24,514

32,476

Total Current Assets

664,481

643,075

Nuclear decommissioning trust

7,255,280

7,013,765

OTHER ASSETS:

Regulatory assets

866,578

887,777

159,631

150,754

235,777

247,885

Total Other Assets

1,261,986

1,286,416

TOTAL ASSETS

9,483,745

9,265,231

CURRENT LIABILITIES:

Short-term debt

410,000

339,200

Accounts payable

149,680

180,825

Accrued dividends

43,150

41,743

Accrued taxes

74,569

58,624

49,599

^[1]

77,891

^[1]

Regulatory liabilities

42,199

37,557

Total Current Liabilities

90,366

84,359

887,336

846,141

LONG-TERM LIABILITIES:

Unamortized investment tax credits

2,968,642

2,819,271

Deferred income taxes

1,233,893

1,197,837

189,931

191,512

Regulatory liabilities

283,360

285,618

Accrued employee benefits

557,033

564,870

Asset retirement obligations

156,690

152,648

Total Long-Term Liabilities

72,007

74,336

5,656,759

5,508,835

COMMITMENTS AND CONTINGENCIES (See Notes 10 and 11)

Westar Energy, Inc. Shareholders' Equity:

Common stock, par value $5 per share; authorized 275,000,000 shares; issued and outstanding 126,935,051 shares and 126,503,748 shares, respective to each date

634,675

632,519

Paid-in capital

1,664,525

1,656,972

Retained earnings

637,900

606,649

Total Westar Energy, Inc. Shareholders' Equity

2,937,100

2,896,140

Noncontrolling Interests

2,550

14,115

Total Equity

2,939,650

2,910,255

TOTAL LIABILITIES AND EQUITY

9,483,745

9,265,231

Variable Interest Entity [Member]

CURRENT ASSETS:

Current maturities of long-term debt

301,998

321,975

CURRENT LIABILITIES:

27,773

25,942

3,475

^[1]

3,948

^[1]

LONG-TERM LIABILITIES:

Summary Of Significant Accounting Policies

$ 195,203

$ 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	Jun. 30, 2013	Dec. 31, 2012
Allowance for doubtful accounts	$ 3,466	$ 4,916
Common stock, par value	$ 5	$ 5
Common stock, shares authorized	275,000,000	275,000,000
Common stock, shares issued	126,935,051	126,503,748
Common stock, shares outstanding	126,935,051	126,503,748

Consolidated Statements Of Income (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
REVENUES	$ 569,589	$ 566,262	$ 1,115,801	$ 1,041,940
OPERATING EXPENSES:
Fuel and purchased power	152,700	147,680	304,452	275,334
Operating and maintenance	163,303	156,470	322,032	312,514
Depreciation and amortization	67,597	66,299	134,443	139,579
Selling, general and administrative	54,477	62,711	103,422	110,046
Total Operating Expenses	438,077	433,160	864,349	837,473
INCOME FROM OPERATIONS	131,512	133,102	251,452	204,467
OTHER INCOME (EXPENSE):
Investment earnings (losses)	1,690	(598)	5,749	3,727
Other income	13,711	7,537	17,427	21,127
Other expense	(2,354)	(2,416)	(7,715)	(7,969)
Total Other Income	13,047	4,523	15,461	16,885
Interest expense	45,798	44,823	90,082	86,869
INCOME BEFORE INCOME TAXES	98,761	92,802	176,831	134,483
Income tax expense	29,310	28,340	54,123	40,783
NET INCOME	69,451	64,462	122,708	93,700
Less: Net income attributable to noncontrolling interests	2,263	1,728	4,375	3,442
NET INCOME ATTRIBUTABLE TO WESTAR ENERGY, INC.	67,188	62,734	118,333	90,258
Preferred dividends	0	1,373	0	1,616
NET INCOME ATTRIBUTABLE TO COMMON STOCK	$ 67,188	$ 61,361	$ 118,333	$ 88,642
Earnings Per Share [Abstract]
Earnings Per Share, Basic	$ 0.53	$ 0.48	$ 0.93	$ 0.70
Earnings Per Share, Diluted	$ 0.52	$ 0.48	$ 0.92	$ 0.70
AVERAGE EQUIVALENT COMMON SHARES OUTSTANDING
Weighted Average Number of Shares Outstanding , Basic	127,311,411	126,637,067	127,254,250	126,566,071
Weighted Average Number of Shares Outstanding, Diluted	127,930,395	126,876,536	127,735,157	126,744,539
DIVIDENDS DECLARED PER COMMON SHARE	$ 0.34	$ 0.33	$ 0.68	$ 0.66

Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net income	$ 122,708	$ 93,700
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	134,443	139,579
Amortization of nuclear fuel	8,631	9,026
Amortization of deferred regulatory gain from sale leaseback	(2,748)	(2,748)
Amortization of corporate-owned life insurance	4,138	10,921
Non-cash compensation	4,146	3,738
Net deferred income taxes and credits	45,409	33,586
Stock-based compensation excess tax benefits	(399)	(1,498)
Allowance for equity funds used during construction	(5,689)	(6,778)
Changes in working capital items:
Accounts receivable	(15,271)	(51,055)
Fuel inventory and supplies	11,780	(26,830)
Prepaid expenses and other	2,396	17,368
Accounts payable	(24,838)	(8,741)
Accrued taxes	16,196	16,276
Other current liabilities	(58,624)	(61,894)
Changes in other assets	(28,048)	(40,100)
Changes in other liabilities	17,080	(21,371)
Cash Flows from Operating Activities	231,310	103,179
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Additions to property, plant and equipment	(398,998)	(417,617)
Purchase of securities - trusts	(59,986)	(16,817)
Sale of securities - trusts	75,475	18,040
Investment in corporate-owned life insurance	17,408	18,167
Proceeds from investment in corporate-owned life insurance	101,085	16,330
Proceeds from federal grant	876	3,289
Investment in affiliated company	0	(4,505)
Other investing activities	(2,362)	(343)
Cash Flows used in Investing Activities	(301,318)	(419,790)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Short-term debt, net	70,617	62,107
Proceeds from long-term debt	245,813	541,504
Retirements of long-term debt	(100,000)	(220,563)
Repayment of capital leases	(1,539)	(1,287)
Borrowings against cash surrender value of corporate-owned life insurance	57,948	63,287
Repayment of borrowings against cash surrender value of corporate-owned life insurance	(100,060)	(18,252)
Stock-based compensation excess tax benefits	399	1,498
Preferred stock redemption	0	(22,567)
Issuance of common stock	2,992	3,697
Distributions to shareholders of noncontrolling interests	1,658	3,252
Cash dividends paid	(80,886)	(78,710)
Cash Flows from Financing Activities	68,152	319,726
NET CHANGE IN CASH AND CASH EQUIVALENTS	(1,856)	3,115
CASH AND CASH EQUIVALENTS:
Beginning of period	5,829	3,539
End of period	3,973	6,654
Variable Interest Entity [Member]
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Retirements of long-term debt	$ (25,474)	$ (7,736)

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, 2011	$ 2,800,741	$ 21,436	$ 628,492	$ 1,639,503	$ 501,216	$ 10,094
Beginning Balance (Shares) at Dec. 31, 2011		214,363	125,698,396
Net income	93,700	0	0	0	90,258	3,442
Issuance of stock	14,901	0	2,627	12,274	0	0
Issuance of stock (shares)		0	525,452
Stock redemption	(21,436)	(21,436)	0	0	0	0
Stock redemption (shares)		(214,363)	0
Preferred dividends	(1,616)	0	0	0	(1,616)	0
Dividends on common stock	(84,138)	0	0	0	(84,138)	0
Amortization of restricted stock	3,004	0	0	3,004	0	0
Stock compensation and tax benefit	(7,790)	0	0	(7,790)	0	0
Deconsolidation of variable interest entity	0
Distributions to shareholders of noncontrolling interests	3,252	0	0	0	0	3,252
Ending Balance at Jun. 30, 2012	2,794,114	0	631,119	1,646,991	505,720	10,284
Ending Balance (Shares) at Jun. 30, 2012		0	126,223,848
Beginning Balance at Dec. 31, 2012	2,910,255	0	632,519	1,656,972	606,649	14,115
Beginning Balance (Shares) at Dec. 31, 2012		0	126,503,748
Net income	122,708	0	0	0		4,375
Issuance of stock	12,708	0	2,156	10,552	0	0
Issuance of stock (shares)		0	431,303
Preferred dividends	0
Dividends on common stock	(87,082)	0	0	0	(87,082)	0
Amortization of restricted stock	3,326	0	0	3,326	0	0
Stock compensation and tax benefit	(6,325)	0	0	(6,325)	0	0
Deconsolidation of variable interest entity	(14,282)	0	0	0	0	(14,282)
Distributions to shareholders of noncontrolling interests	1,658	0	0	0	0	1,658
Ending Balance at Jun. 30, 2013	$ 2,939,650	$ 0	$ 634,675	$ 1,664,525	$ 637,900	$ 2,550
Ending Balance (Shares) at Jun. 30, 2013		0	126,935,051

Description Of Business	6 Months Ended
Description Of Business	Jun. 30, 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 Quarterly Report on Form 10-Q 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 694,000 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

6 Months Ended

Jun. 30, 2013

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

We prepare our unaudited condensed consolidated financial statements in accordance with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, certain information and footnote disclosures normally included in financial statements presented in accordance with generally accepted accounting principles (GAAP) have been condensed or omitted. Our condensed 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. In our opinion, all adjustments, consisting only of normal recurring adjustments considered necessary for a fair presentation of the consolidated financial statements, have been included.

The accompanying condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes included in our 2012 Form 10-K.

Use of Management's Estimates

When we prepare our condensed 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 condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. We evaluate our estimates on an on-going basis, including those related to depreciation, unbilled revenue, valuation of investments, forecasted fuel costs included in our retail energy cost adjustment billed to customers, income taxes, pension and post-retirement benefits, our asset retirement obligations including the decommissioning of Wolf Creek, environmental issues, VIEs, contingencies and litigation. Actual results may differ from those estimates under different assumptions or conditions. The results of operations for the three and six months ended June 30, 2013, are not necessarily indicative of the results to be expected for the full year.

Restricted Cash

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

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		As of
	June 30, 2013		December 31, 2012
	(In Thousands)
Fuel inventory	$	88,453	$	94,664
Supplies	151,044		154,352
Fuel inventory and supplies	$	239,497	$	249,016

Allowance for Funds Used During Construction

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 as follows:



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(Dollars In Thousands)
Borrowed funds	$	2,583		$	2,440		$	5,168		$	5,959
Equity funds	2,943			2,838			5,689			6,778
Total	$	5,526		$	5,278		$	10,857		$	12,737
Average AFUDC Rates	4.3		%	4.9		%	4.3		%	5.4		%

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.



	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	69,451	$	64,462	$	122,708	$	93,700
Less: Net income attributable to noncontrolling interests	2,263		1,728		4,375		3,442
Net income attributable to Westar Energy, Inc.	67,188		62,734		118,333		90,258
Less: Preferred dividends	—		1,373		—		1,616
Net income allocated to RSUs	196		182		339		265
Net income allocated to common stock	$	66,992	$	61,179	$	117,994	$	88,377

Weighted average equivalent common shares outstanding – basic	127,311,411		126,637,067		127,254,250		126,566,071
Effect of dilutive securities:
RSUs	53,570		190,422		45,567		155,340
Forward sale agreements	565,414		49,047		435,340		23,128
Weighted average equivalent common shares outstanding – diluted (a)	127,930,395		126,876,536		127,735,157		126,744,539

Earnings per common share, basic	$	0.53	$	0.48	$	0.93	$	0.70
Earnings per common share, diluted	$	0.52	$	0.48	$	0.92	$	0.70

_______________


(a)	We had no antidilutive shares for the three and six months ended June 30, 2013 and 2012.

Supplemental Cash Flow Information



	Six Months Ended June 30,
	2013			2012
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	73,853		$	68,939
Interest on financing activities of VIEs	7,349			8,281
Income taxes, net of refunds	(86		)	(4,635		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	56,187			37,736
Property, plant and equipment of VIEs	(14,282		)	—
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	6,316			4,920
Deconsolidation of VIE	(14,282		)	—
Assets acquired through capital leases	326			1,543

Rate Matters And Regulation	6 Months Ended
Rate Matters And Regulation	Jun. 30, 2013
Regulated Operations [Abstract]
Rate Matters And Regulation	RATE MATTERS AND REGULATION KCC Proceedings In July 2013, the Kansas Corporation Commission (KCC) issued an order allowing us to adjust our prices to include updated transmission costs as reflected in the transmission formula rate discussed below. The new prices were effective in March 2013 and are expected to increase our annual retail revenues by approximately $11.8 million. In May 2013, the KCC issued an order allowing us to adjust our prices to include costs associated with 2012 investments in environmental projects. The new prices were effective in June 2013 and are expected to increase our annual retail revenues by approximately $27.3 million. In April 2013, we filed with the KCC for an abbreviated rate review to adjust our prices to include $333.4 million of additional investment in the La Cygne Generating Station (La Cygne) environmental upgrades and to reflect cost reductions elsewhere. If approved, we estimate that the new prices will increase our annual retail revenues by approximately $31.7 million. We expect the KCC to issue an order on our request in late 2013. FERC Proceedings Our transmission formula rate that includes projected 2013 transmission capital expenditures and operating costs was effective in January 2013 and is expected to increase our annual transmission revenues by approximately $12.2 million. This updated rate provided the basis for our request with the KCC to adjust our retail prices to include updated transmission costs as discussed above.

Financial and Derivative Instruments and Trading Securities

6 Months Ended

Jun. 30, 2013

Financial And Derivative Instruments and Trading Securities [Abstract]

Financial And Derivative Instruments And Trading Securities

FINANCIAL AND DERIVATIVE 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 are 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 June 30, 2013				As of December 31, 2012
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In Thousands)
Fixed-rate debt	$	2,852,500	$	3,094,753	$	2,702,500	$	3,178,752
Fixed-rate debt of VIEs	222,149		245,022		247,624		275,341

Recurring Fair Value Measurements

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



As of June 30, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity	$	—	$	44,571	$	5,014	$	49,585
International equity	—		28,118		—		28,118
Core bonds	—		16,423		—		16,423
High-yield bonds	—		12,171		—		12,171
Emerging market bonds	—		9,949		—		9,949
Other fixed income	—		4,605		—		4,605
Combination debt/equity/other funds	—		15,377		—		15,377
Alternative investments	—		—		15,234		15,234
Real estate securities	—		—		8,161		8,161
Cash equivalents	8		—		—		8
Total Nuclear Decommissioning Trust	8		131,214		28,409		159,631
Trading Securities (a):
Domestic equity	—		16,812		—		16,812
International equity	—		4,175		—		4,175
Core bonds	—		11,297		—		11,297
Cash equivalents	166		—		—		166
Total Trading Securities	166		32,284		—		32,450
Total Assets Measured at Fair Value	$	174	$	163,498	$	28,409	$	192,081

As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
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 $14.3 million.

The following table provides reconciliations of assets and liabilities measured at fair value using significant level 3 inputs for the three and six months ended June 30, 2013.



	Domestic Equity			Alternative Investments		Real Estate Securities			Net Balance
	(In Thousands)
Balance as of March 31, 2013	$	4,785		$	15,000	$	8,027		$	27,812
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	229			234		134			597
Purchases	72			—		71			143
Sales	(72		)	—		(71		)	(143		)
Balance as of June 30, 2013	$	5,014		$	15,234	$	8,161		$	28,409

Balance as of December 31, 2012	$	4,899		$	—	$	7,865		$	12,764
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	197			234		296			727
Purchases	135			15,000		140			15,275
Sales	(217		)	—		(140		)	(357		)
Balance as of June 30, 2013	$	5,014		$	15,234	$	8,161		$	28,409

The following table provides reconciliations of assets and liabilities measured at fair value using significant level 3 inputs for the three and six months ended June 30, 2012.



	Domestic Equity			Real Estate Securities			Net Balance
	(In Thousands)
Balance as of March 31, 2012	$	4,100		$	7,271		$	11,371
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	104			178			282
Purchases	589			62			651
Sales	(13		)	(62		)	(75		)
Balance as of June 30, 2012	$	4,780		$	7,449		$	12,229

Balance as of December 31, 2011	$	3,931		$	7,095		$	11,026
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	193			354			547
Purchases	669			122			791
Sales	(13		)	(122		)	(135		)
Balance as of June 30, 2012	$	4,780		$	7,449		$	12,229

Portions of the gains and losses contributing to changes in net assets in the above tables are unrealized. The following tables summarize the unrealized gains and losses we recorded on our consolidated financial statements during the three and six months ended June 30, 2013 and 2012, attributed to level 3 assets and liabilities.



	Three Months Ended June 30, 2013
	Nuclear Decommissioning Trust
	Domestic Equity			Alternative Investments		Real Estate Securities		Net Balance
	(In Thousands)
Total unrealized gains (losses) included in:
Regulatory liabilities	$	157		$	234	$	62	$	453

	Six Months Ended June 30, 2013
Total unrealized gains (losses) included in:
Regulatory liabilities	$	(20	)	$	234	$	155	$	369



	Three Months Ended June 30, 2012
	Nuclear Decommissioning Trust
	Domestic Equity		Real Estate Securities		Net Balance
	(In Thousands)
Total unrealized gains (losses) included in:
Regulatory liabilities	$	91	$	116	$	207

	Six Months Ended June 30, 2012
Total unrealized gains (losses) included in:
Regulatory liabilities	$	180	$	232	$	412

Some of our investments in the nuclear decommissioning trust (NDT) and our trading securities portfolio are measured at net asset value and do not have readily determinable fair values. These investments 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 June 30, 2013				As of December 31, 2012				As of June 30, 2013
	Fair Value		Unfunded Commitments		Fair Value		Unfunded Commitments		Redemption Frequency	Length of Settlement
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity	$	5,014	$	889	$	4,899	$	1,024	(a)	(a)
Alternative investments	15,234		—		—		—		(b)	(b)
Real estate securities	8,161		—		7,865		—		Quarterly	80 days
Total Nuclear Decommissioning Trust	28,409		889		12,764		1,024

Trading Securities:
Domestic equity	16,812		—		22,470		—		Upon Notice	1 day
International equity	4,175		—		5,744		—		Upon Notice	1 day
Core bonds	11,297		—		15,104		—		Upon Notice	1 day
Total Trading Securities	32,284		—		43,318		—
Total	$	60,693	$	889	$	56,082	$	1,024

_______________


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


(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.

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 interest rates. Volatility in these markets impacts our costs of purchased power and costs of fuel for our generating plants. We strive to manage our customers' and our exposure to the market risks through regulatory, operating and financing activities.

Interest Rate Risk

We have entered into numerous fixed and variable rate debt obligations. 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

6 Months Ended

Jun. 30, 2013

Investments [Abstract]

Financial Investments

FINANCIAL INVESTMENTS

We report some of 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 in a trust used to fund retirement benefits that we classify as trading securities. We include unrealized gains or losses on these securities in investment earnings on our consolidated statements of income. For the three and six months ended June 30, 2013, we recorded unrealized losses on these investments of $6.2 million and $3.7 million, respectively. For the three and six months ended June 30, 2012, we recorded an unrealized loss of $1.8 million and unrealized gain of $1.8 million respectively.

Available-for-Sale Securities

We hold investments in equity, debt and real estate securities in a trust for the purpose of funding the decommissioning of Wolf Creek. We have classified these investments as available-for-sale and have recorded all such investments at their fair market value as of June 30, 2013, and December 31, 2012. As of June 30, 2013, the fair value of available-for-sale bond funds was $43.1 million. The NDT did not have investments in debt securities outside of investment funds as of June 30, 2013.

Using the specific identification method to determine cost, we realized gains on our available-for-sale securities of $3.2 million and $4.5 million, respectively, during the three and six months ended June 30, 2013. During the three and six months ended June 30, 2012, we realized gains of $0.4 million and $0.6 million, respectively. 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 June 30, 2013, and December 31, 2012.



			Gross Unrealized
Security Type	Cost		Gain		Loss			Fair Value		Allocation
	(Dollars In Thousands)
As of June 30, 2013
Domestic equity	$	38,515	$	11,071	$	(1	)	$	49,585	30	%
International equity	26,301		2,299		(482		)	28,118		18	%
Core bonds	16,404		19		—			16,423		10	%
High-yield bonds	11,554		617		—			12,171		8	%
Emerging market bonds	10,462		—		(513		)	9,949		6	%
Other fixed income	4,616		—		(11		)	4,605		3	%
Combination debt/equity/other funds	14,377		1,342		(342		)	15,377		10	%
Alternative investments	15,000		234		—			15,234		10	%
Real estate securities	10,122		—		(1,961		)	8,161		5	%
Cash equivalents	8		—		—			8		<1%
Total	$	147,359	$	15,582	$	(3,310	)	$	159,631	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 June 30, 2013, and December 31, 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 June 30, 2013
Domestic equity	$	1,543	$	(1	)	$	—	$	—		$	1,543	$	(1	)
International equity	5,712		(482		)	—		—			5,712		(482		)
Emerging market bonds	9,949		(513		)	—		—			9,949		(513		)
Other fixed income	4,605		(11		)	—		—			4,605		(11		)
Combination debt/equity/other funds	5,854		(342		)	—		—			5,854		(342		)
Real estate securities	—		—			8,161		(1,961		)	8,161		(1,961		)
Total	$	27,663	$	(1,349	)	$	8,161	$	(1,961	)	$	35,824	$	(3,310	)

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

Debt Financing	6 Months Ended
Debt Financing	Jun. 30, 2013
Long-term Debt, Unclassified [Abstract]
Debt Financing	DEBT FINANCING In June 2013, KGE redeemed two pollution control bond issues with an aggregate principal amount of $100.0 million and stated interest rates of 5.60% and 6.00%. In March 2013, Westar Energy issued $250.0 million principal amount of first mortgage bonds bearing stated interest of 4.10% and maturing in April 2043. Proceeds were used to repay short-term debt, which had been used primarily to purchase capital equipment, to redeem bonds and for working capital and general corporate purposes.

Taxes	6 Months Ended
Taxes	Jun. 30, 2013
Income Tax Disclosure [Abstract]
Taxes	TAXES We recorded income tax expense of $29.3 million with an effective income tax rate of 30% for the three months ended June 30, 2013, and income tax expense of $28.3 million with an effective income tax rate of 31% for the same period of 2012. We recorded income tax expense of $54.1 million with an effective income tax rate of 31% for the six months ended June 30, 2013, and income tax expense of $40.8 million with an effective income tax rate of 30% for the same period of 2012. The decrease in the effective income tax rate for the three months ended June 30, 2013, was due primarily to an increase in non-taxable income from corporate-owned life insurance (COLI). The Internal Revenue Service (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. As of June 30, 2013, and December 31, 2012, our liability for unrecognized income tax benefits was $1.2 million. We do not expect significant changes in this liability in the next 12 months. As of June 30, 2013, and December 31, 2012, we had $0.2 million accrued for interest on our liability related to unrecognized income tax benefits. We accrued no penalties at either June 30, 2013, or December 31, 2012. As of June 30, 2013, and December 31, 2012, we had recorded $1.5 million for probable assessments of taxes other than income taxes.

Pension and Post-Retirement Benefit Plans

6 Months Ended

Jun. 30, 2013

Compensation and Retirement Disclosure [Abstract]

Pension And Post-Retirement Benefit Plans

PENSION AND POST-RETIREMENT BENEFIT PLANS

The following tables summarize the net periodic costs for our pension and post-retirement benefit plans prior to the effects of capitalization.



	Pension Benefits						Post-retirement Benefits
Three Months Ended June 30,	2013			2012			2013			2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	5,355		$	4,889		$	507		$	514
Interest cost	9,630			9,894			1,502			1,574
Expected return on plan assets	(8,351		)	(8,070		)	(1,672		)	(1,372		)
Amortization of unrecognized:
Transition obligation, net	—			—			81			978
Prior service costs	150			153			631			631
Actuarial loss, net	8,479			8,194			281			376
Net periodic cost before regulatory adjustment	15,263			15,060			1,330			2,701
Regulatory adjustment (a)	783			(2,005		)	717			(278		)
Net periodic cost	$	16,046		$	13,055		$	2,047		$	2,423

_______________


(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.



	Pension Benefits						Post-retirement Benefits
Six Months Ended June 30,	2013			2012			2013			2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	10,710		$	9,777		$	1,014		$	1,029
Interest cost	19,260			19,789			3,004			3,149
Expected return on plan assets	(16,702		)	(16,142		)	(3,345		)	(2,746		)
Amortization of unrecognized:
Transition obligation, net	—			—			162			1,956
Prior service costs	300			307			1,262			1,262
Actuarial loss, net	16,957			16,389			562			752
Net periodic cost before regulatory adjustment	30,525			30,120			2,659			5,402
Regulatory adjustment (a)	1,567			(9,250		)	1,434			40
Net periodic cost	$	32,092		$	20,870		$	4,093		$	5,442

_______________


(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.

During the six months ended June 30, 2013 and 2012, we contributed $17.7 million and $49.4 million, respectively, to the Westar Energy pension trust.

Wolf Creek Pension and Post-Retirement Benefit Plans

6 Months Ended

Jun. 30, 2013

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

Wolf Creek Pension And Post-Retirement Benefit Plans

WOLF CREEK 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. The following tables summarize the net periodic costs for KGE's 47% share of the Wolf Creek pension and post-retirement benefit plans prior to the effects of capitalization.



	Pension Benefits						Post-retirement Benefits
Three Months Ended June 30,	2013			2012			2013		2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	1,708		$	1,516		$	52	$	48
Interest cost	1,891			1,884			103		103
Expected return on plan assets	(1,843		)	(1,644		)	—		—
Amortization of unrecognized:
Transition obligation, net	—			—			—		14
Prior service costs	14			1			—		—
Actuarial loss, net	1,355			1,341			66		58
Net periodic cost before regulatory adjustment	3,125			3,098			221		223
Regulatory adjustment (a)	(203		)	(484		)	—		—
Net periodic cost	$	2,922		$	2,614		$	221	$	223

_______________


(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.



	Pension Benefits						Post-retirement Benefits
Six Months Ended June 30,	2013			2012			2013		2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	3,417		$	3,031		$	104	$	96
Interest cost	3,782			3,769			206		205
Expected return on plan assets	(3,686		)	(3,289		)	—		—
Amortization of unrecognized:
Transition obligation, net	—			—			—		29
Prior service costs	28			3			—		—
Actuarial loss, net	2,710			2,683			132		117
Net periodic cost before regulatory adjustment	6,251			6,197			442		447
Regulatory adjustment (a)	(406		)	(1,514		)	—		—
Net periodic cost	$	5,845		$	4,683		$	442	$	447

_______________


(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.

During the six months ended June 30, 2013 and 2012, we funded $3.7 million and $9.0 million, respectively, of Wolf Creek's pension plan contributions.

Commitments And Contingencies	6 Months Ended
Commitments And Contingencies	Jun. 30, 2013
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES 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, however, we cannot at this time predict the impact it may have on our operations or consolidated financial results, but it could be material. In 2010 the EPA strengthened the NAAQS for both NOx and SO₂. We continue to communicate with our regulators regarding these standards and are currently evaluating what impact this could have on our operations. If we are required to install additional equipment to control emissions at our facilities, the revised NAAQS could have a material impact on our operations and consolidated financial results. Environmental Projects We will continue to make significant capital and operating expenditures at our power plants to reduce regulated emissions. The amount of these expenditures could change materially depending on the timing and nature of required investments, the specific outcomes resulting from existing regulations, new regulations, legislation and the manner in which we operate the plants. In addition to the capital investment, in the event we install new equipment, such equipment may cause us to incur significant increases in annual operating and maintenance expense and may reduce the net production, reliability and availability of the plants. The degree to which we will need to reduce emissions and the timing of when such emissions controls may be required is uncertain. Additionally, our ability to access capital markets and the availability of materials, equipment and contractors may affect the timing and ultimate amount of such capital investments. In comparison to a general rate review, the environmental cost recovery rider (ECRR) reduces the amount of time it takes to begin collecting in retail prices the costs associated with capital expenditures for qualifying environmental improvements. We are not allowed to use the ECRR to collect cost associated with our approximately $610.0 million share of the projected capital investment associated with the $1.2 billion of environmental upgrades at La Cygne. We therefore must file for a general review of our rates or an abbreviated rate review with the KCC in order to collect these costs. The KCC approved our request to file an abbreviated rate review to collect a portion of these costs. 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, which replaces the prior federal Clean Air Mercury Rule (CAMR) and requires significant reductions in mercury, acid gases and other emissions. Companies impacted by the new standards will have up to three years, or four years with approval from a state environmental regulatory agency, and in certain limited circumstances up to five years, from the effective date to comply. We have obtained approval from our state environmental regulatory agency and expect to be compliant with the new standards by April 2016. We continue to evaluate the new standards and believe that our related investment will be less than $16.0 million. Additionally, in March 2013, the EPA finalized updates to certain emission limits for new power plants under MATS. We are currently evaluating these updates; however, because of environmental upgrades we have made and continue to make at our power plants to comply with regional haze requirements and the EPA consent decree discussed below, we believe the EPA's updates will have an immaterial impact on our future generation plans. In 2011 the EPA finalized the Cross-State Air Pollution Rule (CSAPR) requiring 28 states, including Kansas, Missouri and Oklahoma, to further reduce power plant emissions of SO₂ and NOx. Under CSAPR, reductions in annual SO₂ and NOx emissions were required to begin January 2012, with further reductions required beginning January 2014. In August 2012, the U.S. Court of Appeals for the District of Columbia Circuit vacated CSAPR and remanded the rule to the EPA to promulgate a replacement. In October 2012, the EPA filed a petition with the circuit court requesting a rehearing before the full court, which was declined in January 2013. The EPA subsequently petitioned the U.S. Supreme Court to review the circuit court's ruling and the petition was granted in June 2013. We cannot at this time predict the outcome of the U.S. Supreme Court's review; however, based on our current and planned environmental controls, if the regulations were to be reinstated or replaced, either in part or in whole, we do not believe the impact on our operations and consolidated financial results would be material. Greenhouse Gases Under regulations known as the Tailoring Rule, the EPA regulates 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 future operations and consolidated financial results, but we believe the cost of compliance with the regulations could be material. Renewable Energy Standard Kansas law mandates that we maintain a minimum amount of renewable energy sources. Through 2015 net renewable generation capacity must be 10% of the average peak demand for the three prior years, subject to limited exceptions. This requirement increases to 15% for years 2016 through 2019 and 20% for 2020 and thereafter. With our existing wind generation facilities, supply contracts and renewable energy credits, we are able to satisfy the net renewable generation requirement through 2015 and we are on track to meet the increased requirements beginning in 2016. If we are unable to meet future requirements, our operations and consolidated financial results could be adversely impacted. EPA Consent Decree As part of a 2010 settlement of a lawsuit filed by the Department of Justice on behalf of the EPA, we are installing selective catalytic reduction (SCR) equipment on one of three Jeffrey Energy Center (JEC) coal units by the end of 2014, which we estimate will cost approximately $240.0 million. The settlement also required that we determine whether we needed to install additional SCR equipment on another JEC unit or if we can meet agreed upon plant-wide NOx emissions reduction limits using other controls. We have informed the EPA that we believe we can meet the terms of the settlement by installing less expensive NOx reduction equipment rather than additional SCR equipment. We plan to complete these projects in 2014 and to recover the costs to install the equipment through our ECRR, but such recovery remains subject to the approval of our regulators.

Legal Proceedings	6 Months Ended
Legal Proceedings	Jun. 30, 2013
Legal Proceedings [Abstract]
Legal Proceedings	LEGAL PROCEEDINGS We and our subsidiaries are involved in various legal, environmental and regulatory proceedings. We believe that adequate provisions have been made and accordingly believe that the ultimate disposition of such matters will not have a material effect on our consolidated financial results. See Note 3, "Rate Matters and Regulation," and Note 10, "Commitments and Contingencies," for additional information.

Common Stock	6 Months Ended
Common Stock	Jun. 30, 2013
Class of Stock [Line Items]
Common Stock	COMMON STOCK In addition to forward sale transactions entered into during prior periods, during the six months ended June 30, 2013, Westar Energy entered into transactions with respect to an aggregate of approximately 2.2 million shares of common stock. Westar Energy must settle such transactions within 18 months of the date each transaction was entered. Assuming physical share settlement of the approximately 4.0 million shares associated with all forward sale transactions as of June 30, 2013, Westar Energy would have received aggregate proceeds of approximately $115.8 million based on a forward price of $29.23 per share. In March 2013, Westar Energy entered into a new, three-year sales agency financing agreement and master forward sale agreement. The maximum amount that Westar Energy may offer and sell under the agreements is the lesser of an aggregate of $500.0 million or approximately 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 sales agency financing agreement and master forward sale agreement, Westar Energy may from time to time enter into one or more forward sale transactions with the bank, as forward purchaser, and the bank will borrow shares of Westar Energy's common stock from third parties and sell them through its 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. The forward sale transactions are entered into at market prices; therefore, the forward sale agreements have no initial fair value. Westar Energy will 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.

Variable Interest Entities

6 Months Ended

Jun. 30, 2013

Variable Interest Entities [Abstract]

Variable Interest Entities

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. The primary beneficiary of a VIE is required 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		As of
	June 30, 2013		December 31, 2012
	(In Thousands)
Assets:
Property, plant and equipment of variable interest entities, net	$	301,998	$	321,975
Regulatory assets (a)	6,330		5,810

Liabilities:
Current maturities of long-term debt of variable interest entities	$	27,773	$	25,942
Accrued interest (b)	3,475		3,948
Long-term debt of variable interest entities, net	195,203		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 recorded no gain or loss upon initial consolidation of the VIEs or upon deconsolidation of the rail car VIE.

Summary Of Significant Accounting Policies (Policy)

6 Months Ended

Jun. 30, 2013

Accounting Policies [Abstract]

Principles Of Consolidation

Principles of Consolidation

Use Of Management's Estimates

Use of Management's Estimates

Restricted Cash

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

Fuel Inventory And Supplies

Fuel Inventory and Supplies

We state fuel inventory and supplies at average cost.

Allowance For Funds Used During Construction

Allowance for Funds Used During Construction

Earnings Per Share

Supplemental Cash Flow Information



	Six Months Ended June 30,
	2013			2012
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	73,853		$	68,939
Interest on financing activities of VIEs	7,349			8,281
Income taxes, net of refunds	(86		)	(4,635		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	56,187			37,736
Property, plant and equipment of VIEs	(14,282		)	—
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	6,316			4,920
Deconsolidation of VIE	(14,282		)	—
Assets acquired through capital leases	326			1,543

Summary Of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2013

Accounting Policies [Abstract]

Schedule of Utility Inventory

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



	As of		As of
	June 30, 2013		December 31, 2012
	(In Thousands)
Fuel inventory	$	88,453	$	94,664
Supplies	151,044		154,352
Fuel inventory and supplies	$	239,497	$	249,016

Allowance For Funds Used During Construction

on the accompanying consolidated statements of income as follows:



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(Dollars In Thousands)
Borrowed funds	$	2,583		$	2,440		$	5,168		$	5,959
Equity funds	2,943			2,838			5,689			6,778
Total	$	5,526		$	5,278		$	10,857		$	12,737
Average AFUDC Rates	4.3		%	4.9		%	4.3		%	5.4		%

Reconciliation Of Basic And Diluted EPS

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



	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	69,451	$	64,462	$	122,708	$	93,700
Less: Net income attributable to noncontrolling interests	2,263		1,728		4,375		3,442
Net income attributable to Westar Energy, Inc.	67,188		62,734		118,333		90,258
Less: Preferred dividends	—		1,373		—		1,616
Net income allocated to RSUs	196		182		339		265
Net income allocated to common stock	$	66,992	$	61,179	$	117,994	$	88,377

Weighted average equivalent common shares outstanding – basic	127,311,411		126,637,067		127,254,250		126,566,071
Effect of dilutive securities:
RSUs	53,570		190,422		45,567		155,340
Forward sale agreements	565,414		49,047		435,340		23,128
Weighted average equivalent common shares outstanding – diluted (a)	127,930,395		126,876,536		127,735,157		126,744,539

Earnings per common share, basic	$	0.53	$	0.48	$	0.93	$	0.70
Earnings per common share, diluted	$	0.52	$	0.48	$	0.92	$	0.70

_______________


(a)	We had no antidilutive shares for the three and six months ended June 30, 2013 and 2012.

Supplemental Cash Flow Information



	Six Months Ended June 30,
	2013			2012
	(In Thousands)
CASH PAID FOR (RECEIVED FROM):
Interest on financing activities, net of amount capitalized	$	73,853		$	68,939
Interest on financing activities of VIEs	7,349			8,281
Income taxes, net of refunds	(86		)	(4,635		)
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	56,187			37,736
Property, plant and equipment of VIEs	(14,282		)	—
NON-CASH FINANCING TRANSACTIONS:
Issuance of common stock for reinvested dividends and compensation plans	6,316			4,920
Deconsolidation of VIE	(14,282		)	—
Assets acquired through capital leases	326			1,543

Financial and Derivative Instruments and Trading Securities (Tables)

6 Months Ended

Jun. 30, 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 June 30, 2013				As of December 31, 2012
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In Thousands)
Fixed-rate debt	$	2,852,500	$	3,094,753	$	2,702,500	$	3,178,752
Fixed-rate debt of VIEs	222,149		245,022		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 that are measured at fair value.



As of June 30, 2013	Level 1		Level 2		Level 3		Total
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity	$	—	$	44,571	$	5,014	$	49,585
International equity	—		28,118		—		28,118
Core bonds	—		16,423		—		16,423
High-yield bonds	—		12,171		—		12,171
Emerging market bonds	—		9,949		—		9,949
Other fixed income	—		4,605		—		4,605
Combination debt/equity/other funds	—		15,377		—		15,377
Alternative investments	—		—		15,234		15,234
Real estate securities	—		—		8,161		8,161
Cash equivalents	8		—		—		8
Total Nuclear Decommissioning Trust	8		131,214		28,409		159,631
Trading Securities (a):
Domestic equity	—		16,812		—		16,812
International equity	—		4,175		—		4,175
Core bonds	—		11,297		—		11,297
Cash equivalents	166		—		—		166
Total Trading Securities	166		32,284		—		32,450
Total Assets Measured at Fair Value	$	174	$	163,498	$	28,409	$	192,081

As of December 31, 2012	Level 1		Level 2		Level 3		Total
	(In Thousands)
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 $14.3 million.

Reconciliations Of Assets And Liabilities At Fair Value

The following table provides reconciliations of assets and liabilities measured at fair value using significant level 3 inputs for the three and six months ended June 30, 2013.



	Domestic Equity			Alternative Investments		Real Estate Securities			Net Balance
	(In Thousands)
Balance as of March 31, 2013	$	4,785		$	15,000	$	8,027		$	27,812
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	229			234		134			597
Purchases	72			—		71			143
Sales	(72		)	—		(71		)	(143		)
Balance as of June 30, 2013	$	5,014		$	15,234	$	8,161		$	28,409

Balance as of December 31, 2012	$	4,899		$	—	$	7,865		$	12,764
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	197			234		296			727
Purchases	135			15,000		140			15,275
Sales	(217		)	—		(140		)	(357		)
Balance as of June 30, 2013	$	5,014		$	15,234	$	8,161		$	28,409

The following table provides reconciliations of assets and liabilities measured at fair value using significant level 3 inputs for the three and six months ended June 30, 2012.



	Domestic Equity			Real Estate Securities			Net Balance
	(In Thousands)
Balance as of March 31, 2012	$	4,100		$	7,271		$	11,371
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	104			178			282
Purchases	589			62			651
Sales	(13		)	(62		)	(75		)
Balance as of June 30, 2012	$	4,780		$	7,449		$	12,229

Balance as of December 31, 2011	$	3,931		$	7,095		$	11,026
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	193			354			547
Purchases	669			122			791
Sales	(13		)	(122		)	(135		)
Balance as of June 30, 2012	$	4,780		$	7,449		$	12,229

Unrealized Gains And Losses On Fair Value Assets And Liabilities

The following tables summarize the unrealized gains and losses we recorded on our consolidated financial statements during the three and six months ended June 30, 2013 and 2012, attributed to level 3 assets and liabilities.



	Three Months Ended June 30, 2013
	Nuclear Decommissioning Trust
	Domestic Equity			Alternative Investments		Real Estate Securities		Net Balance
	(In Thousands)
Total unrealized gains (losses) included in:
Regulatory liabilities	$	157		$	234	$	62	$	453

	Six Months Ended June 30, 2013
Total unrealized gains (losses) included in:
Regulatory liabilities	$	(20	)	$	234	$	155	$	369



	Three Months Ended June 30, 2012
	Nuclear Decommissioning Trust
	Domestic Equity		Real Estate Securities		Net Balance
	(In Thousands)
Total unrealized gains (losses) included in:
Regulatory liabilities	$	91	$	116	$	207

	Six Months Ended June 30, 2012
Total unrealized gains (losses) included in:
Regulatory liabilities	$	180	$	232	$	412

Investments In Financial Instruments

The following table provides additional information on these investments.



	As of June 30, 2013				As of December 31, 2012				As of June 30, 2013
	Fair Value		Unfunded Commitments		Fair Value		Unfunded Commitments		Redemption Frequency	Length of Settlement
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity	$	5,014	$	889	$	4,899	$	1,024	(a)	(a)
Alternative investments	15,234		—		—		—		(b)	(b)
Real estate securities	8,161		—		7,865		—		Quarterly	80 days
Total Nuclear Decommissioning Trust	28,409		889		12,764		1,024

Trading Securities:
Domestic equity	16,812		—		22,470		—		Upon Notice	1 day
International equity	4,175		—		5,744		—		Upon Notice	1 day
Core bonds	11,297		—		15,104		—		Upon Notice	1 day
Total Trading Securities	32,284		—		43,318		—
Total	$	60,693	$	889	$	56,082	$	1,024

_______________


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


(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.

- Definition

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)

6 Months Ended

Jun. 30, 2013

Investments [Abstract]

Cost And Fair Value Of Investments

The following table presents the cost, gross unrealized gains and losses, fair value and allocation of investments in the NDT fund as of June 30, 2013, and December 31, 2012.



			Gross Unrealized
Security Type	Cost		Gain		Loss			Fair Value		Allocation
	(Dollars In Thousands)
As of June 30, 2013
Domestic equity	$	38,515	$	11,071	$	(1	)	$	49,585	30	%
International equity	26,301		2,299		(482		)	28,118		18	%
Core bonds	16,404		19		—			16,423		10	%
High-yield bonds	11,554		617		—			12,171		8	%
Emerging market bonds	10,462		—		(513		)	9,949		6	%
Other fixed income	4,616		—		(11		)	4,605		3	%
Combination debt/equity/other funds	14,377		1,342		(342		)	15,377		10	%
Alternative investments	15,000		234		—			15,234		10	%
Real estate securities	10,122		—		(1,961		)	8,161		5	%
Cash equivalents	8		—		—			8		<1%
Total	$	147,359	$	15,582	$	(3,310	)	$	159,631	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 June 30, 2013
Domestic equity	$	1,543	$	(1	)	$	—	$	—		$	1,543	$	(1	)
International equity	5,712		(482		)	—		—			5,712		(482		)
Emerging market bonds	9,949		(513		)	—		—			9,949		(513		)
Other fixed income	4,605		(11		)	—		—			4,605		(11		)
Combination debt/equity/other funds	5,854		(342		)	—		—			5,854		(342		)
Real estate securities	—		—			8,161		(1,961		)	8,161		(1,961		)
Total	$	27,663	$	(1,349	)	$	8,161	$	(1,961	)	$	35,824	$	(3,310	)

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

Pension and Post-Retirement Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2013

Defined Benefit Plan Disclosure [Line Items]

Schedule of Net Periodic Benefit Costs [Table Text Block]

The following tables summarize the net periodic costs for our pension and post-retirement benefit plans prior to the effects of capitalization.



	Pension Benefits						Post-retirement Benefits
Three Months Ended June 30,	2013			2012			2013			2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	5,355		$	4,889		$	507		$	514
Interest cost	9,630			9,894			1,502			1,574
Expected return on plan assets	(8,351		)	(8,070		)	(1,672		)	(1,372		)
Amortization of unrecognized:
Transition obligation, net	—			—			81			978
Prior service costs	150			153			631			631
Actuarial loss, net	8,479			8,194			281			376
Net periodic cost before regulatory adjustment	15,263			15,060			1,330			2,701
Regulatory adjustment (a)	783			(2,005		)	717			(278		)
Net periodic cost	$	16,046		$	13,055		$	2,047		$	2,423

_______________


(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.



	Pension Benefits						Post-retirement Benefits
Six Months Ended June 30,	2013			2012			2013			2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	10,710		$	9,777		$	1,014		$	1,029
Interest cost	19,260			19,789			3,004			3,149
Expected return on plan assets	(16,702		)	(16,142		)	(3,345		)	(2,746		)
Amortization of unrecognized:
Transition obligation, net	—			—			162			1,956
Prior service costs	300			307			1,262			1,262
Actuarial loss, net	16,957			16,389			562			752
Net periodic cost before regulatory adjustment	30,525			30,120			2,659			5,402
Regulatory adjustment (a)	1,567			(9,250		)	1,434			40
Net periodic cost	$	32,092		$	20,870		$	4,093		$	5,442

_______________


(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.

Wolf Creek Pension and Post-Retirement Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2013

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

Schedule of Net Periodic Benefit Costs [Table Text Block]

The following tables summarize the net periodic costs for our pension and post-retirement benefit plans prior to the effects of capitalization.



	Pension Benefits						Post-retirement Benefits
Three Months Ended June 30,	2013			2012			2013			2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	5,355		$	4,889		$	507		$	514
Interest cost	9,630			9,894			1,502			1,574
Expected return on plan assets	(8,351		)	(8,070		)	(1,672		)	(1,372		)
Amortization of unrecognized:
Transition obligation, net	—			—			81			978
Prior service costs	150			153			631			631
Actuarial loss, net	8,479			8,194			281			376
Net periodic cost before regulatory adjustment	15,263			15,060			1,330			2,701
Regulatory adjustment (a)	783			(2,005		)	717			(278		)
Net periodic cost	$	16,046		$	13,055		$	2,047		$	2,423

_______________


(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.



	Pension Benefits						Post-retirement Benefits
Six Months Ended June 30,	2013			2012			2013			2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	10,710		$	9,777		$	1,014		$	1,029
Interest cost	19,260			19,789			3,004			3,149
Expected return on plan assets	(16,702		)	(16,142		)	(3,345		)	(2,746		)
Amortization of unrecognized:
Transition obligation, net	—			—			162			1,956
Prior service costs	300			307			1,262			1,262
Actuarial loss, net	16,957			16,389			562			752
Net periodic cost before regulatory adjustment	30,525			30,120			2,659			5,402
Regulatory adjustment (a)	1,567			(9,250		)	1,434			40
Net periodic cost	$	32,092		$	20,870		$	4,093		$	5,442

_______________


(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.

Wolf Creek [Member]

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

Schedule of Net Periodic Benefit Costs [Table Text Block]

The following tables summarize the net periodic costs for KGE's 47% share of the Wolf Creek pension and post-retirement benefit plans prior to the effects of capitalization.



	Pension Benefits						Post-retirement Benefits
Three Months Ended June 30,	2013			2012			2013		2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	1,708		$	1,516		$	52	$	48
Interest cost	1,891			1,884			103		103
Expected return on plan assets	(1,843		)	(1,644		)	—		—
Amortization of unrecognized:
Transition obligation, net	—			—			—		14
Prior service costs	14			1			—		—
Actuarial loss, net	1,355			1,341			66		58
Net periodic cost before regulatory adjustment	3,125			3,098			221		223
Regulatory adjustment (a)	(203		)	(484		)	—		—
Net periodic cost	$	2,922		$	2,614		$	221	$	223

_______________


(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.



	Pension Benefits						Post-retirement Benefits
Six Months Ended June 30,	2013			2012			2013		2012
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	3,417		$	3,031		$	104	$	96
Interest cost	3,782			3,769			206		205
Expected return on plan assets	(3,686		)	(3,289		)	—		—
Amortization of unrecognized:
Transition obligation, net	—			—			—		29
Prior service costs	28			3			—		—
Actuarial loss, net	2,710			2,683			132		117
Net periodic cost before regulatory adjustment	6,251			6,197			442		447
Regulatory adjustment (a)	(406		)	(1,514		)	—		—
Net periodic cost	$	5,845		$	4,683		$	442	$	447

_______________


(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.

Variable Interest Entities (Tables)

6 Months Ended

Jun. 30, 2013

Variable Interest Entities [Abstract]

Assets And Liabilities of VIEs

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



	As of		As of
	June 30, 2013		December 31, 2012
	(In Thousands)
Assets:
Property, plant and equipment of variable interest entities, net	$	301,998	$	321,975
Regulatory assets (a)	6,330		5,810

Liabilities:
Current maturities of long-term debt of variable interest entities	$	27,773	$	25,942
Accrued interest (b)	3,475		3,948
Long-term debt of variable interest entities, net	195,203		222,743

_______________

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

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

Summary Of Significant Accounting Policies (Fuel Inventory And Supplies) (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Public Utilities, Inventory [Line Items]
Total	$ 239,497	$ 249,016
Fuel Inventory [Member]
Public Utilities, Inventory [Line Items]
Public Utilitiy Inventory	88,453	94,664
Supplies [Member]
Public Utilities, Inventory [Line Items]
Public Utilitiy Inventory	$ 151,044	$ 154,352

Summary Of Significant Accounting Policies (Allowance For Funds Used During Construction) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Accounting Policies [Abstract]
Borrowed funds	$ 2,583	$ 2,440	$ 5,168	$ 5,959
Equity funds	2,943	2,838	5,689	6,778
Total	$ 5,526	$ 5,278	$ 10,857	$ 12,737
Average AFUDC rates	4.30%	4.90%	4.30%	5.40%

Summary Of Significant Accounting Policies (Reconciliation Of Basic And Diluted EPS) (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Accounting Policies [Abstract]
Less: Preferred dividends	$ 0	$ 1,373	$ 0	$ 1,616
Net income allocated to RSUs	196	182	339	265
Net income allocated to common stock	$ 66,992	$ 61,179	$ 117,994	$ 88,377
Weighted Average Number of Shares Outstanding , Basic	127,311,411	126,637,067	127,254,250	126,566,071
RSUs	53,570	190,422	45,567	155,340
Forward sale agreements	565,414	49,047	435,340	23,128
Weighted average equivalent common shares outstanding - diluted	127,930,395	126,876,536	127,735,157	126,744,539
Earnings Per Share, Basic	$ 0.53	$ 0.48	$ 0.93	$ 0.70
Earnings Per Share, Diluted	$ 0.52	$ 0.48	$ 0.92	$ 0.70
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities	0	0	0	0

Summary Of Significant Accounting Policies (Supplemental Cash Flow Information) (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Cash Paid For (Received From)
Interest on financing activities	$ 73,853	$ 68,939
Income taxes, net of refunds	(86)	(4,635)
Noncash Investing and Financing Transactions
Property, plant and equipment	56,187	37,736
Issuance of common stock for reinvested dividends and compensation plans	6,316	4,920
Deconsolidation of VIE	(14,282)	0
Assets acquired through capital leases	326	1,543
Variable Interest Entity, Primary Beneficiary [Member]
Cash Paid For (Received From)
Interest on financing activities	7,349	8,281
Noncash Investing and Financing Transactions
Property, plant and equipment	$ (14,282)	$ 0

Rate Matters And Regulation (Narrative) (Details) (USD $) In Millions, unless otherwise specified	1 Months Ended
	Apr. 30, 2013	Dec. 31, 2013	Jun. 30, 2013	Mar. 20, 2013	Jan. 31, 2013
Regulatory Proceedings [Line Items]
Estimated Increase In Annual Retail Revenues For Transmission Costs				$ 11.8
Estimated Increase In Annual Retail Revenues For Environmental Costs			27.3
Investment In Environmental Upgrades Jointly Owned Utility Plant	333.4
Proposed Increase In Annual Retail Revenues		31.7
Expected Increase In Annual Transmission Revenues					$ 12.2

Financial and Derivative Instruments and Trading Securities (Carrying Values And Fair Values Of Financial Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Fixed Rate Debt Member
Debt Instrument [Line Items]
Carrying Value	$ 2,852,500	$ 2,702,500
Fair Value	3,094,753	3,178,752
Fixed Rate Debt Of Variable Interest Entities Member
Debt Instrument [Line Items]
Carrying Value	222,149	247,624
Fair Value	$ 245,022	$ 275,341

Financial and Derivative Instruments and Trading Securities(Reconciliations Of Assets And Liabilities At Fair Value) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	$ 27,812	$ 11,371	$ 12,764	$ 11,026
Regulatory liabilities	597	282	727	547
Purchases	143	651	15,275	791
Sales	(143)	(75)	(357)	(135)
Balance at period end	28,409	12,229	28,409	12,229
Domestic Equity [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	4,785	4,100	4,899	3,931
Regulatory liabilities	229	104	197	193
Purchases	72	589	135	669
Sales	(72)	(13)	(217)	(13)
Balance at period end	5,014	4,780	5,014	4,780
Alternative Funds [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	15,000		0
Regulatory liabilities	234		234
Purchases	0		15,000
Sales	0		0
Balance at period end	15,234		15,234
Real Estate Securities [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	8,027	7,271	7,865	7,095
Regulatory liabilities	134	178	296	354
Purchases	71	62	140	122
Sales	(71)	(62)	(140)	(122)
Balance at period end	$ 8,161	$ 7,449	$ 8,161	$ 7,449

Financial and Derivative Instruments and Trading Securities (Unrealized Gains And Losses On Financial Statements) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Unrealized gain (loss) included in regulatory liabilities	$ 453	$ 207	$ 369	$ 412
Domestic Equity [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Unrealized gain (loss) included in regulatory liabilities	157	91	(20)	180
Alternative Funds [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Unrealized gain (loss) included in regulatory liabilities	234		234
Real Estate Securities [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Unrealized gain (loss) included in regulatory liabilities	$ 62	$ 116	$ 155	$ 232

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

6 Months Ended

Jun. 30, 2013

Dec. 31, 2012

Financial and Derivative Instruments and Trading Securities [Line Items]

$ 159,631

$ 150,754

Financial and Derivative Instruments and Trading Securities [Line Items]

32,450

43,484

Total

192,081

194,238

Domestic Equity [Member]

49,585

61,056

Financial and Derivative Instruments and Trading Securities [Line Items]

16,812

22,470

Alternative Funds [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

15,234

Real Estate Securities [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

8,161

7,865

International Equity [Member]

28,118

30,041

Financial and Derivative Instruments and Trading Securities [Line Items]

4,175

5,744

Core Bonds [Member]

16,423

28,350

Financial and Derivative Instruments and Trading Securities [Line Items]

11,297

15,104

Fair Value [Member]

28,409

12,764

32,284

43,318

Total

60,693

56,082

Financial and Derivative Instruments and Trading Securities [Line Items]

889

1,024

Fair Value [Member] | Domestic Equity [Member]

5,014

4,899

Financial and Derivative Instruments and Trading Securities [Line Items]

16,812

22,470

Fair Value [Member] | Alternative Funds [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

15,234

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

Financial and Derivative Instruments and Trading Securities [Line Items]

8,161

^[1]

7,865

^[1]

Fair Value [Member] | International Equity [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

4,175

5,744

Fair Value [Member] | Core Bonds [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

11,297

15,104

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

Financial and Derivative Instruments and Trading Securities [Line Items]

889

1,024

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

889

1,024

(a)

Financial and Derivative Instruments and Trading Securities [Line Items]

(a)

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

(b)

Financial and Derivative Instruments and Trading Securities [Line Items]

(b)

Decommissioning Trust Assets [Member] | Fair Value [Member] | Real Estate Securities [Member]

^[1]

Quarterly

Financial and Derivative Instruments and Trading Securities [Line Items]

80 days

Trading Securities [Member] | Fair Value [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

Trading Securities [Member] | Fair Value [Member] | Domestic Equity [Member]

Upon Notice

Financial and Derivative Instruments and Trading Securities [Line Items]

1 day

Trading Securities [Member] | Fair Value [Member] | International Equity [Member]

Upon Notice

Financial and Derivative Instruments and Trading Securities [Line Items]

1 day

Trading Securities [Member] | Fair Value [Member] | Core Bonds [Member]

$ 0

Upon Notice

Variable Interest Entity [Line Items]

1 day

[1]

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

Financial Investments (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Schedule of Available-for-sale Securities [Line Items]
Unrealized gains losses	$ (6.2)	$ (1.8)	$ (3.7)	$ 1.8
Fair value of available-for-sale bond funds	43.1		43.1
Realized gains on available-for-sale-securities	$ 3.2	$ 0.4	$ 4.5	$ 0.6

Financial Investments (Cost And Fair Value Of Investments) (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended	12 Months Ended
	Jun. 30, 2013	Dec. 31, 2012
Schedule of Available-for-sale Securities [Line Items]
Cost	$ 147,359	$ 141,350
Available-for-sale Securities, Gross Unrealized Gain	15,582	11,520
Available-for-sale Securities, Gross Unrealized Loss	(3,310)	(2,116)
Available-for-sale Securities	159,631	150,754
Allocation	100.00%	100.00%
Domestic Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	38,515	53,598
Available-for-sale Securities, Gross Unrealized Gain	11,071	7,458
Available-for-sale Securities, Gross Unrealized Loss	(1)	0
Available-for-sale Securities	49,585	61,056
Allocation	30.00%	41.00%
International Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	26,301	28,248
Available-for-sale Securities, Gross Unrealized Gain	2,299	1,793
Available-for-sale Securities, Gross Unrealized Loss	(482)	0
Available-for-sale Securities	28,118	30,041
Allocation	18.00%	20.00%
Core Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	16,404	27,309
Available-for-sale Securities, Gross Unrealized Gain	19	1,041
Available-for-sale Securities, Gross Unrealized Loss	0	0
Available-for-sale Securities	16,423	28,350
Allocation	10.00%	19.00%
High-Yield Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	11,554	8,022
Available-for-sale Securities, Gross Unrealized Gain	617	760
Available-for-sale Securities, Gross Unrealized Loss	0	0
Available-for-sale Securities	12,171	8,782
Allocation	8.00%	6.00%
Emerging Market Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	10,462	6,080
Available-for-sale Securities, Gross Unrealized Gain	0	348
Available-for-sale Securities, Gross Unrealized Loss	(513)	0
Available-for-sale Securities	9,949	6,428
Allocation	6.00%	4.00%
Other Fixed Income [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	4,616
Available-for-sale Securities, Gross Unrealized Gain	0
Available-for-sale Securities, Gross Unrealized Loss	(11)
Available-for-sale Securities	4,605
Allocation	3.00%
Combination Debt Equity And Other Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	14,377
Available-for-sale Securities, Gross Unrealized Gain	1,342
Available-for-sale Securities, Gross Unrealized Loss	(342)
Available-for-sale Securities	15,377
Allocation	10.00%
Combination Debt and Equity Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost		8,074
Available-for-sale Securities, Gross Unrealized Gain		120
Available-for-sale Securities, Gross Unrealized Loss		0
Available-for-sale Securities		8,194
Allocation		5.00%
Alternative Funds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	15,000
Available-for-sale Securities, Gross Unrealized Gain	234
Available-for-sale Securities, Gross Unrealized Loss	0
Available-for-sale Securities	15,234
Allocation	10.00%
Real Estate Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	10,122	9,981
Available-for-sale Securities, Gross Unrealized Gain	0	0
Available-for-sale Securities, Gross Unrealized Loss	(1,961)	(2,116)
Available-for-sale Securities	8,161	7,865
Allocation	5.00%	5.00%
Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	8	38
Available-for-sale Securities, Gross Unrealized Gain	0	0
Available-for-sale Securities, Gross Unrealized Loss	0	0
Available-for-sale Securities	$ 8	$ 38

Financial Investments (Fair Value And The Gross Unrealized Losses Of the Available-For-Sale Securities) (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended	12 Months Ended
	Jun. 30, 2013	Dec. 31, 2012
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	$ 27,663
Gross Unrealized Losses, Less than 12 Months	(1,349)
Fair Value, 12 Months or Greater	8,161
Gross Unrealized Losses, 12 Months or Greater	(1,961)
Fair Value, Total	35,824
Gross Unrealized Losses, Total	(3,310)
Domestic Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	1,543
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	1,543
Gross Unrealized Losses, Total	(1)
International Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	5,712
Gross Unrealized Losses, Less than 12 Months	(482)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	5,712
Gross Unrealized Losses, Total	(482)
Emerging Market Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	9,949
Gross Unrealized Losses, Less than 12 Months	(513)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	9,949
Gross Unrealized Losses, Total	(513)
Other Fixed Income [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	4,605
Gross Unrealized Losses, Less than 12 Months	(11)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	4,605
Gross Unrealized Losses, Total	(11)
Combination Debt Equity And Other Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	5,854
Gross Unrealized Losses, Less than 12 Months	(342)
Fair Value, 12 Months or Greater	0
Gross Unrealized Losses, 12 Months or Greater	0
Fair Value, Total	5,854
Gross Unrealized Losses, Total	(342)
Real Estate Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	0	0
Gross Unrealized Losses, Less than 12 Months	0	0
Fair Value, 12 Months or Greater	8,161	7,865
Gross Unrealized Losses, 12 Months or Greater	(1,961)	(2,116)
Fair Value, Total	8,161	7,865
Gross Unrealized Losses, Total	$ (1,961)	$ (2,116)

Debt Financing (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended		1 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013 KGE [Member] Pollution Control Bond Series [Member] Debt Instruments 8780 And 8790 [Member]	Jun. 30, 2013 KGE [Member] Pollution Control Bond Series [Member] Debt Instrument 8780 [Member]	Jun. 30, 2013 KGE [Member] Pollution Control Bond Series [Member] Debt Instrument 8790 [Member]	Mar. 28, 2013 Westar Energy [Member] Secured Debt [Member] Debt Instrument 8860 [Member]
Debt Instrument [Line Items]
Retirements of long-term debt	$ 100,000	$ 220,563	$ 100,000
Principal amount of first mortgage bonds						$ 250,000
Stated interest rate on first mortgage bonds				5.60%	6.00%	4.10%

Taxes Taxes (Narrative) (Details) (USD $)	3 Months Ended		6 Months Ended
Taxes Taxes (Narrative) (Details) (USD $)	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Income Tax Contingency [Line Items]
Income tax expense	$ 29,310,000	$ 28,340,000	$ 54,123,000	$ 40,783,000
Effective income tax rate	30.00%	31.00%	31.00%	30.00%
Liability for unrecognized income tax benefits	1,200,000		1,200,000		1,200,000
Interest on liability related to unrecognized income tax benefits	200,000		200,000		200,000
Penalties accrued for unrecognized income tax benefits	0		0		0
Accrual for taxes other than income taxes	$ 1,500,000		$ 1,500,000		$ 1,500,000

Pension and Post-Retirement Benefit Plans (Net Periodic Costs And Pension Contributions) (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Components of Net Periodic Cost (Benefit):
Pension Contributions			$ 17,700,000	$ 49,400,000
Pension Benefits [Member]
Components of Net Periodic Cost (Benefit):
Service cost	5,355,000	4,889,000	10,710,000	9,777,000
Interest cost	9,630,000	9,894,000	19,260,000	19,789,000
Expected return on plan assets	(8,351,000)	(8,070,000)	(16,702,000)	(16,142,000)
Transition obligation, net	0	0	0	0
Prior service costs	150,000	153,000	300,000	307,000
Actuarial loss, net	8,479,000	8,194,000	16,957,000	16,389,000
Net periodic cost before regulatory adjustment	15,263,000	15,060,000	30,525,000	30,120,000
Regulatory adjustment	783,000	(2,005,000)	1,567,000	(9,250,000)
Net periodic cost	16,046,000	13,055,000	32,092,000	20,870,000
Post-Retirement Benefits [Member]
Components of Net Periodic Cost (Benefit):
Service cost	507,000	514,000	1,014,000	1,029,000
Interest cost	1,502,000	1,574,000	3,004,000	3,149,000
Expected return on plan assets	(1,672,000)	(1,372,000)	(3,345,000)	(2,746,000)
Transition obligation, net	81,000	978,000	162,000	1,956,000
Prior service costs	631,000	631,000	1,262,000	1,262,000
Actuarial loss, net	281,000	376,000	562,000	752,000
Net periodic cost before regulatory adjustment	1,330,000	2,701,000	2,659,000	5,402,000
Regulatory adjustment	717,000	(278,000)	1,434,000	40,000
Net periodic cost	$ 2,047,000	$ 2,423,000	$ 4,093,000	$ 5,442,000

Wolf Creek Pension and Post-Retirement Benefit Plans Wolf Creek Pension and Post-Retirement Benefit Plans (Net Periodic Costs and Pension Contributions) (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Components of Net Periodic Cost (Benefit):
Pension Contributions			$ 17,700,000	$ 49,400,000
Wolf Creek [Member]
Components of Net Periodic Cost (Benefit):
Pension Contributions			3,700,000	9,000,000
KGE [Member]
Subsidiary Interest in Defined Benefit Plans			47.00%
Pension Benefits [Member]
Components of Net Periodic Cost (Benefit):
Service cost	5,355,000	4,889,000	10,710,000	9,777,000
Interest cost	9,630,000	9,894,000	19,260,000	19,789,000
Expected return on plan assets	(8,351,000)	(8,070,000)	(16,702,000)	(16,142,000)
Transition obligation, net	0	0	0	0
Prior service costs	150,000	153,000	300,000	307,000
Actuarial loss, net	8,479,000	8,194,000	16,957,000	16,389,000
Net periodic cost before regulatory adjustment	15,263,000	15,060,000	30,525,000	30,120,000
Regulatory adjustment	783,000	(2,005,000)	1,567,000	(9,250,000)
Net periodic cost	16,046,000	13,055,000	32,092,000	20,870,000
Pension Benefits [Member] \| Wolf Creek [Member]
Components of Net Periodic Cost (Benefit):
Service cost	1,708,000	1,516,000	3,417,000	3,031,000
Interest cost	1,891,000	1,884,000	3,782,000	3,769,000
Expected return on plan assets	(1,843,000)	(1,644,000)	(3,686,000)	(3,289,000)
Transition obligation, net	0	0	0	0
Prior service costs	14,000	1,000	28,000	3,000
Actuarial loss, net	1,355,000	1,341,000	2,710,000	2,683,000
Net periodic cost before regulatory adjustment	3,125,000	3,098,000	6,251,000	6,197,000
Regulatory adjustment	(203,000)	(484,000)	(406,000)	(1,514,000)
Net periodic cost	2,922,000	2,614,000	5,845,000	4,683,000
Post-Retirement Benefits [Member]
Components of Net Periodic Cost (Benefit):
Service cost	507,000	514,000	1,014,000	1,029,000
Interest cost	1,502,000	1,574,000	3,004,000	3,149,000
Expected return on plan assets	(1,672,000)	(1,372,000)	(3,345,000)	(2,746,000)
Transition obligation, net	81,000	978,000	162,000	1,956,000
Prior service costs	631,000	631,000	1,262,000	1,262,000
Actuarial loss, net	281,000	376,000	562,000	752,000
Net periodic cost before regulatory adjustment	1,330,000	2,701,000	2,659,000	5,402,000
Regulatory adjustment	717,000	(278,000)	1,434,000	40,000
Net periodic cost	2,047,000	2,423,000	4,093,000	5,442,000
Post-Retirement Benefits [Member] \| Wolf Creek [Member]
Components of Net Periodic Cost (Benefit):
Service cost	52,000	48,000	104,000	96,000
Interest cost	103,000	103,000	206,000	205,000
Expected return on plan assets	0	0	0	0
Transition obligation, net	0	14,000	0	29,000
Prior service costs	0	0	0	0
Actuarial loss, net	66,000	58,000	132,000	117,000
Net periodic cost before regulatory adjustment	221,000	223,000	442,000	447,000
Regulatory adjustment	0	0	0	0
Net periodic cost	$ 221,000	$ 223,000	$ 442,000	$ 447,000

Commitments And Contingencies (Details) (USD $)	6 Months Ended
Commitments And Contingencies (Details) (USD $)	Jun. 30, 2013 States
Environmental Projects [Abstract]
Environmental upgrades jointly owned utility plant entity share	$ 610,000,000
Environmental upgrades jointly owned utility plant	1,200,000,000
Air Emissions [Abstract]
Estimated cost to comply with environmental regulation	16,000,000
Number of states required to comply with regulations	28
EPA Consent Decree [Abstract]
Preliminary estimate of the cost of selective catalytic reduction (SCR) equipment	$ 240,000,000
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

Common Stock Common Stock (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	6 Months Ended
	Jun. 30, 2013 months
Forward Contract Indexed To Issuers Equity, Indexed Shares For Period	2.2
Forward Contract Indexed to Issuer's Equity, Settlement Period	18
Forward Contract Indexed to Issuer's Equity, Indexed Shares	4.0
Forward Contract Indexed to Issuer's Equity, Estimated Proceeds	$ 115.8
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share	$ 29.23
Forward Sale Agreement, Maximum Amount Authorized	$ 500.0
Forward Sale Agreement, Maximum Shares Authorized	25.0
Commissions Paid, Percentage of Sales Price of Shares Sold	1.00%

Variable Interest Entities (Narrative) (Details) (USD $)	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Variable Interest Entity [Line Items]
Deconsolidation of variable interest entity	$ 14,282,000	$ 0
Gain or loss upon initial consolidation of VIEs	0
Jeffrey Energy Center [Member]
Variable Interest Entity [Line Items]
Variable interest entity percentage of asset held	8.00%
Agreement expiration date	Jan. 01, 2019
La Cygne Generating Station [Member]
Variable Interest Entity [Line Items]
Variable interest entity percentage of asset held	50.00%
Agreement expiration date	Sep. 01, 2029
Railroad Transportation Equipment [Member]
Variable Interest Entity [Line Items]
Agreement expiration date	May 01, 2013
Gain or loss upon deconsolidation of VIE	0
Railroad Transportation Equipment 2 [Member]
Variable Interest Entity [Line Items]
Agreement expiration date	Nov. 01, 2014
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Decrease in property, plant and equipment of VIE due to deconsolidation of VIE	$ 14,300,000

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

Jun. 30, 2013

Dec. 31, 2012

$ 7,255,280

$ 7,013,765

49,599

^[1]

77,891

^[1]

Variable Interest Entity [Line Items]

2,968,642

2,819,271

Variable Interest Entity, Primary Beneficiary [Member]

Current maturities of long-term debt

301,998

321,975

Regulatory assets

6,330

^[2]

5,810

^[2]

27,773

25,942

3,475

^[1]

3,948

^[1]