	7,562			7,537			413			411
Plan participants’ contributions	—			—			696			608
Benefits paid (a)	(4,349		)	(8,569		)	(1,022		)	(988		)
Actuarial (gains) losses	(24,119		)	9,815			(1,303		)	669
Amendments	—			650			—			—
Benefit obligation, end of year	$	162,820		$	176,891		$	10,010		$	11,020

Change in Plan Assets:
Fair value of plan assets, beginning of year	$	98,051		$	80,727		$	13		$	4
Actual return on plan assets	13,166			11,764			—			—
Employer contributions	7,624			13,887			330			389
Plan participants' contributions	—			—			696			608
Benefits paid	(4,107		)	(8,327		)	(1,022		)	(988		)
Fair value of plan assets, end of year	$	114,734		$	98,051		$	17		$	13

Funded status, end of year	$	(48,086	)	$	(78,840	)	$	(9,993	)	$	(11,007	)

Amounts Recognized in the Balance Sheets Consist of:
Current liability	$	(237	)	$	(243	)	$	(614	)	$	(625	)
Noncurrent liability	(47,849		)	(78,597		)	(9,379		)	(10,382		)
Net amount recognized	$	(48,086	)	$	(78,840	)	$	(9,993	)	$	(11,007	)

Amounts Recognized in Regulatory Assets Consist of:
Net actuarial loss	$	29,203		$	64,535		$	2,076		$	3,643
Prior service cost	617			675			—			—
Transition obligation	—			—			—			1
Net amount recognized	$	29,820		$	65,210		$	2,076		$	3,644

_______________


(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.

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,	2013			2012			2013			2012
	(Dollars in Thousands)
Pension Plans With a Projected Benefit Obligation In Excess of Plan Assets:
Projected benefit obligation	$	162,820		$	176,891		$	—		$	—
Fair value of plan assets	114,734			98,051			—			—

Pension Plans With an Accumulated Benefit Obligation In Excess of Plan Assets:
Accumulated benefit obligation	$	137,459		$	141,722		$	—		$	—
Fair value of plan assets	114,734			98,051			—			—

Post-retirement Plans With an Accumulated Post-retirement Benefit Obligation In Excess of Plan Assets:
Accumulated post-retirement benefit obligation	$	—		$	—		$	10,010		$	11,020
Fair value of plan assets	—			—			16			13

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Benefit Obligation:
Discount rate	5.11		%	4.16		%	4.70		%	3.78		%
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,	2013			2012			2011			2013			2012			2011
	(Dollars in Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	6,835		$	6,062		$	4,957		$	206		$	191		$	165
Interest cost	7,562			7,537			7,370			413			411			458
Expected return on plan assets	(7,373		)	(6,577		)	(5,904		)	—			—			—
Amortization of unrecognized:
Transition obligation, net	—			—			52			—			57			58
Prior service costs	58			6			16			—			—			—
Actuarial loss, net	5,421			5,366			3,586			265			234			227
Net periodic cost before regulatory adjustment	12,503			12,394			10,077			884			893			908
Regulatory adjustment (a)	(641		)	(1,776		)	(2,546		)	—			—			—
Net periodic cost	$	11,862		$	10,618		$	7,531		$	884		$	893		$	908

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:
Current year actuarial (gain)/loss	$	(29,911	)	$	4,629		$	29,124		$	(1,303	)	$	669		$	(360	)
Amortization of actuarial loss	(5,421		)	(5,366		)	(3,586		)	(265		)	(234		)	(227		)
Current year prior service cost	—			650			—			—			—			—
Amortization of prior service cost	(58		)	(6		)	(16		)	—			—			—
Amortization of transition obligation	—			—			(52		)	—			(57		)	(58		)
Total recognized in regulatory assets	$	(35,390	)	$	(93	)	$	25,470		$	(1,568	)	$	378		$	(645	)

Total recognized in net periodic cost and regulatory assets	$	(23,528	)	$	10,525		$	33,001		$	(684	)	$	1,271		$	263

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:
Discount rate	4.16		%	4.55		%	5.45		%	3.78		%	4.10		%	4.90		%
Expected long-term return on plan assets	7.50		%	7.50		%	7.50		%	—			—			—
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 2014.



	Pension Benefits		Post-retirement Benefits
	(In Thousands)
Actuarial loss	$	2,987	$	165
Prior service cost	58		—
Total	$	3,045	$	165

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,
	2013		2012
Health care cost trend rate assumed for next year	7.5	%	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		2019

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	$	(9	)	$	9
Effect on post-retirement benefit obligation	(102		)	97

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, 2013 and 2012.



As of December 31, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Assets:
Domestic equity	$	—	$	30,599	$	—	$	30,599
International equity	—		36,868		—		36,868
Core bonds	—		26,926		—		26,926
Real estate securities	—		5,440		5,094		10,534
Commodities	—		5,245		—		5,245
Alternative investments	—		—		4,147		4,147
Cash equivalents	—		415		—		415
Total Assets Measured at Fair Value	$	—	$	105,493	$	9,241	$	114,734

As of December 31, 2012
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

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




	Real Estate Securities			Alternative Investments		Total
	(In Thousands)
Balance as of December 31, 2012	$	4,541		$	3,900	$	8,441
Actual gain (loss) on plan assets:
Relating to assets still held at the reporting date	553			247		800
Balance as of December 31, 2013	$	5,094		$	4,147	$	9,241

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

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:
2014	$	5.4					$	0.6

Expected benefit payments:
2014	$	(4.6	)	$	(0.2	)	$	(0.6	)	$	—
2015	(5.3		)	(0.2		)	(0.7		)	—
2016	(6.1		)	(0.2		)	(0.8		)	—
2017	(7.0		)	(0.2		)	(0.8		)	—
2018	(7.8		)	(0.2		)	(0.8		)	—
2019 - 2022	(53.0		)	(1.3		)	(4.4		)	—

Variable Interest Entities (Tables)

12 Months Ended

Dec. 31, 2013

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,
	2013		2012
	(In Thousands)
Assets:
Property, plant and equipment of variable interest entities, net	$	296,626	$	321,975
Regulatory assets (a)	6,792		5,810

Liabilities:
Current maturities of long-term debt of variable interest entities	$	27,479	$	25,942
Accrued interest (b)	3,472		3,948
Long-term debt of variable interest entities, net	194,802		222,743

_______________

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

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

Operating Leases, Minimum Annual Rental Payments

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.

+ References+ Details

Leases (Tables)

12 Months Ended

Dec. 31, 2013

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:
2011	$	17,577
2012	17,080
2013	16,484

Future commitments:
2014	$	14,384
2015	11,980
2016	10,232
2017	8,383
2018	5,248
Thereafter	15,361
Total future commitments	$	65,588

Assets Recorded Under Capital Leases

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



	As of December 31,
	2013			2012
	(In Thousands)
Vehicles	$	12,141		$	12,594
Computer equipment	1,758			1,423
Generation plant	48,346			48,346
Accumulated amortization	(10,493		)	(6,928		)
Total capital leases	$	51,752		$	55,435

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)
2014	$	6,464
2015	5,891
2016	5,179
2017	4,711
2018	4,664
Thereafter	72,135
	99,044
Amounts representing imputed interest	(44,992		)
Present value of net minimum lease payments under capital leases	54,052
Less: Current portion	3,249
Total long-term obligation under capital leases	$	50,803

Quarterly Results (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2013

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.



2013	First		Second		Third		Fourth
	(In Thousands, Except Per Share Amounts)

Revenues (a)	$	546,212	$	569,589	$	694,974	$	559,878
Net income (a)	53,256		69,451		135,095		43,061
Net income attributable to Westar Energy, Inc. (a)	51,144		67,188		133,125		41,062

Per Share Data (a):

Basic:
Earnings available	$	0.40	$	0.53	$	1.04	$	0.32

Diluted:
Earnings available	$	0.40	$	0.52	$	1.04	$	0.32

Cash dividend declared per common share	$	0.34	$	0.34	$	0.34	$	0.34
Market price per common share:
High	$	33.35	$	34.96	$	34.31	$	32.56
Low	$	28.59	$	30.13	$	29.79	$	29.95

_______________


(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.



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 yea

Summary Of Significant Accounting Policies (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Nov. 01, 2013	Oct. 31, 2012	Oct. 27, 2011
Property, Plant and Equipment [Line Items]
Estimated Increase In Annual Retail Revenues For Energy Efficiency Costs				$ 1,300,000	$ 1,100,000	$ 4,900,000
Average annual composite basis group depreciation rates	2.50%	2.60%	3.00%
Unbilled revenue	60,100,000	62,500,000
Gain on sale of non-utility investment	0	0	(7,246,000)
Nuclear Fuel [Member]
Property, Plant and Equipment [Line Items]
Accumulated amortization	46,200,000	69,200,000
Nuclear fuel charged to fuel and purchased power expense	$ 26,500,000	$ 28,300,000	$ 24,600,000

Summary Of Significant Accounting Policies (Fuel Inventory And Supplies) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Public Utilities, Inventory [Line Items]
Total	$ 239,511	$ 249,016
Fuel Inventory [Member]
Public Utilities, Inventory [Line Items]
Public Utilitiy Inventory	78,368	94,664
Supplies [Member]
Public Utilities, Inventory [Line Items]
Public Utilitiy Inventory	$ 161,143	$ 154,352

Summary Of Significant Accounting Policies (Allowance For Funds Used During Construction) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accounting Policies [Abstract]
Public Utilities, Allowance for Funds Used During Construction, Additions	$ 25,849	$ 22,105	$ 11,139
Allowance for Funds Used During Construction, Capitalized Interest	$ 11,706	$ 10,399	$ 5,589
Average AFUDC rates	4.80%	5.00%	3.60%

Summary Of Significant Accounting Policies (Depreciable Lives of PP&E) (Details)	12 Months Ended
	Dec. 31, 2013
Minimum [Member]
Depreciable Lives [Line Items]
Transmission facilities, estimated useful life	15 years
Distribution facilities, estimated useful life	22 years
Other property, plant and equipment, estimated useful life	5 years
Maximum [Member]
Depreciable Lives [Line Items]
Transmission facilities, estimated useful life	75 years
Distribution facilities, estimated useful life	68 years
Other property, plant and equipment, estimated useful life	30 years
Fossil Fuel Plant [Member] \| Minimum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	6 years
Fossil Fuel Plant [Member] \| Maximum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	78 years
Nuclear Plant [Member] \| Minimum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	55 years
Nuclear Plant [Member] \| Maximum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	71 years
Other Plant in Service [Member] \| Minimum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	19 years
Other Plant in Service [Member] \| Maximum [Member]
Depreciable Lives [Line Items]
Generating facilities, estimated useful life	20 years

Summary Of Significant Accounting Policies (Cash Surrender Value of Life Insurance) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Accounting Policies [Abstract]
Cash surrender value of policies	$ 1,289,457	$ 1,370,788
Borrowings against policies	(1,156,341)	(1,241,343)
Corporate-owned life insurance, net	$ 133,116	$ 129,445

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, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Less: Net income attributable to noncontrolling interests

Net income

$ 300,863

$ 282,462

$ 236,180

8,343

7,316

5,941

Net income attributable to Westar Energy, Inc.

292,520

275,146

230,239

Less: Preferred dividends

1,616

970

Net income allocated to RSUs

810

778

772

Net income allocated to common stock

$ 291,710

$ 272,752

$ 228,497

Weighted average equivalent common shares outstanding - basic

127,462,994

126,711,869

116,890,552

RSUs

17,195

97,757

188,025

Forward sale agreements

818,505

89,160

1,211,645

Weighted average equivalent common shares outstanding - diluted

128,298,694

^[1]

126,898,786

^[1]

118,290,222

^[1]

Basic earnings per common share

$ 0.32

^[2]

$ 1.04

^[2]

$ 0.53

^[2]

$ 0.40

^[2]

$ 0.36

^[2]

$ 1.10

^[2]

$ 0.48

^[2]

$ 0.21

^[2]

$ 2.29

$ 2.15

$ 1.95

Diluted earnings per common share

$ 0.32

^[2]

$ 1.04

^[2]

$ 0.52

^[2]

$ 0.40

^[2]

$ 0.36

^[2]

$ 1.09

^[2]

$ 0.48

^[2]

$ 0.21

^[2]

$ 2.27

$ 2.15

$ 1.93

Antidilutive shares

[1]	(a)For the years ended December 31, 2013, 2012 and 2011, we had no antidilutive shares.
[2]	(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, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash Paid For (Received From)
Interest on financing activities	$ 148,691	$ 143,564	$ 145,570
Income taxes, net of refunds	(11)	(4,378)	(17,519)
Noncash Investing and Financing Transactions
Property, plant and equipment additions	127,544	89,354	105,435
Issuance of common stock for reinvested dividends and compensation plans	9,641	9,089	7,427
Assets acquired through capital leases	334	10,683	43,011
Variable Interest Entity, Primary Beneficiary [Member]
Cash Paid For (Received From)
Interest on financing activities	13,892	16,214	18,167
Noncash Investing and Financing Transactions
Property, plant and equipment additions	(14,282)	0	0
Debt of VIEs	$ (14,282)	$ 0	$ 0

Rate Matters And Regulation (Regulatory Assets and Liabilities) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		$ 755,414,000	$ 1,002,672,000
Regulatory Liabilities		329,556,000	323,175,000
Removal Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		114,148,000	128,971,000
Deferred Regulatory Gain From Sale Leaseback [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		86,551,000	92,046,000
Nuclear Decommissioning [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		43,272,000	25,937,000
La Cygne Dismantling Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		20,505,000	18,093,000
Retail Energy Cost Adjustment [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		15,414,000	16,595,000
Kansas Tax Credits [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		11,076,000	10,781,000
jurisdictional allowance for funds used during construction [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		7,893,000	4,457,000
Gain on Sale of Oil [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		4,278,000	6,219,000
Other Post-retirement Benefit Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		19,000,000	10,722,000
Fuel Supply and Electricity Contracts [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		2,635,000	4,387,000
Other Regulatory Liabilities [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities		4,784,000	4,967,000
Other Pension Plans, Postretirement or Supplemental Plans, Defined Benefit [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		223,500,000
Pension Cost [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		53,700,000
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		277,122,000	542,174,000
Deferred Employee Benefit Costs Amortization Expense, Next Twelve Months	24,900,000
Amounts Due From Customers For Future Income Taxes, Net [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		163,742,000	169,091,000
Depreciation [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		71,047,000	73,672,000
Debt Reacquisition Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		63,882,000	67,721,000
Asset Retirement Obligation [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		23,555,000	22,633,000
Ad Valorem Tax [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		34,492,000	21,812,000
Energy Efficiency Program Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		14,477,000	18,835,000
Disallowed Plant Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		15,964,000	16,106,000
Wolf Creek Outage [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		29,026,000	14,143,000
Cash Flow Hedging [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		27,594,000	28,573,000
Storm Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		1,483,000	11,076,000
Retail Energy Cost Adjustment [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		22,138,000	4,262,000
Other Regulatory Assets [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets		10,892,000	12,574,000
Cash Flow Hedging [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets			$ 28,600,000

Rate Matters And Regulation (Narrative) (Details) (USD $)	12 Months Ended															12 Months Ended			12 Months Ended		12 Months Ended		12 Months Ended			12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Nov. 01, 2013	Jun. 30, 2013	Mar. 01, 2013	Jan. 31, 2013	Oct. 31, 2012	Jun. 30, 2012	Apr. 30, 2012	Jan. 31, 2012	Oct. 27, 2011	Jun. 30, 2011	Apr. 01, 2011	Jan. 31, 2011	Dec. 31, 2013 La Cygne Generating Station [Member]	Dec. 31, 2013 Retail Energy Cost Adjustment [Member] Y	Dec. 31, 2012 Retail Energy Cost Adjustment [Member]	Dec. 31, 2013 Postretirement Benefit Costs [Member] Y	Dec. 31, 2012 Postretirement Benefit Costs [Member]	Dec. 31, 2013 Gain on Sale of Oil [Member] Y	Dec. 31, 2012 Gain on Sale of Oil [Member]	Dec. 31, 2013 Pension Cost [Member] Y	Dec. 31, 2014 Pension Cost [Member]	Dec. 31, 2014 Deferred Employee Benefit Costs [Member]	Dec. 31, 2013 Ad Valorem Tax [Member] Y	Dec. 31, 2013 Energy Efficiency Program Costs [Member] Y	Dec. 31, 2013 Retail Energy Cost Adjustment [Member] Y	Dec. 31, 2013 Other Postretirement Benefit Plans, Defined Benefit [Member]	Dec. 31, 2013 Postretirement Benefit Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Deferred Employee Benefit Costs Amortization Expense, Next Twelve Months																								$ 9,800,000	$ 24,900,000
Regulatory Asset, Amortization Period																							5			1	1	1
Ownership Percentage																50.00%
Regulatory Liabilities	329,556,000	323,175,000															15,414,000	16,595,000	19,000,000	10,722,000	4,278,000	6,219,000							6,700,000	12,300,000
Regulatory Liability, Amortization Period																	1		5		3
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					27,300,000				19,500,000				10,400,000
Proposed Increase In Annual Retail Revenues	30,700,000	50,000,000
Estimated Increase In Annual Retail Revenues For Transmission Costs						11,800,000				36,700,000				17,400,000
Estimated Increase In Annual Retail Revenues For Energy Efficiency Costs				1,300,000				1,100,000				4,900,000
Estimated Increase In Annual Revenues For Property Tax							15,200,000				5,900,000				700,000
Estimated Increase In Annual Transmission Revenues	$ 12,200,000	$ 38,200,000	$ 15,900,000

Financial Instruments and Trading Securities (Narrative) (Details) (USD $)	12 Months Ended			0 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Jan. 20, 2012 Cash Flow Hedging [Member]	Dec. 31, 2012 Cash Flow Hedging [Member]	Dec. 31, 2012 Asset Retirement Obligation [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Increase (Decrease) in Trading Securities	$ 15,300,000
Revised ARO estimate	0	3,075,000
Fair Value Inputs, Cost Estimate						3,100,000
Derivative Liability, Notional Amount			125,000,000
Interest rate cash flow hedge settlement cost				29,700,000
Regulatory Assets	$ 755,414,000	$ 1,002,672,000			$ 28,600,000

Financial Instruments and Trading Securities (Carrying Values And Fair Values Of Financial Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
Carrying Value	$ 3,224,440	$ 2,824,440
Fixed Rate Debt Member
Debt Instrument [Line Items]
Carrying Value	3,102,500	2,702,500
Fair Value	3,294,209	3,178,752
Fixed Rate Debt Of Variable Interest Entities [Member]
Debt Instrument [Line Items]
Carrying Value	221,682	247,624
Fair Value	$ 241,241	$ 275,341

Financial Instruments and Trading Securities (Reconciliations Of Assets And Liabilities At Fair Value) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	$ 12,764	$ 11,026
Regulatory liabilities	2,261	860
Purchases	15,628	1,211
Sales	(650)	(333)
Balance at period end	30,003	12,764
Domestic Equity [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	4,899	3,931
Regulatory liabilities	940	90
Purchases	(341)	(891)
Sales	(363)	(13)
Balance at period end	5,817	4,899
Alternative Investments [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	0	0
Regulatory liabilities	675	0
Purchases	(15,000)	0
Sales	0	0
Balance at period end	15,675	0
Real Estate Securities [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	7,865	7,095
Regulatory liabilities	646	770
Purchases	(287)	(320)
Sales	(287)	(320)
Balance at period end	$ 8,511	$ 7,865

Financial Instruments and Trading Securities (Investments In Financial Instruments) (Details) (USD $)
In Thousands, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

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

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Redemption Restriction Period

15 years

$ 175,625

$ 150,754

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

34,926

^[1]

43,484

Total

210,551

194,238

Alternative Investments [Member]

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

15,675

Real Estate Securities [Member]

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

8,511

7,865

International Equity [Member]

31,816

30,041

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

4,519

^[1]

5,744

Core Bonds [Member]

18,107

28,350

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

12,166

^[1]

15,104

Domestic Equity [Member]

55,774

61,056

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

18,075

^[1]

22,470

Fair Value [Member]

30,003

12,764

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments

34,760

43,318

Total

64,763

56,082

2,683

1,024

Fair Value [Member] | Alternative Investments [Member]

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

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

15,675

Fair Value [Member] | Real Estate Securities [Member]

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

8,511

7,865

Fair Value [Member] | International Equity [Member]

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

4,519

5,744

Fair Value [Member] | Core Bonds [Member]

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

12,166

15,104

Fair Value [Member] | Domestic Equity [Member]

5,817

4,899

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

18,075

22,470

Decommissioning Trust Assets [Member] | Fair Value [Member]

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments

2,683

1,024

Decommissioning Trust Assets [Member] | Fair Value [Member] | Alternative Investments [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

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Frequency

quarterly

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

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Frequency

Quarterly

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Notice Period

80 days

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

2,683

1,024

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Notice Period

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

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

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Frequency

Upon Notice

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Notice Period

1 day

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

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Frequency

Upon Notice

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Notice Period

1 day

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

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Frequency

Upon Notice

Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Notice Period

1 day

[1]	(a)The decrease in the fair value of trading securities was due to withdrawing $15.3 million.

Financial Instruments and Trading Securities (Changes In The Fair Value Of Commodity Derivative Instruments) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Asset Retirement Obligation, Revision of Estimate	$ 0	$ 3,075,000
Asset Retirement Obligation Costs [Member]
Financial And Derivative Instruments, Trading Securities, Energy Marketing And Risk Management [Line Items]
Fair Value Inputs, Cost Estimate		$ 3,100,000

Financial Investments (Narrative) (Details) (USD $)

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Schedule of Available-for-sale Securities [Line Items]

Unrealized gains (losses) on trading securities

$ 34,926,000

^[1]

$ 43,484,000

6,700,000

4,100,000

300,000

Fair value of the debt securities in the NDT fund

46,800,000

Realized gains (losses) on available-for-sale-securities

5,300,000

600,000

1,300,000

Supplemental Employee Retirement Plans, Defined Benefit [Member]

Schedule of Available-for-sale Securities [Line Items]

Benefit obligation for certain retirement benefits

$ 27,000,000

$ 30,000,000

[1]	(a)The decrease in the fair value of trading securities was due to withdrawing $15.3 million.

Financial Investments (Cost And Fair Value Of Available-For-Sale Securities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Schedule of Available-for-sale Securities [Line Items]
Cost	$ 155,244	$ 141,350
Gross Unrealized Gain	23,753	11,520
Gross Unrealized Loss	3,372	2,116
Fair Value	175,625	150,754
Allocation	100.00%	100.00%
Domestic Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	40,976	53,598
Gross Unrealized Gain	14,799	7,458
Gross Unrealized Loss	1	0
Fair Value	55,774	61,056
Allocation	32.00%	41.00%
International Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	26,581	28,248
Gross Unrealized Gain	5,266	1,793
Gross Unrealized Loss	31	0
Fair Value	31,816	30,041
Allocation	18.00%	20.00%
Core Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	18,287	27,309
Gross Unrealized Gain	0	1,041
Gross Unrealized Loss	180	0
Fair Value	18,107	28,350
Allocation	10.00%	19.00%
High-Yield Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	12,275	8,022
Gross Unrealized Gain	627	760
Gross Unrealized Loss	0	0
Fair Value	12,902	8,782
Allocation	7.00%	6.00%
Emerging Market Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	12,207	6,080
Gross Unrealized Gain	0	348
Gross Unrealized Loss	1,152	0
Fair Value	11,055	6,428
Allocation	6.00%	4.00%
Other Fixed Income [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	4,684
Gross Unrealized Gain	6
Gross Unrealized Loss	0
Fair Value	4,690
Allocation	3.00%
Combination Debt and Equity Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	14,964	8,074
Gross Unrealized Gain	2,380	120
Gross Unrealized Loss	251	0
Fair Value	17,093	8,194
Allocation	10.00%	5.00%
Alternative Investments [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	15,000
Gross Unrealized Gain	675
Gross Unrealized Loss	0
Fair Value	15,675
Allocation	9.00%
Real Estate Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	10,268	9,981
Gross Unrealized Gain	0	0
Gross Unrealized Loss	1,757	2,116
Fair Value	8,511	7,865
Allocation	5.00%	5.00%
Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	2	38
Gross Unrealized Gain	0	0
Gross Unrealized Loss	0	0
Fair Value	$ 2	$ 38

Financial Investments (Fair Value And Gross Unrealized Losses Of Available-For-Sale Securities) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	$ 41,748
Gross Unrealized Losses, Less than 12 Months	(1,615)
Fair Value, 12 Months or Greater	8,511
Gross Unrealized Losses, 12 Months or Greater	(1,757)
Fair Value, Total	50,259
Gross Unrealized Losses, Total	(3,372)
Domestic Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	59
Gross Unrealized Losses, Less than 12 Months	(1)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	59
Gross Unrealized Losses, Total	(1)
Combination Debt Equity And Other Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	6,283
Gross Unrealized Losses, Less than 12 Months	(251)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	6,283
Gross Unrealized Losses, Total	(251)
Real Estate [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	8,511	7,865
Gross Unrealized Losses, 12 Months or Greater	(1,757)	(2,116)
Fair Value, Total	8,511	7,865
Gross Unrealized Losses, Total	(1,757)	(2,116)
International Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	6,244
Gross Unrealized Losses, Less than 12 Months	(31)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	6,244
Gross Unrealized Losses, Total	(31)
Core Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	18,107
Gross Unrealized Losses, Less than 12 Months	(180)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	18,107
Gross Unrealized Losses, Total	(180)
Emerging Market Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	11,055
Gross Unrealized Losses, Less than 12 Months	(1,152)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	11,055
Gross Unrealized Losses, Total	$ (1,152)

Property, Plant And Equipment (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Public Utility, Property, Plant and Equipment [Line Items]
Electric plant in service	$ 9,753,787	$ 9,389,192
Electric plant acquisition adjustment	(802,318)	(802,318)
Accumulated depreciation	(3,971,735)	(3,791,545)
Electric plant, net	6,584,370	6,399,965
Construction work in progress	904,586	532,332
Nuclear fuel, net	62,960	81,468
Property, plant and equipment, net	7,551,916	7,013,765
Variable Interest Entity [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Electric plant in service	513,793	543,548
Accumulated depreciation	(217,167)	(221,573)
Property, plant and equipment, net	$ 296,626	$ 321,975

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

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

La Cygne unit 1 [Member]

Dec. 31, 2013

JEC unit 1 [Member]

Dec. 31, 2013

JEC unit 2 [Member]

Dec. 31, 2013

JEC unit 3 [Member]

Dec. 31, 2013

Wolf Creek [Member]

Dec. 31, 2013

State Line [Member]

Dec. 31, 2013

La Cygne unit 2 [Member]

Dec. 31, 2013

La Cygne Generating Station [Member]

Dec. 31, 2013

Jeffrey Energy Center [Member]

Dec. 31, 2013

Variable Interest Entity, Primary Beneficiary [Member]

Dec. 31, 2012

Variable Interest Entity, Primary Beneficiary [Member]

Dec. 31, 2013

Variable Interest Entity, Primary Beneficiary [Member]

La Cygne Generating Station [Member]

Jointly Owned Utility Plant, Net Ownership Amount [Abstract]

Investment

$ 3,789,696,000

$ 334,054,000

^[1]

$ 530,407,000

^[1]

$ 504,508,000

^[1]

$ 713,937,000

^[1]

$ 1,596,382,000

^[2]

$ 110,408,000

^[3]

Accumulated Depreciation

1,655,637,000

151,674,000

^[1]

194,944,000

^[1]

190,660,000

^[1]

296,278,000

^[1]

773,724,000

^[2]

48,357,000

^[3]

Construction Work in Progress

606,193,000

280,688,000

^[1]

166,073,000

^[1]

13,138,000

^[1]

1,906,000

^[1]

144,083,000

^[2]

305,000

^[3]

Net Capacity, in MW

3,099

368

^[1]

661

^[1]

658

^[1]

664

^[1]

547

^[1]

201

^[3]

341

^[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

$ 3,971,735,000

$ 3,791,545,000

$ 217,167,000

$ 221,573,000

$ 187,400,000

[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.

Short-Term Debt (Details) (USD $)	12 Months Ended					12 Months Ended		1 Months Ended
Short-Term Debt (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013 Commercial Paper and Revolving LIne of Credit [Member]	Dec. 31, 2012 Commercial Paper and Revolving LIne of Credit [Member]	Dec. 31, 2013 Commercial Paper [Member] days	Dec. 31, 2012 Commercial Paper [Member]	Jul. 31, 2013 Revolving Credit Facility Lender One [Member]	Dec. 31, 2013 Revolving Credit Facility Lender One [Member]	Jul. 02, 2013 Revolving Credit Facility Lender One [Member]	Dec. 31, 2012 Revolving Credit Facility Lender One [Member]	Sep. 29, 2011 Revolving Credit Facility Lender One [Member]	Feb. 28, 2016 Revolving Credit Facility Lender Two [Member]	Dec. 31, 2013 Revolving Credit Facility Lender Two [Member]	Dec. 31, 2012 Revolving Credit Facility Lender Two [Member]	Sep. 29, 2011 Revolving Credit Facility Lender Two [Member]	Feb. 18, 2011 Revolving Credit Facility Lender Two [Member]
Short-term Debt [Line Items]
Expected extended amount for line of credit												$ 1,000,000,000				$ 400,000,000
Line of credit facility expiration date								Sep. 29, 2017
Line of Credit Facility, Increase(Decrease) in Maximum Borrowing Capacity													20,000,000
Issued letters of credit									18,400,000		13,800,000			0	0
Secured revolving credit facility										730,000,000							270,000,000
Short-Term Debt Maximum Borrowings				1,000,000,000		1,000,000,000
Secured revolving credit facility borrowed									0		0			0	0
Commercial paper program, Maximim maturity period						365
Short-term debt amount outstanding	134,600,000	339,200,000				134,600,000	339,200,000
Weighted average interest rate				0.28%	0.46%
Weighted average amount outstanding	228,352,000	298,907,000
Weighted daily average interest rate, excluding fees	0.39%	0.55%
Interest expense on short-term debt	$ 2,400,000	$ 3,200,000	$ 3,900,000

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

Dec. 31, 2013

Dec. 31, 2012

May 31, 2012

Mar. 01, 2012

Long-term debt due within one year

$ 3,224,440

$ 2,824,440

(250,000)

Unamortized debt discount, Net

(5,482)

^[1]

(5,169)

^[1]

2,968,958

2,819,271

Westar Energy [Member] | Secured Debt [Member]

2,250,000

1,750,000

75,500

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] | 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] | Debt Intrument 8860 [Member]

250,000

Westar Energy [Member] | Secured Debt [Member] | Debt Instrument Thirty [Member] [Member]

Westar Energy [Member] | Secured Debt [Member] | Debt Instrument 8870 [Member]

250,000

Westar Energy [Member] | Secured Debt [Member] | Debt Instrument Thirty-One [Member] [Member]

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

KGE [Member] | Secured Debt [Member]

625,000

273,940

373,940

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] | 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

221,682

247,624

(27,479)

(25,942)

Unamortized debt discount, Net

599

^[1]

1,061

^[1]

194,802

222,743

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

316

^[2]

866

^[2]

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

13,243

^[2]

17,630

^[2]

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

$ 208,123

^[2]

$ 229,128

^[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.

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.

+ References+ 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, 2013
Debt Instrument [Line Items]
2013	$ 250,000
2014	0
2015	0
2016	125,000
2017	300,000
Thereafter	2,549,440
Variable Interest Entity, Primary Beneficiary [Member]
Debt Instrument [Line Items]
2013	27,479
2014	27,933
2015	28,309
2016	26,842
2017	28,538
Thereafter	$ 82,581

Long-term Debt (Narrative) (Details) (USD $)	12 Months Ended									12 Months Ended			0 Months Ended										0 Months Ended
Long-term Debt (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013 Variable Interest Entity [Member]	Dec. 31, 2012 Variable Interest Entity [Member]	Dec. 31, 2011 Variable Interest Entity [Member]	Dec. 31, 2013 KGE [Member] First Mortgage Bond Series [Member]	Dec. 31, 2013 KGE [Member] Secured Debt [Member]	Dec. 31, 2012 KGE [Member] Secured Debt [Member]	Dec. 31, 2013 KGE [Member] Pollution Control Bond Series [Member] DebtInstruments8780And8790 [Member]	Dec. 31, 2013 KGE [Member] Pollution Control Bond Series [Member] Debt Instrument 8780 [Member]	Dec. 31, 2013 KGE [Member] Pollution Control Bond Series [Member] Debt Instrument 8790 [Member]	Mar. 30, 2012 KGE [Member] Pollution Control Bond Series [Member] 5.10% Pollution Control Bonds Due 2023 [Member]	Dec. 31, 2013 Westar Energy [Member] First Mortgage Bond Series [Member]	Dec. 31, 2013 Westar Energy [Member] Secured Debt [Member]	Dec. 31, 2012 Westar Energy [Member] Secured Debt [Member]	Dec. 31, 2013 Westar Energy [Member] Secured Debt [Member] Debt Instrument 8870 [Member]	Dec. 31, 2013 Westar Energy [Member] Secured Debt [Member] Debt Intrument 8860 [Member]	Dec. 31, 2013 Westar Energy [Member] Secured Debt [Member] Debt Instrument Twenty-Nine [Member]	Dec. 31, 2012 Westar Energy [Member] Secured Debt [Member] Debt Instrument Twenty-Nine [Member]	May 31, 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]	May 15, 2012 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							1,100,000,000							505,300,000
Variable Rate Tax-Exempt Bonds	121,900,000
Long-term debt	3,224,440,000	2,824,440,000		221,682,000	247,624,000			625,000,000	625,000,000						2,250,000,000	1,750,000,000	250,000,000	250,000,000	550,000,000	550,000,000	300,000,000	250,000,000
Stated interest percentage											5.60%	6.00%	5.10%				4.625%	4.10%			0.00%	4.125%	6.10%	5.00%
Bond discount yield percentage																					4.157%	4.13%
Repayments of Long-term Debt	(100,000,000)	(220,563,000)	(371,000)	(25,942,000)	(28,114,000)	(30,159,000)				(100,000,000)			(13,300,000)										(150,000,000)	(57,200,000)
Interest expense on long-term debt	$ 154,900,000	$ 145,600,000	$ 142,600,000	$ 13,000,000	$ 15,100,000	$ 16,800,000

Taxes (Components of Income Tax Expense) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Current income taxes:
Federal	$ 135	$ (691)	$ (8,575)
State	279	579	196
Deferred income taxes:
Federal	102,030	102,960	93,089
State	24,443	26,300	21,337
Investment tax credit amortization	(3,166)	(3,012)	(2,703)
Income tax expense	$ 123,721	$ 126,136	$ 103,344

Amount of current federal tax expense (benefit) pertaining to income (loss) from continuing operations.

+ References+ Details

Amount of current state and local tax expense (benefit) pertaining to income (loss) from continuing operations.

+ References+ Details

Amount of deferred federal income tax expense (benefit) pertaining to income (loss) from continuing operations.

+ References+ Details

Amount of deferred state and local tax expense (benefit) pertaining to income (loss) from continuing operations.

+ References+ Details

Taxes (Deferred Tax Assets and Liabilities in Balance Sheet) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Other current liabilities (assets)	$ (37,927)	$ 0
Deferred Tax Liabilities, Net, Current	0	8,654
Deferred Tax Liabilities, Net	$ 1,323,491	$ 1,206,491

Deferred Tax Liabilities, Net, Noncurrent

Amount of deferred tax liability attributable to taxable temporary differences, net of deferred tax asset attributable to deductible temporary differences and carryforwards net of valuation allowances expected to be realized or consumed within one year or operating cycle, if longer.

+ References+ Details

Taxes (Schedule of Deferred Tax Assets and Liabilities) (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Income Tax Contingency [Line Items]

$ 1,361,418,000

$ 1,197,837,000

Deferred Tax Liabilities, Net

1,323,491,000

1,206,491,000

Deferred Tax Assets, Net, Current

37,927,000

Deferred Tax Liabilities, Net, Current

8,654,000

Business tax credit carryforward

212,635,000

^[1]

199,160,000

^[1]

Deferred employee benefit costs

85,720,000

191,997,000

Net operating loss carryforward

110,588,000

^[2]

111,869,000

^[2]

Deferred state income taxes

57,243,000

55,577,000

Deferred regulatory gain on sale-leaseback

38,124,000

40,543,000

Alternative minimum tax carryforward

35,666,000

^[3]

36,471,000

^[3]

Deferred compensation

30,022,000

28,319,000

Accrued liabilities

17,396,000

15,969,000

Disallowed costs

11,453,000

12,083,000

Deferred Tax Assets, Dismantling Costs

8,110,000

7,156,000

Capital loss carryforward

3,447,000

11,509,000

Total gross deferred tax assets

20,058,000

13,741,000

630,462,000

724,394,000

Less: Valuation allowance

3,504,000

^[4]

13,812,000

^[4]

Deferred tax assets

626,958,000

710,582,000

Deferred tax liabilities:

Accelerated depreciation

1,390,669,000

1,255,892,000

Deferred employee benefit costs

85,720,000

191,997,000

Acquisition premium

171,907,000

179,920,000

Amounts due from customers for future income taxes, net

163,742,000

169,091,000

Deferred state income taxes

51,504,000

50,134,000

Pension expense tracker

21,230,000

22,437,000

Debt reacquisition costs

19,985,000

22,313,000

Storm costs

21,165,000

4,373,000

Total deferred tax liabilities

24,527,000

20,916,000

1,950,449,000

1,917,073,000

Net deferred tax liabilities

1,323,491,000

1,206,491,000

Capital loss carryforwards

8,700,000

Deferred Tax Asset, Capital Loss [Member]

Less: Valuation allowance

3,500,000

Internal Revenue Service (IRS) [Member]

Business tax credit carryforward

50,200,000

Deferred tax liabilities:

Operating Loss Carryforwards

277,600,000

State and Local Jurisdiction [Member]

Business tax credit carryforward

$ 162,400,000

[1]	Based on filed tax returns and amounts expected to be reported in current year tax returns (December 31, 2013), we had available federal general business tax credits of $50.2 million and state investment tax credits of $162.4 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 2033. The state investment tax credits expire beginning in 2017 and ending in 2029.
[2]	As of December 31, 2013, we had a federal net operating loss carryforward of $277.6 million, which is available to offset federal taxable income. The net operating losses will expire beginning in 2031 and ending in 2032.
[3]	As of December 31, 2013, we had available an alternative minimum tax credit carryforward of $35.7 million, which has an unlimited carryforward period.
[4]	As we do not expect to realize any significant capital gains in the future, we have established a valuation allowance of $3.5 million. The total valuation allowance related to the deferred tax assets was $3.5 million as of December 31, 2013, and $13.8 million as of December 31, 2012

Taxes (Effective Income Tax Reconciliation) (Details)	12 Months Ended
Taxes (Effective Income Tax Reconciliation) (Details)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Effective Income Tax Rate
Statutory federal income tax rate	35.00%	35.00%	35.00%
Corporate-owned life insurance policies	(5.40%)	(4.90%)	(4.50%)
State income taxes	3.80%	4.30%	4.10%
Production tax credits	(2.30%)	(2.40%)	(2.90%)
Accelerated depreciation flow through and amortization	2.20%	1.40%	1.80%
AFUDC equity	(1.20%)	(1.00%)	(0.60%)
Amortization of federal investment tax credits	(0.70%)	(0.70%)	(0.80%)
Capital loss utilization	(1.10%)	(0.30%)	(0.50%)
Liability for unrecognized income tax benefits	0.10%	0.20%	0.00%
Other	(1.30%)	(0.70%)	(1.20%)
Effective income tax rate	29.10%	30.90%	30.40%

Taxes (Unrecognized Tax Benefits) (Details) (USD $)	12 Months Ended
Taxes (Unrecognized Tax Benefits) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized income tax benefits at January 1	$ 1,219,000	$ 2,483,000	$ 1,888,000
Additions based on tax positions related to the current year	224,000	373,000	967,000
Additions for tax positions of prior years	325,000	0	939,000
Reductions for tax positions of prior years	(65,000)	(1,637,000)	(563,000)
Settlements	0	0	(748,000)
Unrecognized income tax benefits at December 31	1,703,000	1,219,000	2,483,000
Tax loss and credit carryforwards	0	300,000	200,000
The amounts of unrecognized income tax benefits that, if recognized, would favorably impact our effective income tax rate	2,400,000	2,000,000	1,200,000
Reversal of interest expense previously recorded for income tax uncertainties			200,000
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, 2013

Dec. 31, 2012

Dec. 31, 2011

$ 34,926

^[1]

$ 43,484

Pension Benefits [Member]

928,708

^[2]

876,308

21,420

19,556

16,076

38,520

39,576

40,045

36,529

^[3]

60,229

^[3]

(128,339)

53,497

823,780

^[2]

928,708

^[2]

876,308

547,931

481,077

68,151

67,328

27,500

56,700

33,765

57,174

609,817

547,931

481,077

Amounts Recognized in the Balance Sheets Consist of:

(213,963)

(380,777)

(2,740)

(2,870)

(211,223)

(377,907)

Amounts Recognized in Regulatory Assets Consist of:

(213,963)

(380,777)

186,365

383,365

3,393

3,994

189,758

387,359

Other Postretirement Benefit Plans, Defined Benefit [Member]

152,564

^[2]

150,078

2,028

2,057

1,803

6,007

6,298

6,793

2,961

2,987

10,968

^[3]

9,799

^[3]

(19,531)

943

133,061

^[2]

152,564

^[2]

150,078

106,793

91,858

17,361

10,673

5,318

10,803

(2,830)

(2,845)

10,536

9,386

121,766

106,793

91,858

Amounts Recognized in the Balance Sheets Consist of:

(11,295)

(45,771)

(242)

(298)

(11,053)

(45,473)

Amounts Recognized in Regulatory Assets Consist of:

(11,295)

(45,771)

(18,890)

12,436

13,942

16,467

325

(4,948)

29,228

Supplemental Employee Retirement Plans, Defined Benefit [Member]

27,000

30,000

OneTimeBenefitPayment [Member] | Pension Benefits [Member]

$ 26,100

[1]	(a)The decrease in the fair value of trading securities was due to withdrawing $15.3 million.
[2]	(b) As of December 31, 2013 and 2012, pension benefits include non-qualified benefit obligations of $27.0 million and $30.0 million, respectively, which are funded by a trust containing assets of $34.9 million and $43.5 million, respectively, classified as trading securities. The assets in the aforementioned trust are not included in the table above. See Notes 4 and 5, "Financial Instruments and Trading Securities" and "Financial Investments," respectively, for additional information regarding these amounts.
[3]	(a)In 2012 certain former employees received a one-time lump sum payment of their pension benefits totaling $26.1 million.

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, 2013	Dec. 31, 2012
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 823,780	$ 928,708
Fair value of plan assets	609,817	547,931
Accumulated benefit obligation	732,150	806,888
Fair value of plan assets	609,817	547,931
Discount rate	5.07%	4.13%
Compensation rate increase	4.00%	4.00%
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	133,061	152,564
Fair value of plan assets	$ 121,766	$ 106,793
Discount rate	4.88%	3.99%
Compensation rate increase	0.00%	0.00%

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, 2013

Dec. 31, 2012

Dec. 31, 2011

Pension Benefits [Member]

$ 21,420

$ 19,556

$ 16,076

38,520

39,576

40,045

(33,405)

(32,283)

(31,087)

Actuarial loss/(gain), net

601

612

1,213

33,914

32,778

23,659

61,050

60,239

49,906

3,693

^[1]

(6,523)

^[1]

(22,098)

^[1]

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:

64,743

53,716

27,808

Amortization of actuarial (loss)/gain

(163,086)

18,451

97,429

(33,914)

(32,778)

(23,659)

(601)

(612)

(1,213)

Total recognized in net periodic cost and regulatory assets

(197,601)

(14,939)

72,557

(132,858)

38,777

100,365

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:

4.13%

4.50%

5.35%

6.50%

4.00%

Other Postretirement Benefit Plans, Defined Benefit [Member]

2,028

2,057

1,803

6,007

6,298

6,793

(6,691)

(5,491)

(5,002)

325

3,912

3,911

Actuarial loss/(gain), net

2,524

1,125

1,503

702

5,318

10,803

10,731

2,922

^[1]

1,344

^[1]

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:

8,240

10,826

12,075

Amortization of actuarial (loss)/gain

(30,201)

(4,239)

10,421

(1,125)

(1,503)

(702)

4,451

(2,525)

(2,524)

(325)

(3,912)

(3,911)

Total recognized in net periodic cost and regulatory assets

(34,176)

(12,178)

7,735

$ (25,936)

$ (1,352)

$ 19,810

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:

3.99%

4.25%

5.00%

6.00%

4.00%

0.00%

[1]	(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.

Employee Benefit Plans (Estimated Amounts From Regulatory Assets Into Net Periodic Cost) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013
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	$ 19,362
Estimated Future Change in Regulatory Assets, Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost (Credit) Recognized in Net Periodic Benefit Cost	(525)
Total	19,887
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	(742)
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)
Total	$ 1,782

Employee Benefit Plans (Assumed Annual Health Care Cost Growth Rates) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.50%	0.00%	8.00%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	5.00%	5.00%	5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	2019	2019	2019

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, 2013	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	0.00%	7.50%	8.00%
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components		$ 153
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components		(136)
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation		2,098
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation		$ (1,901)

Employee Benefit Plans (Fair Value of Plan Assets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 609,817	$ 547,931	$ 481,077
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	524,136	462,976
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	85,681	84,955
Pension Plans, Defined Benefit [Member] \| Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	183,760	147,994
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	161,272	129,501
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	22,488	18,493
Pension Plans, Defined Benefit [Member] \| International Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	75,872	67,743
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	75,872	67,743
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	191,506	178,784
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	191,506	178,784
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	20,796	19,070
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	20,796	19,070
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	13,113	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	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	13,113	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	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	58,336	50,750
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	58,336	50,750
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	24,022	20,927
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	24,022	20,927
Pension Plans, Defined Benefit [Member] \| Alternative Investments [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	39,171	45,535
Pension Plans, Defined Benefit [Member] \| Alternative Investments [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 Investments [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 Investments [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	39,171	45,535
Pension Plans, Defined Benefit [Member] \| Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	3,241	2,852
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	3,241	2,852
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	121,766	106,793	91,858
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	121,766	106,793
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	64,080	55,441
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	64,080	55,441
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	16,018	14,037
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	16,018	14,037
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	41,092	36,738
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	41,092	36,738
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	576	577
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	576	577
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

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, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 30,003	$ 12,764	$ 11,026
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	85,681	84,955	74,939
Defined Benefit Plan, Actual Return on Plan Assets Still Held	9,088	7,090
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	826	26
Purchases, issuances and settlements, net	(9,188)	2,900
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	22,488	18,493	15,375
Defined Benefit Plan, Actual Return on Plan Assets Still Held	3,845	(25)
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	0	53
Purchases, issuances and settlements, net	150	3,090
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	39,171	45,535	40,716
Defined Benefit Plan, Actual Return on Plan Assets Still Held	1,936	4,819
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	826	0
Purchases, issuances and settlements, net	(9,126)	0
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	24,022	20,927	18,848
Defined Benefit Plan, Actual Return on Plan Assets Still Held	3,307	2,296
Defined Benefit Plan, Actual Return on Plan Assets Sold During Period	0	27
Purchases, issuances and settlements, net	$ (212)	$ (190)

Employee Benefit Plans (Expected Cash Flows Related To Pension and Post-Retirement Benefit Plans) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Plan Trust [Member] \| Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2014	$ 30.8
2014	(35.4)
2015	(36.9)
2016	(39.2)
2017	(41.5)
2018	(44.5)
2019 - 2022	(257.9)
Plan Trust [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
2014	2.9
2014	(8.7)
2015	(9.1)
2016	(9.3)
2017	(9.6)
2018	(9.8)
2019 - 2022	(49.7)
Company Assets [Member] \| Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2014	(2.8)
2015	(2.8)
2016	(2.8)
2017	(2.7)
2018	(2.7)
2019 - 2022	(12.8)
Company Assets [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
2014	(0.2)
2015	(0.2)
2016	(0.2)
2017	(0.2)
2018	(0.2)
2019 - 2022	$ (1.0)

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, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Allocated Share-based Compensation Expense	$ 8,121	$ 7,203	$ 8,367
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	$ 3,212	$ 2,849	$ 3,309

Employee Benefit Plans (RSU activity for awards) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
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	$ 3,700,000	$ 4,800,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested balance, beginning of year	351,100	368,500	600,400
Granted	139,600	131,000	284,100
Vested	(125,500)	(127,800)	(187,300)
Forfeited	(12,700)	(20,600)	(328,700)
Nonvested balance, end of year	352,500	351,100	368,500
Weighted Average Grant Date Fair Value, beginning of year	$ 25.47	$ 23.83	$ 21.50
Grants in Period, Weighted Average Grant Date Fair Value	$ 31.06	$ 27.82	$ 26.30
Vested in Period, Weighted Average Grant Date Fair Value	$ 23.22	$ 23.34	$ 23.50
Forfeited in Period, Weighted Average Grant Date Fair Value	$ 28.35	$ 24.40	$ 24.37
Weighted Average Grant Date Fair Value, end of year	$ 28.38	$ 25.47	$ 23.83
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	$ 2,300,000	$ 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	340,100	324,200	348,400
Granted	134,400	122,300	244,400
Vested	(112,500)	(88,200)	(119,500)
Forfeited	(11,900)	(18,200)	(149,100)
Nonvested balance, end of year	350,100	340,100	324,200
Weighted Average Grant Date Fair Value, beginning of year	$ 29.20	$ 28.31	$ 24.98
Grants in Period, Weighted Average Grant Date Fair Value	$ 31.54	$ 28.84	$ 31.26
Vested in Period, Weighted Average Grant Date Fair Value	$ 28.29	$ 25.46	$ 24.12
Forfeited in Period, Weighted Average Grant Date Fair Value	$ 30.45	$ 29.00	$ 28.72
Weighted Average Grant Date Fair Value, end of year	$ 30.35	$ 29.20	$ 28.31

Employee Benefit Plans (Textual) (Details) (USD $)

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Level 2 [Member]

Dec. 31, 2012

Level 2 [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Dec. 31, 2011

Pension Plans, Defined Benefit [Member]

Dec. 31, 2013

Other Postretirement Benefit 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, 2013

Supplemental Employee Retirement Plans, Defined Benefit [Member]

Dec. 31, 2012

Supplemental Employee Retirement Plans, Defined Benefit [Member]

Dec. 31, 2013

KGE [Member]

Dec. 31, 2013

Debt Securities [Member]

Pension Plans, Defined Benefit [Member]

Dec. 31, 2013

Debt Securities [Member]

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2013

Equity Securities [Member]

Pension Plans, Defined Benefit [Member]

Dec. 31, 2013

Equity Securities [Member]

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2013

Alternative Investments [Member]

Pension Plans, Defined Benefit [Member]

Dec. 31, 2013

Other Investments [Member]

Pension Plans, Defined Benefit [Member]

Dec. 31, 2013

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, 2013

Long Term Incentive and Share Award Plan Executive Stock For Compensation Program [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, 2013

RSU Awards With Performance Measures [Member]

Dec. 31, 2012

RSU Awards With Performance Measures [Member]

Dec. 31, 2011

RSU Awards With Performance Measures [Member]

Dec. 31, 2013

RSU Awards With Only Service Requirements [Member]

Dec. 31, 2012

RSU Awards With Only Service Requirements [Member]

Dec. 31, 2011

RSU Awards With Only Service Requirements [Member]

Dec. 31, 2013

OneTimeBenefitPayment [Member]

Pension Plans, Defined Benefit [Member]

Subsidiary Interest in Defined Benefit Plans

47.00%

Benefit obligation for certain retirement benefits

$ 36,529,000

^[1]

$ 60,229,000

^[1]

$ 10,968,000

^[1]

$ 9,799,000

^[1]

$ 26,100,000

823,780,000

^[2]

928,708,000

^[2]

876,308,000

133,061,000

^[2]

152,564,000

^[2]

150,078,000

27,000,000

30,000,000

Defined Benefit Plan Target Allocation Percentage Of Assets Of Any One Industry

34,926,000

^[3]

43,484,000

34,760,000

^[3]

43,318,000

25.00%

Target Defined Benefit Plan Asset Allocations

39.00%

35.00%

39.00%

65.00%

12.00%

10.00%

US Government Securities, at Carrying Value

47,400,000

401k Savings Plan Matching Contributions

6,900,000

7,100,000

7,000,000

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized

8,250,000

5,000,000

Share-based Compensation Arrangement by Share-based Payment Award, Shares Awarded

4,900,000

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

15.00%

17.60%

Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate, Maximum

23.50%

33.60%

Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate, Minimum

0.30%

0.40%

Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized

4,000,000

3,500,000

4,400,000

Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition

1 year 8 months

Share-based Compensation Award Fair Value, Vested During Period

$ 2,300,000

$ 3,600,000

$ 3,600,000.0

$ 3,700,000

$ 4,800,000

Common Stock Dividends, Shares

551

666

4,757

Common stock, shares issued

128,254,229

126,503,748

3,456

1,461

67,426

[1]	(a)In 2012 certain former employees received a one-time lump sum payment of their pension benefits totaling $26.1 million.
[2]	(b) As of December 31, 2013 and 2012, pension benefits include non-qualified benefit obligations of $27.0 million and $30.0 million, respectively, which are funded by a trust containing assets of $34.9 million and $43.5 million, respectively, classified as trading securities. The assets in the aforementioned trust are not included in the table above. See Notes 4 and 5, "Financial Instruments and Trading Securities" and "Financial Investments," respectively, for additional information regarding these amounts.
[3]	(a)The decrease in the fair value of trading securities was due to withdrawing $15.3 million.

Wolf Creek Employee Benefit Plans (Funded Status) (Details) (USD $)
In Thousands, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Wolf Creek [Member]

$ 114,734

$ 98,051

Pension Benefits [Member]

928,708

^[1]

876,308

21,420

19,556

16,076

38,520

39,576

40,045

(36,529)

^[2]

(60,229)

^[2]

(128,339)

53,497

823,780

^[1]

928,708

^[1]

876,308

547,931

481,077

68,151

67,328

27,500

56,700

33,765

57,174

609,817

547,931

481,077

Amounts Recognized in the Balance Sheet Consist of:

(213,963)

(380,777)

(2,740)

(2,870)

(211,223)

(377,907)

Amounts Recognized in Regulatory Assets Consist of:

(213,963)

(380,777)

186,365

383,365

3,393

3,994

189,758

387,359

Pension Benefits [Member] | Wolf Creek [Member]

176,891

161,396

6,835

6,062

4,957

7,562

7,537

7,370

(4,349)

^[3]

(8,569)

^[3]

(24,119)

9,815

Amendments

650

162,820

176,891

161,396

98,051

80,727

13,166

11,764

7,624

13,887

(4,107)

(8,327)

114,734

98,051

80,727

Amounts Recognized in the Balance Sheet Consist of:

(48,086)

(78,840)

(237)

(243)

(47,849)

(78,597)

Amounts Recognized in Regulatory Assets Consist of:

(48,086)

(78,840)

29,203

64,535

617

675

29,820

65,210

Other Postretirement Benefit Plans, Defined Benefit [Member]

152,564

^[1]

150,078

2,028

2,057

1,803

6,007

6,298

6,793

2,961

2,987

(10,968)

^[2]

(9,799)

^[2]

(19,531)

943

133,061

^[1]

152,564

^[1]

150,078

106,793

91,858

17,361

10,673

5,318

10,803

2,830

2,845

10,536

9,386

121,766

106,793

91,858

Amounts Recognized in the Balance Sheet Consist of:

(11,295)

(45,771)

(242)

(298)

(11,053)

(45,473)

Amounts Recognized in Regulatory Assets Consist of:

(11,295)

(45,771)

(18,890)

12,436

13,942

16,467

325

(4,948)

29,228

Other Postretirement Benefit Plans, Defined Benefit [Member] | Wolf Creek [Member]

11,020

10,129

206

191

165

413

411

458

696

608

(1,022)

^[3]

(988)

^[3]

(1,303)

669

Amendments

10,010

11,020

10,129

330

389

696

608

(1,022)

(988)

Amounts Recognized in the Balance Sheet Consist of:

(9,993)

(11,007)

(614)

(625)

(9,379)

(10,382)

Amounts Recognized in Regulatory Assets Consist of:

(9,993)

(11,007)

2,076

3,643

2,076

3,644

OneTimeBenefitPayment [Member] | Pension Benefits [Member]

(26,100)

OneTimeBenefitPayment [Member] | Pension Benefits [Member] | Wolf Creek [Member]

$ (4,900)

[1]	(b) As of December 31, 2013 and 2012, pension benefits include non-qualified benefit obligations of $27.0 million and $30.0 million, respectively, which are funded by a trust containing assets of $34.9 million and $43.5 million, respectively, classified as trading securities. The assets in the aforementioned trust are not included in the table above. See Notes 4 and 5, "Financial Instruments and Trading Securities" and "Financial Investments," respectively, for additional information regarding these amounts.
[2]	(a)In 2012 certain former employees received a one-time lump sum payment of their pension benefits totaling $26.1 million.
[3]	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

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, 2013	Dec. 31, 2012
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 823,780	$ 928,708
Fair value of plan assets	609,817	547,931
Accumulated benefit obligation	732,150	806,888
Fair value of plan assets	609,817	547,931
Discount rate	5.07%	4.13%
Compensation rate increase	4.00%	4.00%
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	133,061	152,564
Fair value of plan assets	121,766	106,793
Discount rate	4.88%	3.99%
Compensation rate increase	0.00%	0.00%
Wolf Creek [Member] \| Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	162,820	176,891
Fair value of plan assets	114,734	98,051
Accumulated benefit obligation	137,459	141,722
Fair value of plan assets	114,734	98,051
Discount rate	5.11%	4.16%
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	10,010	11,020
Fair value of plan assets	$ 16	$ 13
Discount rate	4.70%	3.78%
Compensation rate increase	0.00%	0.00%

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, 2013

Dec. 31, 2012

Dec. 31, 2011

Pension Benefits [Member]

$ 21,420

$ 19,556

$ 16,076

38,520

39,576

40,045

(33,405)

(32,283)

(31,087)

601

612

1,213

33,914

32,778

23,659

61,050

60,239

49,906

3,693

^[1]

(6,523)

^[1]

(22,098)

^[1]

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:

64,743

53,716

27,808

(163,086)

18,451

97,429

(33,914)

(32,778)

(23,659)

(601)

(612)

(1,213)

Total recognized in net periodic cost and regulatory assets

(197,601)

(14,939)

72,557

(132,858)

38,777

100,365

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:

4.13%

4.50%

5.35%

6.50%

4.00%

Pension Benefits [Member] | Wolf Creek [Member]

6,835

6,062

4,957

7,562

7,537

7,370

(7,373)

(6,577)

(5,904)

5,421

5,366

3,586

12,503

12,394

10,077

(641)

^[2]

(1,776)

^[2]

(2,546)

^[2]

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:

11,862

10,618

7,531

(29,911)

4,629

29,124

(5,421)

(5,366)

(3,586)

650

(58)

(6)

(16)

(52)

Total recognized in net periodic cost and regulatory assets

(35,390)

(93)

25,470

(23,528)

10,525

33,001

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:

4.16%

4.55%

5.45%

7.50%

4.00%

Other Postretirement Benefit Plans, Defined Benefit [Member]

2,028

2,057

1,803

6,007

6,298

6,793

(6,691)

(5,491)

(5,002)

325

3,912

3,911

2,524

1,125

1,503

702

5,318

10,803

10,731

2,922

^[1]

1,344

^[1]

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:

8,240

10,826

12,075

(30,201)

(4,239)

10,421

(1,125)

(1,503)

(702)

4,451

(2,525)

(2,524)

(325)

(3,912)

(3,911)

Total recognized in net periodic cost and regulatory assets

(34,176)

(12,178)

7,735

(25,936)

(1,352)

19,810

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:

3.99%

4.25%

5.00%

6.00%

4.00%

0.00%

Other Postretirement Benefit Plans, Defined Benefit [Member] | Wolf Creek [Member]

206

191

165

413

411

458

265

234

227

884

893

908

^[2]

Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets:

884

893

908

(1,303)

669

(360)

(265)

(234)

(227)

(57)

(58)

Total recognized in net periodic cost and regulatory assets

(1,568)

378

(645)

$ (684)

$ 1,271

$ 263

Weighted-Average Actuarial Assumptions used to Determine Net Periodic Cost:

3.78%

4.10%

4.90%

0.00%

Variable Interest Entity [Line Items]

0.00%

[1]	(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.
[2]	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.

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, 2013
Pension Benefits [Member]
Actuarial loss	$ (19,362)
Prior service cost	(525)
Total	19,887
Pension Benefits [Member] \| Wolf Creek [Member]
Actuarial loss	2,987
Prior service cost	58
Total	3,045
Other Postretirement Benefit Plans, Defined Benefit [Member]
Actuarial loss	742
Prior service cost	(2,524)
Total	1,782
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Wolf Creek [Member]
Actuarial loss	165
Prior service cost	0
Total	$ 165

Wolf Creek Employee Benefit Plans Wolf Creek Employee Benefit Plans (Assumed Annual Health Care Cost Growth Rates) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Health care cost trend rate assumed for next year	0.00%	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	2019
Wolf Creek [Member]
Health care cost trend rate assumed for next year	7.50%	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	2019

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, 2013	Dec. 31, 2012
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.50%	8.00%
Effect on total of service and interest cost from one-percentage-point increase	153
Effect on total of service and interest cost from one-percentage-point decrease	(136)
Effect on post-retirement benefit obligation from one-percentage-point increase	2,098
Effect on post-retirement benefit obligation from one-percentage-point decrease	(1,901)
Wolf Creek [Member]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.50%	8.00%
Effect on total of service and interest cost from one-percentage-point increase	(9)
Effect on total of service and interest cost from one-percentage-point decrease	9
Effect on post-retirement benefit obligation from one-percentage-point increase	(102)
Effect on post-retirement benefit obligation from one-percentage-point decrease	$ 97

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, 2013	Dec. 31, 2012
Fair value of pension plan assets	$ 114,734	$ 98,051
Level 1
Fair value of pension plan assets	0	0
Level 2
Fair value of pension plan assets	105,493	89,610
Level 3
Fair value of pension plan assets	9,241	8,441
Domestic Equity Securities [Member]
Fair value of pension plan assets	30,599	24,305
Domestic Equity Securities [Member] \| Level 1
Fair value of pension plan assets	0	0
Domestic Equity Securities [Member] \| Level 2
Fair value of pension plan assets	30,599	24,305
Domestic Equity Securities [Member] \| Level 3
Fair value of pension plan assets	0	0
International Equity Securities [Member]
Fair value of pension plan assets	36,868	30,484
International Equity Securities [Member] \| Level 1
Fair value of pension plan assets	0	0
International Equity Securities [Member] \| Level 2
Fair value of pension plan assets	36,868	30,484
International Equity Securities [Member] \| Level 3
Fair value of pension plan assets	0	0
Core Bonds [Member]
Fair value of pension plan assets	26,926	24,763
Core Bonds [Member] \| Level 1
Fair value of pension plan assets	0	0
Core Bonds [Member] \| Level 2
Fair value of pension plan assets	26,926	24,763
Core Bonds [Member] \| Level 3
Fair value of pension plan assets	0	0
Real Estate [Member]
Fair value of pension plan assets	10,534	9,513
Real Estate [Member] \| Level 1
Fair value of pension plan assets	0	0
Real Estate [Member] \| Level 2
Fair value of pension plan assets	5,440	4,972
Real Estate [Member] \| Level 3
Fair value of pension plan assets	5,094	4,541
Commodities [Member]
Fair value of pension plan assets	5,245	4,789
Commodities [Member] \| Level 1
Fair value of pension plan assets	0	0
Commodities [Member] \| Level 2
Fair value of pension plan assets	5,245	4,789
Commodities [Member] \| Level 3
Fair value of pension plan assets	0	0
Alternative Investments [Member]
Fair value of pension plan assets	4,147	3,900
Alternative Investments [Member] \| Level 1
Fair value of pension plan assets	0	0
Alternative Investments [Member] \| Level 2
Fair value of pension plan assets	0	0
Alternative Investments [Member] \| Level 3
Fair value of pension plan assets	4,147	3,900
Cash Equivalents [Member]
Fair value of pension plan assets	415	297
Cash Equivalents [Member] \| Level 1
Fair value of pension plan assets	0	0
Cash Equivalents [Member] \| Level 2
Fair value of pension plan assets	415	297
Cash Equivalents [Member] \| Level 3
Fair value of pension plan assets	$ 0	$ 0

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, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013 Level 3	Dec. 31, 2012 Level 3	Dec. 31, 2013 Level 3 Wolf Creek [Member]	Dec. 31, 2012 Level 3 Wolf Creek [Member]	Dec. 31, 2013 Real Estate [Member] Level 3	Dec. 31, 2012 Real Estate [Member] Level 3	Dec. 31, 2013 Real Estate [Member] Level 3 Wolf Creek [Member]	Dec. 31, 2012 Real Estate [Member] Level 3 Wolf Creek [Member]	Dec. 31, 2013 Alternative Investments [Member] Level 3 Wolf Creek [Member]	Dec. 31, 2012 Alternative Investments [Member] Level 3 Wolf Creek [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at period start	$ 30,003	$ 12,764	$ 11,026	$ 84,955	$ 74,939	$ 8,441	$ 3,630	$ 20,927	$ 18,848	$ 4,541	$ 3,630	$ 3,900	$ 0
Actual gain (loss) on plan assets relating to assets still held at the reporting date				(9,088)	(7,090)	(800)	388	(3,307)	(2,296)	(553)	411	(247)	(23)
Actual gain (loss) on plan assets relating to assets sold during the period				826	26		755	0	27		755		0
Purchases, issuances and settlements, net				(9,188)	2,900		4,444	(212)	(190)		567		3,877
Balance at period end	$ 30,003	$ 12,764	$ 11,026	$ 85,681	$ 84,955	$ 9,241	$ 8,441	$ 24,022	$ 20,927	$ 5,094	$ 4,541	$ 4,147	$ 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	12 Months Ended
	Dec. 31, 2013
Plan Trust [Member] \| Pension Benefits [Member]
Expected contributions:
2014	$ 30.8
Expected benefit payments:
2014	(35.4)
2015	(36.9)
2016	(39.2)
2017	(41.5)
2018	(44.5)
2019 - 2022	(257.9)
Plan Trust [Member] \| Pension Benefits [Member] \| Wolf Creek [Member]
Expected contributions:
2014	5.4
Expected benefit payments:
2014	(4.6)
2015	(5.3)
2016	(6.1)
2017	(7.0)
2018	(7.8)
2019 - 2022	(53.0)
Plan Trust [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Expected contributions:
2014	2.9
Expected benefit payments:
2014	(8.7)
2015	(9.1)
2016	(9.3)
2017	(9.6)
2018	(9.8)
2019 - 2022	(49.7)
Plan Trust [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member] \| Wolf Creek [Member]
Expected contributions:
2014	0.6
Expected benefit payments:
2014	(0.6)
2015	(0.7)
2016	(0.8)
2017	(0.8)
2018	(0.8)
2019 - 2022	(4.4)
Company Assets [Member] \| Pension Benefits [Member]
Expected benefit payments:
2014	(2.8)
2015	(2.8)
2016	(2.8)
2017	(2.7)
2018	(2.7)
2019 - 2022	(12.8)
Company Assets [Member] \| Pension Benefits [Member] \| Wolf Creek [Member]
Expected benefit payments:
2014	(0.2)
2015	(0.2)
2016	(0.2)
2017	(0.2)
2018	(0.2)
2019 - 2022	(1.3)
Company Assets [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member]
Expected benefit payments:
2014	(0.2)
2015	(0.2)
2016	(0.2)
2017	(0.2)
2018	(0.2)
2019 - 2022	(1.0)
Company Assets [Member] \| Other Postretirement Benefit Plans, Defined Benefit [Member] \| Wolf Creek [Member]
Expected benefit payments:
2014	0
2015	0
2016	0
2017	0
2018	0
2019 - 2022	$ 0

Wolf Creek Employee Benefit Plans (Textual) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
401k Savings Plan Matching Contributions	$ 6.9	$ 7.1	$ 7.0
KGE [Member]
Subsidiary's interest, percentage	47.00%
Wolf Creek [Member]
401k Savings Plan Matching Contributions	$ 1.4	$ 1.3	$ 1.3
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, 2013 Y facilities MW phases	Dec. 31, 2012	Dec. 31, 2011
Aggregate Amount of Required Payments [Abstract]
2014	$ 258,293,000
2015	20,653,000
2016	25,762,000
Thereafter	7,463,000
Total amount committed	312,171,000
Environmental Projects [Abstract]
Entity Share of Environmental Upgrades of Jointly Owned Plant	610,000,000
Proposed Increase In Annual Retail Revenues	30,700,000	50,000,000
Air Emissions [Abstract]
Estimated Cost to Comply with Environmental Regulation	17,000,000
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	230,000,000
FERC Investigation [Abstract]
Estimate of possible loss	1,600,000
Settlement consideration	1,600,000
Nuclear Decommissioning [Abstract]
Site study frequency	3
Number of nuclear decommissioning phases	2
phase one of nuclear decommissioning plan	1
phase two of nuclear decommissioning plan	2
Estimated decommissioning costs	296,200,000
Previously estimated decommissioning costs	279,000,000
Decommissioning fund deposits	2,900,000	3,200,000	3,200,000
Total Nuclear Decommissioning Trust	175,625,000	150,754,000
Fee for future disposal of spent nuclear fuel	3,000,000	3,600,000	3,100,000
Nuclear Insurance Industry Aggregate Limit	3,200,000,000
Nuclear Liability Insurance - Full Limit of Public Liability	13,600,000,000
Nuclear Liability Insurance - Maximum Available Commercial Insurance	375,000,000
Nuclear Liability Insurance - Industry-Wide Retrospective Assessment Program	13,200,000,000
Nuclear Liability Insurance - Owners' Insurance Amount Maximum	127,300,000
Nuclear Liability Insurance - Entity Share of Insurance Amount Maximum	59,800,000
Nuclear Liability Insurance - Owners' Insurance Amount, Per Incident	19,000,000
Nuclear Liability Insurance - Entity Share of Insurance Amount, Per Incident	8,900,000
Nuclear Liability Insurance - Owners' Property Insurance, Maximum	2,800,000,000
nuclear liability insurance - owner's property insurance assessment maximum	34,400,000
nuclear liability insurance - equity share, property insurance assessment maximum	16,100,000
Number of Wind Generation Facilities	5
Capacity of wind generation facilities, megawatts	715
Future wind energy purchase costs	68,200,000
Transmission Capacity per Contractual Obligations	306
Net Capacity, in MW	3,099
Cost of Transmission	33,800,000
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
Uranium Concentrates [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	41,300,000
Conversion [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	6,100,000
Enrichment [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	109,000,000
Fabrication [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	41,100,000
Coal and Coal Transportation [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	900,600,000
Natural Gas Transportation [Member]
Nuclear Decommissioning [Abstract]
Long-term purchase commitment	$ 117,200,000
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, 2013	Dec. 31, 2012
Regulatory Liabilities [Line Items]
KGE ownership share	47.00%
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning ARO	$ 152,648	$ 142,508
Liabilities settled	(973)	(1,389)
Accretion expense	9,007	8,454
Revised ARO estimate	0	3,075
Ending ARO	160,682	152,648
Regulatory liability - removal costs	329,556	323,175
Removal Costs [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Regulatory liability - removal costs	$ 114,148	$ 128,971

Common and Preferred Stock (Common Stock Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended	12 Months Ended
	Mar. 31, 2014	Dec. 31, 2013 months	Dec. 31, 2012	Dec. 31, 2011
Common Stock [Line Items]
Common stock, shares authorized		275,000,000	275,000,000	150,000,000
Common stock, shares issued		128,254,229	126,503,748
Forward Sale Agreement, Maximum Amount Authorized		$ 500.0
Forward Sale Agreement, Maximum Shares Authorized		25,000,000
Commissions Paid, Percentage of Sales Price of Shares Sold		1.00%
Forward Contract Indexed to Issuer's Equity, Settlement Period		18
Forward Contract Indexed To Issuers Equity, Indexed Shares For Period	300,000	2,500,000
Forward Contract Indexed to Issuer's Equity, Indexed Shares		12,100,000
Forward Contract Indexed to Issuer's Equity, Estimated Proceeds	$ 9.2	$ 358.3
Average forward price of shares		$ 29.73
Forward Sale Agreement Entered in April Two Thousand And Ten And March Two Thousand And Thriteen [Member]
Common Stock [Line Items]
Forward Contract Indexed to Issuer's Equity, Indexed Shares		3,100,000
Forward Sale Agreement Entered in September Two Thousand And Thriteen [Member]
Common Stock [Line Items]
Forward Contract Indexed to Issuer's Equity, Shares		8,900,000
Commissions Paid, Percentage of Sales Price of Shares Sold		3.50%
Forward Contract Indexed to Issuer's Equity, Settlement Period		24
Shares Borrowed Under Forward Contracts, Price Per Share		$ 31.15
Forward Sale Agreement Entered in September Two Thousand And Thriteen [Member] \| Over Allotment [Member]
Common Stock [Line Items]
Forward Contract Indexed to Issuer's Equity, Shares		900,000
Base Allotment [Member] \| Forward Sale Agreement Entered in September Two Thousand And Thriteen [Member]
Common Stock [Line Items]
Forward Contract Indexed to Issuer's Equity, Shares		8,000,000
Direct Stock Purchase Plan And Other Stock-Based Plans [Member]
Common Stock [Line Items]
Common stock, shares issued		700,000	800,000
DSPP [Member]
Common Stock [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant		2,000,000	1,500,000

Common and Preferred Stock (Preferred Stock Details) (USD $) In Thousands, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Jun. 30, 2012
Preferred Stock, Value, Issued	$ 21,436		$ 0
Preferred stock, shares outstanding	214,363	0
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 Entities (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Variable Interest Entity [Line Items]
Noncontrolling Interest, Decrease from Deconsolidation	$ 14,282
Jeffrey Energy Center [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Percentage of Asset Held	8.00%
Agreement expiration date	Jan. 31, 2019
La Cygne Generating Station [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Percentage of Asset Held	50.00%
Agreement expiration date	Sep. 20, 2029
Railroad Transportation Equipment [Member]
Variable Interest Entity [Line Items]
Agreement expiration date	May 31, 2013
Railroad Transportation Equipment 2 [Member]
Variable Interest Entity [Line Items]
Agreement expiration date	Nov. 30, 2014

Variable Interest Entities (Assets And Liabilities In Relation To VIEs) (Details) (USD $)
In Thousands, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

$ 7,551,916

$ 7,013,765

Regulatory Assets

755,414

1,002,672

250,000

80,457

77,891

Variable Interest Entity [Line Items]

2,968,958

2,819,271

Variable Interest Entity, Primary Beneficiary [Member]

296,626

321,975

Regulatory Assets

6,792

^[1]

5,810

^[1]

27,479

25,942

3,472

^[2]

3,948

^[2]

$ 194,802

$ 222,743

[1]	(a) Included in long-term regulatory assets on our consolidated balance sheets.(b) Included in accrued interest on our consolidated balance sheets.
[2]	Included in accrued interest on our consolidated balance sheets.

Net Income attributable to common stock

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

Leases (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended					12 Months Ended				12 Months Ended
	Dec. 31, 2013 Minimum [Member]	Dec. 31, 2013 Maximum [Member]	Dec. 31, 2013 Generation Tie Line [Member]	Dec. 31, 2013 Vehicles [Member]	Dec. 31, 2012 Vehicles [Member]	Dec. 31, 2013 Vehicles [Member] Minimum [Member] Y	Dec. 31, 2013 Vehicles [Member] Maximum [Member] Y	Dec. 31, 2013 Computer Equipment [Member]	Dec. 31, 2012 Computer Equipment [Member]	Dec. 31, 2013 Computer Equipment [Member] Minimum [Member] Y	Dec. 31, 2013 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
Capital leased assets gross			$ 8,300	$ 12,141	$ 12,594			$ 1,758	$ 1,423

Leases Leases (Operating Leases, Minimum Annual Rental Payments) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Rental expense:
Rental expense	$ 16,484	$ 17,080	$ 17,577
Future commitments:
2013	14,384
2014	11,980
2015	10,232
2016	8,383
2017	5,248
Thereafter	15,361
Total future commitments	$ 65,588

Leases (Assets Recorded Under Capital Leases) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Leases [Line Items]
Accumulated amortization	$ (10,493)	$ (6,928)
Total capital leases	51,752	55,435
Vehicles [Member]
Leases [Line Items]
Capital leased assets gross	12,141	12,594
Computer Equipment [Member]
Leases [Line Items]
Capital leased assets gross	1,758	1,423
Generation Plant [Member]
Leases [Line Items]
Capital leased assets gross	$ 48,346	$ 48,346

Leases (Capital Leases, Minimum Annual Rental Payments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013
Leases [Abstract]
2013	$ 6,464
2014	5,891
2015	5,179
2016	4,711
2017	4,664
Thereafter	72,135
Total future commitments	99,044
Amounts representing imputed interest	(44,992)
Present value of net minimum lease payments under capital leases	54,052
Less: current portion	3,249
Total long-term obligation under capital leases	$ 50,803

Quarterly Results (Unaudited) (Details) (USD $)
In Thousands, except Per Share data, unless otherwise specified

3 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Quarterly Results [Line Items]

Revenues

$ 559,878

^[1]

$ 694,974

^[1]

$ 569,589

^[1]

$ 546,212

^[1]

$ 523,772

^[1]

$ 695,758

^[1]

$ 566,262

^[1]

$ 475,677

^[1]

$ 2,370,654

$ 2,261,470

$ 2,170,991

Net income

43,061

^[1]

135,095

^[1]

69,451

^[1]

53,256

^[1]

47,695

^[1]

141,067

^[1]

64,462

^[1]

29,237

^[1]

300,863

282,462

236,180

$ 41,062

^[1]

$ 133,125

^[1]

$ 67,188

^[1]

$ 51,144

^[1]

$ 45,607

^[1]

$ 139,281

^[1]

$ 61,361

^[1]

$ 27,282

^[1]

$ 292,520

$ 273,530

$ 229,269

Basic: Earnings available

$ 0.32

^[1]

$ 1.04

^[1]

$ 0.53

^[1]

$ 0.40

^[1]

$ 0.36

^[1]

$ 1.10

^[1]

$ 0.48

^[1]

$ 0.21

^[1]

$ 2.29

$ 2.15

$ 1.95

Diluted: Earnings available

$ 0.32

^[1]

$ 1.04

^[1]

$ 0.52

^[1]

$ 0.40

^[1]

$ 0.36

^[1]

$ 1.09

^[1]

$ 0.48

^[1]

$ 0.21

^[1]

$ 2.27

$ 2.15

$ 1.93

Cash dividend declared per common share

$ 0.34

^[1]

$ 0.34

^[1]

$ 0.34

^[1]

$ 0.34

^[1]

$ 0.33

^[1]

$ 0.33

^[1]

$ 0.33

^[1]

$ 0.33

^[1]

$ 1.36

$ 1.32

$ 1.28

High [Member]

Quarterly Results [Line Items]

Market price per common share

$ 32.56

^[1]

$ 34.31

^[1]

$ 34.96

^[1]

$ 33.35

^[1]

$ 30.29

^[1]

$ 33.04

^[1]

$ 30.17

^[1]

$ 29.13

^[1]

Low [Member]

Quarterly Results [Line Items]

Market price per common share

$ 29.95

^[1]

$ 29.79

^[1]

$ 30.13

^[1]

$ 28.59

^[1]

$ 27.33

^[1]

$ 28.96

^[1]

$ 26.80

^[1]

$ 27.12

^[1]

[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.

+ References+ Details