43,729

30,655

Total Current Assets

753,532

700,922

Nuclear decommissioning trust

8,340,478

8,162,908

OTHER ASSETS:

Regulatory assets

726,923

754,229

191,934

185,016

261,886

265,353

Total Other Assets

1,180,743

1,204,598

TOTAL ASSETS

10,548,159

10,347,001

CURRENT LIABILITIES:

Short-term debt

307,100

257,600

Accounts payable

185,307

219,351

Accrued dividends

49,736

44,971

Accrued taxes

87,792

74,356

48,036

^[1]

79,707

^[1]

Regulatory liabilities

60,860

55,142

Total Current Liabilities

77,779

90,571

844,925

849,631

LONG-TERM LIABILITIES:

Unamortized investment tax credits

3,091,655

3,215,539

Deferred income taxes

1,511,299

1,475,487

209,520

211,040

Regulatory liabilities

283,451

288,343

Accrued employee benefits

524,191

532,622

Asset retirement obligations

283,194

230,668

Total Long-Term Liabilities

77,287

75,799

6,118,770

6,196,063

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 129,272,835 shares and 128,254,229 shares, respective to each date

705,893

658,437

Paid-in capital

1,997,661

1,781,120

Retained earnings

870,820

855,299

Total Westar Energy, Inc. Shareholders' Equity

3,574,374

3,294,856

Noncontrolling Interests

10,090

6,451

Total Equity

3,584,464

3,301,307

TOTAL LIABILITIES AND EQUITY

10,548,159

10,347,001

Variable Interest Entity [Member]

CURRENT ASSETS:

Current maturities of long-term debt

273,406

278,573

CURRENT LIABILITIES:

28,315

27,933

2,458

^[1]

2,961

^[1]

LONG-TERM LIABILITIES:

Summary Of Significant Accounting Policies

$ 138,173

$ 166,565

[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, 2015	Dec. 31, 2014	Mar. 31, 2014
Allowance for doubtful accounts	$ 4,569	$ 5,309
Common stock, par value		$ 5	$ 5
Common stock, shares authorized	275,000,000	275,000,000
Common stock, shares issued	141,178,618	131,687,454
Common stock, shares outstanding	141,178,618	131,687,454

Consolidated Statements Of Income (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
REVENUES	$ 589,563	$ 612,668	$ 1,180,370	$ 1,241,224
OPERATING EXPENSES:
Fuel and purchased power	140,080	164,779	295,561	338,618
Network Transmission Cost	57,352	55,533	114,164	107,491
Operating and maintenance	82,739	101,839	167,819	193,629
Depreciation and amortization	76,759	70,882	151,345	140,992
Selling, general and administrative	63,663	62,168	119,082	118,653
Taxes, Miscellaneous	37,494	34,738	75,365	69,571
Total Operating Expenses	458,087	489,939	923,336	968,954
INCOME FROM OPERATIONS	131,476	122,729	257,034	272,270
OTHER INCOME (EXPENSE):
Investment earnings (losses)	1,634	3,175	4,113	5,553
Other income	15,121	5,658	17,935	11,575
Other expense	(2,633)	(2,287)	(8,345)	(7,952)
Total Other Income	14,122	6,546	13,703	9,176
Interest expense	45,516	47,303	89,814	93,543
INCOME BEFORE INCOME TAXES	100,082	81,972	180,923	187,903
Income tax expense	33,839	26,150	61,517	61,111
NET INCOME	66,243	55,822	119,406	126,792
Less: Net income attributable to noncontrolling interests	2,533	2,349	4,716	4,365
NET INCOME ATTRIBUTABLE TO WESTAR ENERGY, INC.	$ 63,710	$ 53,473	$ 114,690	$ 122,427
Earnings Per Share [Abstract]
Earnings Per Share, Basic	$ 0.47	$ 0.41	$ 0.85	$ 0.95
Earnings Per Share, Diluted	$ 0.46	$ 0.40	$ 0.84	$ 0.93
AVERAGE EQUIVALENT COMMON SHARES OUTSTANDING
Weighted Average Number of Shares Outstanding , Basic	135,939,197	129,363,382	134,177,136	129,184,767
Weighted Average Number of Shares Outstanding, Diluted	137,412,152	131,973,139	136,329,603	131,778,584
DIVIDENDS DECLARED PER COMMON SHARE	$ 0.36	$ 0.35	$ 0.72	$ 0.70

Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net income	$ 119,406	$ 126,792
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	151,345	140,992
Amortization of nuclear fuel	10,085	10,304
Amortization of deferred regulatory gain from sale leaseback	(2,748)	(2,748)
Amortization of corporate-owned life insurance	9,042	8,712
Non-cash compensation	4,241	3,945
Net deferred income taxes and credits	54,740	58,097
Stock-based compensation excess tax benefits	(1,178)	544
Allowance for equity funds used during construction	(2,041)	(9,718)
Changes in working capital items:
Accounts receivable	998	(10,586)
Fuel inventory and supplies	(31,307)	(16,248)
Prepaid expenses and other	(40,195)	(4,891)
Accounts payable	(2,873)	(16,199)
Accrued taxes	16,893	8,293
Other current liabilities	(65,908)	(32,477)
Changes in other assets	(9,712)	1,828
Changes in other liabilities	21,046	16,674
Cash Flows from Operating Activities	231,834	283,314
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Additions to property, plant and equipment	(334,905)	(427,124)
Purchase of securities - trusts	(9,980)	(4,410)
Sale of securities - trusts	10,263	5,552
Investment in corporate-owned life insurance	14,845	15,903
Proceeds from investment in corporate-owned life insurance	1,192	1,773
Investment in affiliated company	0	1,418
Other investing activities	(653)	(1,544)
Cash Flows used in Investing Activities	(348,928)	(440,238)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Short-term debt, net	49,500	208,533
Proceeds from long-term debt	0	171,785
Retirements of long-term debt	(125,000)	(177,500)
Repayment of capital leases	(1,721)	(1,628)
Borrowings against cash surrender value of corporate-owned life insurance	56,622	56,577
Repayment of borrowings against cash surrender value of corporate-owned life insurance	(899)	(1,123)
Stock-based compensation excess tax benefits	1,178	(544)
Issuance of common stock	256,394	20,699
Distributions to shareholders of noncontrolling interests	1,076	0
Cash dividends paid	(89,035)	(84,419)
Other financing activities	(3,234)	(1,887)
Cash Flows from Financing Activities	114,804	163,188
NET CHANGE IN CASH AND CASH EQUIVALENTS	(2,290)	6,264
CASH AND CASH EQUIVALENTS:
Beginning of period	4,556	4,487
End of period	2,266	10,751
Variable Interest Entity [Member]
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Retirements of long-term debt	$ (27,925)	$ (27,305)

Consolidated Statements Of Changes In Equity (USD $) In Thousands, except Share data	Total	Common Stock [Member]	Paid-In Capital [Member]	Retained Earnings [Member]	Noncontrolling Interests [Member]
Beginning Balance at Dec. 31, 2013	$ 3,068,531	$ 641,271	$ 1,696,727	$ 724,776	$ 5,757
Beginning Balance (Shares) at Dec. 31, 2013		128,254,229
Net income	126,792	0	0	122,427	4,365
Issuance of stock	20,699	3,780	16,919	0	0
Issuance of stock (shares)		755,961
Issuance Of Stock For Compensation And Reinvested Dividends, Shares		262,645
Issuance Of Stock For Compensation And Reinvested Dividends	4,212	1,313	2,899
Tax withholding related to stock compensation	(1,887)		(1,887)
Dividends on common stock	(90,761)	0	0	(90,761)	0
Stock compensation expense	3,903		3,903
Tax Benefit on stock compensation	(544)	0	(544)	0	0
Distributions to shareholders of noncontrolling interests	0
Stockholders' Equity, Other	(2)				(2)
Ending Balance at Jun. 30, 2014	3,130,943	646,364	1,718,017	756,442	10,120
Ending Balance (Shares) at Jun. 30, 2014		129,272,835
Beginning Balance at Dec. 31, 2014	3,301,307	658,437	1,781,120	855,299	6,451
Beginning Balance (Shares) at Dec. 31, 2014		131,687,454
Net income	119,406	0	0	114,690	4,716
Issuance of stock	256,394	46,041	210,353	0	0
Issuance of stock (shares)		9,208,267
Issuance Of Stock For Compensation And Reinvested Dividends, Shares		282,897
Issuance Of Stock For Compensation And Reinvested Dividends	5,532	1,415	4,117
Tax withholding related to stock compensation	(3,234)		(3,234)
Dividends on common stock	(99,169)	0	0	(99,169)	0
Stock compensation expense	4,196		4,196
Tax Benefit on stock compensation	1,178	0	1,178	0	0
Deconsolidation of variable interest entity	1,076				1,076
Distributions to shareholders of noncontrolling interests	1,076
Stockholders' Equity, Other	(70)		(69)		(1)
Ending Balance at Jun. 30, 2015	$ 3,584,464	$ 705,893	$ 1,997,661	$ 870,820	$ 10,090
Ending Balance (Shares) at Jun. 30, 2015		141,178,618

Description Of Business	6 Months Ended
Description Of Business	Jun. 30, 2015
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 700,000 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, 2015

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) for the United States of America 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 2014 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 ongoing basis, including those related to depreciation, unbilled revenue, valuation of investments, forecasted fuel costs included in our retail energy cost adjustment (RECA) billed to customers, income taxes, pension and post-retirement benefits, our asset retirement obligations (AROs) including the decommissioning of Wolf Creek, 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, 2015, are not necessarily indicative of the results to be expected for the full year.

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, 2015		December 31, 2014
	(In Thousands)
Fuel inventory	$	94,450	$	70,416
Supplies	184,576		176,990
Fuel inventory and supplies	$	279,026	$	247,406

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,
	2015			2014			2015			2014
	(Dollars In Thousands)
Borrowed funds	$	552		$	3,213		$	2,581		$	6,944
Equity funds	90			4,712			2,041			9,718
Total	$	642		$	7,925		$	4,622		$	16,662
Average AFUDC Rates	1.2		%	6.8		%	3.2		%	7.0		%

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).

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 issuable 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,
	2015		2014		2015		2014
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	66,243	$	55,822	$	119,406	$	126,792
Less: Net income attributable to noncontrolling interests	2,533		2,349		4,716		4,365
Net income attributable to Westar Energy, Inc.	63,710		53,473		114,690		122,427
Less: Net income allocated to RSUs	141		148		257		336
Net income allocated to common stock	$	63,569	$	53,325	$	114,433	$	122,091

Weighted average equivalent common shares outstanding – basic	135,939,197		129,363,382		134,177,136		129,184,767
Effect of dilutive securities:
RSUs	121,234		164,641		127,999		122,221
Forward sale agreements	1,351,721		2,445,116		2,024,468		2,471,596
Weighted average equivalent common shares outstanding – diluted (a)	137,412,152		131,973,139		136,329,603		131,778,584

Earnings per common share, basic	$	0.47	$	0.41	$	0.85	$	0.95
Earnings per common share, diluted	$	0.46	$	0.40	$	0.84	$	0.93

_______________

(a)We had no antidilutive securities for the three and six months ended June 30, 2015 and 2014.

Supplemental Cash Flow Information



	Six Months Ended June 30,
	2015		2014
	(In Thousands)
CASH PAID FOR:
Interest on financing activities, net of amount capitalized	$	82,297	$	80,373
Interest on financing activities of VIEs	5,651		6,526
Income taxes, net of refunds	126		236
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	66,861		90,395
NON-CASH FINANCING TRANSACTIONS:
Issuance of stock for compensation and reinvested dividends	5,532		4,212
Assets acquired through capital leases	1,102		1,195

New Accounting Pronouncements

We prepare our consolidated financial statements in accordance with GAAP for the United States of America. To address current issues in accounting, the Financial Accounting Standards Board (FASB) issued the following new accounting pronouncement which may affect our accounting and/or disclosure.

Revenue Recognition

In May 2014, the FASB issued guidance that addresses revenue from contracts with customers. The objective of the new guidance is to establish principles to report useful information to users of financial statements about the nature, amount, timing and uncertainty of revenue from contracts with customers. This guidance was effective for fiscal years beginning after December 15, 2016. However, in July 2015, the FASB approved to defer the effective date by one year. Early application of the standard is permitted for fiscal years beginning after December 15, 2016. The standard permits the use of either the retrospective application or cumulative effect transition method. We have not yet selected a transition method or determined the impact on our consolidated financial statements but we do not expect it to be material.

Presentation of Financial Statements

In April 2015, the FASB issued guidance to simplify the presentation of debt issuance costs. This guidance requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The guidance is effective for fiscal years beginning after December 15, 2015, with early adoption permitted. We have elected to adopt effective December 31, 2015, and do not expect this to have a material impact to our financial statements.

Rate Matters And Regulation	6 Months Ended
Rate Matters And Regulation	Jun. 30, 2015
Regulated Operations [Abstract]
Rate Matters And Regulation	RATE MATTERS AND REGULATION KCC Proceedings In May 2015, the Kansas Corporation Commission (KCC) issued an order allowing us to adjust our prices to include costs associated with investments in environmental projects during 2014. The new prices became effective in June 2015 and are expected to increase our annual retail revenues by approximately $10.8 million. In March 2015, the KCC issued an order allowing us to adjust our prices to include updated transmission costs as reflected in the transmission formula rate (TFR) discussed below. The new prices became effective in April 2015 and are expected to increase our annual retail revenues by approximately $7.2 million. In March 2015, we filed an application with the KCC to increase our prices by $152.0 million to include, among other things, additional investment in La Cygne Generating Station (La Cygne) environmental upgrades, investment to extend the life of Wolf Creek and costs related to programs to improve reliability. We subsequently reduced our request to $130.0 million due primarily to updating the estimated investments for La Cygne and Wolf Creek with actual costs through May 2015. In July 2015, the KCC staff and intervenors in our rate case filed testimony with the KCC stating their proposed adjustments to our electric prices. The KCC staff's proposed adjustments would result in an increase in our prices by approximately $55.0 million. Subsequently, we filed with the KCC additional testimony to rebut the KCC staff's and intervenors' findings, conclusions and proposed adjustments. We cannot predict the outcome of the rate case and expect the KCC to issue an order on our request by late October 2015 with new prices effective November 2015. In December 2014, the KCC approved an order allowing us to adjust our prices to include costs incurred for property taxes. The new prices were effective in January 2015 and are expected to increase our annual retail revenues by approximately $4.9 million. FERC Proceedings Our TFR that includes projected 2015 transmission capital expenditures and operating costs was effective in January 2015 and is expected to decrease our annual transmission revenues by approximately $4.6 million. This updated rate provided the basis for our request to the KCC to adjust our retail prices to include updated transmission costs as discussed above. In August 2014, the KCC filed a complaint against us with the Federal Energy Regulatory Commission (FERC) under Section 206 of the Federal Power Act (FPA). The complaint sought to lower our base return on equity (ROE) used in determining our TFR, which would result in a refund obligation and reduce our future transmission revenues. In June 2015, we filed a settlement agreement with the FERC, which if approved, would result in an ROE of 10.3%, which consists of a 9.8% base ROE plus a 0.5% incentive ROE for participation in an RTO. In July 2015, FERC staff filed initial comments supporting the proposed settlement. As a result, we have recorded a liability of $8.6 million for our estimated refund obligation from the refund effective date of August 20, 2014 through June 30, 2015. In addition, we estimate our future transmission revenues would be reduced by approximately $10.0 million on an annualized basis as a result of the reduced ROE.

Financial Instruments and Risk Management

6 Months Ended

Jun. 30, 2015

Financial And Derivative Instruments and Trading Securities [Abstract]

Financial And Derivative Instruments And Trading Securities

FINANCIAL INSTRUMENTS AND TRADING SECURITIES

Values of Financial Instruments

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


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

•

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


•	Level 3 - Significant inputs to pricing have little or no transparency. The types of assets and liabilities included in level 3 are those with inputs requiring significant management judgment or estimation. Level 3 includes investments in private equity, real estate securities and other alternative investments, which are measured at net asset value.

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

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

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



	As of June 30, 2015				As of December 31, 2014
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In Thousands)
Fixed-rate debt	$	2,980,000	$	3,207,527	$	3,105,000	$	3,488,410
Fixed-rate debt of VIEs	166,278		181,951		194,204		213,579

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, 2015	Level 1		Level 2		Level 3		Total
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity funds	$	—	$	52,432	$	5,910	$	58,342
International equity funds	—		35,297		—		35,297
Core bond fund	—		19,435		—		19,435
High-yield bond fund	—		13,710		—		13,710
Emerging market bond fund	—		12,462		—		12,462
Other fixed income fund	—		4,906		—		4,906
Combination debt/equity/other funds	—		20,002		—		20,002
Alternative investment fund	—		—		17,425		17,425
Real estate securities fund	—		—		10,042		10,042
Cash equivalents	313		—		—		313
Total Nuclear Decommissioning Trust	313		158,244		33,377		191,934
Trading Securities:
Domestic equity funds	—		18,207		—		18,207
International equity fund	—		4,510		—		4,510
Core bond fund	—		12,264		—		12,264
Cash equivalents	168		—		—		168
Total Trading Securities	168		34,981		—		35,149
Total Assets Measured at Fair Value	$	481	$	193,225	$	33,377	$	227,083

As of December 31, 2014	Level 1		Level 2		Level 3		Total
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity funds	$	—	$	54,925	$	6,047	$	60,972
International equity funds	—		30,791		—		30,791
Core bond fund	—		19,289		—		19,289
High-yield bond fund	—		13,198		—		13,198
Emerging market bond fund	—		10,988		—		10,988
Other fixed income fund	—		4,779		—		4,779
Combination debt/equity/other funds	—		18,141		—		18,141
Alternative investment fund	—		—		16,970		16,970
Real estate securities fund	—		—		9,548		9,548
Cash equivalents	340		—		—		340
Total Nuclear Decommissioning Trust	340		152,111		32,565		185,016
Trading Securities:
Domestic equity funds	—		18,698		—		18,698
International equity fund	—		4,252		—		4,252
Core bond fund	—		12,379		—		12,379
Cash equivalents	168		—		—		168
Total Trading Securities	168		35,329		—		35,497
Total Assets Measured at Fair Value	$	508	$	187,440	$	32,565	$	220,513

The following table provides reconciliations of assets measured at fair value using significant level 3 inputs for the three and six months ended June 30, 2015.



	Domestic Equity Funds			Alternative Investment Fund		Real Estate Securities Fund			Net Balance
	(In Thousands)
Balance as of March 31, 2015	$	6,061		$	16,784	$	9,758		$	32,603
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	226			641		284			1,151
Purchases	—			—		100			100
Sales	(377		)	—		(100		)	(477		)
Balance as of June 30, 2015	$	5,910		$	17,425	$	10,042		$	33,377

Balance as of December 31, 2014	$	6,047		$	16,970	$	9,548		$	32,565
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	563			455		494			1,512
Purchases	100			—		197			297
Sales	(800		)	—		(197		)	(997		)
Balance as of June 30, 2015	$	5,910		$	17,425	$	10,042		$	33,377

The following table provides reconciliations of assets measured at fair value using significant level 3 inputs for the three and six months ended June 30, 2014.



	Domestic Equity Funds			Alternative Investment Fund		Real Estate Securities Fund			Net Balance
	(In Thousands)
Balance as of March 31, 2014	$	5,984		$	16,102	$	8,812		$	30,898
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	447			344		214			1,005
Purchases	46			—		89			135
Sales	(189		)	—		(89		)	(278		)
Balance as of June 30, 2014	$	6,288		$	16,446	$	9,026		$	31,760

Balance as of December 31, 2013	$	5,817		$	15,675	$	8,511		$	30,003
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	609			771		515			1,895
Purchases	96			—		166			262
Sales	(234		)	—		(166		)	(400		)
Balance as of June 30, 2014	$	6,288		$	16,446	$	9,026		$	31,760

Portions of the gains and losses contributing to changes in net assets in the above table are unrealized. The following table summarizes the unrealized gains and losses we recorded to regulatory liabilities on our consolidated financial statements during the three and six months ended June 30, 2015 and 2014, attributed to level 3 assets and liabilities. See Note 3, "Rate Matters and Regulation," in the 2014 Form 10-K for additional information regarding our regulatory assets and liabilities.



	Domestic Equity Funds			Alternative Investment Fund		Real Estate Securities Fund		Net Balance
	(In Thousands)
Three months ended June 30, 2015	$	(150	)	$	641	$	185	$	676
Three months ended June 30, 2014	259			344		124		727
Six months ended June 30, 2015	(236		)	455		297		516
Six months ended June 30, 2014	375			772		349		1,496

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, 2015				As of December 31, 2014				As of June 30, 2015
	Fair Value		Unfunded Commitments		Fair Value		Unfunded Commitments		Redemption Frequency	Length of Settlement
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity funds	$	5,910	$	2,148	$	6,047	$	2,348	(a)	(a)
Alternative investment fund (b)	17,425		—		16,970		—		Quarterly	65 days
Real estate securities fund	10,042		—		9,548		—		Quarterly	80 days
Total Nuclear Decommissioning Trust	33,377		2,148		32,565		2,348

Trading Securities:
Domestic equity funds	18,207		—		18,698		—		Upon Notice	1 day
International equity funds	4,510		—		4,252		—		Upon Notice	1 day
Core bond fund	12,264		—		12,379		—		Upon Notice	1 day
Total Trading Securities	34,981		—		35,329		—
Total	$	68,358	$	2,148	$	67,894	$	2,348

_______________

(a)

This investment is in three long-term private equity funds that do not permit early withdrawal. Our investments in these funds cannot be distributed until the underlying investments have been liquidated, which may take years from the date of initial liquidation. Two funds have begun to make distributions. Our initial investment in the third fund occurred in the third quarter of 2013. This fund's term is expected to be 15 years, subject to the general partner's right to extend the term for up to three additional one-year periods.


(b)	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 from interest rates. Volatility in these markets impacts our costs of purchased power, costs of fuel for our generating plants and our participation in energy markets. We strive to manage our customers' and our exposure to market risks through regulatory, operating and financing activities and when we deem appropriate, we economically hedge a portion of these risks through the use of derivative financial instruments for non-trading purposes.

Interest Rate Risk

We have entered into numerous fixed and variable rate debt obligations. 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, 2015

Investments [Abstract]

Financial Investments

FINANCIAL INVESTMENTS

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

Trading Securities

We hold equity and debt investments which we classify as trading securities in a trust used to fund certain retirement benefit obligations. As of June 30, 2015, and December 31, 2014, we measured the fair value of trust assets at $35.1 million and $35.5 million, respectively. We include unrealized gains or losses on these securities in investment earnings on our consolidated statements of income. For the three months ended June 30, 2015, we recorded no unrealized gain or loss on assets still held. For the six months ended June 30, 2015, we recorded unrealized gains of $0.7 million on assets still held. For the three and six months ended June 30, 2014, we recorded unrealized gains of $1.1 million and $1.6 million on assets still held, respectively.

Available-for-Sale Securities

We hold investments in a trust for the purpose of funding the decommissioning of Wolf Creek. We have classified these investments as available-for-sale and have recorded all such investments at their fair market value as of June 30, 2015, and December 31, 2014.

Using the specific identification method to determine cost, we realized a loss of $0.6 million during the three months ended June 30, 2015, and a loss of $0.5 million during the six months ended June 30, 2015, on our available-for-sale securities. We realized no gains on our available-for-sale securities for the three months ended June 30, 2014, and a gain of $0.1 million for the six months ended June 30, 2014. 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, respectively, 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, 2015, and December 31, 2014.



			Gross Unrealized
Security Type	Cost		Gain		Loss			Fair Value		Allocation
	(Dollars In Thousands)
As of June 30, 2015
Domestic equity funds	$	42,157	$	16,301	$	(116	)	$	58,342	31	%
International equity funds	30,819		4,778		(300		)	35,297		19	%
Core bond fund	19,163		272		—			19,435		10	%
High-yield bond fund	13,819		—		(109		)	13,710		7	%
Emerging market bond fund	14,135		—		(1,673		)	12,462		6	%
Other fixed income fund	4,889		17		—			4,906		3	%
Combination debt/equity/other funds	16,124		4,424		(546		)	20,002		10	%
Alternative investment fund	15,000		2,425		—			17,425		9	%
Real estate securities fund	10,816		—		(774		)	10,042		5	%
Cash equivalents	313		—		—			313		<1%
Total	$	167,235	$	28,217	$	(3,518	)	$	191,934	100	%

As of December 31, 2014
Domestic equity funds	$	46,126	$	14,853	$	(7	)	$	60,972	33	%
International equity funds	27,521		3,683		(413		)	30,791		17	%
Core bond fund	18,811		478		—			19,289		10	%
High-yield bond fund	13,342		—		(144		)	13,198		7	%
Emerging market bond fund	12,556		—		(1,568		)	10,988		6	%
Other fixed income fund	4,798		—		(19		)	4,779		3	%
Combination debt/equity/other funds	14,975		3,786		(620		)	18,141		10	%
Alternative investment fund	15,000		1,970		—			16,970		9	%
Real estate securities fund	10,619		—		(1,071		)	9,548		5	%
Cash equivalents	340		—		—			340		<1%
Total	$	164,088	$	24,770	$	(3,842	)	$	185,016	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, 2015, and December 31, 2014.



	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, 2015
Domestic equity funds	$	—	$	—		$	354	$	(116	)	$	354	$	(116	)
International equity funds	7,415		(300		)	—		—			7,415		(300		)
High-yield bond fund	13,710		(109		)	—		—			13,710		(109		)
Emerging market bond fund	—		—			12,462		(1,673		)	12,462		(1,673		)
Combination debt/equity/other funds	—		—			6,457		(546		)	6,457		(546		)
Real estate securities fund	—		—			10,042		(774		)	10,042		(774		)
Total	$	21,125	$	(409	)	$	29,315	$	(3,109	)	$	50,440	$	(3,518	)

As of December 31, 2014
Domestic equity funds	$	—	$	—		$	263	$	(7	)	$	263	$	(7	)
International equity funds	5,905		(413		)	—		—			5,905		(413		)
High-yield bond fund	13,198		(144		)	—		—			13,198		(144		)
Emerging market bond fund	—		—			10,988		(1,568		)	10,988		(1,568		)
Other fixed income funds	4,779		(19		)	—		—			4,779		(19		)
Combination debt/equity/other funds	—		—			5,892		(620		)	5,892		(620		)
Real estate securities fund	—		—			9,548		(1,071		)	9,548		(1,071		)
Total	$	23,882	$	(576	)	$	26,691	$	(3,266	)	$	50,573	$	(3,842	)

Taxes	6 Months Ended
Taxes	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Taxes	TAXES We recorded income tax expense of $33.8 million with an effective income tax rate of 34% for the three months ended June 30, 2015, and income tax expense of $26.2 million with an effective income tax rate of 32% for the same period of 2014. We recorded income tax expense of $61.5 million with an effective income tax rate of 34% for the six months ended June 30, 2015, and income tax expense of $61.1 million with an effective income tax rate of 33% for the same period of 2014. As of June 30, 2015, and December 31, 2014, our unrecognized income tax benefits totaled $3.3 million and $3.2 million, respectively. We do not expect significant changes in our unrecognized income tax benefits in the next 12 months. As of June 30, 2015, and December 31, 2014, we had no amounts accrued for interest related to our unrecognized income tax benefits. We accrued no penalties at either June 30, 2015, or December 31, 2014. As of June 30, 2015, and December 31, 2014, we had recorded $1.5 million for probable assessments of taxes other than income taxes. Effective January 1, 2014, we adopted new regulations released by the Internal Revenue Service and the United States Treasury Department regarding deduction and capitalization of expenditures related to tangible property, including the tax treatment of, among other things, materials and supplies and the determination of whether expenditures with respect to tangible property are a deductible repair or must be capitalized, and regulations regarding dispositions of property under the Modified Accelerated Cost Recovery System. The adoption of these regulations did not have a material impact on our consolidated financial results.

Pension and Post-Retirement Benefit Plans

6 Months Ended

Jun. 30, 2015

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,	2015			2014			2015			2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	5,348		$	4,055		$	361		$	345
Interest cost	10,753			10,400			1,422			1,588
Expected return on plan assets	(10,059		)	(9,109		)	(1,654		)	(1,644		)
Amortization of unrecognized:
Prior service costs	130			131			114			631
Actuarial loss (gain), net	8,053			4,840			95			(185		)
Net periodic cost before regulatory adjustment	14,225			10,317			338			735
Regulatory adjustment (a)	1,534			4,002			1,013			1,124
Net periodic cost	$	15,759		$	14,319		$	1,351		$	1,859

_______________


(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,	2015			2014			2015			2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	10,696		$	8,110		$	722		$	691
Interest cost	21,507			20,800			2,845			3,175
Expected return on plan assets	(20,118		)	(18,219		)	(3,307		)	(3,288		)
Amortization of unrecognized:
Prior service costs	260			262			227			1,262
Actuarial loss (gain), net	15,714			9,681			190			(371		)
Net periodic cost before regulatory adjustment	28,059			20,634			677			1,469
Regulatory adjustment (a)	3,332			8,003			2,026			2,247
Net periodic cost	$	31,391		$	28,637		$	2,703		$	3,716

_______________


(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, 2015 and 2014, we contributed $19.4 million and $19.0 million, respectively,

to the Westar Energy pension trust.

Wolf Creek Pension and Post-Retirement Benefit Plans

6 Months Ended

Jun. 30, 2015

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,	2015			2014			2015		2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	1,899		$	1,424		$	34	$	43
Interest cost	2,254			2,117			79		116
Expected return on plan assets	(2,261		)	(2,021		)	—		—
Amortization of unrecognized:
Prior service costs	14			14			—		—
Actuarial loss, net	1,482			747			1		41
Net periodic cost before regulatory adjustment	3,388			2,281			114		200
Regulatory adjustment (a)	(304		)	501			—		—
Net periodic cost	$	3,084		$	2,782		$	114	$	200

_______________


(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,	2015			2014			2015		2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	3,797		$	2,847		$	69	$	87
Interest cost	4,508			4,235			157		232
Expected return on plan assets	(4,522		)	(4,042		)	—		—
Amortization of unrecognized:
Prior service costs	28			29			—		—
Actuarial loss, net	2,965			1,493			1		82
Net periodic cost before regulatory adjustment	6,776			4,562			227		401
Regulatory adjustment (a)	(608		)	1,002			—		—
Net periodic cost	$	6,168		$	5,564		$	227	$	401

_______________


(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, 2015, we funded $2.5 million of Wolf Creek's pension plan contributions. During the six months ended June 30, 2014, we did not fund Wolf Creek's pension plan contributions.

Commitments And Contingencies	6 Months Ended
Commitments And Contingencies	Jun. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES Federal Clean Air Act We must comply with the federal Clean Air Act (CAA), state laws and implementing federal and state regulations that impose, among other things, limitations on emissions generated from our operations, including sulfur dioxide (SO₂), particulate matter (PM), nitrogen oxides (NOx), carbon monoxide (CO), mercury and acid gases. Emissions from our generating facilities, including PM, SO₂ and NOx, have been determined by regulation to reduce visibility by causing or contributing to regional haze. Under federal laws, such as the Clean Air Visibility Rule, and pursuant to an agreement with the Kansas Department of Health and Environment (KDHE) and the Environmental Protection Agency (EPA), we are required to install, operate and maintain controls to reduce emissions found to cause or contribute to regional haze. Cross-State Air Pollution Rule In 2011, the EPA finalized the Cross-State Air Pollution Rule (CSAPR) requiring 28 states, including Kansas, Missouri and Oklahoma, to further reduce emissions of SO₂ and NOx. In April 2014, the U.S. Supreme Court reversed a 2012 decision by the U.S. Court of Appeals for the District of Columbia Circuit that had vacated CSAPR and remanded CSAPR back to the U.S. Court of Appeals for further proceedings consistent with the U.S. Supreme Court decision. In June 2014, the U.S. Department of Justice, on behalf of the EPA, filed a motion to lift the CSAPR stay. In October 2014, the U.S. Court of Appeals granted the motion to lift the CSAPR stay and established a schedule to hear arguments on the remaining outstanding issues, which began in March 2015. In July 2015, the U.S. Court of Appeals found the EPA erred in certain SO₂ and ozone season NOx emissions budgets for several states and sent these back to the EPA for reconsideration, but upheld the remainder of the rule. During the CSAPR stay, we installed various emission controls at our generation facilities that we expect reduces the impact of CSAPR. We are unable to determine the full impact of reinstatement, and any possible revisions, of CSAPR. However, we are prepared to comply with CSAPR in its current form. National Ambient Air Quality Standards Under the federal CAA, 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, ozone, 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. In December 2014, the EPA published a proposed rule revising NAAQS for ozone and to make certain other changes, including extending the ozone monitoring season by at least one month. The EPA intends to issue a final rule regarding the ozone NAAQS by October 2015 and make attainment/nonattainment designations for any revised standards by October 2017. We are currently reviewing this proposed rule and cannot at this time predict the impact it may have on our operations, but it could be material. Nonattainment designations on areas that impact our operations could have a material impact on our consolidated financial results. In December 2012, the EPA strengthened an existing NAAQS for one class of PM. In December 2014, the EPA designated the entire state of Kansas as unclassifiable/in attainment with the standard. We cannot at this time predict the impact this designation may have on our operations or consolidated financial results, but it could be material. In 2010, the EPA revised the NAAQS for both NOx and SO₂. In March 2015, a federal court approved a consent decree between the EPA and environmental groups. The decree includes specific SO₂ emissions criteria for certain electric generating plants that, if met, requires the EPA to promulgate attainment/nonattainment designations for areas surrounding these plants by July 2016. Tecumseh Energy Center (TEC) meets this criteria. We are working with KDHE to determine the appropriate designation for the areas surrounding the facility. In addition, we continue to communicate with our regulatory agencies regarding these standards and evaluate what impact the revised NAAQS could have on our operations and consolidated financial results. If areas surrounding our facilities are designated as nonattainment and/or we are required to install additional equipment to control emissions at our facilities, it could have a material impact on our operations and consolidated financial results. Greenhouse Gases Byproducts of burning coal and other fossil fuels include carbon dioxide (CO₂) and other gases referred to as GHGs, which are believed by many to contribute to climate change. Various regulations under the federal CAA limit CO₂ and other GHG emissions, and other measures are being imposed or offered by individual states, municipalities and regional agreements with the goal of reducing GHG emissions. In August 2015, the EPA issued a rule establishing new source performance standards that limit CO₂ emissions for new, modified and reconstructed coal and natural gas fueled electric generating units to various levels per Megawatt hour (MWh) depending on various characteristics of the units. In August 2015, the EPA also issued a rule establishing guidelines for states to regulate CO₂ emissions from existing power plants. The standards for existing plants are known as the Clean Power Plan (CPP). Interim emissions performance rates must be achieved beginning in 2022 and final emissions performance rates must be achieved by 2030. Legal challenges to the CPP are expected. We are evaluating the CPP and cannot at this time determine the impact of the CPP on our operations or consolidated financial results, but we believe the costs to comply could be material. Under regulations formerly known as the Tailoring Rule, the EPA regulates GHG emissions from certain stationary sources. The regulations are implemented pursuant to two federal CAA programs, the Prevention of Significant Deterioration (PSD) and Title V Operating Permit Programs, that 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 (currently defined to be more than 75,000 tons or more per year or 100,000 tons or more per year, depending on various factors). In June 2014, the U.S. Supreme Court ruled that the EPA had exceeded its statutory authority in issuing the Tailoring Rule by regulating under the PSD program sources based solely on their GHG emissions. However, the U.S. Supreme Court also held that the EPA could impose GHG BACT requirements for sources already required to implement PSD for other pollutants. Therefore, if future modifications to our sources require PSD review for other pollutants, it may also trigger GHG BACT requirements. 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 or consolidated financial results as we would not be required to implement BACT until we construct a new major source or make a major modification of an existing major source. The cost of compliance, however, could be material. Mercury and Air Toxics Standards In 2012, the Mercury and Air Toxics Standards (MATS) rule became effective. Under the MATS rule the EPA regulates the emissions of mercury, non-mercury metals, acid gases and organics. MATS required compliance to begin in April 2015, three years after the effective date. Sources could petition their state air regulatory agency to ask for an additional year to prepare for compliance. We petitioned the KDHE and our petition request was granted. Our current compliance date is April 2016 for all of our MATS affected units. In June 2015, the U.S. Supreme Court reversed and remanded a decision by the U.S. Court of Appeals for the District of Columbia Circuit regarding the need for the EPA to consider costs during the initial phase of MATS development. On remand, the court could instruct the EPA on the cost benefit analysis needed to support the rule, vacate the rule in its entirety or take other action. MATS will remain in effect during the remand proceedings unless a stay is requested and granted. There will not be a material impact on our operations or consolidated financial results if MATS in its current form becomes a final rule. We are unable to predict the impact on our operations or consolidated financial results if MATS is vacated and the EPA proposes a replacement rule. Water We discharge some of the water used in our operations. This water may contain substances deemed to be pollutants. Revised rules governing such discharges from coal-fired power plants are expected to be issued by the EPA by the end of September 2015. Although we cannot at this time determine the timing or impact of compliance with any new regulations, more stringent regulations could have a material impact on our operations or consolidated financial results. In October 2014, the EPA’s final standards for cooling intake structures at power plants to protect aquatic life took effect. The standards, based on Section 316(b) of the federal Clean Water Act (CWA), require subject facilities to choose among seven best technology available options to reduce fish impingement. In addition, some facilities must conduct studies to assist permitting authorities to determine whether and what site-specific controls, if any, would be required to reduce entrainment of aquatic organisms. Our current analysis indicates this rule will not have a significant impact on our coal plants that employ cooling towers. Biological monitoring may be required for LaCygne and Wolf Creek. We are currently evaluating the rule's impact on those two plants and cannot predict the resulting impact on our operations or consolidated financial results, but we do not expect it to be material. In June 2015, the EPA along with the U.S. Army Corps of Engineers issued a final rule, effective August 2015, defining the Waters of the United States for purposes of the CWA. This rulemaking has the potential to impact all programs under the CWA. Expansion of regulated waterways is possible under the rule depending on regulating authority interpretation, which could impact several permitting programs. Also in June 2015, a group of states filed a lawsuit challenging the rule. We are currently evaluating this more stringent rule. The resulting impact of the rule could have a material impact on our operations or consolidated financial results. Regulation of Coal Combustion Byproducts In the course of operating our coal generation plants, we produce coal combustion byproducts (CCBs), including fly ash, gypsum and bottom ash. We recycle some of our ash production, principally by selling to the aggregate industry. The EPA published a rule to regulate CCBs in April 2015, which we believe will require additional CCB handling, processing and storage equipment and potential closure of certain ash disposal areas. While we cannot at this time estimate the full impact and costs associated with future regulations of CCBs, we have recorded an increase of approximately $48.8 million to our ARO and property, plant and equipment to recognize estimated future costs associated with closure and post-closure of disposal sites. We believe further impact on our operations or consolidated financial results could be material. See Note 11, "Asset Retirement Obligations," for additional information. Renewable Energy Standard In May 2015, Kansas repealed a state mandate to maintain a minimum amount of renewable energy sources, effective January 1, 2016. Storage of Spent Nuclear Fuel In 2010, the DOE filed a motion with the NRC to withdraw its then pending application to construct a national repository for the disposal of spent nuclear fuel and high-level radioactive waste at Yucca Mountain, Nevada. An NRC board denied the DOE's motion to withdraw its application and the DOE appealed that decision to the full NRC. In 2011, the NRC issued an evenly split decision on the appeal and also ordered the licensing board to close out its work on the DOE's application by the end of 2011 due to a lack of funding. These agency actions prompted the States of Washington and South Carolina, and a county in South Carolina, to file a lawsuit in a federal Court of Appeals asking the court to compel the NRC to resume its license review and to issue a decision on the license application. In August 2013, the court ordered the NRC to resume its review of the DOE's application. The NRC has not yet issued its decision. Wolf Creek is currently evaluating alternatives for expanding its existing on-site spent nuclear fuel storage to provide additional capacity prior to 2025. We cannot predict when, or if, an off-site storage site or alternative disposal site will be available to receive Wolf Creek's spent nuclear fuel and will continue to monitor this activity. FERC Proceedings See Note 3, "Rate Matters and Regulation - FERC Proceedings," for information regarding a complaint that was filed by the KCC against us with the FERC under Section 206 of the FPA.

Asset Retirement Obligations (Notes)

6 Months Ended

Jun. 30, 2015

Asset Retirement Obligation [Abstract]

Asset Retirement Obligation Disclosure [Text Block]

ASSET RETIREMENT OBLIGATIONS

In 2015, we recorded an approximately $48.8 million increase in our ARO in response to the EPA's published rule to regulate CCBs. The increase is to recognize costs associated with closure and post-closure of disposal sites to be compliant. See Note 10, "Commitments and Contingencies - Regulation of Coal Combustion Byproducts," for additional information.

The change in the balance of our ARO liability from December 31, 2014, through June 30, 2015, is summarized in the following table.



	(In Thousands)
Balance as of December 31, 2014	$	230,668
Liabilities incurred	48,767
Liabilities settled	(1,139		)
Accretion expense	6,132
Revisions in estimated cash flows	(1,234		)
Balance as of June 30, 2015	$	283,194

Variable Interest Entities

6 Months Ended

Jun. 30, 2015

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 Jeffrey Energy Center (JEC) and our 50% interest in La Cygne

unit 2 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.

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, 2015		December 31, 2014
	(In Thousands)
Assets:
Property, plant and equipment of variable interest entities, net	$	273,406	$	278,573
Regulatory assets (a)	8,513		7,882

Liabilities:
Current maturities of long-term debt of variable interest entities	$	28,315	$	27,933
Accrued interest (b)	2,458		2,961
Long-term debt of variable interest entities, net	138,173		166,565

_______________

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

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

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

Summary Of Significant Accounting Policies (Policy)	6 Months Ended
Summary Of Significant Accounting Policies (Policy)	Jun. 30, 2015
Accounting Policies [Abstract]
Principles Of Consolidation	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) for the United States of America 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.
Use Of Management's Estimates	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 ongoing basis, including those related to depreciation, unbilled revenue, valuation of investments, forecasted fuel costs included in our retail energy cost adjustment (RECA) billed to customers, income taxes, pension and post-retirement benefits, our asset retirement obligations (AROs) including the decommissioning of Wolf Creek, environmental issues, VIEs, contingencies and litigation. Actual results may differ from those estimates under different assumptions or conditions.
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 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
Earnings Per Share	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). 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 issuable 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.

Summary Of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2015

Accounting Policies [Abstract]

Schedule of Utility Inventory

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



	As of		As of
	June 30, 2015		December 31, 2014
	(In Thousands)
Fuel inventory	$	94,450	$	70,416
Supplies	184,576		176,990
Fuel inventory and supplies	$	279,026	$	247,406

Allowance For Funds Used During Construction

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



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Dollars In Thousands)
Borrowed funds	$	552		$	3,213		$	2,581		$	6,944
Equity funds	90			4,712			2,041			9,718
Total	$	642		$	7,925		$	4,622		$	16,662
Average AFUDC Rates	1.2		%	6.8		%	3.2		%	7.0		%

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,
	2015		2014		2015		2014
	(Dollars In Thousands, Except Per Share Amounts)
Net income	$	66,243	$	55,822	$	119,406	$	126,792
Less: Net income attributable to noncontrolling interests	2,533		2,349		4,716		4,365
Net income attributable to Westar Energy, Inc.	63,710		53,473		114,690		122,427
Less: Net income allocated to RSUs	141		148		257		336
Net income allocated to common stock	$	63,569	$	53,325	$	114,433	$	122,091

Weighted average equivalent common shares outstanding – basic	135,939,197		129,363,382		134,177,136		129,184,767
Effect of dilutive securities:
RSUs	121,234		164,641		127,999		122,221
Forward sale agreements	1,351,721		2,445,116		2,024,468		2,471,596
Weighted average equivalent common shares outstanding – diluted (a)	137,412,152		131,973,139		136,329,603		131,778,584

Earnings per common share, basic	$	0.47	$	0.41	$	0.85	$	0.95
Earnings per common share, diluted	$	0.46	$	0.40	$	0.84	$	0.93

_______________

(a)We had no antidilutive securities for the three and six months ended June 30, 2015 and 2014.

Supplemental Cash Flow Information



	Six Months Ended June 30,
	2015		2014
	(In Thousands)
CASH PAID FOR:
Interest on financing activities, net of amount capitalized	$	82,297	$	80,373
Interest on financing activities of VIEs	5,651		6,526
Income taxes, net of refunds	126		236
NON-CASH INVESTING TRANSACTIONS:
Property, plant and equipment additions	66,861		90,395
NON-CASH FINANCING TRANSACTIONS:
Issuance of stock for compensation and reinvested dividends	5,532		4,212
Assets acquired through capital leases	1,102		1,195

Financial Instruments and Risk Management (Tables)

6 Months Ended

Jun. 30, 2015

Jun. 30, 2014

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, 2015				As of December 31, 2014
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In Thousands)
Fixed-rate debt	$	2,980,000	$	3,207,527	$	3,105,000	$	3,488,410
Fixed-rate debt of VIEs	166,278		181,951		194,204		213,579

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, 2015	Level 1		Level 2		Level 3		Total
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity funds	$	—	$	52,432	$	5,910	$	58,342
International equity funds	—		35,297		—		35,297
Core bond fund	—		19,435		—		19,435
High-yield bond fund	—		13,710		—		13,710
Emerging market bond fund	—		12,462		—		12,462
Other fixed income fund	—		4,906		—		4,906
Combination debt/equity/other funds	—		20,002		—		20,002
Alternative investment fund	—		—		17,425		17,425
Real estate securities fund	—		—		10,042		10,042
Cash equivalents	313		—		—		313
Total Nuclear Decommissioning Trust	313		158,244		33,377		191,934
Trading Securities:
Domestic equity funds	—		18,207		—		18,207
International equity fund	—		4,510		—		4,510
Core bond fund	—		12,264		—		12,264
Cash equivalents	168		—		—		168
Total Trading Securities	168		34,981		—		35,149
Total Assets Measured at Fair Value	$	481	$	193,225	$	33,377	$	227,083

As of December 31, 2014	Level 1		Level 2		Level 3		Total
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity funds	$	—	$	54,925	$	6,047	$	60,972
International equity funds	—		30,791		—		30,791
Core bond fund	—		19,289		—		19,289
High-yield bond fund	—		13,198		—		13,198
Emerging market bond fund	—		10,988		—		10,988
Other fixed income fund	—		4,779		—		4,779
Combination debt/equity/other funds	—		18,141		—		18,141
Alternative investment fund	—		—		16,970		16,970
Real estate securities fund	—		—		9,548		9,548
Cash equivalents	340		—		—		340
Total Nuclear Decommissioning Trust	340		152,111		32,565		185,016
Trading Securities:
Domestic equity funds	—		18,698		—		18,698
International equity fund	—		4,252		—		4,252
Core bond fund	—		12,379		—		12,379
Cash equivalents	168		—		—		168
Total Trading Securities	168		35,329		—		35,497
Total Assets Measured at Fair Value	$	508	$	187,440	$	32,565	$	220,513

Reconciliations Of Assets And Liabilities At Fair Value

The following table provides reconciliations of assets measured at fair value using significant level 3 inputs for the three and six months ended June 30, 2015.



	Domestic Equity Funds			Alternative Investment Fund		Real Estate Securities Fund			Net Balance
	(In Thousands)
Balance as of March 31, 2015	$	6,061		$	16,784	$	9,758		$	32,603
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	226			641		284			1,151
Purchases	—			—		100			100
Sales	(377		)	—		(100		)	(477		)
Balance as of June 30, 2015	$	5,910		$	17,425	$	10,042		$	33,377

Balance as of December 31, 2014	$	6,047		$	16,970	$	9,548		$	32,565
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	563			455		494			1,512
Purchases	100			—		197			297
Sales	(800		)	—		(197		)	(997		)
Balance as of June 30, 2015	$	5,910		$	17,425	$	10,042		$	33,377

The following table provides reconciliations of assets measured at fair value using significant level 3 inputs for the three and six months ended June 30, 2014.



	Domestic Equity Funds			Alternative Investment Fund		Real Estate Securities Fund			Net Balance
	(In Thousands)
Balance as of March 31, 2014	$	5,984		$	16,102	$	8,812		$	30,898
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	447			344		214			1,005
Purchases	46			—		89			135
Sales	(189		)	—		(89		)	(278		)
Balance as of June 30, 2014	$	6,288		$	16,446	$	9,026		$	31,760

Balance as of December 31, 2013	$	5,817		$	15,675	$	8,511		$	30,003
Total realized and unrealized gains (losses) included in:
Regulatory liabilities	609			771		515			1,895
Purchases	96			—		166			262
Sales	(234		)	—		(166		)	(400		)
Balance as of June 30, 2014	$	6,288		$	16,446	$	9,026		$	31,760

Unrealized Gains And Losses On Fair Value Assets And Liabilities

The following table summarizes the unrealized gains and losses we recorded to regulatory liabilities on our consolidated financial statements during the three and six months ended June 30, 2015 and 2014, attributed to level 3 assets and liabilities. See Note 3, "Rate Matters and Regulation," in the 2014 Form 10-K for additional information regarding our regulatory assets and liabilities.



	Domestic Equity Funds			Alternative Investment Fund		Real Estate Securities Fund		Net Balance
	(In Thousands)
Three months ended June 30, 2015	$	(150	)	$	641	$	185	$	676
Three months ended June 30, 2014	259			344		124		727
Six months ended June 30, 2015	(236		)	455		297		516
Six months ended June 30, 2014	375			772		349		1,496

Investments In Financial Instruments

The following table provides additional information on these investments.



	As of June 30, 2015				As of December 31, 2014				As of June 30, 2015
	Fair Value		Unfunded Commitments		Fair Value		Unfunded Commitments		Redemption Frequency	Length of Settlement
	(In Thousands)
Nuclear Decommissioning Trust:
Domestic equity funds	$	5,910	$	2,148	$	6,047	$	2,348	(a)	(a)
Alternative investment fund (b)	17,425		—		16,970		—		Quarterly	65 days
Real estate securities fund	10,042		—		9,548		—		Quarterly	80 days
Total Nuclear Decommissioning Trust	33,377		2,148		32,565		2,348

Trading Securities:
Domestic equity funds	18,207		—		18,698		—		Upon Notice	1 day
International equity funds	4,510		—		4,252		—		Upon Notice	1 day
Core bond fund	12,264		—		12,379		—		Upon Notice	1 day
Total Trading Securities	34,981		—		35,329		—
Total	$	68,358	$	2,148	$	67,894	$	2,348

_______________

(a)


(b)	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, 2015

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, 2015, and December 31, 2014.



			Gross Unrealized
Security Type	Cost		Gain		Loss			Fair Value		Allocation
	(Dollars In Thousands)
As of June 30, 2015
Domestic equity funds	$	42,157	$	16,301	$	(116	)	$	58,342	31	%
International equity funds	30,819		4,778		(300		)	35,297		19	%
Core bond fund	19,163		272		—			19,435		10	%
High-yield bond fund	13,819		—		(109		)	13,710		7	%
Emerging market bond fund	14,135		—		(1,673		)	12,462		6	%
Other fixed income fund	4,889		17		—			4,906		3	%
Combination debt/equity/other funds	16,124		4,424		(546		)	20,002		10	%
Alternative investment fund	15,000		2,425		—			17,425		9	%
Real estate securities fund	10,816		—		(774		)	10,042		5	%
Cash equivalents	313		—		—			313		<1%
Total	$	167,235	$	28,217	$	(3,518	)	$	191,934	100	%

As of December 31, 2014
Domestic equity funds	$	46,126	$	14,853	$	(7	)	$	60,972	33	%
International equity funds	27,521		3,683		(413		)	30,791		17	%
Core bond fund	18,811		478		—			19,289		10	%
High-yield bond fund	13,342		—		(144		)	13,198		7	%
Emerging market bond fund	12,556		—		(1,568		)	10,988		6	%
Other fixed income fund	4,798		—		(19		)	4,779		3	%
Combination debt/equity/other funds	14,975		3,786		(620		)	18,141		10	%
Alternative investment fund	15,000		1,970		—			16,970		9	%
Real estate securities fund	10,619		—		(1,071		)	9,548		5	%
Cash equivalents	340		—		—			340		<1%
Total	$	164,088	$	24,770	$	(3,842	)	$	185,016	100	%

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

June 30, 2015, and December 31, 2014.



	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, 2015
Domestic equity funds	$	—	$	—		$	354	$	(116	)	$	354	$	(116	)
International equity funds	7,415		(300		)	—		—			7,415		(300		)
High-yield bond fund	13,710		(109		)	—		—			13,710		(109		)
Emerging market bond fund	—		—			12,462		(1,673		)	12,462		(1,673		)
Combination debt/equity/other funds	—		—			6,457		(546		)	6,457		(546		)
Real estate securities fund	—		—			10,042		(774		)	10,042		(774		)
Total	$	21,125	$	(409	)	$	29,315	$	(3,109	)	$	50,440	$	(3,518	)

As of December 31, 2014
Domestic equity funds	$	—	$	—		$	263	$	(7	)	$	263	$	(7	)
International equity funds	5,905		(413		)	—		—			5,905		(413		)
High-yield bond fund	13,198		(144		)	—		—			13,198		(144		)
Emerging market bond fund	—		—			10,988		(1,568		)	10,988		(1,568		)
Other fixed income funds	4,779		(19		)	—		—			4,779		(19		)
Combination debt/equity/other funds	—		—			5,892		(620		)	5,892		(620		)
Real estate securities fund	—		—			9,548		(1,071		)	9,548		(1,071		)
Total	$	23,882	$	(576	)	$	26,691	$	(3,266	)	$	50,573	$	(3,842	)

Pension and Post-Retirement Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2015

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,	2015			2014			2015			2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	5,348		$	4,055		$	361		$	345
Interest cost	10,753			10,400			1,422			1,588
Expected return on plan assets	(10,059		)	(9,109		)	(1,654		)	(1,644		)
Amortization of unrecognized:
Prior service costs	130			131			114			631
Actuarial loss (gain), net	8,053			4,840			95			(185		)
Net periodic cost before regulatory adjustment	14,225			10,317			338			735
Regulatory adjustment (a)	1,534			4,002			1,013			1,124
Net periodic cost	$	15,759		$	14,319		$	1,351		$	1,859

_______________


(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,	2015			2014			2015			2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	10,696		$	8,110		$	722		$	691
Interest cost	21,507			20,800			2,845			3,175
Expected return on plan assets	(20,118		)	(18,219		)	(3,307		)	(3,288		)
Amortization of unrecognized:
Prior service costs	260			262			227			1,262
Actuarial loss (gain), net	15,714			9,681			190			(371		)
Net periodic cost before regulatory adjustment	28,059			20,634			677			1,469
Regulatory adjustment (a)	3,332			8,003			2,026			2,247
Net periodic cost	$	31,391		$	28,637		$	2,703		$	3,716

_______________


(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, 2015

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,	2015			2014			2015			2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	5,348		$	4,055		$	361		$	345
Interest cost	10,753			10,400			1,422			1,588
Expected return on plan assets	(10,059		)	(9,109		)	(1,654		)	(1,644		)
Amortization of unrecognized:
Prior service costs	130			131			114			631
Actuarial loss (gain), net	8,053			4,840			95			(185		)
Net periodic cost before regulatory adjustment	14,225			10,317			338			735
Regulatory adjustment (a)	1,534			4,002			1,013			1,124
Net periodic cost	$	15,759		$	14,319		$	1,351		$	1,859

_______________


(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,	2015			2014			2015			2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	10,696		$	8,110		$	722		$	691
Interest cost	21,507			20,800			2,845			3,175
Expected return on plan assets	(20,118		)	(18,219		)	(3,307		)	(3,288		)
Amortization of unrecognized:
Prior service costs	260			262			227			1,262
Actuarial loss (gain), net	15,714			9,681			190			(371		)
Net periodic cost before regulatory adjustment	28,059			20,634			677			1,469
Regulatory adjustment (a)	3,332			8,003			2,026			2,247
Net periodic cost	$	31,391		$	28,637		$	2,703		$	3,716

_______________


(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,	2015			2014			2015		2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	1,899		$	1,424		$	34	$	43
Interest cost	2,254			2,117			79		116
Expected return on plan assets	(2,261		)	(2,021		)	—		—
Amortization of unrecognized:
Prior service costs	14			14			—		—
Actuarial loss, net	1,482			747			1		41
Net periodic cost before regulatory adjustment	3,388			2,281			114		200
Regulatory adjustment (a)	(304		)	501			—		—
Net periodic cost	$	3,084		$	2,782		$	114	$	200

_______________


(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,	2015			2014			2015		2014
	(In Thousands)
Components of Net Periodic Cost (Benefit):
Service cost	$	3,797		$	2,847		$	69	$	87
Interest cost	4,508			4,235			157		232
Expected return on plan assets	(4,522		)	(4,042		)	—		—
Amortization of unrecognized:
Prior service costs	28			29			—		—
Actuarial loss, net	2,965			1,493			1		82
Net periodic cost before regulatory adjustment	6,776			4,562			227		401
Regulatory adjustment (a)	(608		)	1,002			—		—
Net periodic cost	$	6,168		$	5,564		$	227	$	401

_______________


(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, 2015

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, 2015		December 31, 2014
	(In Thousands)
Assets:
Property, plant and equipment of variable interest entities, net	$	273,406	$	278,573
Regulatory assets (a)	8,513		7,882

Liabilities:
Current maturities of long-term debt of variable interest entities	$	28,315	$	27,933
Accrued interest (b)	2,458		2,961
Long-term debt of variable interest entities, net	138,173		166,565

_______________

(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, 2015	Dec. 31, 2014
Public Utilities, Inventory [Line Items]
Total	$ 279,026	$ 247,406
Fuel Inventory [Member]
Public Utilities, Inventory [Line Items]
Public Utility Inventory	94,450	70,416
Supplies [Member]
Public Utilities, Inventory [Line Items]
Public Utility Inventory	$ 184,576	$ 176,990

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, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Accounting Policies [Abstract]
Borrowed funds	$ (552)	$ (3,213)	$ (2,581)	$ (6,944)
Equity funds	90	4,712	2,041	9,718
Total	$ 642	$ 7,925	$ 4,622	$ 16,662
Average AFUDC rates	1.20%	6.80%	3.20%	7.00%

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, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Accounting Policies [Abstract]
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic	$ 141	$ 148	$ 257	$ 336
Net income allocated to common stock	$ 63,569	$ 53,325	$ 114,433	$ 122,091
Weighted Average Number of Shares Outstanding , Basic	135,939,197	129,363,382	134,177,136	129,184,767
RSUs	121,234	164,641	127,999	122,221
Forward sale agreements	1,351,721	2,445,116	2,024,468	2,471,596
Weighted average equivalent common shares outstanding - diluted	137,412,152	131,973,139	136,329,603	131,778,584
Earnings Per Share, Basic	$ 0.47	$ 0.41	$ 0.85	$ 0.95
Earnings Per Share, Diluted	$ 0.46	$ 0.40	$ 0.84	$ 0.93
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities			0	0

Summary Of Significant Accounting Policies (Supplemental Cash Flow Information) (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash Paid For (Received From)
Interest on financing activities	$ 82,297	$ 80,373
Income taxes, net of refunds	126	236
Noncash Investing and Financing Transactions
Property, plant and equipment	66,861	90,395
Issuance of common stock for reinvested dividends and compensation plans	5,532	4,212
Deconsolidation of VIE	(1,076)
Assets acquired through capital leases	1,102	1,195
Variable Interest Entity, Primary Beneficiary [Member]
Cash Paid For (Received From)
Interest on financing activities	$ 5,651	$ 6,526

Rate Matters And Regulation (Narrative) (Details) (USD $) In Millions, unless otherwise specified	1 Months Ended
	Jun. 30, 2015
FERC 206 [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 10.0
Loss Contingency Accrual	8.6
Kansas Corporation Commission [Member] \| Electric Transmission [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	7.2
Kansas Corporation Commission [Member] \| Environmental Cost Recovery Rider [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	10.8
Kansas Corporation Commission [Member] \| Ad Valorem Tax [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	4.9
Federal Energy Regulatory Commission [Member] \| Electric Transmission [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	4.6
Westar Energy [Member] \| Kansas Corporation Commission [Member] \| General Rate Case [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	152.0
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount	130.0
Kansas Corporation Commission Staff [Member] \| Kansas Corporation Commission [Member] \| General Rate Case [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 55.0
Total Return on Equity [Member] \| FERC 206 [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Return on Equity, Percentage	10.30%
Base Return on Equity [Member] \| FERC 206 [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Requested Return on Equity, Percentage	9.80%
Incentive Return on Equity [Member] \| FERC 206 [Member]
Regulatory Proceedings [Line Items]
Public Utilities, Approved Return on Equity, Percentage	0.50%

Financial Instruments and Risk Management (Carrying Values And Fair Values Of Financial Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2015	Dec. 31, 2014
Fixed Rate Debt Member
Debt Instrument [Line Items]
Carrying Value	$ 2,980,000	$ 3,105,000
Fair Value	3,207,527	3,488,410
Fixed Rate Debt Of Variable Interest Entities Member
Debt Instrument [Line Items]
Carrying Value	166,278	194,204
Fair Value	$ 181,951	$ 213,579

Financial Instruments and Risk Management (Reconciliations Of Assets And Liabilities At Fair Value) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	$ 32,603	$ 30,898	$ 32,565	$ 30,003
Regulatory liabilities	1,151	1,005	1,512	1,895
Purchases	100	135	297	262
Sales	(477)	(278)	(997)	(400)
Balance at period end	33,377	31,760	33,377	31,760
Domestic Equity [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	6,061	5,984	6,047	5,817
Regulatory liabilities	226	447	563	609
Purchases	0	46	100	96
Sales	(377)	(189)	(800)	(234)
Balance at period end	5,910	6,288	5,910	6,288
Alternative Funds [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	16,784	16,102	16,970	15,675
Regulatory liabilities	641	344	455	771
Purchases	0	0	0	0
Sales	0	0	0	0
Balance at period end	17,425	16,446	17,425	16,446
Real Estate Securities [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Balance at period start	9,758	8,812	9,548	8,511
Regulatory liabilities	284	214	494	515
Purchases	100	89	197	166
Sales	(100)	(89)	(197)	(166)
Balance at period end	$ 10,042	$ 9,026	$ 10,042	$ 9,026

Financial Instruments and Risk Management (Unrealized Gains And Losses On Financial Statements) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Unrealized gain (loss) included in regulatory liabilities	$ 676	$ 727	$ 516	$ 1,496
Domestic Equity [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Unrealized gain (loss) included in regulatory liabilities	(150)	(259)	(236)	375
Alternative Funds [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Unrealized gain (loss) included in regulatory liabilities	641	(344)	455	772
Real Estate Securities [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Unrealized gain (loss) included in regulatory liabilities	$ 185	$ (124)	$ 297	$ 349

Financial Instruments and Risk Management (Investments In Financial Instruments) (Details) (USD $)
In Thousands, unless otherwise specified

6 Months Ended

Jun. 30, 2015

Dec. 31, 2014

Financial and Derivative Instruments and Trading Securities [Line Items]

$ 191,934

$ 185,016

Asset Retirement Obligation, Revision of Estimate

35,149

35,497

Total

227,083

220,513

(1,234)

Domestic Equity [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

58,342

60,972

Financial and Derivative Instruments and Trading Securities [Line Items]

18,207

18,698

Alternative Funds [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

17,425

16,970

Real Estate Securities [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

10,042

9,548

International Equity [Member]

35,297

30,791

Financial and Derivative Instruments and Trading Securities [Line Items]

4,510

4,252

Core Bonds [Member]

19,435

19,289

Financial and Derivative Instruments and Trading Securities [Line Items]

12,264

12,379

Fair Value [Member]

33,377

32,565

34,981

35,329

Total

68,358

67,894

Financial and Derivative Instruments and Trading Securities [Line Items]

2,148

2,348

Fair Value [Member] | Domestic Equity [Member]

5,910

^[1]

6,047

^[1]

Financial and Derivative Instruments and Trading Securities [Line Items]

18,207

18,698

Fair Value [Member] | Alternative Funds [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

17,425

16,970

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

Financial and Derivative Instruments and Trading Securities [Line Items]

10,042

9,548

Fair Value [Member] | International Equity [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

4,510

4,252

Fair Value [Member] | Core Bonds [Member]

Financial and Derivative Instruments and Trading Securities [Line Items]

12,264

12,379

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

Financial and Derivative Instruments and Trading Securities [Line Items]

2,148

2,348

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

2,148

2,348

Financial and Derivative Instruments and Trading Securities [Line Items]

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

Quarterly

Financial and Derivative Instruments and Trading Securities [Line Items]

65 days

^[2]

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

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

1 day

[1]

[2]

{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOjMwYTIyMzlkMDk4ZTQ3YmViMTBmNGQ2NmYzZjczZjQwfFRleHRTZWxlY3Rpb246M0Y3MUM2NDhENDlGNkNENDNFNTlBQkVBQkY2MUVEMjIM}

Financial Investments (Narrative) (Details) (USD $)	3 Months Ended		6 Months Ended
Financial Investments (Narrative) (Details) (USD $)	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Schedule of Available-for-sale Securities [Line Items]
Trading securities	$ 35,149,000		$ 35,149,000		$ 35,497,000
Unrealized gains losses	0	1,100,000	700,000	1,600,000
Realized gains on available-for-sale-securities	600,000	0	500,000	100,000
Revolving Credit Facility Lender Two [Member]
Schedule of Available-for-sale Securities [Line Items]
Long-term Line of Credit	$ 0		$ 0		$ 0

Financial Investments (Cost And Fair Value Of Investments) (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Schedule of Available-for-sale Securities [Line Items]
Trading Securities, Change in Unrealized Holding Gain (Loss)	$ 0	$ 1,100,000	$ 700,000	$ 1,600,000
Trading securities	35,149,000		35,149,000		35,497,000
Cost	167,235,000		167,235,000		164,088,000
Available-for-sale Securities, Gross Unrealized Gain			28,217,000	24,770,000
Available-for-sale Securities, Gross Unrealized Loss			(3,518,000)	(3,842,000)
Available-for-sale Securities	191,934,000		191,934,000		185,016,000
Allocation	100.00%		100.00%		100.00%
Domestic Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Trading securities	18,207,000		18,207,000		18,698,000
Cost	42,157,000		42,157,000		46,126,000
Available-for-sale Securities, Gross Unrealized Gain			16,301,000	14,853,000
Available-for-sale Securities, Gross Unrealized Loss			(116,000)	(7,000)
Available-for-sale Securities	58,342,000		58,342,000		60,972,000
Allocation	31.00%		31.00%		33.00%
International Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Trading securities	4,510,000		4,510,000		4,252,000
Cost	30,819,000		30,819,000		27,521,000
Available-for-sale Securities, Gross Unrealized Gain			4,778,000	3,683,000
Available-for-sale Securities, Gross Unrealized Loss			(300,000)	(413,000)
Available-for-sale Securities	35,297,000		35,297,000		30,791,000
Allocation	19.00%		19.00%		17.00%
Core Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Trading securities	12,264,000		12,264,000		12,379,000
Cost	19,163,000		19,163,000		18,811,000
Available-for-sale Securities, Gross Unrealized Gain			272,000	478,000
Available-for-sale Securities, Gross Unrealized Loss			0	0
Available-for-sale Securities	19,435,000		19,435,000		19,289,000
Allocation	10.00%		10.00%		10.00%
High-Yield Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	13,819,000		13,819,000		13,342,000
Available-for-sale Securities, Gross Unrealized Gain			0	0
Available-for-sale Securities, Gross Unrealized Loss			(109,000)	(144,000)
Available-for-sale Securities	13,710,000		13,710,000		13,198,000
Allocation	7.00%		7.00%		7.00%
Emerging Market Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	14,135,000		14,135,000		12,556,000
Available-for-sale Securities, Gross Unrealized Gain			0	0
Available-for-sale Securities, Gross Unrealized Loss			(1,673,000)	(1,568,000)
Available-for-sale Securities	12,462,000		12,462,000		10,988,000
Allocation	6.00%		6.00%		6.00%
Other Fixed Income [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	4,889,000		4,889,000		4,798,000
Available-for-sale Securities, Gross Unrealized Gain			17,000	0
Available-for-sale Securities, Gross Unrealized Loss			0	(19,000)
Available-for-sale Securities	4,906,000		4,906,000		4,779,000
Allocation	3.00%		3.00%		3.00%
Combination Debt Equity And Other Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	16,124,000		16,124,000
Available-for-sale Securities, Gross Unrealized Gain			4,424,000
Available-for-sale Securities, Gross Unrealized Loss			(546,000)
Available-for-sale Securities	20,002,000		20,002,000
Allocation	10.00%		10.00%
Combination Debt and Equity Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost					14,975,000
Available-for-sale Securities, Gross Unrealized Gain				3,786,000
Available-for-sale Securities, Gross Unrealized Loss				(620,000)
Available-for-sale Securities					18,141,000
Allocation					10.00%
Alternative Funds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	15,000,000		15,000,000		15,000,000
Available-for-sale Securities, Gross Unrealized Gain			2,425,000	1,970,000
Available-for-sale Securities, Gross Unrealized Loss			0	0
Available-for-sale Securities	17,425,000		17,425,000		16,970,000
Allocation	9.00%		9.00%		9.00%
Real Estate Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	10,816,000		10,816,000		10,619,000
Available-for-sale Securities, Gross Unrealized Gain			0	0
Available-for-sale Securities, Gross Unrealized Loss			(774,000)	(1,071,000)
Available-for-sale Securities	10,042,000		10,042,000		9,548,000
Allocation	5.00%		5.00%		5.00%
Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Trading securities	168,000		168,000		168,000
Cost	313,000		313,000		340,000
Available-for-sale Securities, Gross Unrealized Gain			0	0
Available-for-sale Securities, Gross Unrealized Loss			0	0
Available-for-sale Securities	$ 313,000		$ 313,000		$ 340,000

Financial Investments (Fair Value And The Gross Unrealized Losses Of the Available-For-Sale Securities) (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Schedule of Available-for-sale Securities [Line Items]
Trading Securities, Change in Unrealized Holding Gain (Loss)	$ 0	$ 1,100,000	$ 700,000	$ 1,600,000
Fair Value, Less than 12 Months	21,125,000		21,125,000		23,882,000
Gross Unrealized Losses, Less than 12 Months			(409,000)	(576,000)
Fair Value, 12 Months or Greater	29,315,000		29,315,000		26,691,000
Gross Unrealized Losses, 12 Months or Greater			(3,109,000)	(3,266,000)
Fair Value, Total	50,440,000		50,440,000		50,573,000
Gross Unrealized Losses, Total			(3,518,000)	(3,842,000)
Domestic Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	0		0		0
Gross Unrealized Losses, Less than 12 Months			0	0
Fair Value, 12 Months or Greater	354,000		354,000		263,000
Gross Unrealized Losses, 12 Months or Greater			(116,000)	(7,000)
Fair Value, Total	354,000		354,000		263,000
Gross Unrealized Losses, Total			(116,000)	(7,000)
International Equity [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	7,415,000		7,415,000		5,905,000
Gross Unrealized Losses, Less than 12 Months			(300,000)	(413,000)
Fair Value, 12 Months or Greater	0		0		0
Gross Unrealized Losses, 12 Months or Greater			0	0
Fair Value, Total	7,415,000		7,415,000		5,905,000
Gross Unrealized Losses, Total			(300,000)	(413,000)
Core Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	13,710,000		13,710,000		13,198,000
Gross Unrealized Losses, Less than 12 Months			(109,000)	(144,000)
Fair Value, 12 Months or Greater	0		0		0
Gross Unrealized Losses, 12 Months or Greater			0	0
Fair Value, Total	13,710,000		13,710,000		13,198,000
Gross Unrealized Losses, Total			(109,000)	(144,000)
Emerging Market Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	0		0		0
Gross Unrealized Losses, Less than 12 Months			0	0
Fair Value, 12 Months or Greater	12,462,000		12,462,000		10,988,000
Gross Unrealized Losses, 12 Months or Greater			(1,673,000)	(1,568,000)
Fair Value, Total	12,462,000		12,462,000		10,988,000
Gross Unrealized Losses, Total			(1,673,000)	(1,568,000)
Other Fixed Income [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months					4,779,000
Gross Unrealized Losses, Less than 12 Months				(19,000)
Fair Value, 12 Months or Greater					0
Gross Unrealized Losses, 12 Months or Greater				0
Fair Value, Total					4,779,000
Gross Unrealized Losses, Total				(19,000)
Combination Debt Equity And Other Fund [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	0		0		0
Gross Unrealized Losses, Less than 12 Months			0	0
Fair Value, 12 Months or Greater	6,457,000		6,457,000		5,892,000
Gross Unrealized Losses, 12 Months or Greater			(546,000)	(620,000)
Fair Value, Total	6,457,000		6,457,000		5,892,000
Gross Unrealized Losses, Total			(546,000)	(620,000)
Real Estate Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value, Less than 12 Months	0		0		0
Gross Unrealized Losses, Less than 12 Months			0	0
Fair Value, 12 Months or Greater	10,042,000		10,042,000		9,548,000
Gross Unrealized Losses, 12 Months or Greater			(774,000)	(1,071,000)
Fair Value, Total	10,042,000		10,042,000		9,548,000
Gross Unrealized Losses, Total			$ (774,000)	$ (1,071,000)

Debt Financing (Narrative) (Details) (USD $)	6 Months Ended							1 Months Ended
Debt Financing (Narrative) (Details) (USD $)	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015 Revolving Credit Facility Lender One [Member]	Jun. 30, 2015 Revolving Credit Facility Lender Two [Member]	Feb. 01, 2015 Revolving Credit Facility Lender Two [Member]	Dec. 31, 2014 Revolving Credit Facility Lender Two [Member]	Feb. 18, 2011 Revolving Credit Facility Lender Two [Member]	Jan. 31, 2015 Westar Energy [Member] Debt Instrument Three [Member] Secured Debt [Member]
Debt Instrument [Line Items]
Long-term Line of Credit				$ 0		$ 0
Debt Instrument, Interest Rate, Stated Percentage								5.95%
Line of Credit Facility, Maximum Borrowing Capacity							270,000,000
Line of Credit Facility, Increase(Decrease) in Maximum Borrowing Capacity					20,000,000
Letters of Credit Outstanding, Amount			0
Repayments of Long-term Debt	$ 125,000,000	$ 177,500,000						$ 125,000,000

Taxes Taxes (Narrative) (Details) (USD $)	3 Months Ended		6 Months Ended
Taxes Taxes (Narrative) (Details) (USD $)	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Income Tax Contingency [Line Items]
Income tax expense	$ 33,839,000	$ 26,150,000	$ 61,517,000	$ 61,111,000
Effective income tax rate	34.00%	32.00%	34.00%	33.00%
Liability for unrecognized income tax benefits	3,300,000		3,300,000		3,200,000
Interest on liability related to unrecognized income tax benefits	0		0		0
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, 2015

Jun. 30, 2014

Jun. 30, 2015

Jun. 30, 2014

Pension Contributions

$ 19,400,000

$ 19,000,000

Pension Benefits [Member]

5,348,000

4,055,000

10,696,000

8,110,000

10,753,000

10,400,000

21,507,000

20,800,000

(10,059,000)

(9,109,000)

(20,118,000)

(18,219,000)

130,000

131,000

260,000

262,000

8,053,000

4,840,000

15,714,000

9,681,000

14,225,000

10,317,000

28,059,000

20,634,000

1,534,000

^[1]

4,002,000

^[1]

3,332,000

^[2]

8,003,000

^[2]

15,759,000

14,319,000

31,391,000

28,637,000

Post-Retirement Benefits [Member]

361,000

345,000

722,000

691,000

1,422,000

1,588,000

2,845,000

3,175,000

(1,654,000)

(1,644,000)

(3,307,000)

(3,288,000)

114,000

631,000

227,000

1,262,000

95,000

(185,000)

190,000

(371,000)

338,000

735,000

677,000

1,469,000

1,013,000

^[1]

1,124,000

^[1]

2,026,000

^[2]

2,247,000

^[2]

$ 1,351,000

$ 1,859,000

$ 2,703,000

$ 3,716,000

[1]	The regulatory adjustment represents the difference between current period pension or post-retirement benefit expense and the amount of such expense recognized in setting our prices.
[2]	(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 Wolf Creek Pension and Post-Retirement Benefit Plans (Net Periodic Costs and Pension Contributions) (Details) (USD $)

3 Months Ended

6 Months Ended

Jun. 30, 2015

Jun. 30, 2014

Jun. 30, 2015

Jun. 30, 2014

Pension Contributions

$ 19,400,000

$ 19,000,000

Wolf Creek [Member]

Subsidiary Interest in Defined Benefit Plans

Pension Contributions

2,500,000

KGE [Member]

47.00%

Pension Benefits [Member]

5,348,000

4,055,000

10,696,000

8,110,000

10,753,000

10,400,000

21,507,000

20,800,000

(10,059,000)

(9,109,000)

(20,118,000)

(18,219,000)

130,000

131,000

260,000

262,000

8,053,000

4,840,000

15,714,000

9,681,000

14,225,000

10,317,000

28,059,000

20,634,000

1,534,000

^[1]

4,002,000

^[1]

3,332,000

^[2]

8,003,000

^[2]

15,759,000

14,319,000

31,391,000

28,637,000

Pension Benefits [Member] | Wolf Creek [Member]

1,899,000

1,424,000

3,797,000

2,847,000

2,254,000

2,117,000

4,508,000

4,235,000

(2,261,000)

(2,021,000)

(4,522,000)

(4,042,000)

14,000

28,000

29,000

1,482,000

747,000

2,965,000

1,493,000

3,388,000

2,281,000

6,776,000

4,562,000

(304,000)

^[2]

501,000

^[2]

(608,000)

^[1]

1,002,000

^[1]

3,084,000

2,782,000

6,168,000

5,564,000

Post-Retirement Benefits [Member]

361,000

345,000

722,000

691,000

1,422,000

1,588,000

2,845,000

3,175,000

(1,654,000)

(1,644,000)

(3,307,000)

(3,288,000)

114,000

631,000

227,000

1,262,000

95,000

(185,000)

190,000

(371,000)

338,000

735,000

677,000

1,469,000

1,013,000

^[1]

1,124,000

^[1]

2,026,000

^[2]

2,247,000

^[2]

1,351,000

1,859,000

2,703,000

3,716,000

Post-Retirement Benefits [Member] | Wolf Creek [Member]

34,000

43,000

69,000

87,000

79,000

116,000

157,000

232,000

1,000

41,000

1,000

82,000

114,000

200,000

227,000

401,000

^[2]

^[1]

Variable Interest Entity [Line Items]

$ 114,000

$ 200,000

$ 227,000

$ 401,000

[1]	The regulatory adjustment represents the difference between current period pension or post-retirement benefit expense and the amount of such expense recognized in setting our prices.
[2]	(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.

Asset Retirement Obligations (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Asset Retirement Obligation [Abstract]
Asset Retirement Obligation	$ 283,194	$ 230,668
Asset Retirement Obligation, Liabilities Settled	(1,139)
Asset Retirement Obligation, Accretion Expense	6,132
Asset Retirement Obligation, Liabilities Incurred	48,767
Asset Retirement Obligation, Cash Paid to Settle	$ (1,234)

Variable Interest Entities (Narrative) (Details) (USD $)	6 Months Ended
	Jun. 30, 2015
Variable Interest Entity [Line Items]
Variable Interest Entity, Initial Consolidation, Gain (Loss)	$ 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

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

Jun. 30, 2015

Dec. 31, 2014

$ 8,340,478

$ 8,162,908

48,036

^[1]

79,707

^[1]

Variable Interest Entity [Line Items]

3,091,655

3,215,539

Variable Interest Entity, Primary Beneficiary [Member]

Current maturities of long-term debt

273,406

278,573

Regulatory assets

8,513

^[2]

7,882

^[2]

28,315

27,933

2,458

^[1]

2,961

^[1]