Cash and cash equivalents

$ 10.6

$ 9.3

Funds on deposit

0.8

1.0

Receivables, net

162.2

154.5

Accounts receivable pledged as collateral

175.0

174.0

Fuel inventories, at average cost

76.4

95.1

Materials and supplies, at average cost

152.3

151.3

Deferred refueling outage costs

29.5

11.9

Refundable income taxes

10.5

9.5

Prepaid expenses and other assets

80.3

88.5

Assets held for sale

36.2

33.2

28.6

Less-accumulated depreciation

767.0

723.7

Utility Plant, at Original Cost

Electric

11,575.3

^[1]

11,160.5

^[1]

4,628.4

4,424.2

Net utility plant in service

6,946.9

6,736.3

Construction work in progress

736.7

584.5

Nuclear Fuel, Net of Amortization

62.8

81.3

Public Utilities, Property, Plant and Equipment, Net

7,746.4

7,402.1

Nuclear decommissioning trust fund

183.9

154.7

Regulatory Assets

849.7

1,120.9

Goodwill

169.0

Investments and Other Assets, Total

79.4

76.9

1,282.0

1,521.5

9,795.4

9,647.3

Collateralized note payable

Notes payable

9.0

12.0

175.0

174.0

Commercial paper

108.2

530.1

1.1

263.1

Accounts payable

327.4

330.2

29.7

27.1

Accrued compensation and benefits

45.4

41.5

47.3

44.8

3.2

2.8

23.5

23.9

769.8

1,449.5

Asset retirement obligations

964.8

832.4

Deferred tax credits

127.4

128.8

158.8

149.3

360.5

557.5

Other Liabilities, Noncurrent

264.0

283.8

121.0

110.2

1,996.5

2,062.0

Common shareholders' equity

2,631.1

2,624.7

Accumulated other comprehensive loss

871.4

758.8

Treasury Stock, Value

(2.8)

(5.1)

(25.3)

^[2]

(38.4)

^[2]

3,474.4

3,340.0

39.0

3,515.7

2,756.8

7,029.1

6,135.8

9,795.4

9,647.3

Preferred Stock 3 Point 80 [Member]

10.0

Preferred Stock 4 Point 50 [Member]

10.0

Preferred Stock 4 Point 20 [Member]

7.0

Preferred Stock 4 Point 35 [Member]

12.0

Kansas City Power and Light Company [Member]

Cash and cash equivalents

4.0

5.2

Funds on deposit

0.7

0.1

Receivables, net

179.6

163.2

Accounts receivable pledged as collateral

110.0

Fuel inventories, at average cost

50.3

63.6

Materials and supplies, at average cost

109.0

110.1

Deferred refueling outage costs

29.5

11.9

Refundable income taxes

15.1

9.1

Prepaid expenses and other assets

4.6

Assets held for sale

4.7

27.5

23.8

Less-accumulated depreciation

530.4

501.6

Utility Plant, at Original Cost

Electric

8,274.9

^[3]

7,971.4

^[3]

3,518.3

3,374.4

Net utility plant in service

4,756.6

4,597.0

Construction work in progress

660.4

486.5

Nuclear Fuel, Net of Amortization

62.8

81.3

Public Utilities, Property, Plant and Equipment, Net

5,479.8

5,164.8

Nuclear decommissioning trust fund

183.9

154.7

Regulatory Assets

614.1

853.2

Investments and Other Assets, Total

31.0

29.5

829.0

1,037.4

6,839.2

6,703.8

Collateralized note payable

110.0

Commercial paper

93.2

361.0

0.4

Accounts payable

240.0

254.0

23.8

21.9

Accrued compensation and benefits

29.1

27.7

47.3

44.8

1.9

1.4

1.7

13.0

12.8

560.0

834.0

Asset retirement obligations

922.1

836.4

Deferred tax credits

125.3

126.1

141.7

133.2

339.9

534.5

Other Liabilities, Noncurrent

168.3

153.0

90.4

88.2

1,787.7

1,871.4

Common shareholders' equity

1,563.1

Accumulated other comprehensive loss

636.4

559.4

(20.2)

(25.8)

2,179.3

2,096.7

2,312.2

1,901.7

4,491.5

3,998.4

Utility operating and maintenance expenses

$ 6,839.2

$ 6,703.8

[1]	Includes $107.8 million and $104.5 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.
[2]	Net of tax
[3]	Includes $54.1 million and $54.7 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.

Consolidated Balance Sheets (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Utility Plant, at Original Cost
Nuclear fuel, amortization	$ 161.4	$ 157.4
Common shareholder's equity
Common stock - shares authorized (in shares)	250,000,000.0	250,000,000.0
Common stock-shares issued (in shares)	153,995,621.0	153,779,806.0
Treasury stock- shares (in shares)	129,290	250,236
Preferred Stock 3 Point 80 [Member]
Cumulative preferred stock
Cumulative preferred stock par value (in dollars per share)	$ 100.00	$ 100.00
Cumulative preferred stock, Shares issued (in share)	100,000	100,000
Preferred Stock, Dividend Rate, Percentage	3.80%	3.80%
Preferred Stock 4 Point 50 [Member]
Cumulative preferred stock
Cumulative preferred stock par value (in dollars per share)	$ 100.00	$ 100.00
Cumulative preferred stock, Shares issued (in share)	100,000	100,000
Preferred Stock, Dividend Rate, Percentage	4.50%	4.50%
Preferred Stock 4 Point 20 [Member]
Cumulative preferred stock
Cumulative preferred stock par value (in dollars per share)	$ 100.00	$ 100.00
Cumulative preferred stock, Shares issued (in share)	70,000	70,000
Preferred Stock, Dividend Rate, Percentage	4.20%	4.20%
Preferred Stock 4 Point 35 [Member]
Cumulative preferred stock
Cumulative preferred stock par value (in dollars per share)	$ 100.00	$ 100.00
Cumulative preferred stock, Shares issued (in share)	120,000	120,000
Preferred Stock, Dividend Rate, Percentage	4.35%	4.35%
Kansas City Power and Light Company [Member]
Utility Plant, at Original Cost
Nuclear fuel, amortization	$ 161.4	$ 157.4
Common shareholder's equity
Common stock - shares authorized (in shares)	1,000.0	1,000.0
Common stock-shares issued (in shares)	1.0	1.0

Consolidated Statements of Income and Comprehensive Income (USD $)
In Millions, except Per Share data, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Operating Revenues

Electric revenues

$ 2,446.3

$ 2,309.9

$ 2,318.0

Operating Expenses

Fuel

539.5

483.8

Purchased power

125.9

94.0

203.4

Transmission

53.2

35.4

30.2

671.4

647.3

658.2

(4.3)

12.7

Other General and Administrative Expense

289.7

272.3

273.1

General taxes

194.4

179.3

170.9

3.0

7.5

5.9

Costs and Expenses, Total

1,877.1

1,771.0

1,838.2

Operating Income (Loss)

569.2

538.9

479.8

Non-operating income

18.4

7.3

5.9

Non-operating expenses

(9.6)

(20.5)

(8.2)

Interest charges

(198.4)

(220.8)

(218.4)

Income before income tax (expense) benefit and income (loss) from equity investments

379.6

304.9

259.1

Income tax (expense) benefit

(129.2)

(104.6)

(84.8)

Income (loss) from equity investments, net of income taxes

(0.2)

(0.4)

(0.1)

Less: Net (income) loss attributable to noncontrolling interest

250.2

199.9

174.2

0.2

Net income (loss) attributable to Great Plains Energy

250.2

199.9

174.4

Preferred stock dividend requirements

1.6

Earnings (loss) available for common shareholders

248.6

198.3

172.8

Average number of common shares outstanding (in shares)

153.5

145.5

135.6

Average number of diluted common shares outstanding (in shares)

153.7

147.2

138.7

Basic earnings (loss) per common share

Basic earnings per share

$ 1.62

$ 1.36

$ 1.27

Diluted earnings (loss) per common share

Diluted earnings per share

$ 1.62

$ 1.35

$ 1.25

Comprehensive Income

Gain (loss) on derivative hedging instruments

250.2

199.9

174.2

Other comprehensive income

(0.1)

(5.9)

Income tax benefit (expense)

2.3

Net gain (loss) on derivative hedging instruments

(0.1)

(3.6)

Reclassification to expenses, net of tax

11.6

12.6

10.4

Derivative hedging activity, net of tax

11.6

12.5

6.8

Net gain (loss) arising during period

2.1

(2.3)

(1.2)

Income tax (expense) benefit

(0.9)

0.9

0.4

Net gain (loss) arising during period, net of tax

1.2

(1.4)

(0.8)

Amortization of net losses included in net periodic benefit costs, net of tax

0.3

Change in unrecognized pension expense, net of tax

1.5

(1.1)

(0.5)

Total other comprehensive income (loss)

13.1

^[1]

11.4

6.3

Comprehensive income (loss)

263.3

211.3

180.5

Less: comprehensive (income) loss attributable to noncontrolling interest

0.2

Comprehensive income (loss) attributable to Great Plains Energy

263.3

211.3

180.7

Kansas City Power and Light Company [Member]

Operating Revenues

Electric revenues

1,671.4

1,579.9

1,558.3

Operating Expenses

Fuel

383.0

384.8

333.5

Purchased power

62.4

35.5

70.8

Transmission

37.3

24.0

18.8

Utility operating and maintenance expenses

475.9

460.1

470.9

(4.3)

9.2

Other General and Administrative Expense

198.3

185.6

193.1

General taxes

152.0

145.5

139.7

1.1

Costs and Expenses, Total

1,308.9

1,231.2

1,237.1

Operating Income (Loss)

362.5

348.7

321.2

Non-operating income

16.3

4.4

2.9

Non-operating expenses

(4.7)

(8.6)

(3.9)

Interest charges

(125.3)

(127.6)

(115.6)

Income before income tax (expense) benefit and income (loss) from equity investments

248.8

216.9

204.6

Income tax (expense) benefit

(79.8)

(75.3)

(69.1)

169.0

141.6

135.5

Comprehensive Income

Gain (loss) on derivative hedging instruments

169.0

141.6

135.5

Other comprehensive income

(0.1)

(0.6)

Income tax benefit (expense)

0.2

Net gain (loss) on derivative hedging instruments

(0.1)

(0.4)

Reclassification to expenses, net of tax

5.6

5.7

5.4

Derivative hedging activity, net of tax

5.6

5.0

Total other comprehensive income (loss)

5.6

5.0

Comprehensive income (loss) attributable to Great Plains Energy

$ 174.6

$ 147.2

$ 140.5

[1]	Net of tax

Consolidated Statements of Cash Flows (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash Flows from Operating Activities
Net income (loss)	$ 250.2	$ 199.9	$ 174.2
Adjustments to reconcile income to net cash from operating activities:
Depreciation and amortization	289.7	272.3	273.1
Amortization of:
Nuclear fuel	22.8	24.7	21.4
Other	57.5	36.0	12.7
Deferred income taxes, net	134.0	121.2	111.2
Investment tax credit amortization	(1.7)	(2.4)	(2.2)
Loss from equity investments, net of income taxes	0.2	0.4	0.1
Other operating activities	24.1	11.7	(147.5)
Net cash from operating activities	776.8	663.8	443.0
Cash Flows from Investing Activities
Utility capital expenditures	(669.0)	(610.2)	(456.6)
Allowance for borrowed funds used during construction	(11.8)	(5.3)	(5.8)
Purchases of nuclear decommissioning trust investments	(73.5)	(24.2)	(18.5)
Proceeds from nuclear decommissioning trust investments	70.2	20.9	15.1
Other investing activities	(21.7)	(19.6)	(19.9)
Net cash from investing activities	(705.8)	(638.4)	(485.7)
Cash Flows from Financing Activities
Issuance of common stock	4.9	293.0	5.9
Issuance of long-term debt	762.5	0	747.1
Repayment of long-term debt	(265.3)	(513.8)	(598.5)
Net change in short-term borrowings	(424.9)	253.1	16.0
Net change in collateralized short-term borrowings	1.0	79.0	0
Dividends paid	(137.3)	(125.5)	(115.1)
Issuance fees	(9.0)	(2.9)	(10.7)
Other financing activities	(1.6)	(5.2)	(6.6)
Net cash from financing activities	(69.7)	(22.3)	38.1
Net Change in Cash and Cash Equivalents	1.3	3.1	(4.6)
Cash and Cash Equivalents at Beginning of Year	9.3	6.2	10.8
Cash and Cash Equivalents at End of Year	10.6	9.3	6.2
Kansas City Power and Light Company [Member]
Cash Flows from Operating Activities
Net income (loss)	169.0	141.6	135.5
Adjustments to reconcile income to net cash from operating activities:
Depreciation and amortization	198.3	185.6	193.1
Amortization of:
Nuclear fuel	22.8	24.7	21.4
Other	34.3	30.1	29.5
Deferred income taxes, net	92.1	60.2	80.6
Investment tax credit amortization	(1.1)	(1.8)	(1.5)
Other operating activities	(9.2)	27.9	(118.3)
Net cash from operating activities	506.2	468.3	340.3
Cash Flows from Investing Activities
Utility capital expenditures	(521.9)	(482.0)	(336.5)
Allowance for borrowed funds used during construction	(10.6)	(3.7)	(2.9)
Purchases of nuclear decommissioning trust investments	(73.5)	(24.2)	(18.5)
Proceeds from nuclear decommissioning trust investments	70.2	20.9	15.1
Net money pool lending	0	0	12.1
Other investing activities	(12.4)	(11.7)	(9.7)
Net cash from investing activities	(548.2)	(500.7)	(340.4)
Cash Flows from Financing Activities
Issuance of long-term debt	412.5	0	397.4
Repayment of long-term debt	(2.6)	(12.7)	(263.1)
Net change in short-term borrowings	(267.8)	134.0	(36.5)
Net change in collateralized short-term borrowings	0	15.0	0
Net money pool borrowings	(3.6)	(4.7)	6.7
Dividends paid	(92.0)	(96.0)	(100.0)
Issuance fees	(5.7)	0	(6.1)
Other financing activities	0	0.1	0
Net cash from financing activities	40.8	35.7	(1.6)
Net Change in Cash and Cash Equivalents	(1.2)	3.3	(1.7)
Cash and Cash Equivalents at Beginning of Year	5.2	1.9	3.6
Cash and Cash Equivalents at End of Year	$ 4.0	$ 5.2	$ 1.9

Consolidated Statements of Common Shareholders' Equity and Noncontrolling Interest (USD $) In Millions, except Share data, unless otherwise specified	Total	Kansas City Power and Light Company [Member]	Parent Company [Member]	Common Stock [Member]	Common Stock [Member] Kansas City Power and Light Company [Member]	Retained Earnings [Member]	Retained Earnings [Member] Kansas City Power and Light Company [Member]	Treasury Stock [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Accumulated Other Comprehensive Income (Loss) [Member] Kansas City Power and Light Company [Member]	Noncontrolling Interest [Member]
Beginning balance at Dec. 31, 2010				$ 2,324.4	$ 1,563.1	$ 626.5	$ 478.3	$ (8.9)	$ (56.1)	$ (36.4)	$ 1.2
Beginning balance, treasury stock (in shares) at Dec. 31, 2010								(400,889)
Beginning balance (in shares) at Dec. 31, 2010				136,113,954	1
Issuance of common stock				5.9
Issuance of common stock (in shares)				292,352
Equity compensation expense, net of forfeitures				0.3
Unearned Compensation [Abstract]
Issuance of restricted common stock				(3.5)
Forfeiture of restricted common stock				0.9
Compensation expense recognized				2.3
Stockholders' Equity, Other				0.3
Net income (loss) attributable to Great Plains Energy	174.4					174.4	135.5
Loss on reissuance of treasury stock						(0.7)
Dividends:
Common stock						(113.5)	(100.0)
Preferred stock - at required rates						(1.6)
Performance shares						(0.4)
Treasury shares acquired								(2.4)
Treasury shares acquired (in shares)								(125,234)
Treasury shares reissued								5.7
Treasury shares reissued (in shares)								261,556
Derivative hedging activity, net of tax	6.8	5.0	1.8						6.8	5.0
Change in unrecognized pension expense, net of tax	(0.5)								(0.5)
Net income (loss) attributable to noncontrolling interest	0.2										(0.2)
Distribution											0
Ending balance at Dec. 31, 2011	2,959.9	2,045.5		2,330.6	1,563.1	684.7	513.8	(5.6)	(49.8)	(31.4)	1.0
Ending balance (in shares) at Dec. 31, 2011				136,406,306	1
Ending balance, treasury stock (in shares) at Dec. 31, 2011								(264,567)
Issuance of common stock				293.0
Issuance of common stock (in shares)				17,373,500
Equity compensation expense, net of forfeitures				0.3
Unearned Compensation [Abstract]
Issuance of restricted common stock				(3.3)
Forfeiture of restricted common stock				1.3
Compensation expense recognized				2.3
Stockholders' Equity, Other				0.5
Net income (loss) attributable to Great Plains Energy	199.9					199.9	141.6
Loss on reissuance of treasury stock						(0.2)
Dividends:
Common stock						(123.9)	(96.0)
Preferred stock - at required rates						(1.6)
Performance shares						(0.1)
Treasury shares acquired								(3.3)
Treasury shares acquired (in shares)								(164,454)
Treasury shares reissued								3.8
Treasury shares reissued (in shares)								178,785
Derivative hedging activity, net of tax	12.5	5.6	6.9						12.5	5.6
Change in unrecognized pension expense, net of tax	(1.1)								(1.1)
Net income (loss) attributable to noncontrolling interest	0										0
Distribution											(1.0)
Ending balance at Dec. 31, 2012	3,340.0	2,096.7	3,340.0	2,624.7	1,563.1	758.8	559.4	(5.1)	(38.4)	(25.8)	0
Ending balance (in shares) at Dec. 31, 2012				153,779,806	1
Ending balance, treasury stock (in shares) at Dec. 31, 2012	(250,236)		(250,236)					(250,236)
Issuance of common stock				4.9
Issuance of common stock (in shares)				215,815
Equity compensation expense, net of forfeitures				0.4
Unearned Compensation [Abstract]
Issuance of restricted common stock				(1.8)
Forfeiture of restricted common stock				0.1
Compensation expense recognized				2.1
Stockholders' Equity, Other				0.7
Net income (loss) attributable to Great Plains Energy	250.2					250.2	169.0
Loss on reissuance of treasury stock						0
Dividends:
Common stock						(135.7)	(92.0)
Preferred stock - at required rates						(1.6)
Performance shares						(0.3)
Treasury shares acquired								(1.6)
Treasury shares acquired (in shares)								(73,201)
Treasury shares reissued								3.9
Treasury shares reissued (in shares)								194,147
Derivative hedging activity, net of tax	11.6	5.6	6.0						11.6	5.6
Change in unrecognized pension expense, net of tax	1.5								1.5
Net income (loss) attributable to noncontrolling interest	0										0
Distribution											0
Ending balance at Dec. 31, 2013	$ 3,474.4	$ 2,179.3	$ 3,474.4	$ 2,631.1	$ 1,563.1	$ 871.4	$ 636.4	$ (2.8)	$ (25.3)	$ (20.2)	$ 0
Ending balance (in shares) at Dec. 31, 2013				153,995,621	1
Ending balance, treasury stock (in shares) at Dec. 31, 2013	(129,290)		(129,290)					(129,290)

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2013

Accounting Policies [Abstract]

Summary of Significant Accounting Policies [Text Block]

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Organization

Great Plains Energy, a Missouri corporation incorporated in 2001, is a public utility holding company and does not own or operate any significant assets other than the stock of its subsidiaries. Great Plains Energy's wholly owned direct subsidiaries with operations or active subsidiaries are as follows:


•	KCP&L is an integrated, regulated electric utility that provides electricity to customers primarily in the states of Missouri and Kansas. KCP&L has one active wholly owned subsidiary, Kansas City Power & Light Receivables Company (KCP&L Receivables Company).

•

KCP&L Greater Missouri Operations Company (GMO) is an integrated, regulated electric utility that provides electricity to customers in the state of Missouri. GMO also provides regulated steam service to certain customers in the St. Joseph, Missouri area. GMO has two active wholly owned subsidiaries, GMO Receivables Company and MPS Merchant Services, Inc. (MPS Merchant). MPS Merchant has certain long-term natural gas contracts remaining from its former non-regulated trading operations.


•	GPE Transmission Holding Company, LLC (GPETHC) owns 13.5% of Transource Energy, LLC (Transource) with the remaining 86.5% owned by AEP Transmission Holding Company, LLC (AEPTHC), a subsidiary of American Electric Power Company, Inc. GPETHC accounts for its investment in Transource under the equity method. Transource is focused on the development of competitive electric transmission projects.

Each of Great Plains Energy's and KCP&L's consolidated financial statements includes the accounts of their subsidiaries. Intercompany transactions have been eliminated.

Great Plains Energy's sole reportable business segment is electric utility. See Note 23 for additional information.

Use of Estimates

The process of preparing financial statements in conformity with Generally Accepted Accounting Principles (GAAP) requires the use of estimates and assumptions that affect the reported amounts of certain types of assets, liabilities, revenues and expenses. Such estimates primarily relate to unsettled transactions and events as of the date of the financial statements. Accordingly, upon settlement, actual results may differ from estimated amounts.

Cash and Cash Equivalents

Cash equivalents consist of highly liquid investments with original maturities of three months or less at acquisition.

Funds on Deposit

Funds on deposit consist primarily of cash provided to counterparties in support of margin requirements related to commodity purchases, commodity swaps and futures contracts. Pursuant to individual contract terms with counterparties, deposit amounts required vary with changes in market prices, credit provisions and various other factors. Interest is earned on most funds on deposit. Great Plains Energy also holds funds on deposit from counterparties in the same manner. These funds are included in other current liabilities on the consolidated balance sheets.

Fair Value of Financial Instruments

The following methods and assumptions were used to estimate the fair value of each class of financial instrument for which it is practicable to estimate that value.

Nuclear decommissioning trust fund - KCP&L's nuclear decommissioning trust fund assets are recorded at fair value based on quoted market prices of the investments held by the fund and/or valuation models.

Derivative instruments - The fair value of derivative instruments is estimated using market quotes, over-the-counter forward price and volatility curves and correlation among fuel prices, net of estimated credit risk.

Pension plans - For financial reporting purposes, the market value of plan assets is the fair value. For regulatory reporting purposes, a five-year smoothing of assets is used to determine fair value.

Derivative Instruments

The Company records derivative instruments on the balance sheet at fair value in accordance with GAAP. Great Plains Energy and KCP&L enter into derivative contracts to manage exposure to commodity price and interest rate fluctuations. Derivative instruments designated as normal purchases and normal sales (NPNS) and cash flow hedges are used solely for hedging purposes and are not issued or held for speculative reasons.

The Company considers various qualitative factors, such as contract and market place attributes, in designating derivative instruments at inception. Great Plains Energy and KCP&L may elect the NPNS exception, which requires the effects of the derivative to be recorded when the underlying contract settles. Great Plains Energy and KCP&L account for derivative instruments that are not designated as NPNS as cash flow hedges or non-hedging derivatives, which are recorded as assets or liabilities on the consolidated balance sheets at fair value. In addition, if a derivative instrument is designated as a cash flow hedge, Great Plains Energy and KCP&L document the method of determining hedge effectiveness and measuring ineffectiveness. See Note 19 for additional information regarding derivative financial instruments and hedging activities.

Great Plains Energy and KCP&L offset fair value amounts recognized for derivative instruments under master netting arrangements, which include rights to reclaim cash collateral (a receivable), or the obligation to return cash collateral (a payable). Great Plains Energy and KCP&L classify cash flows from derivative instruments in the same category as the cash flows from the items being hedged.

Utility Plant

Great Plains Energy's and KCP&L's utility plant is stated at historical cost. These costs include taxes, an allowance for the cost of borrowed and equity funds used to finance construction and payroll-related costs, including pensions and other fringe benefits. Replacements, improvements and additions to units of property are capitalized. Repairs of property and replacements of items not considered to be units of property are expensed as incurred (except as discussed under Deferred Refueling Outage Costs). When property units are retired or otherwise disposed, the original cost, net of salvage, is charged to accumulated depreciation. Substantially all of KCP&L's utility plant is pledged as collateral for KCP&L's mortgage bonds under the General Mortgage Indenture and Deed of Trust dated December 1, 1986, as supplemented. Substantially all of GMO's St. Joseph Light & Power division utility plant is pledged as collateral for GMO's mortgage bonds under the General Mortgage Indenture and Deed of Trust dated April 1, 1946, as supplemented.

As prescribed by The Federal Energy Regulatory Commission (FERC), Allowance for Funds Used During Construction (AFUDC) is charged to the cost of the plant during construction. AFUDC equity funds are included as a non-cash item in non-operating income and AFUDC borrowed funds are a reduction of interest charges. The rates used to compute gross AFUDC are compounded semi-annually and averaged 6.1% in 2013, 2.0% in 2012 and 2.9% in 2011 for KCP&L. The rates used to compute gross AFUDC for GMO averaged 2.1% in 2013, 2.4% in 2012 and 5.4% in 2011.

Great Plains Energy's and KCP&L's balances of utility plant, at original cost, with a range of estimated useful lives are listed in the following tables.



Great Plains Energy
December 31	2013		2012
Utility plant, at original cost	(millions)
Generation (20 - 60 years)	$	6,874.6	$	6,697.1
Transmission (15 - 70 years)	794.0		754.0
Distribution (8 - 66 years)	3,149.4		3,019.6
General (5 - 50 years)	757.3		689.8
Total ^(a)	$	11,575.3	$	11,160.5

^(a) Includes $107.8 million and $104.5 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.



KCP&L
December 31	2013		2012
Utility plant, at original cost	(millions)
Generation (20 - 60 years)	$	5,288.3	$	5,140.0
Transmission (15 - 70 years)	433.7		414.7
Distribution (8 - 55 years)	1,970.2		1,893.8
General (5 - 50 years)	582.7		522.9
Total ^(a)	$	8,274.9	$	7,971.4

^(a) Includes $54.1 million and $54.7 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.

Depreciation and Amortization

Depreciation and amortization of utility plant other than nuclear fuel is computed using the straight-line method over the estimated lives of depreciable property based on rates approved by state regulatory authorities. Annual depreciation rates average approximately 3%. Nuclear fuel is amortized to fuel expense based on the quantity of heat produced during the generation of electricity.

Great Plains Energy's depreciation expense was $265.4 million, $251.4 million and $239.9 million for 2013, 2012 and 2011, respectively. KCP&L's depreciation expense was $179.2 million, $168.0 million and $162.0 million for 2013, 2012 and 2011, respectively.

Nuclear Plant Decommissioning Costs

Nuclear plant decommissioning cost estimates are based on the immediate dismantlement method and include the costs of decontamination, dismantlement and site restoration. Based on these cost estimates, KCP&L contributes to a tax-qualified trust fund to be used to decommission Wolf Creek Generating Station (Wolf Creek). Related liabilities for decommissioning are included on Great Plains Energy's and KCP&L's balance sheets in Asset Retirement Obligations (AROs).

As a result of the authorized regulatory treatment and related regulatory accounting, differences between the decommissioning trust fund asset and the related ARO are recorded as a regulatory asset or liability. See Note 7 for discussion of AROs including those associated with nuclear plant decommissioning costs.

Deferred Refueling Outage Costs

KCP&L uses the deferral method to account for operations and maintenance expenses incurred in support of Wolf Creek's scheduled refueling outages and amortizes them evenly (monthly) over the unit's operating cycle, which is approximately 18 months, until the next scheduled outage. Replacement power costs during an outage are expensed as incurred.

Regulatory Matters

KCP&L and GMO defer items on the balance sheet resulting from the effects of the ratemaking process, which would not be recorded if KCP&L and GMO were not regulated. See Note 5 for additional information concerning regulatory matters.

Revenue Recognition

Great Plains Energy and KCP&L recognize revenues on sales of electricity when the service is provided. Revenues recorded include electric services provided but not yet billed by KCP&L and GMO. Unbilled revenues are recorded for kWh usage in the period following the customers' billing cycle to the end of the month. KCP&L's and GMO's estimate is based on net system kWh usage less actual billed kWhs. KCP&L's and GMO's estimated unbilled kWhs are allocated and priced by regulatory jurisdiction across the rate classes based on actual billing rates.

KCP&L and GMO collect from customers gross receipts taxes levied by state and local governments. These taxes from KCP&L's Missouri customers are recorded gross in operating revenues and general taxes on Great Plains Energy's and KCP&L's statements of income. KCP&L's gross receipts taxes collected from Missouri customers were $58.9 million, $55.8 million and $55.6 million in 2013, 2012 and 2011, respectively. These taxes from KCP&L's Kansas customers and GMO's customers are recorded net in operating revenues on Great Plains Energy's and KCP&L's statements of income.

Great Plains Energy and KCP&L collect sales taxes from customers and remit to state and local governments. These taxes are presented on a net basis on Great Plains Energy's and KCP&L's statements of income.

Great Plains Energy and KCP&L record sale and purchase activity on a net basis in wholesale revenue or purchased power when transacting with Regional Transmission Organization (RTO)/Independent System Operator (ISO) markets.

Allowance for Doubtful Accounts

This reserve represents estimated uncollectible accounts receivable and is based on management's judgment considering historical loss experience and the characteristics of existing accounts. Provisions for losses on receivables are expensed to maintain the allowance at a level considered adequate to cover expected losses. Receivables are charged off against the reserve when they are deemed uncollectible.

Property Gains and Losses

Net gains and losses from the sale of assets and businesses and from asset impairments are recorded in operating expenses.

Asset Impairments

Long-lived assets and finite-lived intangible assets subject to amortization are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If the sum of the undiscounted expected future cash flows from an asset to be held and used is less than the carrying value of the asset, an asset impairment must be recognized in the financial statements. The amount of impairment recognized is the excess of the carrying value of the asset over its fair value.

Goodwill and indefinite lived intangible assets are tested for impairment annually and when an event occurs indicating the possibility that an impairment exists. The annual test must be performed at the same time each year. If the fair value of a reporting unit is less than its carrying value including goodwill, an impairment charge for goodwill must be recognized in the financial statements. To measure the amount of the impairment loss to recognize, the implied fair value of the reporting unit goodwill is compared with its carrying value.

Income Taxes

Income taxes are accounted for using the asset/liability approach. Deferred tax assets and liabilities are determined based on the temporary differences between the financial reporting and tax bases of assets and liabilities, applying enacted statutory tax rates in effect for the year in which the differences are expected to reverse. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized.

Great Plains Energy and KCP&L recognize tax benefits based on a “more-likely-than-not” recognition threshold. In addition, Great Plains Energy and KCP&L recognize interest accrued related to unrecognized tax benefits in interest expense and penalties in non-operating expenses.

Great Plains Energy files a consolidated federal income tax return as well as unitary and combined income tax returns in several state jurisdictions with Kansas and Missouri being the most significant. Income taxes for consolidated or combined subsidiaries are allocated to the subsidiaries based on separate company computations of income or loss. KCP&L's income tax provision includes taxes allocated based on its separate company income or loss.

Great Plains Energy and KCP&L have established a net regulatory asset for the additional future revenues to be collected from customers for deferred income taxes. Tax credits are recognized in the year generated except for certain KCP&L and GMO investment tax credits that have been deferred and amortized over the remaining service lives of the related properties.

Environmental Matters

Environmental costs are accrued when it is probable a liability has been incurred and the amount of the liability can be reasonably estimated.

Basic and Diluted Earnings per Common Share Calculation

To determine basic EPS, preferred stock dividend requirements and net loss attributable to noncontrolling interest are deducted from net income before dividing by the average number of common shares outstanding. The effect of dilutive securities, calculated using the treasury stock method, assumes the issuance of common shares applicable to performance shares, restricted stock, stock options and Equity Units. Great Plains Energy settled the Equity Units in June 2012.

The following table reconciles Great Plains Energy's basic and diluted EPS.



	2013		2012		2011
Income	(millions, except per share amounts)
Net income	$	250.2	$	199.9	$	174.2
Less: net loss attributable to noncontrolling interest	—		—		(0.2		)
Less: preferred stock dividend requirements	1.6		1.6		1.6
Earnings available for common shareholders	$	248.6	$	198.3	$	172.8
Common Shares Outstanding
Average number of common shares outstanding	153.5		145.5		135.6
Add: effect of dilutive securities	0.2		1.7		3.1
Diluted average number of common shares outstanding	153.7		147.2		138.7
Basic EPS	$	1.62	$	1.36	$	1.27
Diluted EPS	$	1.62	$	1.35	$	1.25

Anti-dilutive shares excluded from the computation of diluted EPS are detailed in the following table.



	2013	2012	2011
Performance shares	548,242	—	50,897
Restricted stock shares	2,228	3,781	43,641
Stock options	—	—	6,000

Dividends Declared

In February 2014, Great Plains Energy's Board of Directors (Board) declared a quarterly dividend of $0.23 per share on Great Plains Energy's common stock. The common dividend is payable March 20, 2014, to shareholders of record as of February 27, 2014. The Board also declared regular dividends on Great Plains Energy's preferred stock, payable June 1, 2014, to shareholders of record as of May 9, 2014.

In February 2014, KCP&L’s Board of Directors declared a cash dividend payable to Great Plains Energy of $18 million payable on March 19, 2014.

Supplemental Cash Flow Elements [Abstract]

The entire disclosure for the organization, consolidation and basis of presentation of financial statements disclosure, and significant accounting policies of the reporting entity. May be provided in more than one note to the financial statements, as long as users are provided with an understanding of (1) the significant judgments and assumptions made by an enterprise in determining whether it must consolidate a VIE and/or disclose information about its involvement with a VIE, (2) the nature of restrictions on a consolidated VIE's assets reported by an enterprise in its statement of financial position, including the carrying amounts of such assets, (3) the nature of, and changes in, the risks associated with an enterprise's involvement with the VIE, and (4) how an enterprise's involvement with the VIE affects the enterprise's financial position, financial performance, and cash flows. Describes procedure if disclosures are provided in more than one note to the financial statements.

+ References+ Details

Supplemental Cash Flow Information

12 Months Ended

Dec. 31, 2013

Cash Flow, Supplemental Disclosures [Text Block]

2. SUPPLEMENTAL CASH FLOW INFORMATION



Great Plains Energy Other Operating Activities
Year Ended December 31	2013			2012			2011
Cash flows affected by changes in:	(millions)
Receivables	$	(7.1	)	$	76.8		$	3.6
Accounts receivable pledged as collateral	(1.0		)	(79.0		)	—
Fuel inventories	18.7			(6.1		)	(3.9		)
Materials and supplies	(1.0		)	(11.0		)	(7.5		)
Accounts payable	26.4			57.3			5.7
Accrued taxes	2.2			(7.8		)	1.4
Accrued interest	3.9			(35.2		)	1.5
Deferred refueling outage costs	(17.6		)	15.6			(17.9		)
Pension and post-retirement benefit obligations	31.3			14.4			(56.0		)
Allowance for equity funds used during construction	(14.1		)	(1.3		)	(1.0		)
Interest rate hedge settlements	—			—			(26.1		)
Fuel recovery mechanism	(1.3		)	22.5			(1.7		)
Uncertain tax positions	(0.8		)	(4.7		)	(20.8		)
Other	(15.5		)	(29.8		)	(24.8		)
Total other operating activities	$	24.1		$	11.7		$	(147.5	)
Cash paid during the period:
Interest	$	170.8		$	247.9		$	254.4
Income taxes	$	—		$	3.3		$	2.8
Non-cash investing activities:
Liabilities accrued for capital expenditures	$	48.1		$	57.5		$	39.7



KCP&L Other Operating Activities
Year Ended December 31	2013			2012			2011
Cash flows affected by changes in:	(millions)
Receivables	$	(12.6	)	$	8.8		$	(20.2	)
Accounts receivable pledged as collateral	—			(15.0		)	—
Fuel inventories	13.3			(4.6		)	(14.1		)
Materials and supplies	1.1			(9.0		)	(6.7		)
Accounts payable	7.3			48.3			11.0
Accrued taxes	(3.7		)	(2.0		)	2.7
Accrued interest	1.4			(2.3		)	3.8
Deferred refueling outage costs	(17.6		)	15.6			(17.9		)
Pension and post-retirement benefit obligations	35.7			18.0			(45.6		)
Allowance for equity funds used during construction	(14.1		)	(1.3		)	(0.7		)
Fuel recovery mechanism	(1.8		)	5.1			(5.8		)
Uncertain tax positions	(10.5		)	1.8			(10.4		)
Other	(7.7		)	(35.5		)	(14.4		)
Total other operating activities	$	(9.2	)	$	27.9		$	(118.3	)
Cash paid during the period:
Interest	$	111.7		$	118.0		$	111.3
Income taxes	$	4.6		$	18.0		$	0.1
Non-cash investing activities:
Liabilities accrued for capital expenditures	$	40.5		$	48.4		$	32.0

Receivables

12 Months Ended

Dec. 31, 2013

Receivables [Abstract]

Receivables [Text Block]

3. RECEIVABLES

Great Plains Energy's and KCP&L's receivables are detailed in the following table.



	December 31
	2013			2012
Great Plains Energy	(millions)
Customer accounts receivable - billed	$	1.5		$	—
Customer accounts receivable - unbilled	74.6			58.3
Allowance for doubtful accounts - customer accounts receivable	(2.5		)	(2.6		)
Other receivables	88.6			98.8
Total	$	162.2		$	154.5
KCP&L
Customer accounts receivable - billed	$	1.3		$	—
Customer accounts receivable - unbilled	51.2			42.9
Allowance for doubtful accounts - customer accounts receivable	(1.1		)	(1.5		)
Intercompany receivables	50.4			40.0
Other receivables	77.8			81.8
Total	$	179.6		$	163.2

Great Plains Energy's and KCP&L's other receivables at December 31, 2013 and 2012 consisted primarily of receivables from partners in jointly owned electric utility plants and wholesale sales receivables.

Sale of Accounts Receivable – KCP&L and GMO

KCP&L and GMO sell all of their retail electric accounts receivable to their wholly owned subsidiaries, KCP&L Receivables Company and GMO Receivables Company, respectively, which in turn sell an undivided percentage ownership interest in the accounts receivable to Victory Receivables Corporation, an independent outside investor. Each of KCP&L Receivables Company's and GMO Receivables Company's sale of the undivided percentage ownership interest in accounts receivable to Victory Receivables Corporation is accounted for as a secured borrowing with accounts receivable pledged as collateral and a corresponding short-term collateralized note payable recognized on the balance sheets. At December 31, 2013 and 2012, Great Plains Energy's accounts receivable pledged as collateral and the corresponding short-term collateralized note payable were $175.0 million and $174.0 million, respectively. At December 31, 2013 and 2012, KCP&L's accounts receivable pledged as collateral and the corresponding short-term collateralized note payable were $110.0 million.

KCP&L and GMO each sell their receivables at a fixed price based upon the expected cost of funds and charge-offs. These costs comprise KCP&L's and GMO's loss on the sale of accounts receivable. KCP&L and GMO service the receivables and receive annual servicing fees of 1.5% and 1.25%, respectively, of the outstanding principal amount of the receivables sold to KCP&L Receivables Company and GMO Receivables Company. KCP&L and GMO do not recognize a servicing asset or liability because management determined the collection agent fees earned by KCP&L and GMO approximate market value. KCP&L's agreement expires in September 2014 and allows for $110 million in aggregate outstanding principal amount at any time. GMO's agreement expires in September 2014 and allows for $80 million in aggregate outstanding principal during the period of June 1 through October 31 and $65 million in aggregate outstanding principal during the period of November 1 through May 31 of each year.

Information regarding KCP&L's sale of accounts receivable to KCP&L Receivables Company and GMO's sale of accounts receivable to GMO Receivables Company is reflected in the following tables.



2013	KCP&L				KCP&L Receivables Company				Consolidated KCP&L				GMO				GMO Receivables Company				Consolidated Great Plains Energy
	(millions)
Receivables (sold) purchased		$	(1,517.2	)		$	1,517.2			$	—			$	(834.7	)		$	834.7			$	—
Gain (loss) on sale of accounts receivable ^(a)		(19.2		)		19.1				(0.1		)		(10.6		)		10.5				(0.2		)
Servicing fees received (paid)		2.6				(2.6		)		—				1.4				(1.4		)		—
Fees paid to outside investor		—				(1.2		)		(1.2		)		—				(0.7		)		(1.9		)
Cash from customers (transferred) received		(1,516.2		)		1,516.2				—				(830.9		)		830.9				—
Cash received from (paid for) receivables purchased		1,497.2				(1,497.2		)		—				820.5				(820.5		)		—
Interest on intercompany note received (paid)		0.3				(0.3		)		—				0.1				(0.1		)		—



2012	KCP&L				KCP&L Receivables Company				Consolidated KCP&L				GMO				GMO Receivables Company				Consolidated Great Plains Energy
	(millions)
Receivables (sold) purchased		$	(1,436.0	)		$	1,436.0			$	—			$	(597.8	)		$	597.8			$	—
Gain (loss) on sale of accounts receivable ^(a)		(18.2		)		18.3				0.1				(7.6		)		6.6				(0.9		)
Servicing fees received (paid)		2.5				(2.5		)		—				0.9				(0.9		)		—
Fees paid to outside investor		—				(1.2		)		(1.2		)		—				(0.5		)		(1.7		)
Cash from customers (transferred) received		(1,452.4		)		1,452.4				—				(524.0		)		524.0				—
Cash received from (paid for) receivables purchased		1,434.2				(1,434.2		)		—				517.5				(517.5		)		—
Interest on intercompany note received (paid)		0.3				(0.3		)		—				0.1				(0.1		)		—

^(a) Any net gain (loss) is the result of the timing difference inherent in collecting receivables and over the life of the agreement will net to zero.

Nuclear Plant

12 Months Ended

Dec. 31, 2013

Nuclear Plant [Abstract]

Nuclear Plant

4. NUCLEAR PLANT

KCP&L owns 47% of Wolf Creek, its only nuclear generating unit. Wolf Creek is located in Coffey County, Kansas, just northeast of Burlington, Kansas. Wolf Creek's operating license expires in 2045. Wolf Creek is regulated by the Nuclear Regulatory Commission (NRC), with respect to licensing, operations and safety-related requirements.

Spent Nuclear Fuel and High-Level Radioactive Waste

Under the Nuclear Waste Policy Act of 1982, the Department of Energy (DOE) is responsible for the permanent disposal of spent nuclear fuel. KCP&L pays the DOE a quarterly fee of one-tenth of a cent for each kWh of net nuclear generation delivered and sold for the future disposal of spent nuclear fuel. These disposal costs are charged to fuel expense. In 2010, the DOE filed a motion with the NRC to withdraw its then pending application to the NRC to construct a national repository for the disposal of spent nuclear fuel and high-level radioactive waste at Yucca Mountain, Nevada. 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 ordered the licensing board to close out its work on the DOE's application due to a lack of funding. In August 2013, a federal court of appeals ruled that the NRC must resume its review of the DOE's application. Wolf Creek has an on-site storage facility designed to hold all spent fuel generated at the plant through 2025, and believes it will be able to expand on-site storage as needed past 2025. Management cannot predict when, or if, an alternative disposal site will be available to receive Wolf Creek's spent nuclear fuel and will continue to monitor this activity.

Low-Level Radioactive Waste

Wolf Creek disposes of most of its low-level radioactive waste (Class A waste) at an existing third-party repository in Utah. Management expects that the site located in Utah will remain available to Wolf Creek for disposal of its Class A waste. Wolf Creek has contracted with a waste processor that will process, take title and dispose in another state most of the remainder of Wolf Creek's low-level radioactive waste (Classes B and C waste, which is higher in radioactivity but much lower in volume). Should on-site waste storage be needed in the future, Wolf Creek has current storage capacity on site for about four years' generation of Classes B and C waste and believes it will be able to expand that storage capacity as needed if it becomes necessary to do so.

Nuclear Plant Decommissioning Costs

The Public Service Commission of the State of Missouri (MPSC) and The State Corporation Commission of the State of Kansas (KCC) require KCP&L and the other owners of Wolf Creek to submit an updated decommissioning cost study every three years and to propose funding levels. The most recent study was submitted to the MPSC and KCC in August 2011 and is the basis for the current cost of decommissioning estimates in the following table. Funding levels included in KCP&L retail rates have not changed.



	Total Station			KCP&L's 47% Share
	(millions)
Current cost of decommissioning (in 2011 dollars)		$	630		$	296
Future cost of decommissioning (in 2045-2053 dollars) ^(a)		1,788			840

Annual escalation factor	2.85%
Annual return on trust assets ^(b)	5.13%

^(a)Total future cost over an eight year decommissioning period

^(b)The 5.13% rate of return is through 2025. The rate then systematically decreases through 2053 to 0.76% based on the assumption that the fund's investment mix will become increasingly conservative as the decommissioning period approaches.

Nuclear Decommissioning Trust Fund

In 2013 and 2012, KCP&L contributed approximately $3.3 million to a tax-qualified trust fund to be used to decommission Wolf Creek. Amounts funded are charged to other operating expense and recovered in customers' rates. The funding level assumes a projected level of return on trust assets. If the actual return on trust assets is below the projected level or actual decommissioning costs are higher than estimated, KCP&L could be responsible for the balance of funds required; however, while there can be no assurances, management believes a rate increase would be allowed to recover decommissioning costs over the remaining life of the unit.

The following table summarizes the change in Great Plains Energy's and KCP&L's nuclear decommissioning trust fund.



	2013			2012
Decommissioning Trust		(millions)
Beginning balance January 1		$	154.7		$	135.3
Contributions		3.3			3.3
Earned income, net of fees		2.7			3.0
Net realized gains		1.7			1.0
Net unrealized gains		21.5			12.1
Ending balance December 31		$	183.9		$	154.7

The nuclear decommissioning trust is reported at fair value on the balance sheets and is invested in assets as detailed in the following table.



	December 31
	2013													2012
	Cost Basis		Unrealized Gains			Unrealized Losses				Fair Value			Cost Basis			Unrealized Gains			Unrealized Losses				Fair Value
	(millions)
Equity securities	$	83.7		$	44.6		$	(0.6	)		$	127.7		$	80.6		$	21.1		$	(1.6	)		$	100.1
Debt securities	51.0			2.5			(0.7		)		52.8			46.6			4.9			(0.1		)		51.4
Other	3.4			—			—				3.4			3.2			—			—				3.2
Total	$	138.1		$	47.1		$	(1.3	)		$	183.9		$	130.4		$	26.0		$	(1.7	)		$	154.7

The weighted average maturity of debt securities held by the trust at December 31, 2013, was approximately 7 years. The costs of securities sold are determined on the basis of specific identification. The following table summarizes the realized gains and losses from the sale of securities in the nuclear decommissioning trust fund.



	2013			2012			2011
	(millions)
Realized gains	$	2.4		$	1.7		$	1.0
Realized losses	(0.7		)	(0.7		)	(0.7		)

Nuclear Insurance

The owners of Wolf Creek (Owners) maintain nuclear insurance for Wolf Creek for nuclear liability, nuclear property and accidental outage. These policies contain certain industry standard exclusions, including, but not limited to, ordinary wear and tear, and war. The nuclear property insurance programs subscribed to by members of the nuclear power generating industry include industry aggregate limits for acts of terrorism and related losses, including replacement power costs. There is no industry aggregate limit for liability claims related to terrorism, regardless of the number of acts of terrorism affecting Wolf Creek or any other nuclear energy liability policy or the number of policies in place. An industry aggregate limit of $3.2 billion plus any reinsurance recoverable by Nuclear Electric Insurance Limited (NEIL), the Owners' insurance provider, exists for property claims related to nuclear acts of terrorism, including accidental outage power costs for nuclear acts of terrorism affecting Wolf Creek or any other nuclear energy facility property policy within twelve months from the date of the first act. An industry aggregate limit of $1.8 billion exists for property claims related to non-nuclear acts of terrorism. These limits plus any recoverable reinsurance are the maximum amount to be paid to members who sustain losses or damages from these types of terrorist acts. In addition, industry-wide retrospective assessment programs (discussed below) can apply once these insurance programs have been exhausted.

In the event of a catastrophic loss at Wolf Creek, the insurance coverage may not be adequate to cover property damage and extra expenses incurred. Uninsured losses, to the extent not recovered through rates, would be assumed by KCP&L and the other owners and could have a material effect on Great Plains Energy's and KCP&L's results of operations, financial position and cash flows.

Nuclear Liability Insurance

Pursuant to the Price-Anderson Act, which was reauthorized through December 31, 2025, by the Energy Policy Act of 2005, the Owners are required to insure against public liability claims resulting from nuclear incidents to the full limit of public liability, which is currently $13.6 billion. This limit of liability consists of the maximum available commercial insurance of $0.4 billion and the remaining $13.2 billion is provided through an industry-wide retrospective assessment program mandated by law, known as the Secondary Financial Protection (SFP) program. Under the SFP program, the Owners can be assessed up to $127.3 million ($59.8 million, KCP&L's 47% share) per incident at any commercial reactor in the country, payable at no more than $19.0 million ($8.9 million, KCP&L's 47% share) per incident per year. This assessment is subject to an inflation adjustment based on the Consumer Price Index and applicable premium taxes. In addition, the U.S. Congress could impose additional revenue-raising measures to pay claims.

Nuclear Property Insurance

The Owners carry decontamination liability, premature decommissioning liability and property damage insurance from NEIL for Wolf Creek totaling approximately $2.8 billion ($1.3 billion, KCP&L's 47% share). In the event of an accident, insurance proceeds must first be used for reactor stabilization and site decontamination in accordance with a plan mandated by the NRC. KCP&L's share of any remaining proceeds can be used for further decontamination, property damage restoration and premature decommissioning costs. Premature decommissioning coverage applies only if an accident at Wolf Creek exceeds $500 million in property damage and decontamination expenses, and only after trust funds have been exhausted.

Accidental Nuclear Outage Insurance

The Owners also carry additional insurance from NEIL to cover costs of replacement power and other extra expenses incurred in the event of a prolonged outage resulting from accidental property damage at Wolf Creek.

Under all NEIL policies, the Owners are subject to retrospective assessments if NEIL losses, for each policy year, exceed the accumulated funds available to the insurer under that policy. The estimated maximum amount of retrospective assessments under the current policies could total approximately $34.4 million ($16.1 million, KCP&L's 47% share) per policy year.

Regulatory Matters

12 Months Ended

Dec. 31, 2013

Regulated Operations [Abstract]

Regulatory Matters

5. REGULATORY MATTERS

KCP&L Kansas Abbreviated Rate Case Proceedings

In December 2013, KCP&L filed an abbreviated application with KCC to request an increase to its retail revenues of $12.1 million, including the recovery of costs to reflect the completion of certain components of environmental upgrades at the La Cygne Station, construction work in progress for those components of the upgrades still under construction and updates to certain regulatory asset amortizations. The previously approved return on equity and rate-making equity ratio for KCP&L will not be addressed in this case. Testimony from KCC staff and other parties regarding the case is expected in April 2014, with an evidentiary hearing to occur in May 2014. The increase to retail revenues is anticipated to be effective in August 2014.

KCP&L Missouri Rate Case Proceedings

On January 9, 2013, the MPSC issued an order for KCP&L authorizing an increase in annual revenues of $67.4 million effective January 26, 2013. An appeal of the January 9, 2013, MPSC order filed in February 2013 with the Missouri Court of Appeals, Western District (Court of Appeals) by the Missouri Energy Consumers Group (MECG) was dismissed in January 2014. The rates established by the January 9, 2013, MPSC order are effective unless and until modified by the MPSC or stayed by a court.

GMO Missouri Rate Case Proceedings

On January 9, 2013, the MPSC issued an order for GMO authorizing an increase in annual revenues of $26.2 million for its Missouri Public Service division and $21.7 million for its St. Joseph Light & Power division effective January 26, 2013. Appeals of the January 9, 2013, MPSC order were filed in February 2013 with the Court of Appeals by GMO and MECG regarding various issues. The rates established by the January 9, 2013, MPSC order are effective unless and until modified by the MPSC or stayed by a court.

KCP&L Missouri Energy Efficiency Investment Act Proceedings

In January 2014, KCP&L filed a request with the MPSC seeking to recover costs for new and enhanced demand side management programs under the Missouri Energy Efficiency Investment Act (MEEIA). If approved, the costs would be deferred to a regulatory asset and recovered through a rider mechanism beginning in June 2015. Testimony from MPSC staff and other parties regarding the case is expected at the end February 2014, with hearings to occur in March 2014. An order is expected in the second quarter of 2014.

KCP&L and GMO Transmission Cost Accounting Authority Order

In September 2013, KCP&L and GMO filed an application with the MPSC requesting an accounting authority order to defer transmission costs above or below the amount included in current base rates, including carrying costs, as a regulatory asset or liability with the recovery from or refund to Missouri retail customers to be determined in the next general rate case for each company. Hearings were held in January 2014 and a final order is expected in the first half of 2014.

Regulatory Assets and Liabilities

Great Plains Energy and KCP&L have recorded assets and liabilities on their consolidated balance sheets resulting from the effects of the ratemaking process, which would not otherwise be recorded if the Companies were not regulated. Regulatory assets represent incurred costs that are probable of recovery from future revenues. Regulatory liabilities represent future reductions in revenues or refunds to customers.

Management regularly assesses whether regulatory assets and liabilities are probable of future recovery or refund by considering factors such as decisions by the MPSC, KCC or FERC in KCP&L's and GMO's rate case filings; decisions in other regulatory proceedings, including decisions related to other companies that establish precedent on matters applicable to the Companies; and changes in laws and regulations. If recovery or refund of regulatory assets or liabilities is not approved by regulators or is no longer deemed probable, these regulatory assets or liabilities are recognized in the current period results of operations. The Companies' continued ability to meet the criteria for recording regulatory assets and liabilities may be affected in the future by restructuring and deregulation in the electric industry or changes in accounting rules. In the event that the criteria no longer applied to any or all of the Companies' operations, the related regulatory assets and liabilities would be written off unless an appropriate regulatory recovery mechanism were provided. Additionally, these factors could result in an impairment on utility plant assets. Great Plains Energy's and KCP&L's regulatory assets and liabilities are detailed in the following table.



	December 31
	2013								2012
	KCP&L			GMO			Great Plains Energy		KCP&L		GMO		Great Plains Energy
Regulatory Assets	(millions)
Taxes recoverable through future rates	$	111.0		$	25.4		$	136.4	$	114.7	$	23.7	$	138.4
Loss on reacquired debt	7.1		^(a)	1.5		^(a)	8.6		8.1		2.0		10.1
Cost of removal	1.0			—			1.0		2.8		—		2.8
Asset retirement obligations	34.8			16.0			50.8		31.5		14.9		46.4
Pension and post-retirement costs	310.0		^(b)	91.2		^(b)	401.2		541.2		129.7		670.9
Deferred customer programs	50.2		^(c)	21.8		^(d)	72.0		49.8		24.6		74.4
Rate case expenses	3.6		^(e)	0.6		^(f)	4.2		7.5		1.7		9.2
Fuel recovery mechanism	10.8		^(e)	12.8		^(e)	23.6		8.9		16.9		25.8
Acquisition transition costs	12.9		^(g)	11.0		^(g)	23.9		18.7		15.5		34.2
Derivative instruments	—			—			—		—		3.7		3.7
Iatan No. 1 and common facilities depreciation and carrying costs	15.3		^(h)	5.7		^(h)	21.0		15.9		5.9		21.8
Iatan No. 2 construction accounting costs	29.3		⁽ⁱ⁾	16.0		⁽ⁱ⁾	45.3		30.6		16.2		46.8
Kansas property tax surcharge	4.0		^(e)	—			4.0		5.4		—		5.4
Solar rebates	13.0		^(e)	32.3		^(e)	45.3		5.8		10.0		15.8
Voluntary separation program	3.4		^(j)	—			3.4		4.3		—		4.3
Other	7.7		^(e)	1.3		^(e)	9.0		8.0		2.9		10.9
Total	$	614.1		$	235.6		$	849.7	$	853.2	$	267.7	$	1,120.9
Regulatory Liabilities
Emission allowances	$	74.0		$	—		$	74.0	$	78.0	$	0.1	$	78.1
Asset retirement obligations	86.2			—			86.2		63.1		—		63.1
Pension	—			—			—		1.5		44.6		46.1
Cost of removal	—			68.1		^(k)	68.1		—		64.0		64.0
Other	8.1			27.6			35.7		10.4		22.1		32.5
Total	$	168.3		$	95.7		$	264.0	$	153.0	$	130.8	$	283.8

^(a)Amortized over the life of the related new debt issuances or the remaining lives of the old debt issuances if no new debt was issued.

^(b) Represents unrecognized gains and losses, prior service and transition costs that will be recognized in future net periodic pension and post-retirement costs, pension settlements amortized over various periods and financial and regulatory accounting method differences that will be eliminated over the life of the pension plans. Of these amounts, $288.5 million and $57.0 million for KCP&L and GMO, respectively, are not included in rate base and are amortized over various periods.

^(c) $15.4 million not included in rate base and amortized over various periods.

^(d)$2.1 million not included in rate base and amortized over various periods.

^(e)Not included in rate base and amortized over various periods.

^(f)Not included in rate base and amortized through 2014.

^(g)Not included in rate base and amortized through 2016.

^(h)Included in rate base and amortized through 2038.

⁽ⁱ⁾Included in rate base and amortized through 2058.

^(j)Not included in rate base and amortized through 2017.

^(k)Estimated cumulative net provision for future removal costs.

Goodwill and Intangible Assets

12 Months Ended

Dec. 31, 2013

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Intangible Assets [Text Block]

6. GOODWILL AND INTANGIBLE ASSETS

Accounting rules require goodwill to be tested for impairment annually and when an event occurs indicating the possibility that an impairment exists. The annual impairment test for the $169.0 million of GMO acquisition goodwill was conducted on September 1, 2013. The goodwill impairment test is a two step process. The first step compares the fair value of a reporting unit to its carrying amount, including goodwill, to identify potential impairment. If the carrying amount exceeds the fair value of the reporting unit, the second step of the test is performed, consisting of assignment of the reporting unit's fair value to its assets and liabilities to determine an implied fair value of goodwill, which is compared to the carrying amount of goodwill to determine the impairment loss, if any, to be recognized in the financial statements. Great Plains Energy's regulated electric utility operations are considered one reporting unit for assessment of impairment, as they are included within the same operating segment and have similar economic characteristics. The determination of fair value of the reporting unit consisted of two valuation techniques: an income approach consisting of a discounted cash flow analysis and a market approach consisting of a determination of reporting unit invested capital using market multiples derived from the historical revenue, EBITDA, net utility asset values and market prices of stock of peer companies. The results of the two techniques were evaluated and weighted to determine a point within the range that management considered representative of fair value for the reporting unit. Fair value of the reporting unit exceeded the carrying amount, including goodwill; therefore, there was no impairment of goodwill.

Great Plains Energy's and KCP&L's intangible assets are included in electric utility plant on the consolidated balance sheets and are detailed in the following table.



		December 31, 2013							December 31, 2012
	Gross Carrying Amount			Accumulated Amortization				Gross Carrying Amount			Accumulated Amortization
Great Plains Energy	(millions)
Computer software		$	255.4		$	(169.9	)		$	211.2		$	(152.9	)
Asset improvements		26.5			(4.9		)		26.5			(4.2		)

KCP&L
Computer software		$	231.2		$	(156.5	)		$	189.9		$	(142.9	)
Asset improvements		11.2			(1.1		)		11.2			(0.8		)

Great Plains Energy's and KCP&L's amortization expense related to intangible assets is detailed in the following table.



	2013		2012
	(millions)
Great Plains Energy	$	17.6	$	15.6
KCP&L	14.3		13.2

The following table provides the estimated amortization expense related to Great Plains Energy's and KCP&L's intangible assets for 2014 through 2018 for the intangible assets included in the consolidated balance sheets at December 31, 2013.



	2014		2015		2016		2017		2018
	(millions)
Great Plains Energy	$	17.2	$	15.1	$	13.6	$	9.5	$	6.7
KCP&L	14.0		12.1		10.7		8.4		6.3

Asset Retirement Obligation Disclosure [Abstract]

The entire disclosure for the aggregate amount of goodwill and a description of intangible assets, which may include (a) for amortizable intangible assets (also referred to as finite-lived intangible assets), the carrying amount, the amount of any significant residual value, and the weighted-average amortization period, (b) for intangible assets not subject to amortization (also referred to as indefinite-lived intangible assets), the carrying amount, and (c) the amount of research and development assets acquired and written off in the period, including the line item in the income statement in which the amounts written off are aggregated, if not readily apparent from the income statement. Also discloses (a) for amortizable intangibles assets in total and by major class, the gross carrying amount and accumulated amortization, the total amortization expense for the period, and the estimated aggregate amortization expense for each of the five succeeding fiscal years, (b) for intangible assets not subject to amortization the carrying amount in total and by major class, and (c) for goodwill, in total and for each reportable segment, the changes in the carrying amount of goodwill during the period (including the aggregate amount of goodwill acquired, the aggregate amount of impairment losses recognized, and the amount of goodwill included in the gain (loss) on disposal of a reporting unit). If any part of goodwill has not been allocated to a reportable segment, discloses the unallocated amount and the reasons for not allocating. For each impairment loss recognized related to an intangible asset (excluding goodwill), discloses: (a) a description of the impaired intangible asset and the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method for determining fair value, (c) the caption in the income statement or the statement of activities in which the impairment loss is aggregated, and (d) the segment in which the impaired intangible asset is reported. For each goodwill impairment loss recognized, discloses: (a) a description of the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method of determining the fair value of the associated reporting unit, and (c) if a recognized impairment loss is an estimate not finalized and the reasons why the estimate is not final. May also disclose the nature and amount of any significant adjustments made to a previous estimate of an impairment loss.

+ References+ Details

Asset Retirement Obligations

12 Months Ended

Dec. 31, 2013

Asset Retirement Obligations [Text Block]

7. ASSET RETIREMENT OBLIGATIONS

Asset retirement obligations associated with tangible long-lived assets are those for which a legal obligation exists under enacted laws, statutes and written or oral contracts, including obligations arising under the doctrine of promissory estoppel. These liabilities are recognized at estimated fair value as incurred with a corresponding amount capitalized as part of the cost of the related long-lived assets and depreciated over their useful lives. Accretion of the liabilities due to the passage of time is recorded to a regulatory asset and/or liability. Changes in the estimated fair values of the liabilities are recognized when known.

KCP&L has AROs related to decommissioning Wolf Creek, site remediation of its Spearville Wind Energy Facilities, asbestos abatement and removal of storage tanks, ash ponds and landfills. GMO has AROs related to asbestos abatement and removal of storage tanks, ash ponds and landfills.

Additionally, certain wiring used in Great Plains Energy's and KCP&L's generating stations include asbestos insulation, which would require special handling if disturbed. Due to the inability to reasonably estimate the quantities or the amount of disturbance that will be necessary during dismantlement at the end of the life of a plant, the fair value of this ARO cannot be reasonably estimated at this time. Management will continue to monitor the obligation and will recognize a liability in the period in which sufficient information becomes available to reasonably estimate its fair value.

The following table summarizes the change in Great Plains Energy's and KCP&L's AROs.



	Great Plains Energy					KCP&L
	2013		2012			2013		2012
	(millions)
Beginning balance	$	149.3	$	149.6		$	133.2	$	134.3
Revision in timing and/or estimates	—		(7.7		)	—		(7.7		)
Settlements	—		(1.8		)	—		(1.8		)
Accretion	9.5		9.2			8.5		8.4
Ending balance	$	158.8	$	149.3		$	141.7	$	133.2

Pension Plans and Other Employee Benefits

12 Months Ended

Dec. 31, 2013

Compensation and Retirement Disclosure [Abstract]

Pension Plans and Other Employee Benefits

8. PENSION PLANS, OTHER EMPLOYEE BENEFITS AND VOLUNTARY SEPARATION PROGRAM

Great Plains Energy incurs significant costs in providing defined benefit plans for substantially all active and inactive employees, including officers, of KCP&L, GMO and its 47% ownership share of Wolf Creek Nuclear Operating Corporation (WCNOC) defined benefit plans. For the majority of employees, pension benefits under these plans reflect the employees' compensation, years of service and age at retirement; however, for union employees hired after October 1, 2013, the benefits are derived from a cash balance account formula. Effective in 2014, the non-union plan was closed to future employees. Great Plains Energy also provides certain post-retirement health care and life insurance benefits for substantially all retired employees of KCP&L, GMO and its 47% ownership share of WCNOC.

KCP&L and GMO record pension and post-retirement expense in accordance with rate orders from the MPSC and KCC that allow the difference between pension and post-retirement costs under GAAP and costs for ratemaking to be recognized as a regulatory asset or liability. This difference between financial and regulatory accounting methods is due to timing and will be eliminated over the life of the plans.

In 2013, 2012 and 2011, Great Plains Energy recorded pension settlement charges of $4.9 million, $0.8 million and $10.1 million, respectively, as a result of accelerated pension distributions. The 2011 distributions were related to the voluntary separation program which is explained in more detail below. The Companies deferred substantially all of the charges as a regulatory asset and will recover it over future periods pursuant to regulatory agreements.

The following pension benefits tables provide information relating to the funded status of all defined benefit pension plans on an aggregate basis as well as the components of net periodic benefit costs. For financial reporting purposes, the market value of plan assets is the fair value. For regulatory reporting purposes, a five-year smoothing of assets is used to determine fair value. Net periodic benefit costs reflect total plan benefit costs prior to the effects of capitalization and sharing with joint owners of power plants.



	Pension Benefits						Other Benefits
	2013			2012			2013			2012
Change in projected benefit obligation (PBO)	(millions)
PBO at January 1	$	1,130.5		$	980.6		$	186.5		$	154.2
Service cost	41.2			35.4			4.4			3.3
Interest cost	47.2			48.9			7.7			7.8
Contribution by participants	—			—			6.2			6.7
Amendments	0.3			1.1			(6.0		)	—
Actuarial (gain) loss	(118.4		)	127.0			(26.1		)	26.7
Benefits paid	(52.9		)	(58.1		)	(12.2		)	(12.2		)
Settlements	(40.5		)	(4.4		)	—			—
PBO at December 31	$	1,007.4		$	1,130.5		$	160.5		$	186.5
Change in plan assets
Fair value of plan assets at January 1	$	666.4		$	591.1		$	90.3		$	77.4
Actual return on plan assets	70.9			71.2			(2.0		)	1.4
Contributions by employer and participants	57.4			60.4			25.0			23.7
Benefits paid	(51.2		)	(56.3		)	(12.1		)	(12.2		)
Settlements	(40.5		)	—			—			—
Fair value of plan assets at December 31	$	703.0		$	666.4		$	101.2		$	90.3
Funded status at December 31	$	(304.4	)	$	(464.1	)	$	(59.3	)	$	(96.2	)
Amounts recognized in the consolidated balance sheets
Current pension and other post-retirement liability	$	(2.3	)	$	(1.9	)	$	(0.9	)	$	(0.9	)
Noncurrent pension liability and other post-retirement liability	(302.1		)	(462.2		)	(58.4		)	(95.3		)
Net amount recognized before regulatory treatment	(304.4		)	(464.1		)	(59.3		)	(96.2		)
Accumulated OCI or regulatory asset/liability	368.3			559.5			35.3			70.4
Net amount recognized at December 31	$	63.9		$	95.4		$	(24.0	)	$	(25.8	)
Amounts in accumulated OCI or regulatory asset/liability not yet recognized as a component of net periodic benefit cost:
Actuarial loss	$	147.7		$	349.0		$	19.2		$	43.0
Prior service cost	5.6			7.3			16.6			29.8
Transition obligation	—			—			0.4			0.6
Other	215.0			203.2			(0.9		)	(3.0		)
Net amount recognized at December 31	$	368.3		$	559.5		$	35.3		$	70.4



	Pension Benefits									Other Benefits
	2013			2012			2011			2013			2012			2011
Components of net periodic benefit costs	(millions)
Service cost	$	41.2		$	35.4		$	31.1		$	4.4		$	3.3		$	3.1
Interest cost	47.2			48.9			49.6			7.7			7.8			7.8
Expected return on plan assets	(47.1		)	(42.9		)	(38.0		)	(2.0		)	(1.8		)	(1.8		)
Prior service cost	2.0			4.5			4.6			7.2			7.1			7.2
Recognized net actuarial (gain) loss	54.3			44.5			38.7			1.7			(0.2		)	(0.5		)
Transition obligation	—			—			—			0.2			1.1			1.3
Settlement charges	4.9			0.8			10.1			—			—			—
Net periodic benefit costs before regulatory adjustment	102.5			91.2			96.1			19.2			17.3			17.1
Regulatory adjustment	(16.8		)	(15.5		)	(27.9		)	(2.4		)	1.5			1.1
Net periodic benefit costs	85.7			75.7			68.2			16.8			18.8			18.2
Other changes in plan assets and benefit obligations recognized in OCI or regulatory assets/liabilities
Current year net (gain) loss	(147.0		)	97.9			114.8			(22.1		)	27.1			6.7
Amortization of gain (loss)	(54.3		)	(44.5		)	(38.7		)	(1.7		)	0.2			0.5
Prior service cost	0.3			1.1			—			(6.0		)	—			—
Amortization of prior service cost	(2.0		)	(4.5		)	(4.6		)	(7.2		)	(7.1		)	(7.2		)
Amortization of transition obligation	—			—			—			(0.2		)	(1.1		)	(1.3		)
Other regulatory activity	11.8			17.7			17.1			2.1			(1.2		)	(1.0		)
Total recognized in OCI or regulatory asset/liability	(191.2		)	67.7			88.6			(35.1		)	17.9			(2.3		)
Total recognized in net periodic benefit costs and OCI or regulatory asset/liability	$	(105.5	)	$	143.4		$	156.8		$	(18.3	)	$	36.7		$	15.9

For financial reporting purposes, the estimated prior service cost and net loss for the defined benefit plans that will be amortized from accumulated OCI or a regulatory asset into net periodic benefit cost in 2014 are $1.0 million and $49.6 million, respectively. For financial reporting purposes, net actuarial gains and losses are recognized on a rolling five-year average basis. For regulatory reporting purposes, net actuarial gains and losses are amortized over ten years. The estimated prior service cost, net gain and transition costs for the other post-retirement benefit plans that will be amortized from accumulated OCI or a regulatory asset into net periodic benefit cost in 2014 are $3.1 million, $0.1 million and $0.2 million, respectively.

The accumulated benefit obligation (ABO) for all defined benefit pension plans was $889.2 million and $985.8 million at December 31, 2013 and 2012, respectively. Pension and other post-retirement benefit plans with the PBO, ABO or accumulated other post-retirement benefit obligation (APBO) in excess of the fair value of plan assets at year-end are detailed in the following table.



	2013		2012
Pension plans with the PBO in excess of plan assets	(millions)
Projected benefit obligation	$	1,007.4	$	1,130.5
Fair value of plan assets	703.0		666.4
Pension plans with the ABO in excess of plan assets
Accumulated benefit obligation	$	889.2	$	985.8
Fair value of plan assets	703.0		666.4
Other post-retirement benefit plans with the APBO in excess of plan assets
Accumulated other post-retirement benefit obligation	$	160.5	$	186.5
Fair value of plan assets	101.2		90.3

The GMO Supplemental Executive Retirement Plan (SERP) is reflected as an unfunded ABO of $21.5 million. Great Plains Energy has approximately $17.9 million of assets in a non-qualified trust for this plan as of December 31, 2013, and expects to fund future benefit payments from these assets.

The expected long-term rate of return on plan assets represents Great Plains Energy's estimate of the long-term return on plan assets and is based on historical and projected rates of return for current and planned asset classes in the plans' investment portfolios. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns of various asset classes. Based on the target asset allocation for each asset class, the overall expected rate of return for the portfolios was developed and adjusted for the effect of projected benefits paid from plan assets and future plan contributions. The following tables provide the weighted-average assumptions used to determine benefit obligations and net costs.



Weighted-average assumptions used to determine the benefit obligation at December 31	Pension Benefits				Other Benefits
	2013		2012		2013		2012
Discount rate	5.03	%	4.17	%	4.92	%	4.13	%
Rate of compensation increase	3.69	%	3.69	%	3.50	%	3.50	%



Weighted-average assumptions used to determine net costs for years ended December 31	Pension Benefits				Other Benefits
	2013		2012		2013			2012
Discount rate	4.17	%	5.01	%	4.13	%		5.03	%
Expected long-term return on plan assets	7.24	%	7.29	%	2.62	%	*	2.59	%	*
Rate of compensation increase	3.69	%	4.08	%	3.50	%		4.07	%

*after tax

Great Plains Energy expects to contribute $62.8 million to the pension plans in 2014 to meet Employee Retirement Income Security Act of 1974, as amended (ERISA) funding requirements and regulatory orders, the majority of which is expected to be paid by KCP&L. Great Plains Energy's funding policy is to contribute amounts sufficient to meet the ERISA funding requirements and MPSC and KCC rate orders plus additional amounts as considered appropriate; therefore, actual contributions may differ from expected contributions. Great Plains Energy also expects to contribute $11.3 million to other post-retirement benefit plans in 2014, the majority of which is expected to be paid by KCP&L.

The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid through 2023.



	Pension Benefits		Other Benefits
	(millions)
2014	$	67.0	$	7.8
2015	65.3		8.3
2016	69.1		8.9
2017	71.9		9.3
2018	73.6		9.7
2019-2023	401.3		52.1

Pension plan assets are managed in accordance with prudent investor guidelines contained in the ERISA requirements. The investment strategy supports the objective of the fund, which is to earn the highest possible return on plan assets within a reasonable and prudent level of risk. The portfolios are invested, and periodically rebalanced, to achieve targeted allocations of approximately 25% U.S. large cap and small cap equity securities, 23% international equity securities, 35% fixed income securities, 7% real estate, 6% commodities and 4% hedge funds. Fixed income securities include domestic and foreign corporate bonds, collateralized mortgage obligations and asset-backed securities, U.S. government agency, state and local obligations, U.S. Treasury notes and money market funds.

The fair values of Great Plains Energy's pension plan assets at December 31, 2013 and 2012, by asset category are in the following tables.



				Fair Value Measurements Using
Description	December 31 2013			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
		(millions)
Pension Plans
Equity securities
U.S. ^(a)		$	193.7		$	80.5		$	113.2		$	—
International ^(b)		167.1			39.9			127.2			—
Real estate ^(c)		49.1			—			5.4			43.7
Commodities ^(d)		34.8			—			34.8			—
Fixed income securities
Fixed income funds ^(e)		181.3			27.1			154.2			—
U.S. Treasury		2.6			2.6			—			—
U.S. Agency, state and local obligations		17.1			—			17.1			—
U.S. corporate bonds ^(f)		25.6			—			25.6			—
Foreign corporate bonds		2.3			—			2.3			—
Hedge funds ^(g)		23.1			—			—			23.1
Cash equivalents		3.0			3.0			—			—
Other		3.3			—			3.3			—
Total		$	703.0		$	153.1		$	483.1		$	66.8



				Fair Value Measurements Using
Description	December 31 2012			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
		(millions)
Pension Plans
Equity securities
U.S. ^(a)		$	169.6		$	69.7		$	99.9		$	—
International ^(b)		151.2			36.6			114.6			—
Real estate ^(c)		43.4			—			5.0			38.4
Commodities ^(d)		37.3			—			37.3			—
Fixed income securities
Fixed income funds ^(e)		182.1			35.0			147.1			—
U.S. Treasury		4.5			4.5			—			—
U.S. Agency, state and local obligations		19.6			—			19.6			—
U.S. corporate bonds ^(f)		28.9			—			28.9			—
Foreign corporate bonds		2.6			—			2.6			—
Hedge funds ^(g)		21.6			—			—			21.6
Total		$	660.8		$	145.8		$	455.0		$	60.0
Cash equivalents		5.6
Total Pension Plans		$	666.4

^(a) At December 31, 2013 and 2012, this category is comprised of $80.5 million and $69.7 million, respectively, of traded mutual funds valued at daily listed prices and $113.2 million and $99.9 million, respectively, of institutional common/collective trust funds valued at Net Asset Value (NAV) per share.

^(b)At December 31, 2013 and 2012, this category is comprised of $39.9 million and $36.6 million, respectively, of traded mutual funds valued at daily listed prices and $127.2 million and $114.6 million, respectively, of institutional common/collective trust funds valued at daily NAV per share.

^(c)This category is comprised of institutional common/collective trust funds and a limited partnership valued at NAV on a quarterly basis.

^(d) This category is comprised of institutional common/collective trust funds valued at daily NAV per share.

^(e)At December 31, 2013 and 2012, this category is comprised of $27.1 million and $35.0 million, respectively, of traded mutual funds valued at daily listed prices and $154.2 million and $147.1 million, respectively, of institutional common/collective trust funds valued at daily NAV per share.

^(f)At December 31, 2013 and 2012, this category is comprised of $20.1 million and $21.5 million, respectively, of corporate bonds, $3.6 million and $5.2 million, respectively, of collateralized mortgage obligations and $1.9 million and $2.2 million, respectively, of other asset-backed securities.

^(g)This category is comprised of closely-held limited partnerships valued at NAV on a quarterly basis.

The following tables reconcile the beginning and ending balances for all level 3 pension plan assets measured at fair value on a recurring basis for 2013 and 2012.



Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
Description	Real Estate			Hedge Funds			Total
	(millions)
Balance January 1, 2013		$	38.4		$	21.6		$	60.0
Actual return on plan assets
Relating to assets still held		4.6			1.5			6.1
Purchase, sales and settlements		0.7			—			0.7
Balance December 31, 2013		$	43.7		$	23.1		$	66.8



Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
Description	Real Estate			Hedge Funds				Total
	(millions)
Balance January 1, 2012		$	34.7		$	21.7			$	56.4
Actual return on plan assets
Relating to assets still held		1.6			0.6				2.2
Relating to assets sold		1.3			(0.4		)		0.9
Purchase, sales and settlements		0.8			(0.3		)		0.5
Balance December 31, 2012		$	38.4		$	21.6			$	60.0

Other post-retirement plan assets are also managed in accordance with prudent investor guidelines contained in the ERISA requirements. The investment strategy supports the objective of the funds, which is to preserve capital, maintain sufficient liquidity and earn a consistent rate of return. Other post-retirement plan assets are invested primarily in fixed income securities, which may include domestic and foreign corporate bonds, collateralized mortgage obligations and asset-backed securities, U.S. government agency, state and local obligations, U.S. Treasury notes and money market funds, as well as domestic and international equity funds.

The fair values of Great Plains Energy's other post-retirement plan assets at December 31, 2013 and 2012, by asset category are in the following tables.



				Fair Value Measurements Using
Description	December 31 2013			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
		(millions)
Other Post-Retirement Benefit Plans
Equity securities		$	2.2		$	2.2		$	—		$	—
Fixed income securities
Fixed income fund ^(a)		74.6			0.2			74.4			—
U.S. Treasury		1.5			1.5			—			—
U.S. Agency, state and local obligations		4.4			—			4.4			—
U.S. corporate bonds ^(b)		8.6			—			8.6			—
Foreign corporate bonds		1.0			—			1.0			—
Cash equivalents		8.6			8.6			—			—
Other		0.3			—			0.3			—
Total		$	101.2		$	12.5		$	88.7		$	—



				Fair Value Measurements Using
Description	December 31 2012			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
		(millions)
Other Post-Retirement Benefit Plans
Equity securities		$	1.7		$	1.7		$	—		$	—
Fixed income securities
U.S. Treasury		13.7			13.7			—			—
U.S. Agency, state and local obligations		28.6			—			28.6			—
U.S. corporate bonds ^(b)		20.1			—			20.1			—
Foreign corporate bonds		2.2			—			2.2			—
Mutual funds		0.2			0.2			—			—
Total		$	66.5		$	15.6		$	50.9		$	—
Cash equivalents		23.8
Total Other Post-Retirement Benefit Plans		$	90.3

^(a)This category is comprised of $74.4 million of an institutional common/collective trust fund valued at daily NAV per share and $0.2 million of traded mutual funds valued at daily listed prices.

^(b) At December 31, 2013 and 2012, this category is comprised of $7.1 million and $17.1 million, respectively, of corporate bonds, $0.3 million and $1.4 million, respectively, of collateralized mortgage obligations and $1.2 million and $1.6 million, respectively, of other asset-backed securities.

Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans. The cost trends assumed for 2013 and 2014 were 7.5% and 7.0%, respectively, with the rate declining through 2018 to the ultimate cost trend rate of 5%. The health care plan requires retirees to make monthly contributions on behalf of themselves and their dependents in an amount determined by Great Plains Energy.

The effects of a one-percentage point change in the assumed health care cost trend rates, holding all other assumptions constant, at December 31, 2013, are detailed in the following table.



	Increase		Decrease
	(millions)
Effect on total service and interest component	$	1.1	$	(1.0	)
Effect on post-retirement benefit obligation	8.8		(7.3		)

Employee Savings Plans

Great Plains Energy has defined contribution savings plans (401(k)) that cover substantially all employees. Great Plains Energy matches employee contributions, subject to limits. The annual cost of the plans was approximately $9.6 million in 2013 and $9.2 million in 2012 and 2011. KCP&L's annual cost of the plans was approximately $7.0 million in 2013 and $6.7 million in 2012 and 2011.

Voluntary Separation Program

In 2011, Great Plains Energy executed an organizational realignment and voluntary separation program to assist in the management of overall costs within the level reflected in the Company's retail electric rates and to enhance organizational efficiency. Great Plains Energy and KCP&L recorded expense of $12.7 million and $9.2 million, respectively, in 2011 related to this voluntary separation program reflecting severance and related payroll taxes provided to employees who elected to voluntarily separate from the Company. In 2012, KCP&L deferred $4.3 million of expense related to the voluntary separation program to a regulatory asset for recovery in rates beginning January 1, 2013, pursuant to KCP&L's December 2012 KCC rate order.

Equity Compensation

12 Months Ended

Dec. 31, 2013

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Equity Compensation

9. EQUITY COMPENSATION

Great Plains Energy's Long-Term Incentive Plan is an equity compensation plan approved by Great Plains Energy's shareholders. The Long-Term Incentive Plan permits the grant of restricted stock, restricted stock units, bonus shares, stock options, stock appreciation rights, limited stock appreciation rights, director shares, director deferred share units and performance shares to directors, officers and other employees of Great Plains Energy and KCP&L. The maximum number of shares of Great Plains Energy common stock that can be issued under the plan is 8.0 million. Common stock shares delivered by Great Plains Energy under the Long-Term Incentive Plan may be authorized but unissued, held in the treasury or purchased on the open market (including private purchases) in accordance with applicable securities laws. Great Plains Energy has a policy of delivering newly issued shares, or shares surrendered by Long-Term Incentive Plan participants for the withholding of taxes and held in treasury, or both, and does not expect to repurchase common shares during 2014 to satisfy performance share payments and director deferred share unit conversion. Forfeiture rates are based on historical forfeitures and future expectations and are reevaluated annually.

The following table summarizes Great Plains Energy's and KCP&L's equity compensation expense and the associated income tax benefit.



	2013		2012		2011
Great Plains Energy	(millions)
Equity compensation expense	$	5.6	$	3.3	$	5.2
Income tax benefit	1.9		1.4		1.9
KCP&L
Equity compensation expense	$	4.0	$	2.3	$	3.5
Income tax benefit	1.3		1.0		1.3

Performance Shares

The payment of performance shares is contingent upon achievement of specific performance goals over a stated period of time as approved by the Compensation and Development Committee of the Board. The number of performance shares ultimately paid can vary from the number of shares initially granted depending on Great Plains Energy's performance over stated performance periods. Compensation expense for performance shares is calculated by taking the change in fair value between reporting periods for the portion for which the requisite service has been rendered. Dividends are accrued over the vesting period and paid in cash based on the number of performance shares ultimately paid.

The fair value of performance share awards is estimated using the market value of the Company's stock at the valuation date and a Monte Carlo simulation technique that incorporates assumptions for inputs of expected volatilities, dividend yield and risk-free rates. Expected volatility is based on daily stock price change during a historical period commensurate with the remaining term of the performance period of the grant. The risk-free rate is based upon the rate at the time of the evaluation for zero-coupon government bonds with a maturity consistent with the remaining performance period of the grant. The dividend yield is based on the most recent dividends paid and the actual closing stock price on the valuation date. For shares granted in 2013, inputs for expected volatility, dividend yield and risk-free rates were 19%, 3.88%, and 0.35%, respectively.

Performance share activity is summarized in the following table. Performance adjustment represents the number of shares of common stock related to performance shares ultimately issued that can vary from the number of performance shares initially granted depending on Great Plains Energy's performance over a stated period of time.



	Performance Shares			Grant Date Fair Value*
Beginning balance January 1, 2013		370,560			$	23.05
Granted		226,967			24.17
Earned		(104,453	)		23.37
Forfeited		(11,523	)		22.82
Performance adjustment		(51,542	)		23.37
Ending balance December 31, 2013		430,009			23.52

* weighted-average

At December 31, 2013, the remaining weighted-average contractual term was 1.3 years. The weighted-average grant-date fair value of shares granted was $24.17, $19.37 and $26.15 in 2013, 2012 and 2011, respectively. At December 31, 2013, there was $5.7 million of total unrecognized compensation expense, net of forfeiture rates, related to performance shares granted under the Long-Term Incentive Plan, which will be recognized over the remaining weighted-average contractual term. The total fair value of performance shares earned and paid in 2013 was $2.4 million. There were no performance shares earned and paid in 2012. The total fair value of performance shares earned and paid in 2011 was $0.8 million.

Restricted Stock

Restricted stock cannot be sold or otherwise transferred by the recipient prior to vesting and has a value equal to the fair market value of the shares on the issue date. Restricted stock shares vest over a stated period of time with accruing reinvested dividends subject to the same restrictions. Compensation expense, calculated by multiplying shares by the grant-date fair value related to restricted stock, is recognized over the stated vesting period. Restricted stock activity is summarized in the following table.



	Nonvested Restricted Stock			Grant Date Fair Value*
Beginning balance January 1, 2013		277,439			$	19.03
Granted and issued		79,645			22.47
Vested		(64,405	)		17.88
Forfeited		(4,142	)		21.44
Ending balance December 31, 2013		288,537			20.18

* weighted-average

At December 31, 2013, the remaining weighted-average contractual term was 1.2 years. The weighted-average grant-date fair value of shares granted was $22.47, $19.75 and $19.03 in 2013, 2012 and 2011, respectively. At December 31, 2013, there was $2.2 million of total unrecognized compensation expense, net of forfeiture rates, related to nonvested restricted stock granted under the Long-Term Incentive Plan, which will be recognized over the remaining weighted-average contractual term. The total fair value of shares vested was $1.2 million, $3.3 million and $2.6 million in 2013, 2012 and 2011, respectively.

Director Deferred Share Units

Non-employee directors receive shares of Great Plains Energy's common stock as part of their annual retainer. Each director may elect to defer receipt of their shares until the end of January in the year after they leave the Board or such other time as elected by each director. Director Deferred Share Units have a value equal to the market value of Great Plains Energy's common stock on the grant date with accruing dividends. Compensation expense, calculated by multiplying the director deferred share units by the related grant-date fair value, is recognized at the grant date. The total fair value of shares of Director Deferred Share Units issued was insignificant for 2013 and 2012. Director Deferred Share Units activity is summarized in the following table.



	Share Units		Grant Date Fair Value*
Beginning balance January 1, 2013		69,818		$	20.36
Issued		20,302		22.95
Ending balance December 31, 2013		90,120		20.94

* weighted-average

The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details.

+ References+ Details

Short-term Borrowings and Short-term Bank Lines of Credit	12 Months Ended
	Dec. 31, 2013
Short-term Borrowings and Short-term Bank Lines of Credit [Abstract]
Short-term Borrowings and Short-term Bank Lines of Credit [Text Block]	10. SHORT-TERM BORROWINGS AND SHORT-TERM BANK LINES OF CREDIT Great Plains Energy's $200 Million Revolving Credit Facility Great Plains Energy's $200 million revolving credit facility with a group of banks expires in October 2018. The facility's terms permit transfers of unused commitments between this facility and the KCP&L and GMO facilities discussed below, with the total amount of the facility not exceeding $400 million at any one time. A default by Great Plains Energy or any of its significant subsidiaries on other indebtedness totaling more than $50.0 million is a default under the facility. Under the terms of this facility, Great Plains Energy is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the facility, not greater than 0.65 to 1.00 at all times. At December 31, 2013, Great Plains Energy was in compliance with this covenant. At December 31, 2013, Great Plains Energy had $9.0 million of outstanding cash borrowings at a weighted-average interest rate of 1.94% and had issued no letters of credit under the credit facility. At December 31, 2012, Great Plains Energy had $12.0 million of outstanding cash borrowings at a weighted-average interest rate of 2.00% and had issued letters of credit totaling $1.8 million under the credit facility. KCP&L's $600 Million Revolving Credit Facility and Commercial Paper KCP&L's $600 million revolving credit facility with a group of banks provides support for its issuance of commercial paper and other general corporate purposes and expires in October 2018. Great Plains Energy and KCP&L may transfer up to $200 million of unused commitments between Great Plains Energy's and KCP&L's facilities. A default by KCP&L on other indebtedness totaling more than $50.0 million is a default under the facility. Under the terms of this facility, KCP&L is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the facility, not greater than 0.65 to 1.00 at all times. At December 31, 2013, KCP&L was in compliance with this covenant. At December 31, 2013, KCP&L had $93.2 million of commercial paper outstanding at a weighted-average interest rate of 0.29%, had issued letters of credit totaling $3.8 million and had no outstanding cash borrowings under the credit facility. At December 31, 2012, KCP&L had $361.0 million of commercial paper outstanding at a weighted-average interest rate of 0.48%, had issued letters of credit totaling $13.9 million and had no outstanding cash borrowings under the credit facility. GMO's $450 Million Revolving Credit Facility and Commercial Paper GMO's $450 million revolving credit facility with a group of banks provides support for its issuance of commercial paper and other general corporate purposes and expires in October 2018. Great Plains Energy and GMO may transfer up to $200 million of unused commitments between Great Plains Energy's and GMO's facilities. A default by GMO or any of its significant subsidiaries on other indebtedness totaling more than $50.0 million is a default under the facility. Under the terms of this facility, GMO is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the facility, not greater than 0.65 to 1.00 at all times. At December 31, 2013, GMO was in compliance with this covenant. At December 31, 2013, GMO had $15.0 million of commercial paper outstanding at a weighted-average interest rate of 0.66%, had issued letters of credit totaling $16.4 million and had no outstanding cash borrowings under the credit facility. At December 31, 2012, GMO had $169.1 million of commercial paper outstanding at a weighted-average interest rate of 0.94%, had issued letters of credit totaling $15.1 million and had no outstanding cash borrowings under the credit facility.

The entire disclosure for short-term debt.

+ References+ Details

Long-Term Debt

12 Months Ended

Dec. 31, 2013

Debt Disclosure [Abstract]

Long-Term Debt

11. LONG-TERM DEBT

Great Plains Energy's and KCP&L's long-term debt is detailed in the following table.



		December 31
	Year Due	2013				2012
KCP&L			(millions)
General Mortgage Bonds
2.95% EIRR bonds^(a)	2015-2035		$	146.4			$	106.9
7.15% Series 2009A (8.59% rate)^(b)	2019		400.0				400.0
4.65% EIRR Series 2005	2035		50.0				50.0
5.375% Series 2007B			—				73.2
Senior Notes
5.85% Series (5.72% rate)^(b)	2017		250.0				250.0
6.375% Series (7.49% rate)^(b)	2018		350.0				350.0
3.15% Series	2023		300.0				—
6.05% Series (5.78% rate)^(b)	2035		250.0				250.0
5.30% Series	2041		400.0				400.0
EIRR Bonds
0.07% Series 2007A and 2007B^(c)	2035		146.5				—
2.875% Series 2008	2038		23.4				23.4
Other			—				2.6
Current maturities			—				(0.4		)
Unamortized discount			(4.1		)		(4.0		)
Total KCP&L excluding current maturities			2,312.2				1,901.7
Other Great Plains Energy
GMO First Mortgage Bonds 9.44% Series	2014-2021		9.0				10.1
GMO Pollution Control Bonds
0.113% Wamego Series 1996^(c)	2026		7.3				7.3
0.113% State Environmental 1993^(c)	2028		5.0				5.0
5.85% SJLP Pollution Control			—				5.6
GMO Senior Notes
8.27% Series	2021		80.9				80.9
3.49% Series A	2025		125.0				—
4.06% Series B	2033		75.0				—
4.74% Series C	2043		150.0				—
GMO Medium Term Notes
7.33% Series	2023		3.0				3.0
7.17% Series	2023		7.0				7.0
7.16% Series			—				6.0
Great Plains Energy Senior Notes
6.875% Series (7.33% rate)^(b)	2017		100.0				100.0
4.85% Series (7.34% rate)^(b)	2021		350.0				350.0
5.292% Series	2022		287.5				287.5
2.75% Series (3.67% rate)^(b)			—				250.0
Current maturities			(1.1		)		(262.7		)
Unamortized discount and premium, net			4.9				5.4
Total Great Plains Energy excluding current maturities			$	3,515.7			$	2,756.8


^(a)	Weighted-average interest rates at December 31, 2013


^(b)	Rate after amortizing gains/losses recognized in OCI on settlements of interest rate hedging instruments


^(c)	Variable rate

Amortization of Debt Expense

Great Plains Energy's and KCP&L's amortization of debt expense is detailed in the following table.



	2013		2012		2011
	(millions)
KCP&L	$	3.2	$	2.9	$	3.6
Other Great Plains Energy	2.5		2.6		4.5
Total Great Plains Energy	$	5.7	$	5.5	$	8.1

KCP&L General Mortgage Bonds

KCP&L has issued mortgage bonds under the General Mortgage Indenture and Deed of Trust dated December 1, 1986, as supplemented (Indenture). The Indenture creates a mortgage lien on substantially all of KCP&L's utility plant. Mortgage bonds totaling $596.4 million and $630.1 million were outstanding at December 31, 2013 and 2012, respectively.

KCP&L Municipal Bond Insurance Policies

KCP&L's secured and unsecured Series 2005 Environmental Improvement Revenue Refunding (EIRR) bonds totaling $35.9 million and $50.0 million, respectively, are covered by a municipal bond insurance policy between KCP&L and Syncora Guarantee, Inc. (Syncora). The insurance agreements between KCP&L and Syncora provide for reimbursement by KCP&L for any amounts that Syncora pays under the municipal bond insurance policies. The insurance agreements contain a covenant that the indebtedness to total capitalization ratio of KCP&L and its consolidated subsidiaries will not be greater than 0.68 to 1.00. At December 31, 2013, KCP&L was in compliance with this covenant. KCP&L is also restricted from issuing additional bonds under its General Mortgage Indenture if, after giving effect to such additional bonds, the proportion of secured debt to total indebtedness would be more than 75%, or more than 50% if the long term rating for such bonds by Standard & Poor's or Moody's Investors Service would be at or below A- or A3, respectively. The insurance agreement covering the unsecured Series 2005 EIRR bonds also required KCP&L to provide collateral to Syncora in the form of $50.0 million of Mortgage Bonds Series 2005 EIRR Insurer due 2035 for KCP&L's obligations under the insurance agreement as a result of KCP&L issuing general mortgage bonds in 2009 (other than refunding of outstanding general mortgage bonds) that resulted in the aggregate amount of outstanding general mortgage bonds exceeding 10% of total capitalization. The bonds are not incremental debt for KCP&L but collateralize Syncora's claim on KCP&L if Syncora was required to meet its obligation under the insurance agreement. In the event of a default under the insurance agreements, Syncora may take any available legal or equitable action against KCP&L, including seeking specific performance of the covenants.

KCP&L Senior Notes

In March 2013, KCP&L issued, at a discount, $300.0 million of 3.15% unsecured Senior Notes, maturing in 2023.

EIRR Bond Remarketing

In April 2013, KCP&L remarketed the following series of EIRR bonds:


•	secured Series 1992 EIRR bonds maturing in 2017 totaling $31.0 million at a fixed rate of 1.25% through maturity;


•	secured Series 1993B EIRR bonds totaling $39.5 million and previously held by KCP&L and 1993A EIRR bonds totaling $40.0 million maturing in 2023 at a fixed rate of 2.95% through maturity;


•	unsecured Series 2007A-1 and 2007A-2 EIRR bonds totaling $10.0 million and $63.3 million, respectively, maturing in 2035 and previously held by KCP&L into one series: Series 2007A totaling $73.3 million at a variable rate that will be determined weekly; and


•	unsecured Series 2007B EIRR bonds maturing in 2035 totaling $73.2 million at a variable rate that will be determined weekly.

In July 2013, KCP&L remarketed its unsecured Series 2008 EIRR bonds maturing in 2038 totaling $23.4 million at a fixed rate of 2.875% through July 1, 2018.

GMO First Mortgage Bonds

GMO has issued mortgage bonds under the General Mortgage Indenture and Deed of Trust dated April 1, 1946, as supplemented. The Indenture creates a mortgage lien on substantially all of GMO's St. Joseph Light & Power division utility plant. Mortgage bonds totaling $9.0 million and $10.1 million, respectively, were outstanding at December 31, 2013 and 2012.

GMO Pollution Control Bonds

In February 2013, GMO repaid its $5.6 million 5.85% SJLP Pollution Control bonds at maturity. In January 2014, GMO made an early repayment of its $7.3 million Wamego Series 1996 and $5.0 million State Environmental 1993 tax-exempt bonds.

GMO Senior Notes

In August 2013, GMO entered into a note purchase agreement and issued the following series of unsecured senior notes:


•	$125.0 million 3.49% Senior Notes, Series A, maturing in 2025;


•	$75.0 million 4.06% Senior Notes, Series B, maturing in 2033; and


•	$150.0 million 4.74% Senior Notes, Series C, maturing in 2043.

Under the terms of the note purchase agreement, GMO is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the agreement, not greater than 0.65 to 1.00 at all times. In addition, GMO's priority debt, as defined in the agreement, cannot exceed 15% of consolidated tangible net worth, as defined in the agreement. At December 31, 2013, GMO was in compliance with these covenants.

GMO Medium Term Notes

In November 2013, GMO repaid its $6.0 million 7.16% Medium Term Notes at maturity.

Great Plains Energy Senior Notes

In August 2013, Great Plains Energy repaid its $250.0 million 2.75% Senior Notes at maturity.

Scheduled Maturities

Great Plains Energy's and KCP&L's long-term debt maturities for the next five years are detailed in the following table.



	2014		2015		2016		2017		2018
	(millions)
Great Plains Energy	$	1.1	$	15.1	$	1.1	$	382.1	$	351.1
KCP&L	—		14.0		—		281.0		350.0

Common Shareholders' Equity	12 Months Ended
Common Shareholders' Equity	Dec. 31, 2013
Stockholders' Equity Note [Abstract]
Common Shareholders' Equity	13. COMMON SHAREHOLDERS' EQUITY Great Plains Energy has an effective shelf registration statement for the sale of unspecified amounts of securities with the Securities and Exchange Commission (SEC) that became effective in March 2012. Great Plains Energy has 6.0 million shares of common stock registered with the SEC for its Dividend Reinvestment and Direct Stock Purchase Plan. The plan allows for the purchase of common shares by reinvesting dividends or making optional cash payments. Great Plains Energy can issue new shares or purchase shares on the open market for the plan. At December 31, 2013, 1.4 million shares remained available for future issuances. Great Plains Energy has 14.3 million shares of common stock registered with the SEC for a defined contribution savings plan. Shares issued under the plan may be either newly issued shares or shares purchased in the open market. At December 31, 2013, 1.6 million shares remained available for future issuances. Treasury shares are held for future distribution upon issuance of shares in conjunction with the Company's Long-Term Incentive Plan. Great Plains Energy's articles of incorporation restrict the payment of common stock dividends in the event common equity is 25% or less of total capitalization. In addition, if preferred stock dividends are not declared and paid when scheduled, Great Plains Energy could not declare or pay common stock dividends or purchase any common shares. If the unpaid preferred stock dividends equal four or more full quarterly dividends, the preferred shareholders, voting as a single class, could elect the smallest number of directors necessary to constitute a majority of the full Board. Certain conditions in the MPSC and KCC orders authorizing the holding company structure require Great Plains Energy and KCP&L to maintain consolidated common equity of at least 30% and 35%, respectively, of total capitalization (including only the amount of short-term debt in excess of the amount of construction work in progress). Under the Federal Power Act, KCP&L and GMO generally can pay dividends only out of retained earnings. The revolving credit agreements of Great Plains Energy, KCP&L and GMO and the note purchase agreement for GMO's Series A, B and C Senior Notes contain a covenant requiring the respective company to maintain a consolidated indebtedness to consolidated total capitalization ratio of not more than 0.65 to 1.00. As of December 31, 2013, all of Great Plains Energy's and KCP&L's retained earnings and net income were free of restrictions. As a result of the above restrictions, Great Plains Energy's subsidiaries had restricted net assets of approximately $2.8 billion as of December 31, 2013. The restrictions are not expected to affect the Companies' ability to pay dividends at the current level in the foreseeable future.

The entire disclosure for shareholders' equity comprised of portions attributable to the parent entity and noncontrolling interest, including other comprehensive income. Includes, but is not limited to, balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings, accumulated balance for each classification of other comprehensive income and amount of comprehensive income.

Commitments and Contingencies Disclosure [Abstract]

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+ Details

Commitments and Contingencies

12 Months Ended

Dec. 31, 2013

15. COMMITMENTS AND CONTINGENCIES

Environmental Matters

Great Plains Energy and KCP&L are subject to extensive federal, state and local environmental laws, regulations and permit requirements relating to air and water quality, waste management and disposal, natural resources and health and safety. In addition to imposing continuing compliance obligations and remediation costs, these laws, regulations and permits authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. The cost of complying with current and future environmental requirements is expected to be material to Great Plains Energy and KCP&L. Failure to comply with environmental requirements or to timely recover environmental costs through rates could have a material effect on Great Plains Energy's and KCP&L's results of operations, financial position and cash flows.

Great Plains Energy's and KCP&L's current estimate of capital expenditures (exclusive of AFUDC and property taxes) to comply with current final environmental regulations where the timing is certain is approximately $700 million. The total cost of compliance with any existing, proposed or future laws and regulations may be significantly different from the cost estimate provided.

The current estimate of approximately $700 million of capital expenditures reflects costs to install environmental equipment at KCP&L's La Cygne Nos. 1 and 2 by June 2015 to comply with the Best Available Retrofit Technology (BART) rule and environmental upgrades at other coal-fired generating units through 2016 to comply with the Mercury and Air Toxics Standards (MATS) rule.

In September 2011, KCP&L commenced construction of the La Cygne projects and at December 31, 2013, had incurred approximately $377 million of cash capital expenditures, which is included in the approximate $700 million estimate above.

Great Plains Energy and KCP&L estimate that other capital projects at coal-fired generating units for compliance with the Clean Air Act and Clean Water Act based on proposed regulations or final regulations with implementation plans not yet finalized where the timing is uncertain could be approximately $600 million to $800 million for Great Plains Energy, which includes approximately $350 million to $450 million for KCP&L. These other projects are not included in the approximately $700 million estimated cost of compliance discussed above.

The Companies expect to seek recovery of the costs associated with environmental requirements through rate increases; however, there can be no assurance that such rate increases would be granted. The Companies may be subject to materially adverse rate treatment in response to competitive, economic, political, legislative or regulatory factors and/or public perception of the Companies' environmental reputation.

The following discussion groups environmental and certain associated matters into the broad categories of air and climate change, water, solid waste and remediation.

Clean Air Act and Climate Change Overview

The Clean Air Act and associated regulations enacted by the Environmental Protection Agency (EPA) form a comprehensive program to preserve and enhance air quality. States are required to establish regulations and programs to address all requirements of the Clean Air Act and have the flexibility to enact more stringent requirements. All of Great Plains Energy's and KCP&L's generating facilities, and certain of their other facilities, are subject to the Clean Air Act.

Clean Air Interstate Rule (CAIR) and Cross-State Air Pollution Rule (CSAPR)

The CAIR requires reductions in SO₂ and NO_x emissions in 28 states, including Missouri, accomplished through statewide caps. Great Plains Energy's and KCP&L's fossil fuel-fired plants located in Missouri are subject to CAIR, while their fossil fuel-fired plants in Kansas are not.

In July 2008, the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit Court) vacated CAIR in its entirety and remanded the matter to the EPA to promulgate a new rule consistent with its opinion. In December 2008, the court issued an order reinstating CAIR pending EPA's development of a replacement regulation on remand. In July 2011, the EPA finalized the CSAPR to replace the currently-effective CAIR. The CSAPR required states within its scope to reduce power plant SO₂and NO_xemissions that contribute to ozone and fine particle nonattainment in other states. In August 2012, the D.C. Circuit Court issued its opinion in which it vacated the CSAPR and remanded the rule to the EPA to revise in accordance with its opinion. The D.C. Circuit Court directed the EPA to continue to administer the CAIR until a valid replacement is promulgated.

Best Available Retrofit Technology (BART) Rule

The EPA BART rule directs state air quality agencies to identify whether visibility-reducing emissions from sources subject to BART are below limits set by the state or whether retrofit measures are needed to reduce emissions. BART applies to specific eligible facilities including KCP&L's La Cygne Nos. 1 and 2 in Kansas; KCP&L's Iatan No. 1, in which GMO has an 18% interest, and KCP&L's Montrose No. 3 in Missouri; GMO's Sibley Unit No. 3 and Lake Road Unit No. 6 in Missouri; and Westar Energy, Inc.'s (Westar) Jeffrey Unit Nos. 1 and 2 in Kansas, in which GMO has an 8% interest. Both Missouri and Kansas have approved BART plans.

KCP&L has a consent agreement with the Kansas Department of Health and Environment (KDHE) incorporating limits for stack particulate matter emissions, as well as limits for NO_x and SO₂ emissions, at its La Cygne Station that will be below the presumptive limits under BART. KCP&L further agreed to use its best efforts to install emission control technologies to reduce those emissions from the La Cygne Station prior to the required compliance date under BART, but in no event later than June 1, 2015. In August 2011, KCC issued its order on KCP&L's predetermination request that would apply to the recovery of costs for its 50% share of the environmental equipment required to comply with BART at the La Cygne Station. In the order, KCC stated that KCP&L's decision to retrofit La Cygne was reasonable, reliable, efficient and prudent and the $1.23 billion cost estimate is reasonable. If the cost for the project is at or below the $1.23 billion estimate, absent a showing of fraud or other intentional imprudence, KCC stated that it will not re-evaluate the prudency of the cost of the project. If the cost of the project exceeds the $1.23 billion estimate and KCP&L seeks to recover amounts exceeding the estimate, KCP&L will bear the burden of proving that any additional costs were prudently incurred. KCP&L's 50% share of the estimated cost is $615 million. KCP&L began the project in September 2011.

Mercury and Air Toxics Standards (MATS) Rule

In December 2011, the EPA finalized the MATS Rule that will reduce emissions of toxic air pollutants, also known as hazardous air pollutants, from new and existing coal- and oil-fired electric utility generating units with a capacity of greater than 25 MWs. The rule establishes numerical emission limits for mercury, particulate matter (a surrogate for non-mercury metals), and hydrochloric acid (a surrogate for acid gases). The rule establishes work practices, instead of numerical emission limits, for organic air toxics, including dioxin/furan. Compliance with the rule would need to be achieved by installing additional emission control equipment, changes in plant operation, purchasing additional power in the wholesale market or a combination of these and other alternatives. The rule allows three to four years for compliance.

Industrial Boiler Rule

In December 2012, the EPA issued a final rule that would reduce emissions of hazardous air pollutants from new and existing industrial boilers. The final rule establishes numeric emission limits for mercury, particulate matter (as a surrogate for non-mercury metals), hydrogen chloride (as a surrogate for acid gases) and carbon monoxide (as a surrogate for non-dioxin organic hazardous air pollutants). The final rule establishes emission limits for KCP&L's and GMO's existing units that produce steam other than for the generation of electricity. The final rule does not apply to KCP&L's and GMO's electricity generating boilers, but would apply to most of GMO's Lake Road boilers, which also serve steam customers, and to auxiliary boilers at other generating facilities. The rule allows three to four years for compliance.

New Source Review

The Clean Air Act's New Source Review program requires companies to obtain permits and, if necessary, install control equipment to reduce emissions when making a major modification or a change in operation if either is expected to cause a significant net increase in regulated emissions.

In 2010, Westar settled a lawsuit filed by the Department of Justice on behalf of the EPA and agreed to install a selective catalytic reduction (SCR) system at one of the three Jeffrey Energy Center units by the end of 2014. The Jeffrey Energy Center is 92% owned by Westar and operated exclusively by Westar. GMO has an 8% interest in the Jeffrey Energy Center and is generally responsible for its 8% share of the facility's operating costs and capital expenditures. Westar has estimated the cost of this SCR at approximately $240 million. Depending on the NO_x emission reductions attained by that SCR and attainable through the installation of other controls at the other two units, the settlement agreement may require the installation of a second SCR system on one of the other two units. Westar has informed the EPA that they believe that the terms of the settlement can be met through the installation of less expensive NO_xreduction equipment rather than a second SCR system and they plan to complete this project in 2014. GMO expects to seek recovery of its share of these costs through rate increases; however, there can be no assurance that such rate increases would be granted.

SO₂ NAAQS

In June 2010, the EPA strengthened the primary National Ambient Air Quality Standard (NAAQS) for SO₂ by establishing a new 1-hour standard at a level of 0.075 ppm and revoking the two existing primary standards of 0.140 ppm evaluated over 24 hours and 0.030 ppm evaluated over an entire year. In July 2013, the EPA designated a part of Jackson County, Missouri, which is in the Companies' service territory, as a nonattainment area for the new 1-hour SO₂ standard. The Missouri Department of Natural Resources (MDNR) will now develop and submit their plan to the EPA to return the area to attainment of the standard, which may include stricter controls on certain industrial facilities.

Particulate Matter (PM) NAAQS

In December 2012, the EPA strengthened the annual primary NAAQS for fine particulate matter (PM2.5). With the final rule, the EPA provided recent ambient air monitoring data for the Kansas City area indicating it would be in attainment of the revised fine particle standard. States will now make recommendations to designate areas as meeting the standards or not meeting them with the EPA making the final designation.

Climate Change

The Companies are subject to existing greenhouse gas reporting regulations and certain greenhouse gas permitting requirements. Management believes it is possible that additional federal or relevant state or local laws or regulations could be enacted to address global climate change. At the international level, while the United States is not a current party to the international Kyoto Protocol, it has agreed to undertake certain voluntary actions under the non-binding Copenhagen Accord and pursuant to subsequent international discussions relating to climate change, including the establishment of a goal to reduce greenhouse gas emissions. International agreements legally binding on the United States may be reached in the future. Such new laws or regulations could mandate new or increased requirements to control or reduce the emission of greenhouse gases, such as CO₂, which are created in the combustion of fossil fuels. The Companies' current generation capacity is primarily coal-fired and is estimated to produce about one ton of CO₂ per MWh, or approximately 25 million tons and 18 million tons per year for Great Plains Energy and KCP&L, respectively.

Legislation concerning the reduction of emissions of greenhouse gases, including CO₂, is being considered at the federal and state levels. The timing and effects of any such legislation cannot be determined at this time. In the absence of new Congressional mandates, the EPA is proceeding with the regulation of greenhouse gases under the existing Clean Air Act.

In June 2013, United States President Barack Obama announced a climate action plan and issued a presidential memorandum to address one element of the plan which is to reduce power plant carbon pollution. The memorandum directs the EPA to:

(1) issue a proposed and final rule addressing new units in a timely fashion;

(2) issue proposed carbon pollution standards, regulations or guidelines, as appropriate, for modified, reconstructed and existing power plants by no later than June 1, 2014;

(3) issue final standards, regulations or guidelines, as appropriate, for modified, reconstructed and existing power plants by no later than June 1, 2015;

(4) include in the guidelines addressing existing power plants a requirement that states submit to the EPA the implementation plans by no later than June 30, 2016; and

(5) engage with states, leaders in the power sector and other stakeholders on issues related to the rules.

In September 2013, the EPA proposed new source performance standards for emissions of CO₂ for new affected fossil-fuel-fired electric utility generating units. This action pursuant to the Clean Air Act would, for the first time, set national limits on the amount of CO₂ that power plants built in the future can emit. The proposal would not apply to Great Plains Energy's and KCP&L's existing units including modifications to those units.

Greenhouse gas legislation or regulation has the potential of having significant financial and operational impacts on Great Plains Energy and KCP&L, including the potential costs and impacts of achieving compliance with limits that may be established. However, the ultimate financial and operational consequences to Great Plains Energy and KCP&L cannot be determined until such legislation is passed and/or regulations are issued. Management will continue to monitor the progress of relevant legislation and regulations.

Laws have been passed in Missouri and Kansas, the states in which the Companies' retail electric businesses are operated, setting renewable energy standards, and management believes that national clean or renewable energy standards are also possible. While management believes additional requirements addressing these matters will possibly be enacted, the timing, provisions and impact of such requirements, including the cost to obtain and install new equipment to achieve compliance, cannot be reasonably estimated at this time.

A Kansas law enacted in May 2009 required Kansas public electric utilities, including KCP&L, to have renewable energy generation capacity equal to at least 10% of their three-year average Kansas peak retail demand by 2011 increasing to 15% by 2016 and 20% by 2020. A Missouri law enacted in November 2008 required at least 2% of the electricity provided by Missouri investor-owned utilities (including KCP&L and GMO) to their Missouri retail customers to come from renewable resources, including wind, solar, biomass and hydropower, by 2011, increasing to 5% in 2014, 10% in 2018, and 15% in 2021, with a small portion (estimated to be about 2 MW for each of KCP&L and GMO) required to come from solar resources.

KCP&L and GMO project that they will be compliant with the Missouri renewable requirements, exclusive of the solar requirement, through 2035. KCP&L and GMO project that the acquisition of solar renewable energy credits will be sufficient for compliance with the Missouri solar requirements for the foreseeable future. KCP&L also projects that it will be compliant with the Kansas renewable requirements through 2023.

Clean Water Act

The Clean Water Act and associated regulations enacted by the EPA form a comprehensive program to restore and preserve water quality. Like the Clean Air Act, states are required to establish regulations and programs to address all requirements of the Clean Water Act, and have the flexibility to enact more stringent requirements. All of Great Plains Energy's and KCP&L's generating facilities, and certain of their other facilities, are subject to the Clean Water Act.

In March 2011, the EPA proposed regulations pursuant to Section 316(b) of the Clean Water Act regarding cooling water intake structures pursuant to a court approved settlement. KCP&L generation facilities with cooling water intake structures would be subject to a limit on how many fish can be killed by being pinned against intake screens (impingement) and would be required to conduct studies to determine whether and what site-specific controls, if any, would be required to reduce the number of aquatic organisms drawn into cooling water systems (entrainment). The EPA agreed to finalize the rule by April 2014. Although the impact on Great Plains Energy's and KCP&L's operations will not be known until after the rule is finalized, it could have a significant effect on Great Plains Energy's and KCP&L's results of operations, financial position and cash flows.

KCP&L holds a permit from the MDNR covering water discharge from its Hawthorn Station. The permit authorizes KCP&L to, among other things, withdraw water from the Missouri River for cooling purposes and return the heated water to the Missouri River. KCP&L has applied for a renewal of this permit and the EPA has submitted an interim objection letter regarding the allowable amount of heat that can be contained in the returned water. Until this matter is resolved, KCP&L continues to operate under its current permit. KCP&L cannot predict the outcome of this matter; however, while less significant outcomes are possible, this matter may require KCP&L to reduce its generation at Hawthorn Station, install cooling towers or both, any of which could have a significant impact on KCP&L's results of operations, financial position and cash flows. The outcome could also affect the terms of water permit renewals at KCP&L's Iatan Station and at GMO's Sibley and Lake Road Stations.

In April 2013, the EPA proposed to revise the technology-based effluent limitations guidelines and standards regulation to make the existing controls on discharges from steam electric power plants more stringent. The proposal sets the first federal limits on the levels of toxic metals in wastewater that can be discharged from power plants. The new requirements for existing power plants would be phased in between 2017 and 2022. The EPA is under a consent decree to take final action on the proposed rule by May 2014.

The proposal includes a variety of options to reduce pollutants that are discharged into waterways from coal ash, air pollution control waste and other waste from steam electric power plants. Depending on the option, the proposed rule would establish new or additional requirements for wastewaters associated with the following processes and byproducts at certain KCP&L and GMO stations: flue gas desulfurization, fly ash, bottom ash, flue gas mercury control, combustion residual leachate from landfills and surface impoundments, and non-chemical metal cleaning wastes.

The EPA also announced its intention to align this proposal with a related rule for coal combustion residuals (CCRs) proposed in May 2010 under the Resource Conservation and Recovery Act (RCRA). The EPA is considering establishing best management practices requirements that would apply to surface impoundments containing CCRs. The cost of complying with the proposed rules has the potential of having a significant financial and operational impact on Great Plains Energy and KCP&L. However, the financial and operational consequences to Great Plains Energy and KCP&L cannot be determined until the final regulation is enacted.

Solid Waste

Solid and hazardous waste generation, storage, transportation, treatment and disposal are regulated at the federal and state levels under various laws and regulations. In May 2010, the EPA proposed to regulate CCRs under the RCRA to address the risks from the disposal of CCRs generated from the combustion of coal at electric generating facilities. The EPA is considering two options in this proposal. Under the first option, the EPA would regulate CCRs as special wastes under subtitle C of RCRA (hazardous), when they are destined for disposal in landfills or surface impoundments. Under the second option, the EPA would regulate disposal of CCRs under subtitle D of RCRA (non-hazardous). The Companies use coal in generating electricity and dispose of the CCRs in both on-site facilities and facilities owned by third parties. The cost of complying with the proposed CCR rule has the potential of having a significant financial and operational impact on Great Plains Energy and KCP&L. However, the financial and operational consequences to Great Plains Energy and KCP&L cannot be determined until an option is selected by the EPA and the final regulation is enacted.

Remediation

Certain federal and state laws, including the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), hold current and previous owners or operators of contaminated facilities and persons who arranged for the disposal or treatment of hazardous substances liable for the cost of investigation and cleanup. CERCLA and other laws also authorize the EPA and other agencies to issue orders compelling potentially responsible parties to clean up sites that are determined to present an actual or potential threat to human health or the environment. GMO is named as a potentially responsible party at a disposal site for polychlorinated biphenyl (PCB) contamination, and retains some environmental liability for several operations and investments it no longer owns. In addition, GMO also owns, or has acquired liabilities from companies that once owned or operated, former manufactured gas plant (MGP) sites, which are subject to the supervision of the EPA and various state environmental agencies.

At December 31, 2013 and 2012, KCP&L had $0.3 million accrued for environmental remediation expenses, which covers ground water monitoring at a former MGP site. The amount accrued was established on an undiscounted basis and KCP&L does not currently have an estimated time frame over which the accrued amount may be paid.

In addition to the $0.3 million accrual above, at December 31, 2013 and 2012, Great Plains Energy had $1.4 million and $2.0 million, respectively, accrued for the future investigation and remediation of certain additional GMO identified MGP sites and retained liabilities. This estimate was based upon review of the potential costs associated with conducting investigative and remedial actions at identified sites, as well as the likelihood of whether such actions will be necessary. This estimate could change materially after further investigation, and could also be affected by the actions of environmental agencies and the financial viability of other potentially responsible parties; however, given the uncertainty of these items the possible loss or range of loss in excess of the amount accrued is not estimable.

GMO has pursued recovery of remediation costs from insurance carriers and other potentially responsible parties. As a result of a settlement with an insurance carrier, approximately $1.3 million in insurance proceeds less an annual deductible is available to GMO to recover qualified MGP remediation expenses. GMO would seek recovery of additional remediation costs and expenses through rate increases; however, there can be no assurance that such rate increases would be granted.

Contractual Commitments

Great Plains Energy's and KCP&L's expenses related to lease commitments are detailed in the following table.



	2013		2012		2011
	(millions)
Great Plains Energy	$	18.5	$	21.8	$	20.9
KCP&L	16.0		17.7		17.0

Great Plains Energy's and KCP&L's contractual commitments at December 31, 2013, excluding pensions and long-term debt, are detailed in the following tables.



Great Plains Energy
	2014		2015		2016		2017		2018		After 2018			Total
Lease commitments	(millions)
Operating lease	$	15.3	$	13.6	$	10.0	$	9.7	$	9.7		$	138.6		$	196.9
Capital lease	0.4		0.4		0.4		0.4		0.4			4.4			6.4
Purchase commitments
Fuel	381.8		195.0		143.8		142.8		117.2			90.2			1,070.8
Power	46.4		46.4		46.4		44.8		47.3			604.1			835.4
Capacity	3.3		3.0		1.2		—		—			—			7.5
La Cygne environmental project	205.5		7.3		—		—		—			—			212.8
Non-regulated natural gas transportation	3.5		3.5		3.5		1.0		—			—			11.5
Other	56.2		36.8		27.5		8.1		3.9			46.6			179.1
Total contractual commitments	$	712.4	$	306.0	$	232.8	$	206.8	$	178.5		$	883.9		$	2,520.4



KCP&L
	2014		2015		2016		2017		2018		After 2018			Total
Lease commitments	(millions)
Operating lease	$	13.5	$	12.2	$	9.9	$	9.7	$	9.7		$	138.6		$	193.6
Capital lease	0.2		0.2		0.2		0.2		0.2			2.2			3.2
Purchase commitments
Fuel	294.3		148.4		113.2		117.4		90.8			90.2			854.3
Power	34.8		34.8		34.8		34.8		34.8			429.4			603.4
Capacity	2.9		3.0		1.2		—		—			—			7.1
La Cygne environmental project	205.5		7.3		—		—		—			—			212.8
Other	54.0		27.1		26.7		7.2		3.0			38.1			156.1
Total contractual commitments	$	605.2	$	233.0	$	186.0	$	169.3	$	138.5		$	698.5		$	2,030.5

Great Plains Energy's and KCP&L's lease commitments end in 2048. Operating lease commitments include rail cars to serve jointly-owned generating units where KCP&L is the managing partner. Of the amounts included in the table above, KCP&L will be reimbursed by the other owners for approximately $2.0 million per year from 2014 to 2015 and approximately $0.4 million per year from 2016 to 2025, for a total of $8.2 million.

Fuel commitments consist of commitments for nuclear fuel, coal and coal transportation. Power commitments consist of commitments for renewable energy under power purchase agreements. KCP&L and GMO purchase capacity from other utilities and nonutility suppliers. Purchasing capacity provides the option to purchase energy if needed or when market prices are favorable. KCP&L has capacity sales agreements not included above that total $5.5 million from 2014 to 2016 and $1.3 million per year for 2017 and 2018. La Cygne environmental project represents 100% of the contractual commitments related to environmental upgrades at KCP&L's La Cygne Station. KCP&L owns 50% of the La Cygne Station and expects to be reimbursed by the other owner for its 50% share of the costs. Non-regulated natural gas transportation consists of MPS Merchant's commitments. Other represents individual commitments entered into in the ordinary course of business.

The entire disclosure for commitments and contingencies.

+ References+ Details

Legal Proceedings	12 Months Ended
Legal Proceedings	Dec. 31, 2013
Legal Proceedings [Abstract]
Legal Proceedings [Text Block]	16. LEGAL PROCEEDINGS GMO Western Energy Crisis In response to complaints of manipulation of the California energy market, The Federal Energy Regulatory Commission (FERC) issued an order in July 2001 requiring net sellers of power in the California markets from October 2, 2000, through June 20, 2001, at prices above a FERC-determined competitive market clearing price, to make refunds to net purchasers of power in the California market during that time period. Because MPS Merchant was a net purchaser of power during the refund period, it has received approximately $8 million in refunds through settlements with certain sellers of power. MPS Merchant estimates that it is entitled to approximately $12 million in additional refunds under the standards FERC has used in this case. FERC has stated that interest will be applied to the refunds but the amount of interest has not yet been determined. In December 2001, various parties appealed the July 2001 FERC order to the United States Court of Appeals for the Ninth Circuit (Ninth Circuit) seeking review of a number of issues, including expansion of the refund period to include periods prior to October 2, 2000 (the Summer Period). MPS Merchant was a net seller of power during the Summer Period. On August 2, 2006, the Ninth Circuit issued an order finding, among other things, that FERC did not provide a sufficient justification for refusing to exercise its remedial authority under the Federal Power Act to determine whether market participants violated FERC-approved tariffs during the Summer Period. The court remanded the matter to FERC for further consideration. If FERC determines that MPS Merchant violated then-existing tariffs or laws during the Summer Period and that such violations affected market clearing prices in California, MPS Merchant could be found to owe refunds. Due to the uncertainties remaining in the case, the potential refund or range of potential refunds owed by MPS Merchant are not reasonably estimable.

Tabular disclosure of the loss contingencies that were reported in the period or disclosed as of the balance sheet date.

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+ Details

Guarantees

12 Months Ended

Dec. 31, 2013

Guarantees [Abstract]

Guarantees [Text Block]

17. GUARANTEES

In the ordinary course of business, Great Plains Energy and certain of its subsidiaries enter into various agreements providing financial or performance assurance to third parties on behalf of certain subsidiaries. Such agreements include, for example, guarantees and letters of credit. These agreements are entered into primarily to support or enhance the creditworthiness otherwise attributed to a subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish the subsidiary's intended business purposes. The majority of these agreements guarantee the Company's own future performance, so a liability for the fair value of the obligation is not recorded.

At December 31, 2013, Great Plains Energy has provided $140.6 million of credit support for GMO as follows:


•	Great Plains Energy direct guarantees to GMO counterparties totaling $40.7 million, which expire in 2014 and 2015 and


•	Great Plains Energy guarantee of GMO long-term debt totaling $99.9 million, which includes debt with maturity dates ranging from 2014-2023.

Great Plains Energy has also guaranteed GMO's commercial paper program. At December 31, 2013, GMO had $15.0 million of commercial paper outstanding.

Related Party Transactions and Relationships

12 Months Ended

Dec. 31, 2013

18. RELATED PARTY TRANSACTIONS AND RELATIONSHIPS

KCP&L employees manage GMO's business and operate its facilities at cost, including GMO's 18% ownership interest in KCP&L's Iatan Nos. 1 and 2. The operating expenses and capital costs billed from KCP&L to GMO were $223.6 million for 2013, $207.9 million for 2012 and $202.7 million for 2011. Additionally, KCP&L and GMO engage in wholesale electricity transactions with each other. KCP&L's net wholesale sales to GMO were $25.6 million, $29.4 million and $18.2 million in 2013, 2012 and 2011, respectively.

KCP&L and GMO are also authorized to participate in the Great Plains Energy money pool, an internal financing arrangement in which funds may be lent on a short-term basis to KCP&L and GMO from Great Plains Energy and between KCP&L and GMO. At December 31, 2013, KCP&L had a money pool payable to GMO of $0.2 million. At December 31, 2012, KCP&L had a money pool payable to Great Plains Energy of $3.8 million. The following table summarizes KCP&L's related party net receivables.



	December 31
	2013		2012
	(millions)
Net receivable from GMO	$	32.7	$	26.2
Net receivable from Great Plains Energy	17.5		13.8

Derivative Instruments and Hedging Activities Disclosure [Abstract]

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References+ Details

Derivative Instruments

12 Months Ended

Dec. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Text Block]

19. DERIVATIVE INSTRUMENTS

Great Plains Energy and KCP&L are exposed to a variety of market risks including interest rates and commodity prices. Management has established risk management policies and strategies to reduce the potentially adverse effects that the volatility of the markets may have on Great Plains Energy's and KCP&L's operating results. Great Plains Energy's and KCP&L's interest rate risk management activities have included using derivative instruments to hedge against future interest rate fluctuations on anticipated debt issuances. Commodity risk management activities, including the use of certain derivative instruments, are subject to the management, direction and control of an internal commodity risk committee. Management maintains commodity price risk management strategies that use derivative instruments to reduce the effects of fluctuations in fuel and purchased power expense caused by commodity price volatility.

Counterparties to commodity derivatives expose Great Plains Energy and KCP&L to credit loss in the event of nonperformance. This credit loss is limited to the cost of replacing these contracts at current market rates. Derivative instruments, excluding those instruments that qualify for the NPNS election, which are accounted for by accrual accounting, are recorded on the balance sheet at fair value as an asset or liability. Changes in the fair value of derivative instruments are recognized currently in net income unless specific hedge accounting criteria are met, except hedges for GMO's utility operations that are recorded to a regulatory asset or liability consistent with MPSC regulatory orders, as discussed below.

Great Plains Energy and KCP&L have posted collateral, in the ordinary course of business, for the aggregate fair value of all derivative instruments with credit risk-related contingent features that are in a liability position. At December 31, 2013, Great Plains Energy and KCP&L have posted collateral in excess of the aggregate fair value of their derivative instruments; therefore, if the credit risk-related contingent features underlying these agreements were triggered, Great Plains Energy and KCP&L would not be required to post additional collateral to their counterparties. For derivative contracts with counterparties under master netting arrangements, Great Plains Energy and KCP&L can net all receivables and payables with each respective counterparty.

Commodity Risk Management

KCP&L's risk management policy is to use derivative instruments, as needed, in order to mitigate its exposure to market price fluctuations on a portion of its projected natural gas purchases to meet generation requirements for retail and firm wholesale sales. KCP&L designates these natural gas hedges as cash flow hedges. The fair values of these instruments are recorded as derivative assets or liabilities with an offsetting entry to OCI for the effective portion of the hedge. To the extent the hedges are not effective, any ineffective portion of the change in fair market value would be recorded currently in fuel expense. At December 31, 2013, KCP&L had no hedges for its projected natural gas usage for retail load and firm MWh sales. KCP&L has not recorded any ineffectiveness on natural gas hedges in 2013, 2012 or 2011.

Additionally, KCP&L's risk management policy uses derivative instruments to mitigate exposure to market price fluctuations for wholesale power prices. KCP&L has designated these financial contracts as economic hedges (non-hedging derivatives). The fair values of these instruments are recorded as derivative assets or liabilities with an offsetting entry to the consolidated statements of income.

KCP&L and GMO have Transmission Congestion Rights (TCR) that were acquired in the initial auction for the SPP Integrated Marketplace during the fourth quarter of 2013. KCP&L and GMO will utilize the TCRs to hedge against congestion costs and protect load prices when the SPP Integrated Marketplace begins operations in March 2014. These financial contracts have been designated as economic hedges (non-hedging derivatives). The fair value of these instruments are recorded as derivative assets or liabilities with an offsetting entry to the consolidated statements of income. At December 31, 2013, there was no change in the fair value since the initial SPP Integrated Marketplace auction.

GMO's risk management policy is to use derivative instruments to mitigate price exposure to natural gas price volatility in the market. At December 31, 2013, GMO had financial contracts in place to hedge approximately 40% and 6% of the expected on-peak natural gas generation and natural gas equivalent purchased power price exposure for 2014 and 2015, respectively. The fair value of the portfolio will settle against actual purchases of natural gas and purchased power. GMO has designated its natural gas hedges as economic hedges (non-hedging derivatives). In connection with GMO's 2005 Missouri electric rate case, it was agreed that the settlement costs of these contracts would be recognized in fuel expense. The settlement cost is included in GMO's FAC. A regulatory asset or liability is recorded to reflect the change in the timing of recognition authorized by the MPSC. Recovery of actual costs will not impact earnings, but will impact cash flows due to the timing of the recovery mechanism.

MPS Merchant, which has certain long-term natural gas contracts remaining from its former non-regulated trading operations, manages the daily delivery of its remaining contractual commitments with economic hedges (non-hedging derivatives) to reduce its exposure to changes in market prices. Within the trading portfolio, MPS Merchant takes certain positions to hedge physical sale or purchase contracts. MPS Merchant records the fair value of physical trading energy contracts as derivative assets or liabilities with an offsetting entry to the consolidated statements of income.

The notional and recorded fair values of open positions for derivative instruments are summarized in the following table. The fair values of these derivatives are recorded on the consolidated balance sheets. The fair values below are gross values before netting agreements and netting of cash collateral.



	December 31
	2013					2012
	Notional Contract Amount		Fair Value			Notional Contract Amount		Fair Value
Great Plains Energy	(millions)
Futures contracts
Cash flow hedges	$	—	$	—		$	1.0	$	(0.2	)
Non-hedging derivatives	19.3		(0.6		)	17.9		(2.8		)
Forward contracts
Non-hedging derivatives	47.7		5.2			65.5		6.5
Transmission congestion rights
Non-hedging derivatives	22.9		1.7			—		—
Option contracts
Non-hedging derivatives	4.8		1.2			—		—
KCP&L
Futures contracts
Cash flow hedges	$	—	$	—		$	1.0	$	(0.2	)
Non-hedging derivatives	7.7		(0.2		)	—		—
Transmission congestion rights
Non-hedging derivatives	18.0		1.1			—		—

The fair values of Great Plains Energy's and KCP&L's open derivative positions are summarized in the following tables. The tables contain both derivative instruments designated as hedging instruments as well as non-hedging derivatives under GAAP. The fair values below are gross values before netting agreements and netting of cash collateral.

Great Plains Energy

Balance Sheet

Asset Derivatives

Liability Derivatives

December 31, 2013

Classification

Fair Value

Derivatives Not Designated as Hedging Instruments

(millions)

Commodity contracts

Other

8.5

1.0

December 31, 2012

Derivatives Designated as Hedging Instruments

Commodity contracts

Other

—

0.2

Derivatives Not Designated as Hedging Instruments

Commodity contracts

Other

6.5

2.8

Total Derivatives

6.5

3.0

KCP&L

Balance Sheet

Asset Derivatives

Liability Derivatives

December 31, 2013

Classification

Fair Value

Derivatives Not Designated as Hedging Instruments

(millions)

Commodity contracts

Other

1.2

0.3

December 31, 2012

Derivatives Designated as Hedging Instruments

Commodity contracts

Other

—

0.2

The following tables provide information regarding Great Plains Energy's and KCP&L's offsetting of derivative assets and liabilities.



Great Plains Energy
											Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts Recognized			Gross Amounts Offset in the Statement of Financial Position				Net Amounts Presented in the Statement of Financial Position			Financial Instruments			Cash Collateral Received			Net Amount
December 31, 2013	(millions)
Derivative assets		$	8.5		$	(0.7	)		$	7.8		$	—		$	—		$	7.8
Derivative liabilities		1.0			(0.9		)		0.1			—			—			0.1
December 31, 2012
Derivative assets		$	6.5		$	—			$	6.5		$	—		$	—		$	6.5
Derivative liabilities		3.0			(3.0		)		—			—			—			—



KCP&L
											Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts Recognized			Gross Amounts Offset in the Statement of Financial Position				Net Amounts Presented in the Statement of Financial Position			Financial Instruments			Cash Collateral Received			Net Amount
December 31, 2013	(millions)
Derivative assets		$	1.2		$	(0.1	)		$	1.1		$	—		$	—		$	1.1
Derivative liabilities		0.3			(0.3		)		—			—			—			—
December 31, 2012
Derivative liabilities		$	0.2		$	(0.2	)		$	—		$	—		$	—		$	—

The following tables summarize the amount of gain (loss) recognized in OCI or earnings for interest rate and commodity hedges.



Great Plains Energy
Derivatives in Cash Flow Hedging Relationship
					Gain (Loss) Reclassified from
					Accumulated OCI into Income
					(Effective Portion)
	Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)				Income Statement Classification	Amount
2013	(millions)					(millions)
Interest rate contracts		$	—		Interest charges	$	(18.6	)
Commodity contracts		—			Fuel	(0.3		)
Income tax benefit		—			Income tax benefit	7.3
Total		$	—		Total	$	(11.6	)
2012
Interest rate contracts		$	—		Interest charges	$	(20.2	)
Commodity contracts		(0.1		)	Fuel	(0.5		)
Income tax benefit		—			Income tax benefit	8.1
Total		$	(0.1	)	Total	$	(12.6	)



KCP&L
Derivatives in Cash Flow Hedging Relationship
					Gain (Loss) Reclassified from
					Accumulated OCI into Income
					(Effective Portion)
	Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)				Income Statement Classification	Amount
2013	(millions)					(millions)
Interest rate contracts		$	—		Interest charges	$	(8.8	)
Commodity contracts		—			Fuel	(0.3		)
Income tax benefit		—			Income tax benefit	3.5
Total		$	—		Total	$	(5.6	)
2012
Interest rate contracts		$	—		Interest charges	$	(8.7	)
Commodity contracts		(0.1		)	Fuel	(0.5		)
Income tax benefit		—			Income tax benefit	3.5
Total		$	(0.1	)	Total	$	(5.7	)

The following table summarizes the amount of loss recognized in a regulatory asset or earnings for GMO utility commodity hedges. GMO utility commodity derivatives fair value changes are recorded to either a regulatory asset or liability consistent with MPSC regulatory orders.



Great Plains Energy
Derivatives in Regulatory Account Relationship
					Gain (Loss) Reclassified from
					Regulatory Account
	Amount of Gain (Loss) Recognized in Regulatory Asset on Derivatives				Income Statement Classification	Amount
2013	(millions)					(millions)
Commodity contracts		$	2.0		Fuel	$	(1.9	)
Total		$	2.0		Total	$	(1.9	)
2012
Commodity contracts		$	(2.7	)	Fuel	$	(6.6	)
Total		$	(2.7	)	Total	$	(6.6	)

Great Plains Energy's income statement reflects the gain (loss) for the change in fair value of commodity contract derivatives not designated as hedging instruments of $(0.5) million for 2013 and $1.3 million for 2012. KCP&L's income statement reflects the gain for the change in fair value of commodity contract derivatives not designated as hedging instruments of $0.8 million for 2013.

The amounts recorded in accumulated OCI related to the cash flow hedges are summarized in the following table.



	Great Plains Energy								KCP&L
	December 31								December 31
	2013				2012				2013				2012
		(millions)
Current assets		$	9.9			$	10.6			$	9.9			$	10.6
Current liabilities		(48.9		)		(68.4		)		(43.1		)		(52.8		)
Noncurrent liabilities		—				(0.1		)		—				(0.1		)
Deferred income taxes		15.2				22.5				13.0				16.5
Total		$	(23.8	)		$	(35.4	)		$	(20.2	)		$	(25.8	)

Great Plains Energy's accumulated OCI in the table above at December 31, 2013, includes $17.1 million that is expected to be reclassified to expenses over the next twelve months. KCP&L's accumulated OCI in the table above at December 31, 2013, includes $8.7 million that is expected to be reclassified to expenses over the next twelve months.

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

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Fair Value Measurements

12 Months Ended

Dec. 31, 2013

Fair Value Disclosures [Abstract]

Fair Value Measurements

20. FAIR VALUE MEASUREMENTS

GAAP defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. GAAP establishes a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad categories, giving the highest priority to quoted prices in active markets for identical assets or liabilities and lowest priority to unobservable inputs. A definition of the various levels, as well as discussion of the various measurements within the levels, is as follows:

Level 1 – Unadjusted quoted prices for identical assets or liabilities in active markets that Great Plains Energy and KCP&L have access to at the measurement date.

Level 2 – Market-based inputs for assets or liabilities that are observable (either directly or indirectly) or inputs that are not observable but are corroborated by market data.

Level 3 – Unobservable inputs, reflecting Great Plains Energy's and KCP&L's own assumptions about the assumptions market participants would use in pricing the asset or liability.

Great Plains Energy and KCP&L record cash and cash equivalents and short-term borrowings on the balance sheet at cost, which approximates fair value due to the short-term nature of these instruments.

Great Plains Energy and KCP&L record long-term debt on the balance sheet at amortized cost. The fair value of long-term debt is measured as a Level 2 liability and is based on quoted market prices, with the incremental borrowing rate for similar debt used to determine fair value if quoted market prices are not available. At December 31, 2013, the book value and fair value of Great Plains Energy's long-term debt, including current maturities, were $3.5 billion and $3.7 billion, respectively. At December 31, 2012, the book value and fair value of Great Plains Energy's long-term debt, including current maturities, were $3.0 billion and $3.5 billion, respectively. At December 31, 2013, the book value and fair value of KCP&L's long-term debt, including current maturities, were $2.3 billion and $2.5 billion, respectively. At December 31, 2012, the book value and fair value of KCP&L's long-term debt, including current maturities, were $1.9 billion and $2.2 billion, respectively.

The following tables include Great Plains Energy's and KCP&L's balances of financial assets and liabilities measured at fair value on a recurring basis.



Description	December 31 2013				Netting^(e)				Level 1			Level 2				Level 3
KCP&L		(millions)
Assets
Nuclear decommissioning trust ^(a)
Equity securities		$	127.7			$	—			$	127.7		$	—			$	—
Debt securities
U.S. Treasury		21.2				—				21.2			—				—
U.S. Agency		2.8				—				—			2.8				—
State and local obligations		3.9				—				—			3.9				—
Corporate bonds		24.4				—				—			24.4				—
Foreign governments		0.5				—				—			0.5				—
Cash equivalents		3.8				—				3.8			—				—
Other		(0.4		)		—				—			(0.4		)		—
Total nuclear decommissioning trust		183.9				—				152.7			31.2				—
Self-insured health plan trust ^(b)
Equity securities		0.9				—				0.9			—				—
Debt securities		9.3				—				0.5			8.8				—
Cash and cash equivalents		3.4				—				3.4			—				—
Other		1.2				—				—			1.2				—
Total self-insured health plan trust		14.8				—				4.8			10.0				—
Derivative instruments ^(c)		1.1				(0.1		)		0.1			—				1.1
Total		199.8				(0.1		)		157.6			41.2				1.1
Liabilities
Derivative instruments ^(c)		—				(0.3		)		0.3			—				—
Total		$	—			$	(0.3	)		$	0.3		$	—			$	—
Other Great Plains Energy
Assets
Derivative instruments ^(c)		$	6.7			$	(0.6	)		$	0.2		$	4.9			$	2.2
SERP rabbi trusts ^(d)
Equity securities		0.1				—				0.1			—				—
Fixed income funds		18.6				—				—			18.6				—
Total SERP rabbi trusts		18.7				—				0.1			18.6				—
Total		25.4				(0.6		)		0.3			23.5				2.2
Liabilities
Derivative instruments ^(c)		0.1				(0.6		)		0.6			0.1				—
Total		$	0.1			$	(0.6	)		$	0.6		$	0.1			$	—
Great Plains Energy
Assets
Nuclear decommissioning trust ^(a)		$	183.9			$	—			$	152.7		$	31.2			$	—
Self-insured health plan trust ^(b)		14.8				—				4.8			10.0				—
Derivative instruments ^(c)		7.8				(0.7		)		0.3			4.9				3.3
SERP rabbi trusts ^(d)		18.7				—				0.1			18.6				—
Total		225.2				(0.7		)		157.9			64.7				3.3
Liabilities
Derivative instruments ^(c)		0.1				(0.9		)		0.9			0.1				—
Total		$	0.1			$	(0.9	)		$	0.9		$	0.1			$	—



Description	December 31 2012			Netting^(e)				Level 1			Level 2			Level 3
KCP&L		(millions)
Assets
Nuclear decommissioning trust ^(a)
Equity securities		$	100.1		$	—			$	100.1		$	—		$	—
Debt securities
U.S. Treasury		18.5			—				18.5			—			—
U.S. Agency		2.8			—				—			2.8			—
State and local obligations		3.3			—				—			3.3			—
Corporate bonds		26.8			—				—			26.8			—
Other		0.3			—				—			0.3			—
Total nuclear decommissioning trust		151.8			—				118.6			33.2			—
Total		151.8			—				118.6			33.2			—
Liabilities
Derivative instruments ^(c)		—			(0.2		)		0.2			—			—
Total		$	—		$	(0.2	)		$	0.2		$	—		$	—
Other Great Plains Energy
Assets
Derivative instruments ^(c)		$	6.5		$	—			$	—		$	4.2		$	2.3
SERP rabbi trusts ^(d)
Equity securities		0.1			—				0.1			—			—
Fixed income funds		20.2			—				—			20.2			—
Total SERP rabbi trusts		20.3			—				0.1			20.2			—
Total		26.8			—				0.1			24.4			2.3
Liabilities
Derivative instruments ^(c)		—			(2.8		)		2.8			—			—
Total		$	—		$	(2.8	)		$	2.8		$	—		$	—
Great Plains Energy
Assets
Nuclear decommissioning trust ^(a)		$	151.8		$	—			$	118.6		$	33.2		$	—
Derivative instruments ^(c)		6.5			—				—			4.2			2.3
SERP rabbi trusts ^(d)		20.3			—				0.1			20.2			—
Total		178.6			—				118.7			57.6			2.3
Liabilities
Derivative instruments ^(c)		—			(3.0		)		3.0			—			—
Total		$	—		$	(3.0	)		$	3.0		$	—		$	—


^(a)	Fair value is based on quoted market prices of the investments held by the fund and/or valuation models. The total does not include $2.9 million of cash and cash equivalents at December 31, 2012.


^(b)	Fair value is based on quoted market prices of the investments held by the trust. Debt securities classified as Level 1 are comprised of U.S. Treasury securities. Debt securities classified as Level 2 are comprised of corporate bonds, U.S. Agency, state and local obligations, and other asset-backed securities.

^(c)

The fair value of derivative instruments is estimated using market quotes, over-the-counter forward price and volatility curves and correlations among fuel prices, net of estimated credit risk. Derivative instruments classified as Level 1 represent exchange traded derivative instruments. Derivative instruments classified as Level 2 represent non-exchange traded derivative instruments traded in over-the-counter markets. Derivative instruments classified as Level 3 represent non-exchange traded derivatives traded in over-the-counter markets for which observable market data is not available to corroborate the valuation inputs and TCRs valued at the most recent auction price in the SPP Integrated Marketplace.


^(d)	Fair value is based on quoted market prices and/or valuation models for equity securities and NAV per share for fixed income funds.


^(e)	Represents the difference between derivative contracts in an asset or liability position presented on a net basis by counterparty on the consolidated balance sheets where a master netting agreement exists between the Company and the counterparty. At December 31, 2013 and 2012, Great Plains Energy netted $0.2 million and $3.0 million, respectively, of cash collateral posted with counterparties.

The following table reconciles the beginning and ending balances for all Level 3 assets measured at fair value on a recurring basis.



Great Plains Energy
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative Instruments
	2013			2012
	(millions)
Balance at January 1	$	2.3		$	3.1
Total realized/unrealized gains included in non-operating income	9.5			8.2
Purchases	1.7			—
Settlements	(10.2		)	(9.0		)
Balance at December 31	$	3.3		$	2.3
Total unrealized losses included in non-operating income relating to assets still on the
consolidated balance sheet at December 31	$	(0.3	)	$	(0.4	)



KCP&L
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative
	Instruments
	2013
	(millions)
Balance at January 1	$	—
Purchases	1.1
Balance at December 31	$	1.1

Accumulated Other Comprehensive Income (Loss) [Abstract]

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References+ Details

Accumulated Other Comprehensive Income (Loss)

12 Months Ended

Dec. 31, 2013

Accumulated Other Comprehensive Income (Loss) [Text Block]

21. ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

The following tables reflect the change in the balances of each component of accumulated other comprehensive loss for Great Plains Energy and KCP&L.



Great Plains Energy
	Gains and Losses on Cash Flow Hedges^(a)				Defined Benefit Pension Items^(a)				Total^(a)
	(millions)
Beginning balance January 1, 2013		$	(35.4	)		$	(3.0	)	$	(38.4	)
Other comprehensive income before reclassifications		—				1.2			1.2
Amounts reclassified from accumulated other comprehensive loss		11.6				0.3			11.9
Net current period other comprehensive income		11.6				1.5			13.1
Ending balance December 31, 2013		$	(23.8	)		$	(1.5	)	$	(25.3	)

^(a) Net of tax



KCP&L
	Gains and Losses on Cash Flow Hedges^(a)
	(millions)
Beginning balance January 1, 2013		$	(25.8	)
Amounts reclassified from accumulated other comprehensive loss		5.6
Net current period other comprehensive income		5.6
Ending balance December 31, 2013		$	(20.2	)

^(a) Net of tax

The following tables reflect the effect on certain line items of net income from amounts reclassified out of each component of accumulated other comprehensive loss for Great Plains Energy and KCP&L.



Great Plains Energy
Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified from Accumulated Other Comprehensive Loss				Affected Line Item in the Income Statement
2013	(millions)
Gains and (losses) on cash flow hedges (effective portion)
Interest rate contracts		$	(18.6	)	Interest charges
Commodity contracts		(0.3		)	Fuel
		(18.9		)	Income before income tax expense and loss from equity investments
		7.3			Income tax benefit
		$	(11.6	)	Net income
Amortization of defined benefit pension items
Net losses included in net periodic benefit costs		$	(0.5	)	Utility operating and maintenance expenses
		(0.5		)	Income before income tax expense and loss from equity investments
		0.2			Income tax benefit
		(0.3		)	Net income

Total reclassifications, net of tax		$	(11.9	)	Net income



KCP&L
Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified from Accumulated Other Comprehensive Loss				Affected Line Item in the Income Statement
2013	(millions)
Gains and (losses) on cash flow hedges (effective portion)
Interest rate contracts		$	(8.8	)	Interest charges
Commodity contracts		(0.3		)	Fuel
		(9.1		)	Income before income tax expense
		3.5			Income tax benefit
Total reclassifications, net of tax		$	(5.6	)	Net income

The entire disclosure for comprehensive income, which includes, but is not limited to, 1) the amount of income tax expense or benefit allocated to each component of other comprehensive income, including reclassification adjustments, 2) the reclassification adjustments for each classification of other comprehensive income and 3) the ending accumulated balances for each component of comprehensive income.

Income Tax Disclosure [Text Block]

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+ Details

Taxes

12 Months Ended

Dec. 31, 2013

Income Tax Disclosure [Abstract]

22. TAXES

Components of income tax expense are detailed in the following tables.



Great Plains Energy	2013			2012			2011
Current income taxes	(millions)
Federal	$	0.3		$	(3.2	)	$	2.9
State	(3.0		)	(6.3		)	(6.0		)
Foreign	—			—			(0.4		)
Total	(2.7		)	(9.5		)	(3.5		)
Deferred income taxes
Federal	109.1			96.3			90.5
State	24.9			24.9			20.7
Total	134.0			121.2			111.2
Noncurrent income taxes
Federal	—			(0.2		)	(18.0		)
State	(0.3		)	(0.3		)	(2.1		)
Foreign	(0.4		)	(4.2		)	(0.6		)
Total	(0.7		)	(4.7		)	(20.7		)
Investment tax credit
Deferral	0.3			—			—
Amortization	(1.7		)	(2.4		)	(2.2		)
Total	(1.4		)	(2.4		)	(2.2		)
Income tax expense	$	129.2		$	104.6		$	84.8



KCP&L	2013			2012			2011
Current income taxes	(millions)
Federal	$	(0.5	)	$	13.1		$	1.0
State	(0.5		)	2.0			(0.6		)
Total	(1.0		)	15.1			0.4
Deferred income taxes
Federal	75.8			48.8			66.0
State	16.3			11.4			14.6
Total	92.1			60.2			80.6
Noncurrent income taxes
Federal	(9.0		)	1.7			(9.3		)
State	(1.5		)	0.1			(1.1		)
Total	(10.5		)	1.8			(10.4		)
Investment tax credit
Deferral	0.3			—			—
Amortization	(1.1		)	(1.8		)	(1.5		)
Total	(0.8		)	(1.8		)	(1.5		)
Income tax expense	$	79.8		$	75.3		$	69.1

Effective Income Tax Rates

Effective income tax rates reflected in the financial statements and the reasons for their differences from the statutory federal rates are detailed in the following tables.



Great Plains Energy	2013		2012		2011
Federal statutory income tax rate	35.0	%	35.0	%	35.0	%
Differences between book and tax depreciation not normalized	(0.3	)	1.2		1.5
Amortization of investment tax credits	(0.4	)	(0.8	)	(0.8	)
Federal income tax credits	(3.5	)	(3.1	)	(5.0	)
State income taxes	3.8		4.0		4.0
Changes in uncertain tax positions, net	(0.2	)	(1.5	)	(1.7	)
Valuation allowance	—		—		(0.8	)
Other	(0.4	)	(0.5	)	0.5
Effective income tax rate	34.0	%	34.3	%	32.7	%



KCP&L	2013		2012		2011
Federal statutory income tax rate	35.0	%	35.0	%	35.0	%
Differences between book and tax depreciation not normalized	(0.8	)	1.3		1.6
Amortization of investment tax credits	(0.4	)	(0.8	)	(0.7	)
Federal income tax credits	(5.3	)	(4.3	)	(6.3	)
State income taxes	3.7		4.1		3.9
Changes in uncertain tax positions, net	—		—		0.1
Other	(0.1	)	(0.6	)	0.2
Effective income tax rate	32.1	%	34.7	%	33.8	%

Deferred Income Taxes

The tax effects of major temporary differences resulting in deferred income tax assets (liabilities) in the consolidated balance sheets are in the following tables.



	Great Plains Energy						KCP&L
December 31	2013			2012			2013			2012
Current deferred income tax asset (liability)	(millions)
Net operating loss carryforward	$	76.6		$	77.8		$	—		$	—
Other	5.7			12.7			(1.7		)	4.6
Net current deferred income tax asset (liability) before valuation allowance	82.3			90.5			(1.7		)	4.6
Valuation allowance	(2.0		)	(2.0		)	—			—
Net current deferred income tax asset (liability)	80.3			88.5			(1.7		)	4.6
Noncurrent deferred income taxes
Plant related	(1,433.8		)	(1,297.2		)	(1,022.9		)	(930.7		)
Income taxes on future regulatory recoveries	(136.4		)	(138.3		)	(111.0		)	(114.7		)
Derivative instruments	32.3			37.7			23.4			27.4
Pension and post-retirement benefits	(28.2		)	(26.6		)	(1.7		)	(3.4		)
SO₂emission allowance sales	28.8			29.7			28.8			30.4
Tax credit carryforwards	229.3			217.5			139.6			126.3
Customer demand programs	(27.7		)	(28.7		)	(19.4		)	(19.2		)
Net operating loss carryforward	446.7			439.4			71.6			72.4
Other	(57.1		)	(44.1		)	(30.5		)	(24.9		)
Net noncurrent deferred income tax liability before valuation allowance	(946.1		)	(810.6		)	(922.1		)	(836.4		)
Valuation allowance	(18.7		)	(21.8		)	—			—
Net noncurrent deferred income tax liability	(964.8		)	(832.4		)	(922.1		)	(836.4		)
Net deferred income tax liability	$	(884.5	)	$	(743.9	)	$	(923.8	)	$	(831.8	)



	Great Plains Energy						KCP&L
December 31	2013			2012			2013			2012
	(millions)
Gross deferred income tax assets	$	1,148.2		$	1,209.8		$	583.0		$	656.9
Gross deferred income tax liabilities	(2,032.7		)	(1,953.7		)	(1,506.8		)	(1,488.7		)
Net deferred income tax liability	$	(884.5	)	$	(743.9	)	$	(923.8	)	$	(831.8	)

Tax Credit Carryforwards

At December 31, 2013 and 2012, Great Plains Energy had $141.1 million and $127.6 million, respectively, of federal general business income tax credit carryforwards. At December 31, 2013 and 2012, KCP&L had $139.6 million and $126.3 million, respectively, of federal general business income tax credit carryforwards. The carryforwards for both Great Plains Energy and KCP&L relate primarily to Advanced Coal Investment Tax Credits and Wind Production tax credits and expire in the years 2028 to 2033. Approximately $0.5 million of Great Plains Energy's credits are related to Low Income Housing credits that were acquired in the GMO acquisition. Due to federal limitations on the utilization of income tax attributes acquired in the GMO acquisition, management expects a portion of these credits to expire unutilized and has provided a valuation allowance against $0.4 million of the federal income tax benefit.

At December 31, 2013 and 2012, Great Plains Energy had $87.9 million of federal alternative minimum tax credit carryforwards. Of these amounts, $87.6 million, at December 31, 2013 and 2012, were acquired in the GMO acquisition. These credits do not expire and can be used to reduce taxes paid in the future.

At December 31, 2013 and 2012, Great Plains Energy had $0.3 million and $2.0 million, respectively, of state income tax credit carryforwards. The state income tax credits relate primarily to the Company's Missouri affordable housing investment portfolio, and the carryforwards expire in the years 2014 to 2016.

Net Operating Loss Carryforwards

At December 31, 2013 and 2012, Great Plains Energy had $459.9 million and $451.1 million, respectively, of tax benefits related to federal net operating loss (NOL) carryforwards. Approximately $304.6 million and $304.8 million, at December 31, 2013 and 2012, respectively, are tax benefits related to NOLs that were acquired in the GMO acquisition. The tax benefits for NOLs originating in 2003 are $21.5 million, $152.4 million originating in 2004, $74.1 million originating in 2005, $53.3 million originating in 2006, $1.3 million originating in 2007, $2.4 million originating in 2008, $28.8 million originating in 2009, $14.0 million originating in 2010 and $109.5 million originating in 2011, and $2.6 million originating in 2012. The federal NOL carryforwards expire in years 2023 to 2032.

In addition, Great Plains Energy also had deferred tax benefits of $63.4 million and $66.1 million related to state NOLs as of December 31, 2013 and 2012, respectively. Of these amounts, approximately $44.4 million and $47.9 million at December 31, 2013 and 2012, respectively, were acquired in the GMO acquisition. Management does not expect to utilize $20.3 million of NOLs in state tax jurisdictions where the Company does not expect to operate in the future. Therefore, a valuation allowance has been provided against $20.3 million of state tax benefits.

Valuation Allowances

Great Plains Energy is required to assess the ultimate realization of deferred tax assets using a “more likely than not” assessment threshold. This assessment takes into consideration tax planning strategies within Great Plains Energy's control. As a result of this assessment, Great Plains Energy has established a partial valuation allowance for state tax NOL carryforwards, and tax credit carryforwards. During 2013, $3.1 million of tax benefit was recorded in continuing operations primarily related to state NOL carryforwards offset by an increase in deferred tax expense since a portion of state NOLs expired at December 31, 2013. There was no change to the total valuation allowance in 2012.

Uncertain Tax Positions

At December 31, 2013 and 2012, Great Plains Energy had $9.8 million and $21.4 million, respectively, of liabilities related to unrecognized tax benefits. Of these amounts, $6.5 million and $7.3 million at December 31, 2013 and 2012, respectively, are expected to impact the effective tax rate if recognized. The $11.6 million decrease in unrecognized tax benefits is primarily due to a change in certain income tax accounting methods for the capitalization of assets at KCP&L. This reduction in unrecognized tax benefits is offset by an increase to deferred income tax liabilities since the unrecognized tax benefits were related to temporary tax differences.

At December 31, 2011, Great Plains Energy had $24.0 million of liabilities related to unrecognized tax benefits of which $11.8 million was expected to impact the effective tax rate if recognized. The $2.6 million decrease in unrecognized tax benefits in 2012 is primarily due to a decrease of $4.5 million of unrecognized tax benefits related to former GMO non-regulated operations.

At December 31, 2013 and 2012, KCP&L had none and $10.5 million, respectively, of liabilities related to unrecognized tax benefits. None of these amounts were expected to impact the effective tax rate if recognized. The $10.5 million decrease in unrecognized tax benefits is primarily due to a change in certain income tax accounting methods for the capitalization of assets at KCP&L. This reduction in unrecognized tax benefits is offset by an increase to deferred income tax liabilities since the unrecognized tax benefits were related to temporary tax differences.

At December 31, 2011, KCP&L had $8.7 million of liabilities related to unrecognized tax benefits of which $0.2 million was expected to impact the effective rate if recognized. The $1.8 million increase in unrecognized tax benefits in 2012 was primarily due to an increase of $3.6 million related to temporary tax differences for the current tax year.

The following table reflects activity for Great Plains Energy and KCP&L related to the liability for unrecognized tax benefits.



	Great Plains Energy									KCP&L
	2013			2012			2011			2013			2012			2011
	(millions)
Beginning balance January 1	$	21.4		$	24.0		$	42.0		$	10.5		$	8.7		$	19.1
Additions for current year tax positions	—			3.7			1.4			—			3.6			—
Reductions for current year tax positions	(0.3		)	—			—			—			—			—
Additions for prior year tax positions	—			—			2.4			—			—			2.3
Reductions for prior year tax positions	(10.5		)	(1.8		)	(20.9		)	(10.5		)	(1.6		)	(12.6		)
Statute expirations	(0.3		)	(4.7		)	(0.7		)	—			(0.2		)	(0.1		)
Foreign currency translation adjustments	(0.5		)	0.2			(0.2		)	—			—			—
Ending balance December 31	$	9.8		$	21.4		$	24.0		$	—		$	10.5		$	8.7

Great Plains Energy and KCP&L recognize interest related to unrecognized tax benefits in interest expense and penalties in non-operating expenses. At December 31, 2013, 2012 and 2011, amounts accrued for interest related to unrecognized tax benefits for Great Plains Energy were $3.2 million, $3.5 million and $5.7 million, respectively. At December 31, 2013, 2012 and 2011, amounts accrued for penalties with respect to unrecognized tax benefits for Great Plains Energy were $0.6 million, $0.7 million and $1.1 million, respectively. In 2013, 2012 and 2011, Great Plains Energy recognized a decrease of $0.1 million, $2.3 million and $0.9 million, respectively, of interest expense related to unrecognized tax benefits.

At December 31, 2013, 2012 and 2011, amounts accrued for interest related to unrecognized tax benefits for KCP&L were none, $0.1 million and $0.2 million, respectively. At December 31, 2013, 2012 and 2011, amounts accrued for penalties with respect to unrecognized tax benefits for KCP&L were insignificant. In 2013, 2012 and 2011, KCP&L recognized a decrease of $0.1 million, $0.1 million and $1.2 million, respectively, of interest expense related to unrecognized tax benefits.

The IRS is currently auditing Great Plains Energy and its subsidiaries for the 2009 tax year. The Company estimates that it is reasonably possible that $6.9 million of other unrecognized tax benefits for Great Plains Energy may be recognized in the next twelve months due to statute expirations or settlement agreements with tax authorities.

Tangible Property Regulations

In September 2013, the IRS released final regulations regarding amounts paid to acquire, produce or improve tangible property. In addition, proposed regulations were issued regarding the treatment of retirements of depreciable property and general asset accounts. The final regulations are effective for tax years beginning on or after January 1, 2014, for all taxpayers that acquire, produce or improve tangible property. The new regulations have not had a significant impact on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.

Segments and Related Information

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

+ References+ Details

Segments and Related Information

12 Months Ended

Dec. 31, 2013

Segment Reporting [Abstract]

23. SEGMENTS AND RELATED INFORMATION

Great Plains Energy has one reportable segment based on its method of internal reporting, which segregates reportable segments based on products and services, management responsibility and regulation. The one reportable business segment is electric utility, consisting of KCP&L, GMO's regulated utility operations and GMO Receivables Company. Other includes GMO activity other than its regulated utility operations, GPETHC and unallocated corporate charges. The summary of significant accounting policies applies to the reportable segment. Segment performance is evaluated based on net income attributable to Great Plains Energy.

The following tables reflect summarized financial information concerning Great Plains Energy's reportable segment.



2013	Electric Utility				Other				Eliminations			Great Plains Energy
		(millions)
Operating revenues		$	2,446.3			$	—			$	—		$	2,446.3
Depreciation and amortization		(289.7		)		—				—			(289.7		)
Interest charges		(190.5		)		(55.5		)		47.6			(198.4		)
Income tax (expense) benefit		(135.4		)		6.2				—			(129.2		)
Net income (loss) attributable to Great Plains Energy		257.1				(6.9		)		—			250.2



2012	Electric Utility				Other				Eliminations			Great Plains Energy
		(millions)
Operating revenues		$	2,309.9			$	—			$	—		$	2,309.9
Depreciation and amortization		(272.3		)		—				—			(272.3		)
Interest charges		(197.3		)		(67.3		)		43.8			(220.8		)
Income tax (expense) benefit		(122.0		)		17.4				—			(104.6		)
Net income (loss) attributable to Great Plains Energy		216.6				(16.7		)		—			199.9



2011	Electric Utility				Other				Eliminations			Great Plains Energy
		(millions)
Operating revenues		$	2,318.0			$	—			$	—		$	2,318.0
Depreciation and amortization		(273.1		)		—				—			(273.1		)
Interest charges		(176.9		)		(67.2		)		25.7			(218.4		)
Income tax (expense) benefit		(109.3		)		24.5				—			(84.8		)
Net income (loss) attributable to Great Plains Energy		199.9				(25.5		)		—			174.4



	Electric Utility			Other			Eliminations				Great Plains Energy
2013		(millions)
Assets		$	10,019.6		$	105.6		$	(329.8	)		$	9,795.4
Capital expenditures		669.0			—			—				669.0
2012
Assets		$	9,910.6		$	122.4		$	(385.7	)		$	9,647.3
Capital expenditures		610.2			—			—				610.2
2011
Assets		$	9,483.4		$	51.9		$	(417.3	)		$	9,118.0
Capital expenditures		456.6			—			—				456.6

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

Jointly Owned Electric Utility Plants [Abstract]

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+ Details

Jointly Owned Electric Utility Plants

12 Months Ended

Dec. 31, 2013

Jointly Owned Electric Utility Plants [Text Block]

24. JOINTLY-OWNED ELECTRIC UTILITY PLANTS

Great Plains Energy's and KCP&L's share of jointly-owned electric utility plants at December 31, 2013, are detailed in the following tables.



Great Plains Energy
	Wolf Creek Unit			La Cygne Units			Iatan No. 1 Unit			Iatan No. 2 Unit			Iatan Common			Jeffrey Energy Center
	(millions, except MW amounts)
Great Plains Energy's share		47%			50%			88%			73%			79%			8%

Utility plant in service		$	1,550.8		$	542.6		$	645.3		$	1,298.0		$	428.9		$	165.7
Accumulated depreciation		813.6			314.4			245.7			319.4			87.3			75.4
Nuclear fuel, net		62.8			—			—			—			—			—
Construction work in progress		146.4			390.3			8.1			14.9			24.4			13.8
2014 accredited capacity-MWs		547			709			627			641			NA			172



KCP&L
	Wolf Creek Unit			La Cygne Units			Iatan No. 1 Unit			Iatan No. 2 Unit			Iatan Common
	(millions, except MW amounts)
KCP&L's share		47%			50%			70%			55%			61%

Utility plant in service		$	1,550.8		$	542.6		$	515.4		$	987.2		$	347.3
Accumulated depreciation		813.6			314.4			196.8			297.5			79.3
Nuclear fuel, net		62.8			—			—			—			—
Construction work in progress		146.4			390.3			1.8			11.0			3.5
2014 accredited capacity-MWs		547			709			499			482			NA

Each owner must fund its own portion of the plant's operating expenses and capital expenditures. KCP&L's and GMO's share of direct expenses are included in the appropriate operating expense classifications in Great Plains Energy's and KCP&L's financial statements.

Quarterly Operating Results (Unaudited)

12 Months Ended

Dec. 31, 2013

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Information [Text Block]

25. QUARTERLY OPERATING RESULTS (UNAUDITED)



	Quarter
Great Plains Energy	1st			2nd		3rd		4th
2013	(millions, except per share amounts)
Operating revenue	$	542.2		$	600.3	$	765.0	$	538.8
Operating income	86.1			143.6		271.7		67.8
Net income	26.0			63.6		143.1		17.5
Basic and diluted earnings per common share	0.17			0.41		0.93		0.11
2012
Operating revenue	$	479.7		$	603.6	$	746.2	$	480.4
Operating income	49.0			150.0		277.0		62.9
Net income (loss)	(9.3		)	58.1		146.4		4.7
Net income (loss) attributable to Great Plains Energy	(9.1		)	58.1		146.2		4.7
Basic and diluted earnings (loss) per common share	(0.07		)	0.41		0.95		0.03



	Quarter
KCP&L	1st		2nd		3rd		4th
2013	(millions)
Operating revenue	$	366.7	$	410.8	$	522.0	$	371.9
Operating income	52.3		93.4		176.8		40.0
Net income	16.2		44.2		96.4		12.2
2012
Operating revenue	$	327.0	$	409.1	$	508.0	$	335.8
Operating income	31.6		99.9		177.8		39.4
Net income	2.3		43.7		90.2		5.4

Quarterly data is subject to seasonal fluctuations with peak periods occurring in the summer months.

Condensed Financial Information of Parent Company Only Disclosure [Text Block]

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

+ References+ Details

Schedule I Financial Statements of Parent Company

12 Months Ended

Dec. 31, 2013



GREAT PLAINS ENERGY INCORPORATED
Statements of Comprehensive Income of Parent Company

Year Ended December 31	2013			2012			2011
Operating Expenses	(millions, except per share amounts)
General and administrative	$	1.0		$	3.3		$	0.8
General taxes	0.6			0.7			0.9
Total	1.6			4.0			1.7
Operating loss	(1.6		)	(4.0		)	(1.7		)
Equity in earnings from subsidiaries	256.5			219.2			200.8
Non-operating income	45.8			42.7			24.7
Interest charges	(54.7		)	(69.6		)	(66.5		)
Income before income taxes	246.0			188.3			157.3
Income tax benefit	4.2			11.6			17.1
Net income	250.2			199.9			174.4
Preferred stock dividend requirements	1.6			1.6			1.6
Earnings available for common shareholders	$	248.6		$	198.3		$	172.8

Average number of basic common shares outstanding	153.5			145.5			135.6
Average number of diluted common shares outstanding	153.7			147.2			138.7

Basic earnings per common share	$	1.62		$	1.36		$	1.27
Diluted earnings per common share	$	1.62		$	1.35		$	1.25

Cash dividends per common share	$	0.8825		$	0.855		$	0.835
Comprehensive Income
Net income	$	250.2		$	199.9		$	174.4
Other comprehensive income
Derivative hedging activity
Loss on derivative hedging instruments	—			—			(5.3		)
Income tax benefit	—			—			2.1
Net loss on derivative hedging instruments	—			—			(3.2		)
Reclassification to expenses	9.9			11.5			8.2
Income tax expense	(3.9		)	(4.6		)	(3.2		)
Net reclassification to expenses	6.0			6.9			5.0
Derivative hedging activity, net of tax	6.0			6.9			1.8
Other comprehensive income from subsidiaries, net of tax	7.1			4.5			4.5
Total other comprehensive income	13.1			11.4			6.3
Comprehensive income	$	263.3		$	211.3		$	180.7

The accompanying Notes to Financial Statements of Parent Company are an integral part of these statements.



GREAT PLAINS ENERGY INCORPORATED
Balance Sheets of Parent Company

	December 31
	2013				2012
ASSETS	(millions, except share amounts)
Current Assets
Accounts receivable from subsidiaries		$	0.2			$	0.1
Notes receivable from subsidiaries		0.6				0.6
Money pool receivable		9.4				4.0
Taxes receivable		0.2				—
Other		1.2				2.4
Total		11.6				7.1
Investments and Other Assets
Investment in KCP&L		2,179.3				2,096.7
Investment in other subsidiaries		1,447.0				1,405.4
Note receivable from subsidiaries		634.9				883.6
Deferred income taxes		31.4				32.3
Other		6.7				7.6
Total		4,299.3				4,425.6
Total		$	4,310.9			$	4,432.7

LIABILITIES AND CAPITALIZATION
Current Liabilities
Notes payable		$	9.0			$	12.0
Current maturities of long-term debt		—				250.0
Accounts payable to subsidiaries		33.6				34.1
Accrued taxes		0.2				0.5
Accrued interest		4.2				6.8
Other		1.5				2.1
Total		48.5				305.5
Deferred Credits and Other Liabilities		6.6				5.2
Capitalization
Great Plains Energy common shareholders' equity
Common stock - 250,000,000 shares authorized without par value
153,995,621 and 153,779,806 shares issued, stated value		2,631.1				2,624.7
Retained earnings		871.4				758.8
Treasury stock - 129,290 and 250,236 shares, at cost		(2.8		)		(5.1		)
Accumulated other comprehensive loss		(25.3		)		(38.4		)
Total		3,474.4				3,340.0
Cumulative preferred stock $100 par value
3.80% - 100,000 shares issued		10.0				10.0
4.50% - 100,000 shares issued		10.0				10.0
4.20% - 70,000 shares issued		7.0				7.0
4.35% - 120,000 shares issued		12.0				12.0
Total		39.0				39.0
Long-term debt		742.4				743.0
Total		4,255.8				4,122.0
Commitments and Contingencies
Total		$	4,310.9			$	4,432.7

The accompanying Notes to Financial Statements of Parent Company are an integral part of these statements.



GREAT PLAINS ENERGY INCORPORATED
Statements of Cash Flows of Parent Company

Year Ended December 31	2013			2012			2011
Cash Flows from Operating Activities	(millions)
Net income	$	250.2		$	199.9		$	174.4
Adjustments to reconcile income to net cash from operating activities:
Amortization	10.6			12.6			11.2
Deferred income taxes, net	(10.5		)	(4.8		)	(18.6		)
Equity in earnings from subsidiaries	(256.5		)	(219.2		)	(200.8		)
Cash flows affected by changes in:
Accounts receivable from subsidiaries	(0.1		)	(0.1		)	—
Taxes receivable	(0.2		)	0.9			6.3
Accounts payable to subsidiaries	(0.5		)	2.3			(0.3		)
Other accounts payable	0.1			—			—
Accrued taxes	(0.1		)	(4.4		)	5.2
Accrued interest	(2.6		)	6.1			1.2
Cash dividends from subsidiaries	140.0			144.0			148.0
Interest rate hedge settlement	—			—			(26.1		)
Uncertain tax positions	7.3			1.0			(3.3		)
Other	6.8			1.7			5.4
Net cash from operating activities	144.5			140.0			102.6
Cash Flows from Investing Activities
Intercompany lending	248.7			(287.4		)	(347.4		)
Net money pool lending	(5.4		)	(3.1		)	1.1
Other	(0.5		)	—			—
Net cash from investing activities	242.8			(290.5		)	(346.3		)
Cash Flows from Financing Activities
Issuance of common stock	4.9			293.0			5.9
Issuance of long-term debt	—			—			349.7
Issuance fees	(0.4		)	(2.7		)	(3.2		)
Repayment of long-term debt	(250.0		)	—			—
Net change in short-term borrowings	(3.0		)	(10.0		)	12.5
Dividends paid	(137.3		)	(125.5		)	(115.1		)
Other financing activities	(1.5		)	(4.3		)	(6.4		)
Net cash from financing activities	(387.3		)	150.5			243.4
Net Change in Cash and Cash Equivalents	—			—			(0.3		)
Cash and Cash Equivalents at Beginning of Year	—			—			0.3
Cash and Cash Equivalents at End of Year	$	—		$	—		$	—

The accompanying Notes to Financial Statements of Parent Company are an integral part of these statements.

GREAT PLAINS ENERGY INCORPORATED

NOTES TO FINANCIAL STATEMENTS OF PARENT COMPANY

The Great Plains Energy Incorporated Notes to Consolidated Financial Statements in Part II, Item 8 should be read in conjunction with the Great Plains Energy Incorporated Parent Company Financial Statements.

The Great Plains Energy Incorporated Parent Company Financial Statements have been prepared to present the financial position, results of operations and cash flows of Great Plains Energy on a stand-alone basis as a holding company. Investments in subsidiaries are accounted for using the equity method.

Valuation and Qualifying Accounts [Abstract]

The entire disclosure for condensed financial information, including the financial position, cash flows, and the results of operations of the registrant (parent company) as of the same dates or for the same periods for which audited consolidated financial statements are being presented. Alternatively, the details of this disclosure can be reported by the specific parent company taxonomy elements, indicating the appropriate date and period contexts in an instance document.

+ References+ Details

Schedule II Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2013

Schedule II Valuation and Qualifying Accounts

Schedule II - Valuation and Qualifying Accounts and Reserves



Great Plains Energy Incorporated
Valuation and Qualifying Accounts
Years Ended December 31, 2013, 2012 and 2011

				Additions
				Charged
	Balance At			To Costs				Charged								Balance
	Beginning			And				To Other								At End
Description	Of Period			Expenses				Accounts				Deductions				Of Period
Year Ended December 31, 2013	(millions)
Allowance for uncollectible accounts		$	6.9		$	12.3			$	7.6	^(a)		$	24.3	^(b)		$	2.5
Legal reserves		4.6			2.7				—				2.7		^(c)		4.6
Environmental reserves		2.3			—				—				0.6				1.7
Tax valuation allowance		23.8			0.1				—				3.2		^(d)		20.7
Year Ended December 31, 2012
Allowance for uncollectible accounts		$	6.8		$	12.0			$	7.8	^(a)		$	19.7	^(b)		$	6.9
Legal reserves		6.7			(0.2		)		—				1.9		^(c)		4.6
Environmental reserves		2.5			—				—				0.2				2.3
Tax valuation allowance		23.9			0.3				—				0.4		^(d)		23.8
Year Ended December 31, 2011
Allowance for uncollectible accounts		$	7.0		$	13.7			$	6.9	^(a)		$	20.8	^(b)		$	6.8
Legal reserves		10.2			(0.1		)		—				3.4		^(c)		6.7
Environmental reserves		2.5			—				—				—				2.5
Tax valuation allowance		26.6			0.1				—				2.8		^(d)		23.9

(a) Recoveries.

(b) Uncollectible accounts charged off.

(d) Reversal of tax valuation allowance.



Kansas City Power & Light Company
Valuation and Qualifying Accounts
Years Ended December 31, 2013, 2012 and 2011

				Additions
				Charged
	Balance At			To Costs			Charged								Balance
	Beginning			And			To Other								At End
Description	Of Period			Expenses			Accounts				Deductions				Of Period
Year Ended December 31, 2013	(millions)
Allowance for uncollectible accounts		$	1.5		$	8.0		$	5.0	^(a)		$	13.4	^(b)		$	1.1
Legal reserves		2.9			0.9			—				0.9		^(c)		2.9
Environmental reserves		0.3			—			—				—				0.3
Year Ended December 31, 2012
Allowance for uncollectible accounts		$	1.4		$	7.9		$	5.2	^(a)		$	13.0	^(b)		$	1.5
Legal reserves		3.9			0.5			—				1.5		^(c)		2.9
Environmental reserves		0.3			—			—				—				0.3
Year Ended December 31, 2011
Allowance for uncollectible accounts		$	1.5		$	8.8		$	4.5	^(a)		$	13.4	^(b)		$	1.4
Legal reserves		3.0			1.3			—				0.4		^(c)		3.9
Environmental reserves		0.3			—			—				—				0.3

(a) Recoveries.

(b) Uncollectible accounts charged off.

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2013

Accounting Policies [Abstract]

Organization [Policy Text Block]

Organization


•	KCP&L is an integrated, regulated electric utility that provides electricity to customers primarily in the states of Missouri and Kansas. KCP&L has one active wholly owned subsidiary, Kansas City Power & Light Receivables Company (KCP&L Receivables Company).

•


•	GPE Transmission Holding Company, LLC (GPETHC) owns 13.5% of Transource Energy, LLC (Transource) with the remaining 86.5% owned by AEP Transmission Holding Company, LLC (AEPTHC), a subsidiary of American Electric Power Company, Inc. GPETHC accounts for its investment in Transource under the equity method. Transource is focused on the development of competitive electric transmission projects.

Each of Great Plains Energy's and KCP&L's consolidated financial statements includes the accounts of their subsidiaries. Intercompany transactions have been eliminated.

Great Plains Energy's sole reportable business segment is electric utility. See Note 23 for additional information.

Basic and Diluted Earnings per Common Share Calculation [Policy Text Block]

Basic and Diluted Earnings per Common Share Calculation

The following table reconciles Great Plains Energy's basic and diluted EPS.



	2013		2012		2011
Income	(millions, except per share amounts)
Net income	$	250.2	$	199.9	$	174.2
Less: net loss attributable to noncontrolling interest	—		—		(0.2		)
Less: preferred stock dividend requirements	1.6		1.6		1.6
Earnings available for common shareholders	$	248.6	$	198.3	$	172.8
Common Shares Outstanding
Average number of common shares outstanding	153.5		145.5		135.6
Add: effect of dilutive securities	0.2		1.7		3.1
Diluted average number of common shares outstanding	153.7		147.2		138.7
Basic EPS	$	1.62	$	1.36	$	1.27
Diluted EPS	$	1.62	$	1.35	$	1.25

Anti-dilutive shares excluded from the computation of diluted EPS are detailed in the following table.



	2013	2012	2011
Performance shares	548,242	—	50,897
Restricted stock shares	2,228	3,781	43,641
Stock options	—	—	6,000

Cash and Cash Equivalents, Policy [Policy Text Block]

Cash and Cash Equivalents

Cash equivalents consist of highly liquid investments with original maturities of three months or less at acquisition.

Use of Estimates, Policy [Policy Text Block]

Use of Estimates

Funds on Deposit, Policy [Policy Text Block]

Funds on Deposit

Fair Value of Financial Instruments, Policy [Policy Text Block]

Fair Value of Financial Instruments

The following methods and assumptions were used to estimate the fair value of each class of financial instrument for which it is practicable to estimate that value.

Derivatives, Policy [Policy Text Block]

Derivative Instruments

Utility Plant, Policy [Policy Text Block]

Utility Plant

Great Plains Energy's and KCP&L's balances of utility plant, at original cost, with a range of estimated useful lives are listed in the following tables.



Great Plains Energy
December 31	2013		2012
Utility plant, at original cost	(millions)
Generation (20 - 60 years)	$	6,874.6	$	6,697.1
Transmission (15 - 70 years)	794.0		754.0
Distribution (8 - 66 years)	3,149.4		3,019.6
General (5 - 50 years)	757.3		689.8
Total ^(a)	$	11,575.3	$	11,160.5

^(a) Includes $107.8 million and $104.5 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.



KCP&L
December 31	2013		2012
Utility plant, at original cost	(millions)
Generation (20 - 60 years)	$	5,288.3	$	5,140.0
Transmission (15 - 70 years)	433.7		414.7
Distribution (8 - 55 years)	1,970.2		1,893.8
General (5 - 50 years)	582.7		522.9
Total ^(a)	$	8,274.9	$	7,971.4

^(a) Includes $54.1 million and $54.7 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.

Depreciation and Amortization, Policy [Policy Text Block]

Depreciation and Amortization

Nuclear Plant Decommissioning Costs, Policy [Policy Text Block]

Nuclear Plant Decommissioning Costs

Deferred Refueling Outage Costs, Policy [Policy Text Block]

Deferred Refueling Outage Costs

Regulatory Matters, Policy [Policy Text Block]

Regulatory Matters

Revenue Recognition, Policy [Policy Text Block]

Revenue Recognition

Allowance for Doubtful Accounts, Policy [Policy Text Block]

Allowance for Doubtful Accounts

Property Gains And Losses, Policy [Policy Text Block]

Property Gains and Losses

Net gains and losses from the sale of assets and businesses and from asset impairments are recorded in operating expenses.

Asset Impairments, Policy [Policy Text Block]

Asset Impairments

Income Taxes, Policy [Policy Text Block]

Income Taxes

Environmental Matters, Policy [Policy Text Block]

Environmental Matters

Environmental costs are accrued when it is probable a liability has been incurred and the amount of the liability can be reasonably estimated.

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2013

Accounting Policies [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

The following table reconciles Great Plains Energy's basic and diluted EPS.



	2013		2012		2011
Income	(millions, except per share amounts)
Net income	$	250.2	$	199.9	$	174.2
Less: net loss attributable to noncontrolling interest	—		—		(0.2		)
Less: preferred stock dividend requirements	1.6		1.6		1.6
Earnings available for common shareholders	$	248.6	$	198.3	$	172.8
Common Shares Outstanding
Average number of common shares outstanding	153.5		145.5		135.6
Add: effect of dilutive securities	0.2		1.7		3.1
Diluted average number of common shares outstanding	153.7		147.2		138.7
Basic EPS	$	1.62	$	1.36	$	1.27
Diluted EPS	$	1.62	$	1.35	$	1.25

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]

Anti-dilutive shares excluded from the computation of diluted EPS are detailed in the following table.



	2013	2012	2011
Performance shares	548,242	—	50,897
Restricted stock shares	2,228	3,781	43,641
Stock options	—	—	6,000

Schedule of Public Utility Property, Plant, and Equipment [Table Text Block]

Great Plains Energy's and KCP&L's balances of utility plant, at original cost, with a range of estimated useful lives are listed in the following tables.



Great Plains Energy
December 31	2013		2012
Utility plant, at original cost	(millions)
Generation (20 - 60 years)	$	6,874.6	$	6,697.1
Transmission (15 - 70 years)	794.0		754.0
Distribution (8 - 66 years)	3,149.4		3,019.6
General (5 - 50 years)	757.3		689.8
Total ^(a)	$	11,575.3	$	11,160.5

^(a) Includes $107.8 million and $104.5 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.



KCP&L
December 31	2013		2012
Utility plant, at original cost	(millions)
Generation (20 - 60 years)	$	5,288.3	$	5,140.0
Transmission (15 - 70 years)	433.7		414.7
Distribution (8 - 55 years)	1,970.2		1,893.8
General (5 - 50 years)	582.7		522.9
Total ^(a)	$	8,274.9	$	7,971.4

^(a) Includes $54.1 million and $54.7 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.

Supplemental Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2013

Supplemental Cash Flow Elements [Abstract]

Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]



Great Plains Energy Other Operating Activities
Year Ended December 31	2013			2012			2011
Cash flows affected by changes in:	(millions)
Receivables	$	(7.1	)	$	76.8		$	3.6
Accounts receivable pledged as collateral	(1.0		)	(79.0		)	—
Fuel inventories	18.7			(6.1		)	(3.9		)
Materials and supplies	(1.0		)	(11.0		)	(7.5		)
Accounts payable	26.4			57.3			5.7
Accrued taxes	2.2			(7.8		)	1.4
Accrued interest	3.9			(35.2		)	1.5
Deferred refueling outage costs	(17.6		)	15.6			(17.9		)
Pension and post-retirement benefit obligations	31.3			14.4			(56.0		)
Allowance for equity funds used during construction	(14.1		)	(1.3		)	(1.0		)
Interest rate hedge settlements	—			—			(26.1		)
Fuel recovery mechanism	(1.3		)	22.5			(1.7		)
Uncertain tax positions	(0.8		)	(4.7		)	(20.8		)
Other	(15.5		)	(29.8		)	(24.8		)
Total other operating activities	$	24.1		$	11.7		$	(147.5	)
Cash paid during the period:
Interest	$	170.8		$	247.9		$	254.4
Income taxes	$	—		$	3.3		$	2.8
Non-cash investing activities:
Liabilities accrued for capital expenditures	$	48.1		$	57.5		$	39.7



KCP&L Other Operating Activities
Year Ended December 31	2013			2012			2011
Cash flows affected by changes in:	(millions)
Receivables	$	(12.6	)	$	8.8		$	(20.2	)
Accounts receivable pledged as collateral	—			(15.0		)	—
Fuel inventories	13.3			(4.6		)	(14.1		)
Materials and supplies	1.1			(9.0		)	(6.7		)
Accounts payable	7.3			48.3			11.0
Accrued taxes	(3.7		)	(2.0		)	2.7
Accrued interest	1.4			(2.3		)	3.8
Deferred refueling outage costs	(17.6		)	15.6			(17.9		)
Pension and post-retirement benefit obligations	35.7			18.0			(45.6		)
Allowance for equity funds used during construction	(14.1		)	(1.3		)	(0.7		)
Fuel recovery mechanism	(1.8		)	5.1			(5.8		)
Uncertain tax positions	(10.5		)	1.8			(10.4		)
Other	(7.7		)	(35.5		)	(14.4		)
Total other operating activities	$	(9.2	)	$	27.9		$	(118.3	)
Cash paid during the period:
Interest	$	111.7		$	118.0		$	111.3
Income taxes	$	4.6		$	18.0		$	0.1
Non-cash investing activities:
Liabilities accrued for capital expenditures	$	40.5		$	48.4		$	32.0

Receivables (Tables)

12 Months Ended

Dec. 31, 2013

Receivables [Abstract]

Schedule of receivables [Table Text Block]

Great Plains Energy's and KCP&L's receivables are detailed in the following table.



	December 31
	2013			2012
Great Plains Energy	(millions)
Customer accounts receivable - billed	$	1.5		$	—
Customer accounts receivable - unbilled	74.6			58.3
Allowance for doubtful accounts - customer accounts receivable	(2.5		)	(2.6		)
Other receivables	88.6			98.8
Total	$	162.2		$	154.5
KCP&L
Customer accounts receivable - billed	$	1.3		$	—
Customer accounts receivable - unbilled	51.2			42.9
Allowance for doubtful accounts - customer accounts receivable	(1.1		)	(1.5		)
Intercompany receivables	50.4			40.0
Other receivables	77.8			81.8
Total	$	179.6		$	163.2

Schedule of accounts receivable sold [Table Text Block]

Information regarding KCP&L's sale of accounts receivable to KCP&L Receivables Company and GMO's sale of accounts receivable to GMO Receivables Company is reflected in the following tables.



2013	KCP&L				KCP&L Receivables Company				Consolidated KCP&L				GMO				GMO Receivables Company				Consolidated Great Plains Energy
	(millions)
Receivables (sold) purchased		$	(1,517.2	)		$	1,517.2			$	—			$	(834.7	)		$	834.7			$	—
Gain (loss) on sale of accounts receivable ^(a)		(19.2		)		19.1				(0.1		)		(10.6		)		10.5				(0.2		)
Servicing fees received (paid)		2.6				(2.6		)		—				1.4				(1.4		)		—
Fees paid to outside investor		—				(1.2		)		(1.2		)		—				(0.7		)		(1.9		)
Cash from customers (transferred) received		(1,516.2		)		1,516.2				—				(830.9		)		830.9				—
Cash received from (paid for) receivables purchased		1,497.2				(1,497.2		)		—				820.5				(820.5		)		—
Interest on intercompany note received (paid)		0.3				(0.3		)		—				0.1				(0.1		)		—



2012	KCP&L				KCP&L Receivables Company				Consolidated KCP&L				GMO				GMO Receivables Company				Consolidated Great Plains Energy
	(millions)
Receivables (sold) purchased		$	(1,436.0	)		$	1,436.0			$	—			$	(597.8	)		$	597.8			$	—
Gain (loss) on sale of accounts receivable ^(a)		(18.2		)		18.3				0.1				(7.6		)		6.6				(0.9		)
Servicing fees received (paid)		2.5				(2.5		)		—				0.9				(0.9		)		—
Fees paid to outside investor		—				(1.2		)		(1.2		)		—				(0.5		)		(1.7		)
Cash from customers (transferred) received		(1,452.4		)		1,452.4				—				(524.0		)		524.0				—
Cash received from (paid for) receivables purchased		1,434.2				(1,434.2		)		—				517.5				(517.5		)		—
Interest on intercompany note received (paid)		0.3				(0.3		)		—				0.1				(0.1		)		—

^(a) Any net gain (loss) is the result of the timing difference inherent in collecting receivables and over the life of the agreement will net to zero.

Nuclear Plant (Tables)

12 Months Ended

Dec. 31, 2013

Nuclear Plant [Abstract]

Changes in nuclear decommissioning trust fund

The following table summarizes the change in Great Plains Energy's and KCP&L's nuclear decommissioning trust fund.



	2013			2012
Decommissioning Trust		(millions)
Beginning balance January 1		$	154.7		$	135.3
Contributions		3.3			3.3
Earned income, net of fees		2.7			3.0
Net realized gains		1.7			1.0
Net unrealized gains		21.5			12.1
Ending balance December 31		$	183.9		$	154.7

Detail of assets held in nuclear decommissioning trust fund

The nuclear decommissioning trust is reported at fair value on the balance sheets and is invested in assets as detailed in the following table.



	December 31
	2013													2012
	Cost Basis		Unrealized Gains			Unrealized Losses				Fair Value			Cost Basis			Unrealized Gains			Unrealized Losses				Fair Value
	(millions)
Equity securities	$	83.7		$	44.6		$	(0.6	)		$	127.7		$	80.6		$	21.1		$	(1.6	)		$	100.1
Debt securities	51.0			2.5			(0.7		)		52.8			46.6			4.9			(0.1		)		51.4
Other	3.4			—			—				3.4			3.2			—			—				3.2
Total	$	138.1		$	47.1		$	(1.3	)		$	183.9		$	130.4		$	26.0		$	(1.7	)		$	154.7

Gains and losses from the sale of securities by the nuclear decommissioning trust fund

The following table summarizes the realized gains and losses from the sale of securities in the nuclear decommissioning trust fund.



	2013			2012			2011
	(millions)
Realized gains	$	2.4		$	1.7		$	1.0
Realized losses	(0.7		)	(0.7		)	(0.7		)

Nuclear plant decommissioning costs [Table Text Block]



	Total Station			KCP&L's 47% Share
	(millions)
Current cost of decommissioning (in 2011 dollars)		$	630		$	296
Future cost of decommissioning (in 2045-2053 dollars) ^(a)		1,788			840

Annual escalation factor	2.85%
Annual return on trust assets ^(b)	5.13%

^(a)Total future cost over an eight year decommissioning period

Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2013

Regulated Operations [Abstract]

Schedule Of Regulatory Assets And Liabilities [Table Text Block]



	December 31
	2013								2012
	KCP&L			GMO			Great Plains Energy		KCP&L		GMO		Great Plains Energy
Regulatory Assets	(millions)
Taxes recoverable through future rates	$	111.0		$	25.4		$	136.4	$	114.7	$	23.7	$	138.4
Loss on reacquired debt	7.1		^(a)	1.5		^(a)	8.6		8.1		2.0		10.1
Cost of removal	1.0			—			1.0		2.8		—		2.8
Asset retirement obligations	34.8			16.0			50.8		31.5		14.9		46.4
Pension and post-retirement costs	310.0		^(b)	91.2		^(b)	401.2		541.2		129.7		670.9
Deferred customer programs	50.2		^(c)	21.8		^(d)	72.0		49.8		24.6		74.4
Rate case expenses	3.6		^(e)	0.6		^(f)	4.2		7.5		1.7		9.2
Fuel recovery mechanism	10.8		^(e)	12.8		^(e)	23.6		8.9		16.9		25.8
Acquisition transition costs	12.9		^(g)	11.0		^(g)	23.9		18.7		15.5		34.2
Derivative instruments	—			—			—		—		3.7		3.7
Iatan No. 1 and common facilities depreciation and carrying costs	15.3		^(h)	5.7		^(h)	21.0		15.9		5.9		21.8
Iatan No. 2 construction accounting costs	29.3		⁽ⁱ⁾	16.0		⁽ⁱ⁾	45.3		30.6		16.2		46.8
Kansas property tax surcharge	4.0		^(e)	—			4.0		5.4		—		5.4
Solar rebates	13.0		^(e)	32.3		^(e)	45.3		5.8		10.0		15.8
Voluntary separation program	3.4		^(j)	—			3.4		4.3		—		4.3
Other	7.7		^(e)	1.3		^(e)	9.0		8.0		2.9		10.9
Total	$	614.1		$	235.6		$	849.7	$	853.2	$	267.7	$	1,120.9
Regulatory Liabilities
Emission allowances	$	74.0		$	—		$	74.0	$	78.0	$	0.1	$	78.1
Asset retirement obligations	86.2			—			86.2		63.1		—		63.1
Pension	—			—			—		1.5		44.6		46.1
Cost of removal	—			68.1		^(k)	68.1		—		64.0		64.0
Other	8.1			27.6			35.7		10.4		22.1		32.5
Total	$	168.3		$	95.7		$	264.0	$	153.0	$	130.8	$	283.8

^(a)Amortized over the life of the related new debt issuances or the remaining lives of the old debt issuances if no new debt was issued.

^(c) $15.4 million not included in rate base and amortized over various periods.

^(d)$2.1 million not included in rate base and amortized over various periods.

^(e)Not included in rate base and amortized over various periods.

^(f)Not included in rate base and amortized through 2014.

^(g)Not included in rate base and amortized through 2016.

^(h)Included in rate base and amortized through 2038.

⁽ⁱ⁾Included in rate base and amortized through 2058.

^(j)Not included in rate base and amortized through 2017.

^(k)Estimated cumulative net provision for future removal costs.

Goodwill and Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2013

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Finite-Lived Intangible Assets [Table Text Block]

Great Plains Energy's and KCP&L's intangible assets are included in electric utility plant on the consolidated balance sheets and are detailed in the following table.



		December 31, 2013							December 31, 2012
	Gross Carrying Amount			Accumulated Amortization				Gross Carrying Amount			Accumulated Amortization
Great Plains Energy	(millions)
Computer software		$	255.4		$	(169.9	)		$	211.2		$	(152.9	)
Asset improvements		26.5			(4.9		)		26.5			(4.2		)

KCP&L
Computer software		$	231.2		$	(156.5	)		$	189.9		$	(142.9	)
Asset improvements		11.2			(1.1		)		11.2			(0.8		)

Amortization Expense Related to Intangible Assets [Table Text Block]

Great Plains Energy's and KCP&L's amortization expense related to intangible assets is detailed in the following table.



	2013		2012
	(millions)
Great Plains Energy	$	17.6	$	15.6
KCP&L	14.3		13.2

Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block]



	2014		2015		2016		2017		2018
	(millions)
Great Plains Energy	$	17.2	$	15.1	$	13.6	$	9.5	$	6.7
KCP&L	14.0		12.1		10.7		8.4		6.3

Pension Plans and Other Employee Benefits (Tables)

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Schedule of Net Benefit Costs [Table Text Block]



	Pension Benefits									Other Benefits
	2013			2012			2011			2013			2012			2011
Components of net periodic benefit costs	(millions)
Service cost	$	41.2		$	35.4		$	31.1		$	4.4		$	3.3		$	3.1
Interest cost	47.2			48.9			49.6			7.7			7.8			7.8
Expected return on plan assets	(47.1		)	(42.9		)	(38.0		)	(2.0		)	(1.8		)	(1.8		)
Prior service cost	2.0			4.5			4.6			7.2			7.1			7.2
Recognized net actuarial (gain) loss	54.3			44.5			38.7			1.7			(0.2		)	(0.5		)
Transition obligation	—			—			—			0.2			1.1			1.3
Settlement charges	4.9			0.8			10.1			—			—			—
Net periodic benefit costs before regulatory adjustment	102.5			91.2			96.1			19.2			17.3			17.1
Regulatory adjustment	(16.8		)	(15.5		)	(27.9		)	(2.4		)	1.5			1.1
Net periodic benefit costs	85.7			75.7			68.2			16.8			18.8			18.2
Other changes in plan assets and benefit obligations recognized in OCI or regulatory assets/liabilities
Current year net (gain) loss	(147.0		)	97.9			114.8			(22.1		)	27.1			6.7
Amortization of gain (loss)	(54.3		)	(44.5		)	(38.7		)	(1.7		)	0.2			0.5
Prior service cost	0.3			1.1			—			(6.0		)	—			—
Amortization of prior service cost	(2.0		)	(4.5		)	(4.6		)	(7.2		)	(7.1		)	(7.2		)
Amortization of transition obligation	—			—			—			(0.2		)	(1.1		)	(1.3		)
Other regulatory activity	11.8			17.7			17.1			2.1			(1.2		)	(1.0		)
Total recognized in OCI or regulatory asset/liability	(191.2		)	67.7			88.6			(35.1		)	17.9			(2.3		)
Total recognized in net periodic benefit costs and OCI or regulatory asset/liability	$	(105.5	)	$	143.4		$	156.8		$	(18.3	)	$	36.7		$	15.9

Schedule of Net Funded Status [Table Text Block]



	Pension Benefits						Other Benefits
	2013			2012			2013			2012
Change in projected benefit obligation (PBO)	(millions)
PBO at January 1	$	1,130.5		$	980.6		$	186.5		$	154.2
Service cost	41.2			35.4			4.4			3.3
Interest cost	47.2			48.9			7.7			7.8
Contribution by participants	—			—			6.2			6.7
Amendments	0.3			1.1			(6.0		)	—
Actuarial (gain) loss	(118.4		)	127.0			(26.1		)	26.7
Benefits paid	(52.9		)	(58.1		)	(12.2		)	(12.2		)
Settlements	(40.5		)	(4.4		)	—			—
PBO at December 31	$	1,007.4		$	1,130.5		$	160.5		$	186.5
Change in plan assets
Fair value of plan assets at January 1	$	666.4		$	591.1		$	90.3		$	77.4
Actual return on plan assets	70.9			71.2			(2.0		)	1.4
Contributions by employer and participants	57.4			60.4			25.0			23.7
Benefits paid	(51.2		)	(56.3		)	(12.1		)	(12.2		)
Settlements	(40.5		)	—			—			—
Fair value of plan assets at December 31	$	703.0		$	666.4		$	101.2		$	90.3
Funded status at December 31	$	(304.4	)	$	(464.1	)	$	(59.3	)	$	(96.2	)
Amounts recognized in the consolidated balance sheets
Current pension and other post-retirement liability	$	(2.3	)	$	(1.9	)	$	(0.9	)	$	(0.9	)
Noncurrent pension liability and other post-retirement liability	(302.1		)	(462.2		)	(58.4		)	(95.3		)
Net amount recognized before regulatory treatment	(304.4		)	(464.1		)	(59.3		)	(96.2		)
Accumulated OCI or regulatory asset/liability	368.3			559.5			35.3			70.4
Net amount recognized at December 31	$	63.9		$	95.4		$	(24.0	)	$	(25.8	)
Amounts in accumulated OCI or regulatory asset/liability not yet recognized as a component of net periodic benefit cost:
Actuarial loss	$	147.7		$	349.0		$	19.2		$	43.0
Prior service cost	5.6			7.3			16.6			29.8
Transition obligation	—			—			0.4			0.6
Other	215.0			203.2			(0.9		)	(3.0		)
Net amount recognized at December 31	$	368.3		$	559.5		$	35.3		$	70.4

Schedule Of Periodic Benefit Obligation And Accumulated Benefit Obligation And Fair Value Of Plan Assets By Funded And Under Funded Plans [Table Text Block]



	2013		2012
Pension plans with the PBO in excess of plan assets	(millions)
Projected benefit obligation	$	1,007.4	$	1,130.5
Fair value of plan assets	703.0		666.4
Pension plans with the ABO in excess of plan assets
Accumulated benefit obligation	$	889.2	$	985.8
Fair value of plan assets	703.0		666.4
Other post-retirement benefit plans with the APBO in excess of plan assets
Accumulated other post-retirement benefit obligation	$	160.5	$	186.5
Fair value of plan assets	101.2		90.3

Schedule of Assumptions Used [Table Text Block]



Weighted-average assumptions used to determine the benefit obligation at December 31	Pension Benefits				Other Benefits
	2013		2012		2013		2012
Discount rate	5.03	%	4.17	%	4.92	%	4.13	%
Rate of compensation increase	3.69	%	3.69	%	3.50	%	3.50	%



Weighted-average assumptions used to determine net costs for years ended December 31	Pension Benefits				Other Benefits
	2013		2012		2013			2012
Discount rate	4.17	%	5.01	%	4.13	%		5.03	%
Expected long-term return on plan assets	7.24	%	7.29	%	2.62	%	*	2.59	%	*
Rate of compensation increase	3.69	%	4.08	%	3.50	%		4.07	%

*after tax

Schedule of Expected Benefit Payments [Table Text Block]



	Pension Benefits		Other Benefits
	(millions)
2014	$	67.0	$	7.8
2015	65.3		8.3
2016	69.1		8.9
2017	71.9		9.3
2018	73.6		9.7
2019-2023	401.3		52.1

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]



Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
Description	Real Estate			Hedge Funds			Total
	(millions)
Balance January 1, 2013		$	38.4		$	21.6		$	60.0
Actual return on plan assets
Relating to assets still held		4.6			1.5			6.1
Purchase, sales and settlements		0.7			—			0.7
Balance December 31, 2013		$	43.7		$	23.1		$	66.8



Great Plains Energy
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative Instruments
	2013			2012
	(millions)
Balance at January 1	$	2.3		$	3.1
Total realized/unrealized gains included in non-operating income	9.5			8.2
Purchases	1.7			—
Settlements	(10.2		)	(9.0		)
Balance at December 31	$	3.3		$	2.3
Total unrealized losses included in non-operating income relating to assets still on the
consolidated balance sheet at December 31	$	(0.3	)	$	(0.4	)



KCP&L
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative
	Instruments
	2013
	(millions)
Balance at January 1	$	—
Purchases	1.1
Balance at December 31	$	1.1



Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
Description	Real Estate			Hedge Funds				Total
	(millions)
Balance January 1, 2012		$	34.7		$	21.7			$	56.4
Actual return on plan assets
Relating to assets still held		1.6			0.6				2.2
Relating to assets sold		1.3			(0.4		)		0.9
Purchase, sales and settlements		0.8			(0.3		)		0.5
Balance December 31, 2012		$	38.4		$	21.6			$	60.0

Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates [Table Text Block]



	Increase		Decrease
	(millions)
Effect on total service and interest component	$	1.1	$	(1.0	)
Effect on post-retirement benefit obligation	8.8		(7.3		)

Pension Plans, Defined Benefit [Member]

Schedule of Allocation of Plan Assets [Table Text Block]



				Fair Value Measurements Using
Description	December 31 2013			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
		(millions)
Pension Plans
Equity securities
U.S. ^(a)		$	193.7		$	80.5		$	113.2		$	—
International ^(b)		167.1			39.9			127.2			—
Real estate ^(c)		49.1			—			5.4			43.7
Commodities ^(d)		34.8			—			34.8			—
Fixed income securities
Fixed income funds ^(e)		181.3			27.1			154.2			—
U.S. Treasury		2.6			2.6			—			—
U.S. Agency, state and local obligations		17.1			—			17.1			—
U.S. corporate bonds ^(f)		25.6			—			25.6			—
Foreign corporate bonds		2.3			—			2.3			—
Hedge funds ^(g)		23.1			—			—			23.1
Cash equivalents		3.0			3.0			—			—
Other		3.3			—			3.3			—
Total		$	703.0		$	153.1		$	483.1		$	66.8



				Fair Value Measurements Using
Description	December 31 2012			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
		(millions)
Pension Plans
Equity securities
U.S. ^(a)		$	169.6		$	69.7		$	99.9		$	—
International ^(b)		151.2			36.6			114.6			—
Real estate ^(c)		43.4			—			5.0			38.4
Commodities ^(d)		37.3			—			37.3			—
Fixed income securities
Fixed income funds ^(e)		182.1			35.0			147.1			—
U.S. Treasury		4.5			4.5			—			—
U.S. Agency, state and local obligations		19.6			—			19.6			—
U.S. corporate bonds ^(f)		28.9			—			28.9			—
Foreign corporate bonds		2.6			—			2.6			—
Hedge funds ^(g)		21.6			—			—			21.6
Total		$	660.8		$	145.8		$	455.0		$	60.0
Cash equivalents		5.6
Total Pension Plans		$	666.4

^(c)This category is comprised of institutional common/collective trust funds and a limited partnership valued at NAV on a quarterly basis.

^(d) This category is comprised of institutional common/collective trust funds valued at daily NAV per share.

^(g)This category is comprised of closely-held limited partnerships valued at NAV on a quarterly basis.

Other Postretirement Benefit Plans, Defined Benefit [Member]

Schedule of Allocation of Plan Assets [Table Text Block]



				Fair Value Measurements Using
Description	December 31 2013			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
		(millions)
Other Post-Retirement Benefit Plans
Equity securities		$	2.2		$	2.2		$	—		$	—
Fixed income securities
Fixed income fund ^(a)		74.6			0.2			74.4			—
U.S. Treasury		1.5			1.5			—			—
U.S. Agency, state and local obligations		4.4			—			4.4			—
U.S. corporate bonds ^(b)		8.6			—			8.6			—
Foreign corporate bonds		1.0			—			1.0			—
Cash equivalents		8.6			8.6			—			—
Other		0.3			—			0.3			—
Total		$	101.2		$	12.5		$	88.7		$	—



				Fair Value Measurements Using
Description	December 31 2012			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
		(millions)
Other Post-Retirement Benefit Plans
Equity securities		$	1.7		$	1.7		$	—		$	—
Fixed income securities
U.S. Treasury		13.7			13.7			—			—
U.S. Agency, state and local obligations		28.6			—			28.6			—
U.S. corporate bonds ^(b)		20.1			—			20.1			—
Foreign corporate bonds		2.2			—			2.2			—
Mutual funds		0.2			0.2			—			—
Total		$	66.5		$	15.6		$	50.9		$	—
Cash equivalents		23.8
Total Other Post-Retirement Benefit Plans		$	90.3

^(a)This category is comprised of $74.4 million of an institutional common/collective trust fund valued at daily NAV per share and $0.2 million of traded mutual funds valued at daily listed prices.

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

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

+ References+ Details

Equity Compensation (Tables)

12 Months Ended

Dec. 31, 2013

Equity compensation expense and associated income tax benefits

The following table summarizes Great Plains Energy's and KCP&L's equity compensation expense and the associated income tax benefit.



	2013		2012		2011
Great Plains Energy	(millions)
Equity compensation expense	$	5.6	$	3.3	$	5.2
Income tax benefit	1.9		1.4		1.9
KCP&L
Equity compensation expense	$	4.0	$	2.3	$	3.5
Income tax benefit	1.3		1.0		1.3

Performance share activity



	Performance Shares			Grant Date Fair Value*
Beginning balance January 1, 2013		370,560			$	23.05
Granted		226,967			24.17
Earned		(104,453	)		23.37
Forfeited		(11,523	)		22.82
Performance adjustment		(51,542	)		23.37
Ending balance December 31, 2013		430,009			23.52

* weighted-average

Restricted stock activity



	Nonvested Restricted Stock			Grant Date Fair Value*
Beginning balance January 1, 2013		277,439			$	19.03
Granted and issued		79,645			22.47
Vested		(64,405	)		17.88
Forfeited		(4,142	)		21.44
Ending balance December 31, 2013		288,537			20.18

* weighted-average

Director Deferred Share Units



	Share Units		Grant Date Fair Value*
Beginning balance January 1, 2013		69,818		$	20.36
Issued		20,302		22.95
Ending balance December 31, 2013		90,120		20.94

* weighted-average

Schedule of Debt [Table Text Block]

Tabular disclosure of an equity-based arrangement (such as stock or unit options and stock or unit awards) with an individual employee, which is generally an employment contract between the entity and a selected officer or key employee containing a promise by the employer to pay certain equity-based awards at future dates, sometimes including a period after retirement, upon compliance with stipulated requirements. This type of arrangement is distinguished from broader based employee benefit plans as it is usually tailored to the employee. Disclosure also typically includes the amount of related compensation expense recognized during the reporting period, the number of shares or units issued during the period under such arrangements, and the carrying amount as of the balance sheet date of the related liability.

+ References+ Details

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2013

Debt Disclosure [Abstract]

Great Plains Energy's and KCP&L's long-term debt is detailed in the following table.



		December 31
	Year Due	2013				2012
KCP&L			(millions)
General Mortgage Bonds
2.95% EIRR bonds^(a)	2015-2035		$	146.4			$	106.9
7.15% Series 2009A (8.59% rate)^(b)	2019		400.0				400.0
4.65% EIRR Series 2005	2035		50.0				50.0
5.375% Series 2007B			—				73.2
Senior Notes
5.85% Series (5.72% rate)^(b)	2017		250.0				250.0
6.375% Series (7.49% rate)^(b)	2018		350.0				350.0
3.15% Series	2023		300.0				—
6.05% Series (5.78% rate)^(b)	2035		250.0				250.0
5.30% Series	2041		400.0				400.0
EIRR Bonds
0.07% Series 2007A and 2007B^(c)	2035		146.5				—
2.875% Series 2008	2038		23.4				23.4
Other			—				2.6
Current maturities			—				(0.4		)
Unamortized discount			(4.1		)		(4.0		)
Total KCP&L excluding current maturities			2,312.2				1,901.7
Other Great Plains Energy
GMO First Mortgage Bonds 9.44% Series	2014-2021		9.0				10.1
GMO Pollution Control Bonds
0.113% Wamego Series 1996^(c)	2026		7.3				7.3
0.113% State Environmental 1993^(c)	2028		5.0				5.0
5.85% SJLP Pollution Control			—				5.6
GMO Senior Notes
8.27% Series	2021		80.9				80.9
3.49% Series A	2025		125.0				—
4.06% Series B	2033		75.0				—
4.74% Series C	2043		150.0				—
GMO Medium Term Notes
7.33% Series	2023		3.0				3.0
7.17% Series	2023		7.0				7.0
7.16% Series			—				6.0
Great Plains Energy Senior Notes
6.875% Series (7.33% rate)^(b)	2017		100.0				100.0
4.85% Series (7.34% rate)^(b)	2021		350.0				350.0
5.292% Series	2022		287.5				287.5
2.75% Series (3.67% rate)^(b)			—				250.0
Current maturities			(1.1		)		(262.7		)
Unamortized discount and premium, net			4.9				5.4
Total Great Plains Energy excluding current maturities			$	3,515.7			$	2,756.8


^(a)	Weighted-average interest rates at December 31, 2013


^(b)	Rate after amortizing gains/losses recognized in OCI on settlements of interest rate hedging instruments


^(c)	Variable rate

Amortization Of Debt Expense [Table Text Block]

Great Plains Energy's and KCP&L's amortization of debt expense is detailed in the following table.



	2013		2012		2011
	(millions)
KCP&L	$	3.2	$	2.9	$	3.6
Other Great Plains Energy	2.5		2.6		4.5
Total Great Plains Energy	$	5.7	$	5.5	$	8.1

Schedule of Maturities of Long-term Debt [Table Text Block]

Great Plains Energy's and KCP&L's long-term debt maturities for the next five years are detailed in the following table.



	2014		2015		2016		2017		2018
	(millions)
Great Plains Energy	$	1.1	$	15.1	$	1.1	$	382.1	$	351.1
KCP&L	—		14.0		—		281.0		350.0

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2013

Commitments and Contingencies Disclosure [Abstract]

Schedule of Rent Expense [Table Text Block]



	2013		2012		2011
	(millions)
Great Plains Energy	$	18.5	$	21.8	$	20.9
KCP&L	16.0		17.7		17.0

Unrecorded Unconditional Purchase Obligations And Lease Commitments [Table Text Block]

Great Plains Energy's and KCP&L's contractual commitments at December 31, 2013, excluding pensions and long-term debt, are detailed in the following tables.



Great Plains Energy
	2014		2015		2016		2017		2018		After 2018			Total
Lease commitments	(millions)
Operating lease	$	15.3	$	13.6	$	10.0	$	9.7	$	9.7		$	138.6		$	196.9
Capital lease	0.4		0.4		0.4		0.4		0.4			4.4			6.4
Purchase commitments
Fuel	381.8		195.0		143.8		142.8		117.2			90.2			1,070.8
Power	46.4		46.4		46.4		44.8		47.3			604.1			835.4
Capacity	3.3		3.0		1.2		—		—			—			7.5
La Cygne environmental project	205.5		7.3		—		—		—			—			212.8
Non-regulated natural gas transportation	3.5		3.5		3.5		1.0		—			—			11.5
Other	56.2		36.8		27.5		8.1		3.9			46.6			179.1
Total contractual commitments	$	712.4	$	306.0	$	232.8	$	206.8	$	178.5		$	883.9		$	2,520.4



KCP&L
	2014		2015		2016		2017		2018		After 2018			Total
Lease commitments	(millions)
Operating lease	$	13.5	$	12.2	$	9.9	$	9.7	$	9.7		$	138.6		$	193.6
Capital lease	0.2		0.2		0.2		0.2		0.2			2.2			3.2
Purchase commitments
Fuel	294.3		148.4		113.2		117.4		90.8			90.2			854.3
Power	34.8		34.8		34.8		34.8		34.8			429.4			603.4
Capacity	2.9		3.0		1.2		—		—			—			7.1
La Cygne environmental project	205.5		7.3		—		—		—			—			212.8
Other	54.0		27.1		26.7		7.2		3.0			38.1			156.1
Total contractual commitments	$	605.2	$	233.0	$	186.0	$	169.3	$	138.5		$	698.5		$	2,030.5

Derivative Instruments (Tables)

12 Months Ended

Dec. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Values of open positions for derivative instruments [Table Text Block]



	December 31
	2013					2012
	Notional Contract Amount		Fair Value			Notional Contract Amount		Fair Value
Great Plains Energy	(millions)
Futures contracts
Cash flow hedges	$	—	$	—		$	1.0	$	(0.2	)
Non-hedging derivatives	19.3		(0.6		)	17.9		(2.8		)
Forward contracts
Non-hedging derivatives	47.7		5.2			65.5		6.5
Transmission congestion rights
Non-hedging derivatives	22.9		1.7			—		—
Option contracts
Non-hedging derivatives	4.8		1.2			—		—
KCP&L
Futures contracts
Cash flow hedges	$	—	$	—		$	1.0	$	(0.2	)
Non-hedging derivatives	7.7		(0.2		)	—		—
Transmission congestion rights
Non-hedging derivatives	18.0		1.1			—		—

Fair value of open derivative positions, gross values before netting agreements and netting of cash collatral [Table Text Block]

Great Plains Energy

Balance Sheet

Asset Derivatives

Liability Derivatives

December 31, 2013

Classification

Fair Value

Derivatives Not Designated as Hedging Instruments

(millions)

Commodity contracts

Other

8.5

1.0

December 31, 2012

Derivatives Designated as Hedging Instruments

Commodity contracts

Other

—

0.2

Derivatives Not Designated as Hedging Instruments

Commodity contracts

Other

6.5

2.8

Total Derivatives

6.5

3.0

KCP&L

Balance Sheet

Asset Derivatives

Liability Derivatives

December 31, 2013

Classification

Fair Value

Derivatives Not Designated as Hedging Instruments

(millions)

Commodity contracts

Other

1.2

0.3

December 31, 2012

Derivatives Designated as Hedging Instruments

Commodity contracts

Other

—

0.2

Offsetting Derivative Assets and Liabilities [Table Text Block]



Great Plains Energy
											Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts Recognized			Gross Amounts Offset in the Statement of Financial Position				Net Amounts Presented in the Statement of Financial Position			Financial Instruments			Cash Collateral Received			Net Amount
December 31, 2013	(millions)
Derivative assets		$	8.5		$	(0.7	)		$	7.8		$	—		$	—		$	7.8
Derivative liabilities		1.0			(0.9		)		0.1			—			—			0.1
December 31, 2012
Derivative assets		$	6.5		$	—			$	6.5		$	—		$	—		$	6.5
Derivative liabilities		3.0			(3.0		)		—			—			—			—



KCP&L
											Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts Recognized			Gross Amounts Offset in the Statement of Financial Position				Net Amounts Presented in the Statement of Financial Position			Financial Instruments			Cash Collateral Received			Net Amount
December 31, 2013	(millions)
Derivative assets		$	1.2		$	(0.1	)		$	1.1		$	—		$	—		$	1.1
Derivative liabilities		0.3			(0.3		)		—			—			—			—
December 31, 2012
Derivative liabilities		$	0.2		$	(0.2	)		$	—		$	—		$	—		$	—

Gain (loss) recognized in other comprehensive income or earnings for interest rate and commodity hedges [Table Text Block]



Great Plains Energy
Derivatives in Cash Flow Hedging Relationship
					Gain (Loss) Reclassified from
					Accumulated OCI into Income
					(Effective Portion)
	Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)				Income Statement Classification	Amount
2013	(millions)					(millions)
Interest rate contracts		$	—		Interest charges	$	(18.6	)
Commodity contracts		—			Fuel	(0.3		)
Income tax benefit		—			Income tax benefit	7.3
Total		$	—		Total	$	(11.6	)
2012
Interest rate contracts		$	—		Interest charges	$	(20.2	)
Commodity contracts		(0.1		)	Fuel	(0.5		)
Income tax benefit		—			Income tax benefit	8.1
Total		$	(0.1	)	Total	$	(12.6	)



KCP&L
Derivatives in Cash Flow Hedging Relationship
					Gain (Loss) Reclassified from
					Accumulated OCI into Income
					(Effective Portion)
	Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)				Income Statement Classification	Amount
2013	(millions)					(millions)
Interest rate contracts		$	—		Interest charges	$	(8.8	)
Commodity contracts		—			Fuel	(0.3		)
Income tax benefit		—			Income tax benefit	3.5
Total		$	—		Total	$	(5.6	)
2012
Interest rate contracts		$	—		Interest charges	$	(8.7	)
Commodity contracts		(0.1		)	Fuel	(0.5		)
Income tax benefit		—			Income tax benefit	3.5
Total		$	(0.1	)	Total	$	(5.7	)

Gain (loss) recognized in a regulatory balance sheet account or earnings for utility commodity hedges [Table Text Block]



Great Plains Energy
Derivatives in Regulatory Account Relationship
					Gain (Loss) Reclassified from
					Regulatory Account
	Amount of Gain (Loss) Recognized in Regulatory Asset on Derivatives				Income Statement Classification	Amount
2013	(millions)					(millions)
Commodity contracts		$	2.0		Fuel	$	(1.9	)
Total		$	2.0		Total	$	(1.9	)
2012
Commodity contracts		$	(2.7	)	Fuel	$	(6.6	)
Total		$	(2.7	)	Total	$	(6.6	)

Accumulated other comprehensive income related to cash flow hedges [Table Text Block]



	Great Plains Energy								KCP&L
	December 31								December 31
	2013				2012				2013				2012
		(millions)
Current assets		$	9.9			$	10.6			$	9.9			$	10.6
Current liabilities		(48.9		)		(68.4		)		(43.1		)		(52.8		)
Noncurrent liabilities		—				(0.1		)		—				(0.1		)
Deferred income taxes		15.2				22.5				13.0				16.5
Total		$	(23.8	)		$	(35.4	)		$	(20.2	)		$	(25.8	)

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

Fair value of assets and liabilities

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

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+ Details

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Fair Value Disclosures [Abstract]



Description	December 31 2013				Netting^(e)				Level 1			Level 2				Level 3
KCP&L		(millions)
Assets
Nuclear decommissioning trust ^(a)
Equity securities		$	127.7			$	—			$	127.7		$	—			$	—
Debt securities
U.S. Treasury		21.2				—				21.2			—				—
U.S. Agency		2.8				—				—			2.8				—
State and local obligations		3.9				—				—			3.9				—
Corporate bonds		24.4				—				—			24.4				—
Foreign governments		0.5				—				—			0.5				—
Cash equivalents		3.8				—				3.8			—				—
Other		(0.4		)		—				—			(0.4		)		—
Total nuclear decommissioning trust		183.9				—				152.7			31.2				—
Self-insured health plan trust ^(b)
Equity securities		0.9				—				0.9			—				—
Debt securities		9.3				—				0.5			8.8				—
Cash and cash equivalents		3.4				—				3.4			—				—
Other		1.2				—				—			1.2				—
Total self-insured health plan trust		14.8				—				4.8			10.0				—
Derivative instruments ^(c)		1.1				(0.1		)		0.1			—				1.1
Total		199.8				(0.1		)		157.6			41.2				1.1
Liabilities
Derivative instruments ^(c)		—				(0.3		)		0.3			—				—
Total		$	—			$	(0.3	)		$	0.3		$	—			$	—
Other Great Plains Energy
Assets
Derivative instruments ^(c)		$	6.7			$	(0.6	)		$	0.2		$	4.9			$	2.2
SERP rabbi trusts ^(d)
Equity securities		0.1				—				0.1			—				—
Fixed income funds		18.6				—				—			18.6				—
Total SERP rabbi trusts		18.7				—				0.1			18.6				—
Total		25.4				(0.6		)		0.3			23.5				2.2
Liabilities
Derivative instruments ^(c)		0.1				(0.6		)		0.6			0.1				—
Total		$	0.1			$	(0.6	)		$	0.6		$	0.1			$	—
Great Plains Energy
Assets
Nuclear decommissioning trust ^(a)		$	183.9			$	—			$	152.7		$	31.2			$	—
Self-insured health plan trust ^(b)		14.8				—				4.8			10.0				—
Derivative instruments ^(c)		7.8				(0.7		)		0.3			4.9				3.3
SERP rabbi trusts ^(d)		18.7				—				0.1			18.6				—
Total		225.2				(0.7		)		157.9			64.7				3.3
Liabilities
Derivative instruments ^(c)		0.1				(0.9		)		0.9			0.1				—
Total		$	0.1			$	(0.9	)		$	0.9		$	0.1			$	—



Description	December 31 2012			Netting^(e)				Level 1			Level 2			Level 3
KCP&L		(millions)
Assets
Nuclear decommissioning trust ^(a)
Equity securities		$	100.1		$	—			$	100.1		$	—		$	—
Debt securities
U.S. Treasury		18.5			—				18.5			—			—
U.S. Agency		2.8			—				—			2.8			—
State and local obligations		3.3			—				—			3.3			—
Corporate bonds		26.8			—				—			26.8			—
Other		0.3			—				—			0.3			—
Total nuclear decommissioning trust		151.8			—				118.6			33.2			—
Total		151.8			—				118.6			33.2			—
Liabilities
Derivative instruments ^(c)		—			(0.2		)		0.2			—			—
Total		$	—		$	(0.2	)		$	0.2		$	—		$	—
Other Great Plains Energy
Assets
Derivative instruments ^(c)		$	6.5		$	—			$	—		$	4.2		$	2.3
SERP rabbi trusts ^(d)
Equity securities		0.1			—				0.1			—			—
Fixed income funds		20.2			—				—			20.2			—
Total SERP rabbi trusts		20.3			—				0.1			20.2			—
Total		26.8			—				0.1			24.4			2.3
Liabilities
Derivative instruments ^(c)		—			(2.8		)		2.8			—			—
Total		$	—		$	(2.8	)		$	2.8		$	—		$	—
Great Plains Energy
Assets
Nuclear decommissioning trust ^(a)		$	151.8		$	—			$	118.6		$	33.2		$	—
Derivative instruments ^(c)		6.5			—				—			4.2			2.3
SERP rabbi trusts ^(d)		20.3			—				0.1			20.2			—
Total		178.6			—				118.7			57.6			2.3
Liabilities
Derivative instruments ^(c)		—			(3.0		)		3.0			—			—
Total		$	—		$	(3.0	)		$	3.0		$	—		$	—


^(a)	Fair value is based on quoted market prices of the investments held by the fund and/or valuation models. The total does not include $2.9 million of cash and cash equivalents at December 31, 2012.


^(b)	Fair value is based on quoted market prices of the investments held by the trust. Debt securities classified as Level 1 are comprised of U.S. Treasury securities. Debt securities classified as Level 2 are comprised of corporate bonds, U.S. Agency, state and local obligations, and other asset-backed securities.

^(c)


^(d)	Fair value is based on quoted market prices and/or valuation models for equity securities and NAV per share for fixed income funds.


^(e)	Represents the difference between derivative contracts in an asset or liability position presented on a net basis by counterparty on the consolidated balance sheets where a master netting agreement exists between the Company and the counterparty. At December 31, 2013 and 2012, Great Plains Energy netted $0.2 million and $3.0 million, respectively, of cash collateral posted with counterparties.

Unobservable inputs reconciliation



Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
Description	Real Estate			Hedge Funds			Total
	(millions)
Balance January 1, 2013		$	38.4		$	21.6		$	60.0
Actual return on plan assets
Relating to assets still held		4.6			1.5			6.1
Purchase, sales and settlements		0.7			—			0.7
Balance December 31, 2013		$	43.7		$	23.1		$	66.8



Great Plains Energy
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative Instruments
	2013			2012
	(millions)
Balance at January 1	$	2.3		$	3.1
Total realized/unrealized gains included in non-operating income	9.5			8.2
Purchases	1.7			—
Settlements	(10.2		)	(9.0		)
Balance at December 31	$	3.3		$	2.3
Total unrealized losses included in non-operating income relating to assets still on the
consolidated balance sheet at December 31	$	(0.3	)	$	(0.4	)



KCP&L
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative
	Instruments
	2013
	(millions)
Balance at January 1	$	—
Purchases	1.1
Balance at December 31	$	1.1



Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
Description	Real Estate			Hedge Funds				Total
	(millions)
Balance January 1, 2012		$	34.7		$	21.7			$	56.4
Actual return on plan assets
Relating to assets still held		1.6			0.6				2.2
Relating to assets sold		1.3			(0.4		)		0.9
Purchase, sales and settlements		0.8			(0.3		)		0.5
Balance December 31, 2012		$	38.4		$	21.6			$	60.0

Accumulated Other Comprehensive Income (Loss) [Abstract]

+ References+ Details

Accumulated Other Comprehensive Income (Loss) (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]



Great Plains Energy
	Gains and Losses on Cash Flow Hedges^(a)				Defined Benefit Pension Items^(a)				Total^(a)
	(millions)
Beginning balance January 1, 2013		$	(35.4	)		$	(3.0	)	$	(38.4	)
Other comprehensive income before reclassifications		—				1.2			1.2
Amounts reclassified from accumulated other comprehensive loss		11.6				0.3			11.9
Net current period other comprehensive income		11.6				1.5			13.1
Ending balance December 31, 2013		$	(23.8	)		$	(1.5	)	$	(25.3	)

^(a) Net of tax



KCP&L
	Gains and Losses on Cash Flow Hedges^(a)
	(millions)
Beginning balance January 1, 2013		$	(25.8	)
Amounts reclassified from accumulated other comprehensive loss		5.6
Net current period other comprehensive income		5.6
Ending balance December 31, 2013		$	(20.2	)

^(a) Net of tax

Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]



Great Plains Energy
Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified from Accumulated Other Comprehensive Loss				Affected Line Item in the Income Statement
2013	(millions)
Gains and (losses) on cash flow hedges (effective portion)
Interest rate contracts		$	(18.6	)	Interest charges
Commodity contracts		(0.3		)	Fuel
		(18.9		)	Income before income tax expense and loss from equity investments
		7.3			Income tax benefit
		$	(11.6	)	Net income
Amortization of defined benefit pension items
Net losses included in net periodic benefit costs		$	(0.5	)	Utility operating and maintenance expenses
		(0.5		)	Income before income tax expense and loss from equity investments
		0.2			Income tax benefit
		(0.3		)	Net income

Total reclassifications, net of tax		$	(11.9	)	Net income



KCP&L
Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified from Accumulated Other Comprehensive Loss				Affected Line Item in the Income Statement
2013	(millions)
Gains and (losses) on cash flow hedges (effective portion)
Interest rate contracts		$	(8.8	)	Interest charges
Commodity contracts		(0.3		)	Fuel
		(9.1		)	Income before income tax expense
		3.5			Income tax benefit
Total reclassifications, net of tax		$	(5.6	)	Net income

Taxes (Tables)

12 Months Ended

Dec. 31, 2013

Income Tax Disclosure [Abstract]

Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]



Great Plains Energy	2013			2012			2011
Current income taxes	(millions)
Federal	$	0.3		$	(3.2	)	$	2.9
State	(3.0		)	(6.3		)	(6.0		)
Foreign	—			—			(0.4		)
Total	(2.7		)	(9.5		)	(3.5		)
Deferred income taxes
Federal	109.1			96.3			90.5
State	24.9			24.9			20.7
Total	134.0			121.2			111.2
Noncurrent income taxes
Federal	—			(0.2		)	(18.0		)
State	(0.3		)	(0.3		)	(2.1		)
Foreign	(0.4		)	(4.2		)	(0.6		)
Total	(0.7		)	(4.7		)	(20.7		)
Investment tax credit
Deferral	0.3			—			—
Amortization	(1.7		)	(2.4		)	(2.2		)
Total	(1.4		)	(2.4		)	(2.2		)
Income tax expense	$	129.2		$	104.6		$	84.8



KCP&L	2013			2012			2011
Current income taxes	(millions)
Federal	$	(0.5	)	$	13.1		$	1.0
State	(0.5		)	2.0			(0.6		)
Total	(1.0		)	15.1			0.4
Deferred income taxes
Federal	75.8			48.8			66.0
State	16.3			11.4			14.6
Total	92.1			60.2			80.6
Noncurrent income taxes
Federal	(9.0		)	1.7			(9.3		)
State	(1.5		)	0.1			(1.1		)
Total	(10.5		)	1.8			(10.4		)
Investment tax credit
Deferral	0.3			—			—
Amortization	(1.1		)	(1.8		)	(1.5		)
Total	(0.8		)	(1.8		)	(1.5		)
Income tax expense	$	79.8		$	75.3		$	69.1

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]



Great Plains Energy	2013		2012		2011
Federal statutory income tax rate	35.0	%	35.0	%	35.0	%
Differences between book and tax depreciation not normalized	(0.3	)	1.2		1.5
Amortization of investment tax credits	(0.4	)	(0.8	)	(0.8	)
Federal income tax credits	(3.5	)	(3.1	)	(5.0	)
State income taxes	3.8		4.0		4.0
Changes in uncertain tax positions, net	(0.2	)	(1.5	)	(1.7	)
Valuation allowance	—		—		(0.8	)
Other	(0.4	)	(0.5	)	0.5
Effective income tax rate	34.0	%	34.3	%	32.7	%



KCP&L	2013		2012		2011
Federal statutory income tax rate	35.0	%	35.0	%	35.0	%
Differences between book and tax depreciation not normalized	(0.8	)	1.3		1.6
Amortization of investment tax credits	(0.4	)	(0.8	)	(0.7	)
Federal income tax credits	(5.3	)	(4.3	)	(6.3	)
State income taxes	3.7		4.1		3.9
Changes in uncertain tax positions, net	—		—		0.1
Other	(0.1	)	(0.6	)	0.2
Effective income tax rate	32.1	%	34.7	%	33.8	%

Schedule of Deferred Tax Assets and Liabilities [Table Text Block]



	Great Plains Energy						KCP&L
December 31	2013			2012			2013			2012
Current deferred income tax asset (liability)	(millions)
Net operating loss carryforward	$	76.6		$	77.8		$	—		$	—
Other	5.7			12.7			(1.7		)	4.6
Net current deferred income tax asset (liability) before valuation allowance	82.3			90.5			(1.7		)	4.6
Valuation allowance	(2.0		)	(2.0		)	—			—
Net current deferred income tax asset (liability)	80.3			88.5			(1.7		)	4.6
Noncurrent deferred income taxes
Plant related	(1,433.8		)	(1,297.2		)	(1,022.9		)	(930.7		)
Income taxes on future regulatory recoveries	(136.4		)	(138.3		)	(111.0		)	(114.7		)
Derivative instruments	32.3			37.7			23.4			27.4
Pension and post-retirement benefits	(28.2		)	(26.6		)	(1.7		)	(3.4		)
SO₂emission allowance sales	28.8			29.7			28.8			30.4
Tax credit carryforwards	229.3			217.5			139.6			126.3
Customer demand programs	(27.7		)	(28.7		)	(19.4		)	(19.2		)
Net operating loss carryforward	446.7			439.4			71.6			72.4
Other	(57.1		)	(44.1		)	(30.5		)	(24.9		)
Net noncurrent deferred income tax liability before valuation allowance	(946.1		)	(810.6		)	(922.1		)	(836.4		)
Valuation allowance	(18.7		)	(21.8		)	—			—
Net noncurrent deferred income tax liability	(964.8		)	(832.4		)	(922.1		)	(836.4		)
Net deferred income tax liability	$	(884.5	)	$	(743.9	)	$	(923.8	)	$	(831.8	)



	Great Plains Energy						KCP&L
December 31	2013			2012			2013			2012
	(millions)
Gross deferred income tax assets	$	1,148.2		$	1,209.8		$	583.0		$	656.9
Gross deferred income tax liabilities	(2,032.7		)	(1,953.7		)	(1,506.8		)	(1,488.7		)
Net deferred income tax liability	$	(884.5	)	$	(743.9	)	$	(923.8	)	$	(831.8	)

Summary of Income Tax Contingencies [Table Text Block]



	Great Plains Energy									KCP&L
	2013			2012			2011			2013			2012			2011
	(millions)
Beginning balance January 1	$	21.4		$	24.0		$	42.0		$	10.5		$	8.7		$	19.1
Additions for current year tax positions	—			3.7			1.4			—			3.6			—
Reductions for current year tax positions	(0.3		)	—			—			—			—			—
Additions for prior year tax positions	—			—			2.4			—			—			2.3
Reductions for prior year tax positions	(10.5		)	(1.8		)	(20.9		)	(10.5		)	(1.6		)	(12.6		)
Statute expirations	(0.3		)	(4.7		)	(0.7		)	—			(0.2		)	(0.1		)
Foreign currency translation adjustments	(0.5		)	0.2			(0.2		)	—			—			—
Ending balance December 31	$	9.8		$	21.4		$	24.0		$	—		$	10.5		$	8.7

Segment Financial Information [Table Text Block]

Tabular disclosure of tax positions taken in the tax returns filed or to be filed for which it is more likely than not that the tax position will not be sustained upon examination by taxing authorities (i.e., uncertain tax positions) and other types of income tax contingencies, including: (1) the policy on classification of interest and penalties; (2) a tabular reconciliation of the total amounts of unrecognized tax benefits at the beginning and end of the period; the total amount(s) of: (3) unrecognized tax benefits that, if recognized, would affect the effective tax rate, and (4) interest and penalties recognized in each of the income statement and balance sheet; (5) for positions for which it is reasonably possible that the total amounts unrecognized will significantly change within 12 months of the reporting date the: (i) nature of the uncertainty, (ii) nature of the event that could occur that would cause the change, and (iii) an estimate of the range of the reasonably possible change or a statement that an estimate of the range cannot be made; and (6) a description of tax years that remain subject to examination by major tax jurisdictions.

+ References+ Details

Segments and Related Information (Tables)

12 Months Ended

Dec. 31, 2013

Segment Reporting [Abstract]



2013	Electric Utility				Other				Eliminations			Great Plains Energy
		(millions)
Operating revenues		$	2,446.3			$	—			$	—		$	2,446.3
Depreciation and amortization		(289.7		)		—				—			(289.7		)
Interest charges		(190.5		)		(55.5		)		47.6			(198.4		)
Income tax (expense) benefit		(135.4		)		6.2				—			(129.2		)
Net income (loss) attributable to Great Plains Energy		257.1				(6.9		)		—			250.2



2012	Electric Utility				Other				Eliminations			Great Plains Energy
		(millions)
Operating revenues		$	2,309.9			$	—			$	—		$	2,309.9
Depreciation and amortization		(272.3		)		—				—			(272.3		)
Interest charges		(197.3		)		(67.3		)		43.8			(220.8		)
Income tax (expense) benefit		(122.0		)		17.4				—			(104.6		)
Net income (loss) attributable to Great Plains Energy		216.6				(16.7		)		—			199.9



2011	Electric Utility				Other				Eliminations			Great Plains Energy
		(millions)
Operating revenues		$	2,318.0			$	—			$	—		$	2,318.0
Depreciation and amortization		(273.1		)		—				—			(273.1		)
Interest charges		(176.9		)		(67.2		)		25.7			(218.4		)
Income tax (expense) benefit		(109.3		)		24.5				—			(84.8		)
Net income (loss) attributable to Great Plains Energy		199.9				(25.5		)		—			174.4



	Electric Utility			Other			Eliminations				Great Plains Energy
2013		(millions)
Assets		$	10,019.6		$	105.6		$	(329.8	)		$	9,795.4
Capital expenditures		669.0			—			—				669.0
2012
Assets		$	9,910.6		$	122.4		$	(385.7	)		$	9,647.3
Capital expenditures		610.2			—			—				610.2
2011
Assets		$	9,483.4		$	51.9		$	(417.3	)		$	9,118.0
Capital expenditures		456.6			—			—				456.6

Jointly Owned Electric Utility Plants [Abstract]

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

+ References+ Details

Jointly Owned Electric Utility Plants (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Jointly Owned Utility Plants [Table Text Block]



Great Plains Energy
	Wolf Creek Unit			La Cygne Units			Iatan No. 1 Unit			Iatan No. 2 Unit			Iatan Common			Jeffrey Energy Center
	(millions, except MW amounts)
Great Plains Energy's share		47%			50%			88%			73%			79%			8%

Utility plant in service		$	1,550.8		$	542.6		$	645.3		$	1,298.0		$	428.9		$	165.7
Accumulated depreciation		813.6			314.4			245.7			319.4			87.3			75.4
Nuclear fuel, net		62.8			—			—			—			—			—
Construction work in progress		146.4			390.3			8.1			14.9			24.4			13.8
2014 accredited capacity-MWs		547			709			627			641			NA			172



KCP&L
	Wolf Creek Unit			La Cygne Units			Iatan No. 1 Unit			Iatan No. 2 Unit			Iatan Common
	(millions, except MW amounts)
KCP&L's share		47%			50%			70%			55%			61%

Utility plant in service		$	1,550.8		$	542.6		$	515.4		$	987.2		$	347.3
Accumulated depreciation		813.6			314.4			196.8			297.5			79.3
Nuclear fuel, net		62.8			—			—			—			—
Construction work in progress		146.4			390.3			1.8			11.0			3.5
2014 accredited capacity-MWs		547			709			499			482			NA

Quarterly Financial Information Disclosure [Abstract]

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

+ References+ Details

Quarterly Operating Results (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Quarterly Financial Information [Table Text Block]



	Quarter
Great Plains Energy	1st			2nd		3rd		4th
2013	(millions, except per share amounts)
Operating revenue	$	542.2		$	600.3	$	765.0	$	538.8
Operating income	86.1			143.6		271.7		67.8
Net income	26.0			63.6		143.1		17.5
Basic and diluted earnings per common share	0.17			0.41		0.93		0.11
2012
Operating revenue	$	479.7		$	603.6	$	746.2	$	480.4
Operating income	49.0			150.0		277.0		62.9
Net income (loss)	(9.3		)	58.1		146.4		4.7
Net income (loss) attributable to Great Plains Energy	(9.1		)	58.1		146.2		4.7
Basic and diluted earnings (loss) per common share	(0.07		)	0.41		0.95		0.03



	Quarter
KCP&L	1st		2nd		3rd		4th
2013	(millions)
Operating revenue	$	366.7	$	410.8	$	522.0	$	371.9
Operating income	52.3		93.4		176.8		40.0
Net income	16.2		44.2		96.4		12.2
2012
Operating revenue	$	327.0	$	409.1	$	508.0	$	335.8
Operating income	31.6		99.9		177.8		39.4
Net income	2.3		43.7		90.2		5.4

Summary of Significant Accounting Policies Antidilutive Securities (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Performance Shares [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	548,242	0	50,897
Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	2,228	3,781	43,641
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0	0	6,000

Securities (including those issuable pursuant to contingent stock agreements) that could potentially dilute basic earnings per share (EPS) or earnings per unit (EPU) in the future that were not included in the computation of diluted EPS or EPU because to do so would increase EPS or EPU amounts or decrease loss per share or unit amounts for the period presented.

+ References+ Details

Summary of Significant Accounting Policies Earnings Per Share (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income [Abstract]
Net income (loss)	$ 17.5	$ 143.1	$ 63.6	$ 26.0	$ 4.7	$ 146.4	$ 58.1	$ (9.3)	$ 250.2	$ 199.9	$ 174.2
Less: net income (loss) attributable to noncontrolling interest									0	0	(0.2)
Less: preferred stock dividend requirements									1.6	1.6	1.6
Earnings (loss) available for common shareholders									$ 248.6	$ 198.3	$ 172.8
Common Shares Outstanding [Abstract]
Average number of common shares outstanding (in shares)									153.5	145.5	135.6
Add: effect of dilutive securities (in shares)									0.2	1.7	3.1
Diluted average number of common shares outstanding (in shares)									153.7	147.2	138.7
Earnings Per Share [Abstract]
Earnings Per Share, Basic									$ 1.62	$ 1.36	$ 1.27
Earnings Per Share, Diluted									$ 1.62	$ 1.35	$ 1.25
Earnings Per Share, Basic and Diluted	$ 0.11	$ 0.93	$ 0.41	$ 0.17	$ 0.03	$ 0.95	$ 0.41	$ (0.07)

Summary of Significant Accounting Policies Fair Value of Financial Instruments (Details) (USD $) In Billions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Fair value of financial instruments [Abstract]
Long-term Debt	$ 3.5	$ 3.0
Carrying (Reported) Amount, Fair Value Disclosure [Member] \| Kansas City Power and Light Company [Member]
Fair value of financial instruments [Abstract]
Long-term Debt	2.3	1.9
Estimate of Fair Value Measurement [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair value of financial instruments [Abstract]
Long-term Debt, Fair Value	3.7	3.5
Estimate of Fair Value Measurement [Member] \| Fair Value, Inputs, Level 2 [Member] \| Kansas City Power and Light Company [Member]
Fair value of financial instruments [Abstract]
Long-term Debt, Fair Value	$ 2.5	$ 2.2

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

Carrying amount of long-term debt, net of unamortized discount or premium, including current and noncurrent amounts. Includes, but not limited to, notes payable, bonds payable, debentures, mortgage loans and commercial paper. Excludes capital lease obligations.

+ References+ Details

Summary of Significant Accounting Policies Subsequent Events (Details) (Dividend Declared [Member], USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 11, 2014
Kansas City Power and Light Company [Member]
Dividends Declared [Abstract]
Dividends Payable, Amount Per Share		$ 18,000,000
Subsequent Event, Description	KCP&L’s Board of Directors declared a cash dividend payable to Great Plains Energy
Common Stock [Member]
Dividends Declared [Abstract]
Dividends Payable, Amount Per Share		$ 0.23
Subsequent Event, Description	Great Plains Energy's Board of Directors (Board) declared a quarterly dividend
Preferred Stock [Member]
Dividends Declared [Abstract]
Subsequent Event, Description	The Board also declared regular dividends on Great Plains Energy's preferred stock

Summary of Significant Accounting Policies Summary of Significant Accounting Policies Utility Plant (Details) (USD $)
In Millions, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service

3.00%

Depreciation

$ 265.4

$ 251.4

$ 239.9

289.7

272.3

273.1

Public Utilities, Property, Plant and Equipment, Generation or Processing

6,874.6

6,697.1

Public Utilities, Property, Plant and Equipment, Transmission

794.0

754.0

Public Utilities, Property, Plant and Equipment, Distribution

3,149.4

3,019.6

Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment

757.3

689.8

Public Utilities, Property, Plant and Equipment, Plant in Service

11,575.3

^[1]

11,160.5

^[1]

Minimum [Member]

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

Public Utilities, Property, Plant and Equipment, Generation, Useful Life

20 years

Public Utilities, Property, Plant and Equipment, Transmission, Useful Life

15 years

Public Utilities, Property, Plant and Equipment, Distribution, Useful Life

8 years

Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life

5 years

Maximum [Member]

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

Public Utilities, Property, Plant and Equipment, Generation, Useful Life

60 years

Public Utilities, Property, Plant and Equipment, Transmission, Useful Life

70 years

Public Utilities, Property, Plant and Equipment, Distribution, Useful Life

66 years

Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life

50 years

Land and other assets not depreciated [Member]

Public Utilities, Property, Plant and Equipment, Plant in Service

107.8

104.5

Kansas City Power and Light Company [Member]

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

Depreciation

179.2

168.0

162.0

Public Utilities, Allowance for Funds Used During Construction, Rate

198.3

185.6

193.1

6.10%

2.00%

2.90%

Public Utilities, Property, Plant and Equipment, Generation or Processing

5,288.3

5,140.0

Public Utilities, Property, Plant and Equipment, Transmission

433.7

414.7

Public Utilities, Property, Plant and Equipment, Distribution

1,970.2

1,893.8

Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment

582.7

522.9

Public Utilities, Property, Plant and Equipment, Plant in Service

8,274.9

^[2]

7,971.4

^[2]

Kansas City Power and Light Company [Member] | Minimum [Member]

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

Public Utilities, Property, Plant and Equipment, Generation, Useful Life

20 years

Public Utilities, Property, Plant and Equipment, Transmission, Useful Life

15 years

Public Utilities, Property, Plant and Equipment, Distribution, Useful Life

8 years

Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life

5 years

Kansas City Power and Light Company [Member] | Maximum [Member]

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

Public Utilities, Property, Plant and Equipment, Generation, Useful Life

60 years

Public Utilities, Property, Plant and Equipment, Transmission, Useful Life

70 years

Public Utilities, Property, Plant and Equipment, Distribution, Useful Life

55 years

Public Utilities, Property, Plant and Equipment, Other Property Plant and Equipment, Useful Life

50 years

Kansas City Power and Light Company [Member] | Land and other assets not depreciated [Member]

Public Utilities, Property, Plant and Equipment, Plant in Service

$ 54.1

$ 54.7

KCPL Greater Missouri Operations [Member]

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

Public Utilities, Allowance for Funds Used During Construction, Rate

2.10%

2.40%

5.40%

[1]	Includes $107.8 million and $104.5 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.
[2]	Includes $54.1 million and $54.7 million at December 31, 2013 and 2012, respectively, of land and other assets that are not depreciated.

Summary of Significant Accounting Policies Equity Method Investment (Details) (Transource Energy, LLC [Member])	12 Months Ended
	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Description of Principal Activities	Transource is focused on the development of competitive electric transmission projects.
GPE Transmission Holding Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	13.50%
AEP Transmission Holding Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Percentage of Majority Owner	86.50%

Supplemental Cash Flow Information (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows affected by changes in:
Receivables	$ (7.1)	$ 76.8	$ 3.6
Accounts receivable pledged as collateral	(1.0)	(79.0)	0
Fuel inventories	18.7	(6.1)	(3.9)
Materials and supplies	(1.0)	(11.0)	(7.5)
Accounts payable	26.4	57.3	5.7
Accrued taxes	2.2	(7.8)	1.4
Accrued interest	3.9	(35.2)	1.5
Deferred refueling outage costs	(17.6)	15.6	(17.9)
Pension and post-retirement benefit obligations	31.3	14.4	(56.0)
Allowance for equity funds used during construction	(14.1)	(1.3)	(1.0)
Interest rate hedge settlement	0	0	(26.1)
Fuel recovery mechanism	(1.3)	22.5	(1.7)
Uncertain tax positions	(0.8)	(4.7)	(20.8)
Other operating activities	(15.5)	(29.8)	(24.8)
Total other operating activities	24.1	11.7	(147.5)
Cash paid during the period:
Interest Paid, Net	170.8	247.9	254.4
Income Taxes Paid	0	3.3	2.8
Non-cash investing activities:
Liabilities accrued for capital expenditures	48.1	57.5	39.7
Kansas City Power and Light Company [Member]
Cash flows affected by changes in:
Receivables	(12.6)	8.8	(20.2)
Accounts receivable pledged as collateral	0	(15.0)	0
Fuel inventories	13.3	(4.6)	(14.1)
Materials and supplies	1.1	(9.0)	(6.7)
Accounts payable	7.3	48.3	11.0
Accrued taxes	(3.7)	(2.0)	2.7
Accrued interest	1.4	(2.3)	3.8
Deferred refueling outage costs	(17.6)	15.6	(17.9)
Pension and post-retirement benefit obligations	35.7	18.0	(45.6)
Allowance for equity funds used during construction	(14.1)	(1.3)	(0.7)
Fuel recovery mechanism	(1.8)	5.1	(5.8)
Uncertain tax positions	(10.5)	1.8	(10.4)
Other operating activities	(7.7)	(35.5)	(14.4)
Total other operating activities	(9.2)	27.9	(118.3)
Cash paid during the period:
Interest Paid, Net	111.7	118.0	111.3
Income Taxes Paid	4.6	18.0	0.1
Non-cash investing activities:
Liabilities accrued for capital expenditures	$ 40.5	$ 48.4	$ 32.0

Receivables (Details) (USD $)
In Millions, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

$ 0

(0.2)

^[1]

(0.9)

^[1]

(1.9)

(1.7)

Cash received from (paid for) receivables purchased

Kansas City Power and Light Company [Member]

(0.1)

^[1]

0.1

^[1]

(1.2)

Cash received from (paid for) receivables purchased

Kansas City Power And Light Company Unconsolidated [Member]

(1,517.2)

(1,436.0)

(19.2)

^[1]

(18.2)

^[1]

2.6

2.5

Cash received from (paid for) receivables purchased

(1,516.2)

(1,452.4)

1,497.2

1,434.2

0.3

KCPL Receivables Company [Member]

1,517.2

1,436.0

19.1

^[1]

18.3

^[1]

(2.6)

(2.5)

(1.2)

Cash received from (paid for) receivables purchased

1,516.2

1,452.4

(1,497.2)

(1,434.2)

(0.3)

KCPL Greater Missouri Operations [Member]

(834.7)

(597.8)

(10.6)

^[1]

(7.6)

^[1]

1.4

0.9

Cash received from (paid for) receivables purchased

(830.9)

(524.0)

820.5

517.5

0.1

GMO Receivables Company Member

834.7

597.8

10.5

^[1]

6.6

^[1]

(1.4)

(0.9)

(0.7)

(0.5)

Cash received from (paid for) receivables purchased

830.9

524.0

(820.5)

(517.5)

$ (0.1)

[1]	Any net gain (loss) is the result of the timing difference inherent in collecting receivables and over the life of the agreement will net to zero.

Receivables Accounts, Notes, and Financing (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Accounts, Notes, Loans and Financing Receivable [Line Items]
Allowance for doubtful accounts	$ (2.5)	$ (2.6)
Other Receivables, Gross, Current	88.6	98.8
Receivables, net	162.2	154.5
Kansas City Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Allowance for doubtful accounts	(1.1)	(1.5)
Other Receivables, Gross, Current	77.8	81.8
Receivables, net	179.6	163.2
Intercompany receivables	50.4	40.0
Trade Accounts Receivable [Member] \| Billed Revenues [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Gross, Current	1.5	0
Trade Accounts Receivable [Member] \| Billed Revenues [Member] \| Kansas City Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Gross, Current	1.3	0
Trade Accounts Receivable [Member] \| Unbilled Revenues [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Gross, Current	74.6	58.3
Trade Accounts Receivable [Member] \| Unbilled Revenues [Member] \| Kansas City Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Gross, Current	$ 51.2	$ 42.9

Amount of receivables arising from transactions with related parties due within one year or the normal operating cycle, if longer.

+ References+ Details

Receivables Narrative (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Accounts receivable pledged as collateral	$ 175.0	$ 174.0
Transfers Accounted for as Secured Borrowings, Associated Liabilities, Carrying Amount	175.0	174.0
Kansas City Power and Light Company [Member]
Accounts receivable pledged as collateral	110.0	110.0
Transfers Accounted for as Secured Borrowings, Associated Liabilities, Carrying Amount	110.0	110.0
Contractually Specified Servicing Fees Percentage Amount	1.50%
Maximum amount of outstanding principal under receivables agreement	110
KCPL Greater Missouri Operations [Member]
Contractually Specified Servicing Fees Percentage Amount	1.25%
Maximum amount of outstanding principal under receivables agreement from June 1 to October 31 of each year	80
Maximum amount of outstanding principal under receivables agreement from November 1 to May 31 of each year	$ 65

Nuclear Plant (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Investments in decommissioning trust fund [Line Items]
Cost Basis	$ 138.1	$ 130.4
Gross Unrealized Gains	47.1	26.0
Gross Unrealized Losses	(1.3)	(1.7)
Fair Value, Nuclear decommissioning trust fund	183.9	154.7	135.3
Weighted average maturity of debt securities (in years)	7
Realized Gains on investments in decommissioning trust fund	2.4	1.7	1.0
Realized Losses on investments in decommissioning trust fund	(0.7)	(0.7)	(0.7)
Equity Securities [Member]
Investments in decommissioning trust fund [Line Items]
Cost Basis	83.7	80.6
Gross Unrealized Gains	44.6	21.1
Gross Unrealized Losses	(0.6)	(1.6)
Fair Value, Nuclear decommissioning trust fund	127.7	100.1
Debt Securities [Member]
Investments in decommissioning trust fund [Line Items]
Cost Basis	51.0	46.6
Gross Unrealized Gains	2.5	4.9
Gross Unrealized Losses	(0.7)	(0.1)
Fair Value, Nuclear decommissioning trust fund	52.8	51.4
Other Securities [Member]
Investments in decommissioning trust fund [Line Items]
Cost Basis	3.4	3.2
Gross Unrealized Gains	0	0
Gross Unrealized Losses	0	0
Fair Value, Nuclear decommissioning trust fund	3.4	3.2
Kansas City Power and Light Company [Member]
Investments in decommissioning trust fund [Line Items]
Fair Value, Nuclear decommissioning trust fund	$ 183.9	$ 154.7	$ 135.3

Nuclear Plant Decommissioning Trust (Details) (USD $)	12 Months Ended
Nuclear Plant Decommissioning Trust (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Nuclear decommissioning trust fund [Roll Forward]
Nuclear decommissioning trust fund, beginning balance	$ 154,700,000	$ 135,300,000
Contributions to nuclear decommissioning trust fund	3,300,000	3,300,000
Nuclear decommissioning trust fund earned income, net of fees	2,700,000	3,000,000
Net realized gains (losses) on nuclear decommissioning trust fund	1,700,000	1,000,000
Net unrealized gains (losses) on nuclear decommissioning trust fund	21,500,000	12,100,000
Nuclear decommissioning trust fund, ending balance	183,900,000	154,700,000
Wolf Creek [Member]
Nuclear Plant Decommissioning Costs [Abstract]
Current cost of decommissioning (in 2011 dollars)	630,000,000
Future cost of decommissioning (in 2045 through 2053 dollars)	1,788,000,000
Annual Escalation Factor	2.85%
Annual return on trust assets through 2025	5.13%
Annual return on trusts assets beginning in 2053	0.76%
Nuclear Insurance [Abstract]
Industry aggregate limit on nuclear insurance for property claims including accidental damages	3,200,000,000
Industry aggregate limit on non-nuclear acts of terrorism	1,800,000,000
Amount of insurance against public liability claims resulting from nuclear incidents to full limit of public liability	13,600,000,000
Maximum available commercial insurance	400,000,000
Remaining balance provided through industry wide retrospective assesment program mandated by law	13,200,000,000
Maximum amount able to be assessed to owners	127,300,000
SFP Program-annual amount payable per incident	19,000,000
Amount of decontamination liability, premature decommissioning liability and property damage insurance	2,800,000,000
Premature decommissioning coverage applies only if property damage exceeds this amount and trust funds have been exhausted	500,000,000
Estimated maximum amount of retrospective assessments under the current policies	34,400,000
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	47.00%
Kansas City Power and Light Company [Member]
Nuclear decommissioning trust fund [Roll Forward]
Nuclear decommissioning trust fund, beginning balance	154,700,000	135,300,000
Contributions to nuclear decommissioning trust fund	3,300,000	3,300,000
Nuclear decommissioning trust fund earned income, net of fees	2,700,000	3,000,000
Net realized gains (losses) on nuclear decommissioning trust fund	1,700,000	1,000,000
Net unrealized gains (losses) on nuclear decommissioning trust fund	21,500,000	12,100,000
Nuclear decommissioning trust fund, ending balance	183,900,000	154,700,000
Kansas City Power and Light Company [Member] \| Wolf Creek [Member]
Nuclear Plant Decommissioning Costs [Abstract]
Current cost of decommissioning (in 2011 dollars)	296,000,000
Future cost of decommissioning (in 2045 through 2053 dollars)	840,000,000
Nuclear Insurance [Abstract]
Maximum amount able to be assessed to owners	59,800,000
SFP Program-annual amount payable per incident	8,900,000
Amount of decontamination liability, premature decommissioning liability and property damage insurance	1,300,000,000
Estimated maximum amount of retrospective assessments under the current policies	$ 16,100,000
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	47.00%

Regulatory Matters (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Kansas City Power and Light Company [Member] \| Missouri Public Service Commission [Member]
Regulatory Proceedings [Line Items]
Annual revenue increase authorized	$ 67.4
Kansas City Power and Light Company [Member] \| Kansas Corporation Commission [Member]
Regulatory Proceedings [Line Items]
Annual revenue increase, requested	12.1
KCPL Greater Missouri Operations [Member] \| Missouri Public Service Commission [Member] \| St Joseph Light and Power division [Member]
Regulatory Proceedings [Line Items]
Annual revenue increase authorized	21.7
KCPL Greater Missouri Operations [Member] \| Missouri Public Service Commission [Member] \| Missouri Public Service division [Member]
Regulatory Proceedings [Line Items]
Annual revenue increase authorized	$ 26.2

Regulatory Matters Asset (Details) (USD $)
In Millions, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

$ 849.7

$ 1,120.9

Taxes recoverable through future rates [Member]

136.4

138.4

Loss on reacquired debt [Member]

8.6

10.1

Removal Costs [Member]

1.0

2.8

Asset Retirement Obligation Costs [Member]

50.8

46.4

Pension and post-retirement costs [Member]

401.2

670.9

Deferred customer programs [Member]

72.0

74.4

Rate case expenses [Member]

4.2

9.2

Fuel recovery mechanisms [Member]

23.6

25.8

Acquisition transition costs [Member]

23.9

34.2

Derivative instruments [Member]

3.7

Iatan No. 1 and Common facilities depreciation and carrying costs [Member]

21.0

21.8

Iatan No. 2 construction accounting costs [Member]

45.3

46.8

Kansas property tax surcharge [Member]

4.0

5.4

Solar Rebates [Member]

45.3

15.8

Voluntary Separation Program [Member]

3.4

4.3

Other Regulatory Assets (Liabilities) [Member]

9.0

10.9

Kansas City Power and Light Company [Member]

614.1

853.2

Kansas City Power and Light Company [Member] | Taxes recoverable through future rates [Member]

111.0

114.7

Kansas City Power and Light Company [Member] | Loss on reacquired debt [Member]

7.1

^[1]

8.1

over the life of the related new debt issuances or the remaining lives of the old debt issuances if no new debt was issued.

Kansas City Power and Light Company [Member] | Removal Costs [Member]

1.0

2.8

Kansas City Power and Light Company [Member] | Asset Retirement Obligation Costs [Member]

34.8

31.5

Kansas City Power and Light Company [Member] | Pension and post-retirement costs [Member]

310.0

^[2]

541.2

288.5

various

Kansas City Power and Light Company [Member] | Deferred customer programs [Member]

50.2

^[3]

49.8

15.4

various

Kansas City Power and Light Company [Member] | Rate case expenses [Member]

3.6

^[4]

7.5

various

Kansas City Power and Light Company [Member] | Fuel recovery mechanisms [Member]

10.8

^[4]

8.9

various

Kansas City Power and Light Company [Member] | Acquisition transition costs [Member]

12.9

^[5]

18.7

through 2016

Kansas City Power and Light Company [Member] | Derivative instruments [Member]

Kansas City Power and Light Company [Member] | Iatan No. 1 and Common facilities depreciation and carrying costs [Member]

15.3

^[6]

15.9

through 2038

Kansas City Power and Light Company [Member] | Iatan No. 2 construction accounting costs [Member]

29.3

^[7]

30.6

through 2058

Kansas City Power and Light Company [Member] | Kansas property tax surcharge [Member]

4.0

^[4]

5.4

various

Kansas City Power and Light Company [Member] | Solar Rebates [Member]

13.0

^[4]

5.8

various

Kansas City Power and Light Company [Member] | Voluntary Separation Program [Member]

3.4

^[8]

4.3

through 2017

Kansas City Power and Light Company [Member] | Other Regulatory Assets (Liabilities) [Member]

7.7

^[4]

8.0

various

KCPL Greater Missouri Operations [Member]

235.6

267.7

KCPL Greater Missouri Operations [Member] | Taxes recoverable through future rates [Member]

25.4

23.7

KCPL Greater Missouri Operations [Member] | Loss on reacquired debt [Member]

1.5

^[1]

2.0

over the life of the related new debt issuances or the remaining lives of the old debt issuances if no new debt was issued.

KCPL Greater Missouri Operations [Member] | Removal Costs [Member]

KCPL Greater Missouri Operations [Member] | Asset Retirement Obligation Costs [Member]

16.0

14.9

KCPL Greater Missouri Operations [Member] | Pension and post-retirement costs [Member]

91.2

^[2]

129.7

57.0

various

KCPL Greater Missouri Operations [Member] | Deferred customer programs [Member]

21.8

^[9]

24.6

2.1

various

KCPL Greater Missouri Operations [Member] | Rate case expenses [Member]

0.6

^[10]

1.7

through 2014

KCPL Greater Missouri Operations [Member] | Fuel recovery mechanisms [Member]

12.8

^[4]

16.9

various

KCPL Greater Missouri Operations [Member] | Acquisition transition costs [Member]

11.0

^[5]

15.5

through 2016

KCPL Greater Missouri Operations [Member] | Derivative instruments [Member]

^[6]

3.7

KCPL Greater Missouri Operations [Member] | Iatan No. 1 and Common facilities depreciation and carrying costs [Member]

5.7

^[6]

5.9

through 2038

KCPL Greater Missouri Operations [Member] | Iatan No. 2 construction accounting costs [Member]

16.0

^[7]

16.2

through 2058

KCPL Greater Missouri Operations [Member] | Kansas property tax surcharge [Member]

KCPL Greater Missouri Operations [Member] | Solar Rebates [Member]

32.3

^[4]

10.0

various

KCPL Greater Missouri Operations [Member] | Voluntary Separation Program [Member]

KCPL Greater Missouri Operations [Member] | Other Regulatory Assets (Liabilities) [Member]

$ 1.3

^[4]

$ 2.9

various

[1]	Amortized over the life of the related new debt issuances or the remaining lives of the old debt issuances if no new debt was issued.
[2]	Represents unrecognized gains and losses, prior service and transition costs that will be recognized in future net periodic pension and post-retirement costs, pension settlements amortized over various periods and financial and regulatory accounting method differences that will be eliminated over the life of the pension plans. Of these amounts, $288.5 million and $57.0 million for KCP&L and GMO, respectively, are not included in rate base and are amortized over various periods.
[3]	$15.4 million not included in rate base and amortized over various periods.
[4]	Not included in rate base and amortized over various periods.
[5]	Not included in rate base and amortized through 2016.
[6]	Included in rate base and amortized through 2038.
[7]	Included in rate base and amortized through 2058.
[8]	Not included in rate base and amortized through 2017.
[9]	$2.1 million not included in rate base and amortized over various periods.
[10]	Not included in rate base and amortized through 2014.

Regulatory Matters Liabilities (Details) (USD $)
In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

$ 264.0

$ 283.8

Emission allowances [Member]

74.0

78.1

Asset retirement obligations [Member]

86.2

63.1

Pension [Member]

46.1

Removal Costs [Member]

68.1

64.0

Other Regulatory Assets (Liabilities) [Member]

35.7

32.5

Kansas City Power and Light Company [Member]

168.3

153.0

Kansas City Power and Light Company [Member] | Emission allowances [Member]

74.0

78.0

Kansas City Power and Light Company [Member] | Asset retirement obligations [Member]

86.2

63.1

Kansas City Power and Light Company [Member] | Pension [Member]

1.5

Kansas City Power and Light Company [Member] | Removal Costs [Member]

Kansas City Power and Light Company [Member] | Other Regulatory Assets (Liabilities) [Member]

8.1

10.4

KCPL Greater Missouri Operations [Member]

95.7

130.8

KCPL Greater Missouri Operations [Member] | Emission allowances [Member]

0.1

KCPL Greater Missouri Operations [Member] | Asset retirement obligations [Member]

KCPL Greater Missouri Operations [Member] | Pension [Member]

44.6

KCPL Greater Missouri Operations [Member] | Removal Costs [Member]

68.1

^[1]

64.0

KCPL Greater Missouri Operations [Member] | Other Regulatory Assets (Liabilities) [Member]

Amounts recognized in the consolidated balance sheets [Abstract]

$ 27.6

$ 22.1

[1]	Estimated cumulative net provision for future removal costs.

Intangibles Assets (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets	$ 17.6	$ 15.6
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months	17.2
Finite-Lived Intangible Assets, Amortization Expense, Year Two	15.1
Finite-Lived Intangible Assets, Amortization Expense, Year Three	13.6
Finite-Lived Intangible Assets, Amortization Expense, Year Four	9.5
Finite-Lived Intangible Assets, Amortization Expense, Year Five	6.7
Kansas City Power and Light Company [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets	14.3	13.2
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months	14.0
Finite-Lived Intangible Assets, Amortization Expense, Year Two	12.1
Finite-Lived Intangible Assets, Amortization Expense, Year Three	10.7
Finite-Lived Intangible Assets, Amortization Expense, Year Four	8.4
Finite-Lived Intangible Assets, Amortization Expense, Year Five	6.3
Computer Software, Intangible Asset [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	255.4	211.2
Finite-Lived Intangible Assets, Accumulated Amortization	(169.9)	(152.9)
Computer Software, Intangible Asset [Member] \| Kansas City Power and Light Company [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	231.2	189.9
Finite-Lived Intangible Assets, Accumulated Amortization	(156.5)	(142.9)
Asset Improvements [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	26.5	26.5
Finite-Lived Intangible Assets, Accumulated Amortization	(4.9)	(4.2)
Asset Improvements [Member] \| Kansas City Power and Light Company [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	11.2	11.2
Finite-Lived Intangible Assets, Accumulated Amortization	$ (1.1)	$ (0.8)

Asset Retirement Obligations (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligations, Liability Not Recognized	certain wiring used in Great Plains Energy's and KCP&L's generating stations include asbestos insulation, which would require special handling if disturbed. Due to the inability to reasonably estimate the quantities or the amount of disturbance that will be necessary during dismantlement at the end of the life of a plant, the fair value of this ARO cannot be reasonably estimated at this time. Management will continue to monitor the obligation and will recognize a liability in the period in which sufficient information becomes available to reasonably estimate its fair value.
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation, Beginning Balance	$ 149.3	$ 149.6
Revision in timing and/or estimates	0	(7.7)
Settlements	0	(1.8)
Accretion	9.5	9.2
Asset Retirement Obligation, Ending Balance	158.8	149.3
Kansas City Power and Light Company [Member]
Asset Retirement Obligations, Description	KCP&L has AROs related to decommissioning Wolf Creek, site remediation of its Spearville Wind Energy Facilities, asbestos abatement and removal of storage tanks, ash ponds and landfills.
Asset Retirement Obligations, Liability Not Recognized	certain wiring used in Great Plains Energy's and KCP&L's generating stations include asbestos insulation, which would require special handling if disturbed. Due to the inability to reasonably estimate the quantities or the amount of disturbance that will be necessary during dismantlement at the end of the life of a plant, the fair value of this ARO cannot be reasonably estimated at this time. Management will continue to monitor the obligation and will recognize a liability in the period in which sufficient information becomes available to reasonably estimate its fair value.
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation, Beginning Balance	133.2	134.3
Revision in timing and/or estimates	0	(7.7)
Settlements	0	(1.8)
Accretion	8.5	8.4
Asset Retirement Obligation, Ending Balance	$ 141.7	$ 133.2
KCPL Greater Missouri Operations [Member]
Asset Retirement Obligations, Description	GMO has AROs related to asbestos abatement and removal of storage tanks, ash ponds and landfills.

Pension Plans and Other Employee Benefits (Details) (USD $)

12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Pension and Other Postretirement Defined Benefit Plans, Current Liabilities

$ (3,200,000)

$ (2,800,000)

Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent

(360,500,000)

(557,500,000)

Pension plans with the accumulated benefit obligation in excess of plans assets [Abstract]

Unfunded accumulated benefit obligation for GMO SERP

21,500,000

Segregated assets for GMO SERP

17,900,000

Employee Savings Plans [Abstract]

Defined contribution savings plan, cost of plan

9,600,000

9,200,000

Voluntary Separation Program [Abstract]

Amounts recognized in the consolidated balance sheets [Abstract]

(4,300,000)

12,700,000

Kansas City Power and Light Company [Member]

Pension and Other Postretirement Defined Benefit Plans, Current Liabilities

(1,900,000)

(1,400,000)

Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent

(339,900,000)

(534,500,000)

Employee Savings Plans [Abstract]

Defined contribution savings plan, cost of plan

7,000,000

6,700,000

Voluntary Separation Program [Abstract]

Change in projected benefit obligation [Roll Forward]

(4,300,000)

9,200,000

Pension Plans, Defined Benefit [Member]

1,130,500,000

980,600,000

41,200,000

35,400,000

31,100,000

Defined Benefit Plan, Contributions by Plan Participants

47,200,000

48,900,000

49,600,000

Defined Benefit Plan, Plan Amendments

300,000

1,100,000

Actuarial (gain) loss

(118,400,000)

127,000,000

Defined Benefit Plan, Benefits Paid

(52,900,000)

(58,100,000)

Defined Benefit Plan, Settlements, Benefit Obligation

(40,500,000)

(4,400,000)

Change in plan assets [Roll Forward]

1,007,400,000

1,130,500,000

980,600,000

Fair value of plan assets at beginning of the year

666,400,000

591,100,000

Actual return on plan assets

70,900,000

71,200,000

Defined benefit plan, contributions by employer and participants

57,400,000

60,400,000

Defined benefit plan benefits paid portion paid from plan assets

(51,200,000)

(56,300,000)

Defined Benefit Plan, Settlements, Plan Assets

(40,500,000)

Fair value of plan assets at end of the year

703,000,000

666,400,000

591,100,000

Funded status at end of year

(304,400,000)

(464,100,000)

Amounts recognized in the consolidated balance sheets [Abstract]

Pension and Other Postretirement Defined Benefit Plans, Current Liabilities

(2,300,000)

(1,900,000)

Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent

(302,100,000)

(462,200,000)

Defined Benefit Plan Amounts Recognized in Balance Sheet before Regulatory Treatment

(304,400,000)

(464,100,000)

Defined benefit plan amount recognized in Accumulated Other Comprehensive Income or regulatory asset/liability

368,300,000

559,500,000

Defined Benefit Plan, Amounts Recognized in Balance Sheet

63,900,000

95,400,000

Amounts in accumulated other comprehensive income or regulatory asset/liability not yet recognized as a component of net periodic benefit cost [Abstract]

Defined Benefit Plan Accumulated Other Comprehensive Income Or Regulatory Asset/Liability Net Gains/Losses Before Tax

147,700,000

349,000,000

Defined Benefit Plan Accumulated Other Comprehensive Income Or Regulatory Asset/Liability Net Prior Service Cost Credit Before Tax

5,600,000

7,300,000

Defined Benefit Plan Accumulated Other Comprehensive Income Or Regulatory Asset/Liability Net Transition Obligation Before Tax

Defined Benefit Plan Accumulated Other Comprehensive Income Other Before Tax

215,000,000

203,200,000

Defined benefit plan amount recognized in Accumulated Other Comprehensive Income or regulatory asset/liability

368,300,000

559,500,000

Components of net periodic benefit costs [Abstract]

41,200,000

35,400,000

31,100,000

Defined Benefit Plan, Expected Return on Plan Assets

47,200,000

48,900,000

49,600,000

(47,100,000)

(42,900,000)

(38,000,000)

Defined Benefit Plan, Amortization of Prior Service Cost (Credit)

2,000,000

4,500,000

4,600,000

Defined Benefit Plan, Amortization of Gains (Losses)

54,300,000

44,500,000

38,700,000

Defined Benefit Plan, Amortization of Transition Obligations (Assets)

Settlement charges

4,900,000

800,000

10,100,000

Net periodic benefit costs before regulatory adjustment

102,500,000

91,200,000

96,100,000

Defined benefit plan, regulatory adjustment

(16,800,000)

(15,500,000)

(27,900,000)

Defined Benefit Plan, Net Periodic Benefit Cost

85,700,000

75,700,000

68,200,000

Other Changes In Plan Assets And Benefit Obligations Recognized In Other Comprehensive Income Regulatory Assets/Liabilities [Abstract]

Net gain (loss) arising during period

(147,000,000)

97,900,000

114,800,000

Amortization of net losses included in net periodic benefit costs

(54,300,000)

(44,500,000)

(38,700,000)

Prior service cost

300,000

1,100,000

Amortization of prior service cost

(2,000,000)

(4,500,000)

(4,600,000)

Amortization of transition obligation

Other regulatory activity

11,800,000

17,700,000

17,100,000

Total Recognized In Other Comprehensive Income Or Regulatory Asset/Liability

(191,200,000)

67,700,000

88,600,000

Total Recognized In Net Periodic Benefit Costs And Other Comprehensive Income Or Regulatory Asset/Liability

(105,500,000)

143,400,000

156,800,000

Estimated prior service cost that will be amortized in the next fiscal year

1,000,000

Net (gain) loss for the defined benefit plans that will be amortized in the next fiscal year

49,600,000

Length Of Time For Amortization Of Net Actuarial Gains And Losses For Financial Reporting Purposes

rolling five-year average

Length Of Time For Amortization Of Net Actuarial Gains And Losses For Regulatory Reporting Purposes

ten years

Accumulated benefit obligation (ABO) for all defined benefit plans

889,200,000

985,800,000

Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets [Abstract]

Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Benefit Obligation

1,007,400,000

1,130,500,000

Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets

703,000,000

666,400,000

Pension plans with the accumulated benefit obligation in excess of plans assets [Abstract]

Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation

889,200,000

985,800,000

Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets

703,000,000

666,400,000

Weighted average assumptions used to determine the benefit obligation [Abstract]

Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate

5.03%

4.17%

Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase

3.69%

Defined Benefit Plan, Assumptions Used in Calculations, Narrative Description

Weighted average assumptions used to determine net costs [Abstract]

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate

4.17%

5.01%

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets

7.24%

7.29%

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase

3.69%

4.08%

Contribute to plans in next year

62,800,000

Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months

67,000,000

Defined Benefit Plan, Expected Future Benefit Payments, Year Two

65,300,000

Defined Benefit Plan, Expected Future Benefit Payments, Year Three

69,100,000

Defined Benefit Plan, Expected Future Benefit Payments, Year Four

71,900,000

Defined Benefit Plan, Expected Future Benefit Payments, Year Five

73,600,000

Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter

401,300,000

Defined Benefit Plan, Target Allocation Percentage

The portfolios are invested, and periodically rebalanced, to achieve targeted allocations of approximately 25% U.S. large cap and small cap equity securities, 23% international equity securities, 35% fixed income securities, 7% real estate, 6% commodities and 4% hedge funds.

Defined Benefit Plan, Investment Strategies, Investment Fund Category

The investment strategy supports the objective of the fund, which is to earn the highest possible return on plan assets within a reasonable and prudent level of risk.

Other Postretirement Benefit Plans, Defined Benefit [Member]

Change in projected benefit obligation [Roll Forward]

160,500,000

186,500,000

154,200,000

4,400,000

3,300,000

3,100,000

Defined Benefit Plan, Contributions by Plan Participants

7,700,000

7,800,000

6,200,000

6,700,000

Defined Benefit Plan, Plan Amendments

(6,000,000)

Actuarial (gain) loss

(26,100,000)

26,700,000

Defined Benefit Plan, Benefits Paid

(12,200,000)

Defined Benefit Plan, Settlements, Benefit Obligation

Change in plan assets [Roll Forward]

160,500,000

186,500,000

154,200,000

Fair value of plan assets at beginning of the year

101,200,000

90,300,000

77,400,000

Actual return on plan assets

(2,000,000)

1,400,000

Defined benefit plan, contributions by employer and participants

25,000,000

23,700,000

Defined benefit plan benefits paid portion paid from plan assets

(12,100,000)

(12,200,000)

Defined Benefit Plan, Settlements, Plan Assets

Fair value of plan assets at end of the year

101,200,000

90,300,000

77,400,000

Funded status at end of year

(59,300,000)

(96,200,000)

Amounts recognized in the consolidated balance sheets [Abstract]

Pension and Other Postretirement Defined Benefit Plans, Current Liabilities

(900,000)

Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent

(58,400,000)

(95,300,000)

Defined Benefit Plan Amounts Recognized in Balance Sheet before Regulatory Treatment

(59,300,000)

(96,200,000)

Defined benefit plan amount recognized in Accumulated Other Comprehensive Income or regulatory asset/liability

35,300,000

70,400,000

Defined Benefit Plan, Amounts Recognized in Balance Sheet

(24,000,000)

(25,800,000)

Amounts in accumulated other comprehensive income or regulatory asset/liability not yet recognized as a component of net periodic benefit cost [Abstract]

Defined Benefit Plan Accumulated Other Comprehensive Income Or Regulatory Asset/Liability Net Gains/Losses Before Tax

19,200,000

43,000,000

Defined Benefit Plan Accumulated Other Comprehensive Income Or Regulatory Asset/Liability Net Prior Service Cost Credit Before Tax

16,600,000

29,800,000

Defined Benefit Plan Accumulated Other Comprehensive Income Or Regulatory Asset/Liability Net Transition Obligation Before Tax

400,000

600,000

Defined Benefit Plan Accumulated Other Comprehensive Income Other Before Tax

(900,000)

(3,000,000)

Defined benefit plan amount recognized in Accumulated Other Comprehensive Income or regulatory asset/liability

35,300,000

70,400,000

Components of net periodic benefit costs [Abstract]

4,400,000

3,300,000

3,100,000

Defined Benefit Plan, Expected Return on Plan Assets

7,700,000

7,800,000

(2,000,000)

(1,800,000)

Defined Benefit Plan, Amortization of Prior Service Cost (Credit)

7,200,000

7,100,000

7,200,000

Defined Benefit Plan, Amortization of Gains (Losses)

1,700,000

(200,000)

(500,000)

Defined Benefit Plan, Amortization of Transition Obligations (Assets)

200,000

1,100,000

1,300,000

Settlement charges

Net periodic benefit costs before regulatory adjustment

19,200,000

17,300,000

17,100,000

Defined benefit plan, regulatory adjustment

(2,400,000)

1,500,000

1,100,000

Defined Benefit Plan, Net Periodic Benefit Cost

16,800,000

18,800,000

18,200,000

Other Changes In Plan Assets And Benefit Obligations Recognized In Other Comprehensive Income Regulatory Assets/Liabilities [Abstract]

Net gain (loss) arising during period

(22,100,000)

27,100,000

6,700,000

Amortization of net losses included in net periodic benefit costs

(1,700,000)

200,000

500,000

Prior service cost

(6,000,000)

Amortization of prior service cost

(7,200,000)

(7,100,000)

(7,200,000)

Amortization of transition obligation

(200,000)

(1,100,000)

(1,300,000)

Other regulatory activity

2,100,000

(1,200,000)

(1,000,000)

Total Recognized In Other Comprehensive Income Or Regulatory Asset/Liability

(35,100,000)

17,900,000

(2,300,000)

Total Recognized In Net Periodic Benefit Costs And Other Comprehensive Income Or Regulatory Asset/Liability

(18,300,000)

36,700,000

15,900,000

Estimated prior service cost that will be amortized in the next fiscal year

3,100,000

Net (gain) loss for the defined benefit plans that will be amortized in the next fiscal year

(100,000)

Transition costs for the defined benefit plans that will be amortized in the next fiscal year

200,000

Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets [Abstract]

Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Benefit Obligation

160,500,000

186,500,000

Defined Benefit Plan, Plans with Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets

101,200,000

90,300,000

Weighted average assumptions used to determine the benefit obligation [Abstract]

Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate

4.92%

4.13%

Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase

3.50%

Defined Benefit Plan, Assumptions Used in Calculations, Narrative Description

Weighted average assumptions used to determine net costs [Abstract]

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate

4.13%

5.03%

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets

2.62%

^[1]

2.59%

^[1]

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase

3.50%

4.07%

Contribute to plans in next year

11,300,000

Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months

7,800,000

Defined Benefit Plan, Expected Future Benefit Payments, Year Two

8,300,000

Defined Benefit Plan, Expected Future Benefit Payments, Year Three

8,900,000

Defined Benefit Plan, Expected Future Benefit Payments, Year Four

9,300,000

Defined Benefit Plan, Expected Future Benefit Payments, Year Five

9,700,000

Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter

52,100,000

Defined Benefit Plan, Investment Strategies, Investment Fund Category

The investment strategy supports the objective of the funds, which is to preserve capital, maintain sufficient liquidity and earn a consistent rate of return.

Health care cost trend (in hundredths)

7.00%

7.50%

Health care cost rate declining through

2018

Ultimate cost trend rate (in hundredths)

5.00%

Effect on total service and interest component, increase

1,100,000

Effect on total service and interest component, decrease

(1,000,000)

Effect on post-retirement benefit obligation, increase

8,800,000

Effect on post-retirement benefit obligation, decrease

$ (7,300,000)

[1]

after tax

Pension Plans and Other Employee Benefits Pension Plans Fair Value (Details) (USD $)

12 Months Ended

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Dec. 31, 2011

Pension Plans, Defined Benefit [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Real Estate [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Real Estate [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Hedge Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Hedge Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US Equity Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US Equity Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US Equity Securities [Member]

Traded Mutual Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US Equity Securities [Member]

Traded Mutual Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US Equity Securities [Member]

Institutional Common Collective Trust Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US Equity Securities [Member]

Institutional Common Collective Trust Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

International Equity Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

International Equity Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

International Equity Securities [Member]

Traded Mutual Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

International Equity Securities [Member]

Traded Mutual Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

International Equity Securities [Member]

Institutional Common Collective Trust Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

International Equity Securities [Member]

Institutional Common Collective Trust Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Commodity Contract [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Commodity Contract [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Traded Mutual Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Traded Mutual Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Institutional Common Collective Trust Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Institutional Common Collective Trust Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US Treasury [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US Treasury [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US corporate bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US corporate bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US corporate bonds [Member]

Corporate Bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US corporate bonds [Member]

Corporate Bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US corporate bonds [Member]

Collateralized Mortgage Obligation Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US corporate bonds [Member]

Collateralized Mortgage Obligation Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

US corporate bonds [Member]

Asset-backed Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

US corporate bonds [Member]

Asset-backed Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Foreign corporate bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Foreign corporate bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Other Plan Investments [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Total Plan Assets [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Real Estate [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Real Estate [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Hedge Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Hedge Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Equity Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Equity Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

International Equity Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

International Equity Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Commodity Contract [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Commodity Contract [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Fixed Income Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Fixed Income Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Treasury [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Treasury [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US corporate bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US corporate bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Other Plan Investments [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Real Estate [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Real Estate [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Hedge Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Hedge Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Equity Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Equity Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

International Equity Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

International Equity Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Commodity Contract [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Commodity Contract [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Fixed Income Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Fixed Income Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Treasury [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Treasury [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US corporate bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US corporate bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Other Plan Investments [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Real Estate [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Real Estate [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Hedge Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Hedge Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Equity Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Equity Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

International Equity Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

International Equity Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Commodity Contract [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Commodity Contract [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Fixed Income Funds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Fixed Income Funds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Treasury [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Treasury [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US corporate bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US corporate bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2012

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2013

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Other Plan Investments [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2011

Other Postretirement Benefit Plans, Defined Benefit [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Equity Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Equity Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Institutional Common Collective Trust Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fixed Income Funds [Member]

Mutual Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

US Treasury [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

US Treasury [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

US corporate bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

US corporate bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

US corporate bonds [Member]

Corporate Bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

US corporate bonds [Member]

Corporate Bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

US corporate bonds [Member]

Collateralized Mortgage Obligation Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

US corporate bonds [Member]

Collateralized Mortgage Obligation Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

US corporate bonds [Member]

Asset-backed Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

US corporate bonds [Member]

Asset-backed Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Foreign corporate bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Foreign corporate bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Mutual Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Other Plan Investments [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Total Plan Assets [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Equity Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Equity Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Fixed Income Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Treasury [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Treasury [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US corporate bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

US corporate bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Mutual Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 1 [Member]

Other Plan Investments [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Equity Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Equity Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Fixed Income Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Treasury [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Treasury [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US corporate bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

US corporate bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Mutual Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 2 [Member]

Other Plan Investments [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Equity Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Equity Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Fixed Income Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Treasury [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Treasury [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US Agency, State and Political Subdivisions Debt Securities [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US corporate bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

US corporate bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Foreign corporate bonds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Cash and Cash Equivalents [Member]

Dec. 31, 2012

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Mutual Funds [Member]

Dec. 31, 2013

Other Postretirement Benefit Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Other Plan Investments [Member]

Actual return on plan assets [Abstract]

Fair Value, Plan Assets

$ 703,000,000

$ 666,400,000

$ 591,100,000

$ 49,100,000

^[1]

$ 43,400,000

^[1]

$ 23,100,000

^[2]

$ 21,600,000

^[2]

$ 193,700,000

^[3]

$ 169,600,000

^[3]

$ 80,500,000

$ 69,700,000

$ 113,200,000

$ 99,900,000

$ 167,100,000

^[4]

$ 151,200,000

^[4]

$ 39,900,000

$ 36,600,000

$ 127,200,000

$ 114,600,000

$ 34,800,000

^[5]

$ 37,300,000

^[5]

$ 181,300,000

^[6]

$ 182,100,000

^[6]

$ 27,100,000

$ 35,000,000

$ 154,200,000

$ 147,100,000

$ 2,600,000

$ 4,500,000

$ 17,100,000

$ 19,600,000

$ 25,600,000

^[7]

$ 28,900,000

^[7]

$ 20,100,000

$ 21,500,000

$ 3,600,000

$ 5,200,000

$ 1,900,000

$ 2,200,000

$ 2,300,000

$ 2,600,000

$ 3,000,000

$ 5,600,000

$ 3,300,000

$ 660,800,000

$ 153,100,000

$ 145,800,000

$ 0

^[1]

$ 0

^[1]

$ 0

^[2]

$ 0

^[2]

$ 80,500,000

^[3]

$ 69,700,000

^[3]

$ 39,900,000

^[4]

$ 36,600,000

^[4]

$ 0

^[5]

$ 0

^[5]

$ 27,100,000

^[6]

$ 35,000,000

^[6]

$ 2,600,000

$ 4,500,000

$ 0

^[7]

$ 0

^[7]

$ 0

$ 3,000,000

$ 0

$ 483,100,000

$ 455,000,000

$ 5,400,000

^[1]

$ 5,000,000

^[1]

$ 0

^[2]

$ 0

^[2]

$ 113,200,000

^[3]

$ 99,900,000

^[3]

$ 127,200,000

^[4]

$ 114,600,000

^[4]

$ 34,800,000

^[5]

$ 37,300,000

^[5]

$ 154,200,000

^[6]

$ 147,100,000

^[6]

$ 0

$ 17,100,000

$ 19,600,000

$ 25,600,000

^[7]

$ 28,900,000

^[7]

$ 2,300,000

$ 2,600,000

$ 0

$ 3,300,000

$ 66,800,000

$ 60,000,000

$ 43,700,000

^[1]

$ 38,400,000

^[1]

$ 23,100,000

^[2]

$ 21,600,000

^[2]

$ 0

^[3]

$ 0

^[3]

$ 0.0

^[4]

$ 0

^[4]

$ 0

^[5]

$ 0

^[5]

$ 0

^[6]

$ 0

^[6]

$ 0

^[7]

$ 0

^[7]

$ 0

$ 101,200,000

$ 90,300,000

$ 77,400,000

$ 2,200,000

$ 1,700,000

$ 74,600,000

^[8]

$ 74,400,000

$ 200,000

$ 1,500,000

$ 13,700,000

$ 4,400,000

$ 28,600,000

$ 8,600,000

^[9]

$ 20,100,000

^[9]

$ 7,100,000

$ 17,100,000

$ 300,000

$ 1,400,000

$ 1,200,000

$ 1,600,000

$ 1,000,000

$ 2,200,000

$ 8,600,000

$ 23,800,000

$ 200,000

$ 300,000

$ 66,500,000

$ 12,500,000

$ 15,600,000

$ 2,200,000

$ 1,700,000

$ 200,000

^[8]

$ 1,500,000

$ 13,700,000

$ 0

^[9]

$ 0

^[9]

$ 0

$ 8,600,000

$ 200,000

$ 0

$ 88,700,000

$ 50,900,000

$ 0

$ 74,400,000

^[8]

$ 0

$ 4,400,000

$ 28,600,000

$ 8,600,000

^[9]

$ 20,100,000

^[9]

$ 1,000,000

$ 2,200,000

$ 0

$ 300,000

$ 0

^[8]

$ 0

^[9]

$ 0

^[9]

$ 0

Relating to assets still held

60,000,000

56,400,000

38,400,000

34,700,000

21,600,000

21,700,000

6,100,000

2,200,000

4,600,000

1,600,000

1,500,000

600,000

Relating to assets sold

900,000

1,300,000

(400,000)

Purchase, sales and settlements

700,000

500,000

700,000

800,000

(300,000)

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

$ 66,800,000

$ 60,000,000

$ 43,700,000

$ 38,400,000

$ 23,100,000

$ 21,600,000

[1]	This category is comprised of institutional common/collective trust funds and a limited partnership valued at NAV on a quarterly basis.
[2]	This category is comprised of closely-held limited partnerships valued at NAV on a quarterly basis.
[3]	At December 31, 2013 and 2012, this category is comprised of $80.5 million and $69.7 million, respectively, of traded mutual funds valued at daily listed prices and $113.2 million and $99.9 million, respectively, of institutional common/collective trust funds valued at Net Asset Value (NAV) per share.
[4]	At December 31, 2013 and 2012, this category is comprised of $39.9 million and $36.6 million, respectively, of traded mutual funds valued at daily listed prices and $127.2 million and $114.6 million, respectively, of institutional common/collective trust funds valued at daily NAV per share.
[5]	This category is comprised of institutional common/collective trust funds valued at daily NAV per share.
[6]	At December 31, 2013 and 2012, this category is comprised of $27.1 million and $35.0 million, respectively, of traded mutual funds valued at daily listed prices and $154.2 million and $147.1 million, respectively, of institutional common/collective trust funds valued at daily NAV per share.
[7]	At December 31, 2013 and 2012, this category is comprised of $20.1 million and $21.5 million, respectively, of corporate bonds, $3.6 million and $5.2 million, respectively, of collateralized mortgage obligations and $1.9 million and $2.2 million, respectively, of other asset-backed securities.
[8]	This category is comprised of $74.4 million of an institutional common/collective trust fund valued at daily NAV per share and $0.2 million of traded mutual funds valued at daily listed prices.
[9]	At December 31, 2013 and 2012, this category is comprised of $7.1 million and $17.1 million, respectively, of corporate bonds, $0.3 million and $1.4 million, respectively, of collateralized mortgage obligations and $1.2 million and $1.6 million, respectively, of other asset-backed securities.

Equity Compensation (Details) (USD $)
In Millions, except Share data, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Maximum number of shares of common shares authorized (in shares)

8,000,000

Equity compensation expense

$ 5.6

$ 3.3

$ 5.2

Income tax benefit

1.9

1.4

1.9

Performance Shares [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Expected volatility

19.00%

Expected dividend yield

3.88%

Risk-free interest rate

0.35%

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]

Beginning balance (in shares)

370,560

Granted (in shares)

226,967

Earned (in shares)

(104,453)

Forfeited (in shares)

(11,523)

Performance adjustment (in shares)

51,542

Ending balance (in shares)

430,009

370,560

Weighted average beginning balance (in dollars per share)

$ 23.05

^[1]

Weighted average granted (in dollars per share)

$ 24.17

^[1]

$ 19.37

$ 26.15

Weighted average earned (in dollars per share)

$ 23.37

^[1]

Weighted average forfeited (in dollars per share)

$ 22.82

^[1]

Weighted average performance adjustment (in dollars per share)

$ 23.37

^[1]

Weighted average ending balance (in dollars per share)

$ 23.52

^[1]

$ 23.05

^[1]

Total unrecognized compensation expense

5.7

Remaining weighted-average contractual term (in years)

1 year 4 months

Fair value of performance shares earned and paid

2.4

0.8

Restricted Stock [Member]

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]

Beginning balance (in shares)

277,439

Granted (in shares)

79,645

Forfeited (in shares)

(4,142)

Vested (in shares)

(64,405)

Ending balance (in shares)

288,537

277,439

Weighted average beginning balance (in dollars per share)

$ 19.03

^[1]

Weighted average granted (in dollars per share)

$ 22.47

^[1]

$ 19.75

$ 19.03

Weighted average vested (in dollars per share)

$ 17.88

^[1]

Weighted average forfeited (in dollars per share)

$ 21.44

^[1]

Weighted average ending balance (in dollars per share)

$ 20.18

^[1]

$ 19.03

^[1]

Total unrecognized compensation expense

2.2

Total fair value of shares vested

1.2

3.3

2.6

Remaining weighted-average contractual term (in years)

1 year 2 months

Kansas City Power and Light Company [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Equity compensation expense

4.0

2.3

3.5

Income tax benefit

$ 1.3

$ 1.0

$ 1.3

[1]	weighted-average

Equity Compensation Equity Compensation Deferred Directors (Details) (Director [Member], Director Deferred Share Units [Member], USD $)

12 Months Ended

Dec. 31, 2013

Director [Member] | Director Deferred Share Units [Member]

Director deferred share units [Roll Forward]

Director deferred share units, beginning balance (in shares)

69,818

Director deferred share units, issued (in shares)

20,302

Director deferred share units, ending balance (in shares)

90,120

Weighted-average grant date fair value, director deferred share units, beginning balance (in dollars per share)

$ 20.36

^[1]

Weighted-average grant date fair value, director deferred share units, issued (in dollars per share)

$ 22.95

^[1]

Weighted-average grant date fair value, director deferred share units, ending balance (in dollars per share)

$ 20.94

^[1]

[1]	weighted-average

Short-term Borrowings and Short-term Bank Lines of Credit (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Short-term Debt [Line Items]
Amount of outstanding cash borrowings	$ 9,000,000	$ 12,000,000
Commercial paper outstanding	108,200,000	530,100,000
Parent Company [Member]
Short-term Debt [Line Items]
Amount of outstanding cash borrowings	9,000,000	12,000,000
Parent Company [Member] \| Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Amount of revolving credit facility	200,000,000
Revolving credit facility expiration date	Oct. 01, 2018
Maximum borrowing capacity with transfer of unused commitments	400,000,000
Covenant term - amount considered in default	50,000,000
Covenant Term Ratio of Consolidated Indebtedness to Consolidated Capitalization Ratio, Maximum	0.65
Line of Credit Facility, Covenant Compliance	in compliance
Amount of outstanding cash borrowings	9,000,000	12,000,000
Weighted-average interest rate from outstanding borrowings	1.94%	2.00%
Amount of letters of credit outstanding	0	1,800,000
Kansas City Power and Light Company [Member]
Short-term Debt [Line Items]
Commercial paper outstanding	93,200,000	361,000,000
Weighted-average interest rate from outstanding borrowings	0.29%	0.48%
Kansas City Power and Light Company [Member] \| Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Amount of revolving credit facility	600,000,000
Revolving credit facility expiration date	Oct. 01, 2018
Maximum transfer of unused commitments	200,000,000
Covenant term - amount considered in default	50,000,000
Covenant Term Ratio of Consolidated Indebtedness to Consolidated Capitalization Ratio, Maximum	0.65
Line of Credit Facility, Covenant Compliance	in compliance
Amount of outstanding cash borrowings	0	0
Amount of letters of credit outstanding	3,800,000	13,900,000
KCPL Greater Missouri Operations [Member]
Short-term Debt [Line Items]
Commercial paper outstanding	15,000,000	169,100,000
Weighted-average interest rate from outstanding borrowings	0.66%	0.94%
KCPL Greater Missouri Operations [Member] \| Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Amount of revolving credit facility	450,000,000
Revolving credit facility expiration date	Oct. 01, 2018
Maximum transfer of unused commitments	200,000,000
Covenant term - amount considered in default	50,000,000
Covenant Term Ratio of Consolidated Indebtedness to Consolidated Capitalization Ratio, Maximum	0.65
Line of Credit Facility, Covenant Compliance	in compliance
Amount of outstanding cash borrowings	0	0
Amount of letters of credit outstanding	$ 16,400,000	$ 15,100,000

Long-Term Debt (Details) (USD $)

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Long-term debt excluding current maturities

$ (1,100,000)

$ (263,100,000)

3,515,700,000

2,756,800,000

Amortization of Financing Costs

5,700,000

5,500,000

8,100,000

Long-term Debt, Fiscal Year Maturity [Abstract]

265,300,000

513,800,000

598,500,000

Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months

1,100,000

Long-term Debt, Maturities, Repayments of Principal in Year Two

15,100,000

Long-term Debt, Maturities, Repayments of Principal in Year Three

1,100,000

Long-term Debt, Maturities, Repayments of Principal in Year Four

382,100,000

Long-term Debt, Maturities, Repayments of Principal in Year Five

351,100,000

Kansas City Power and Light Company [Member]

Long-term debt excluding current maturities

(400,000)

Unamortized discount

(4,100,000)

(4,000,000)

2,312,200,000

1,901,700,000

Amortization of Financing Costs

3,200,000

2,900,000

3,600,000

Long-term Debt, Fiscal Year Maturity [Abstract]

2,600,000

12,700,000

263,100,000

Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months

Long-term Debt, Maturities, Repayments of Principal in Year Two

14,000,000

Long-term Debt, Maturities, Repayments of Principal in Year Three

Long-term Debt, Maturities, Repayments of Principal in Year Four

281,000,000

Long-term Debt, Maturities, Repayments of Principal in Year Five

350,000,000

Kansas City Power and Light Company [Member] | Secured Debt [Member]

596,400,000

630,100,000

Kansas City Power and Light Company [Member] | Secured Debt [Member] | General Mortgage bonds EIRR due 2015-2035 [Member]

Debt Instrument Maturity Date Range Start

146,400,000

106,900,000

Dec. 31, 2015

Debt Instrument Maturity Date Range End

Dec. 31, 2035

Long-term Debt, Weighted Average Interest Rate

2.95%

^[1]

Kansas City Power and Light Company [Member] | Secured Debt [Member] | General Mortgage bonds Series 2009 due 2019 [Member]

400,000,000

Dec. 31, 2019

Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths)

7.15%

8.59%

^[2]

Kansas City Power and Light Company [Member] | Secured Debt [Member] | General Mortgage bonds EIRR series 2005 due 2035 [Member]

50,000,000

Dec. 31, 2035

4.65%

Kansas City Power and Light Company [Member] | Secured Debt [Member] | General Mortgage bonds EIRR series 2007B due 2035 [Member]

73,200,000

KCPL Municipal Bond Insurance Policies [Abstract]

5.375%

Kansas City Power and Light Company [Member] | Secured Debt [Member] | Secured EIRR Bonds Series 2005 [Member]

Principal outstanding covered by insurance policies

35,900,000

Insurance Agreement Covenant Description

The insurance agreements contain a covenant that the indebtedness to total capitalization ratio of KCP&L and its consolidated subsidiaries will not be greater than 0.68 to 1.00.

Insurance Agreement Covenant Compliance

in compliance

Insurance Agreement Covenant Indebtedness To Total Capitalization Ratio Maximum

75.00%

Proportion Of Secured Debt To Total Indebtedness Based On Bond Ratings Maximum In Hundredths

50.00%

Aggregate Amount Of Outstanding General Mortgage Bonds As Percentage Of Total Capitalization Maximum In Hundredths

10.00%

Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior notes due 2017 KCPL [Member]

250,000,000

Dec. 31, 2017

Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths)

5.85%

5.72%

^[2]

Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior notes due 2018 KCPL [Member]

350,000,000

Dec. 31, 2018

Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths)

6.375%

7.49%

^[2]

Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior Notes due 2023 KCPL [Member]

300,000,000

Dec. 31, 2023

3.15%

Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior notes due 2035 KCPL [Member]

250,000,000

Dec. 31, 2035

Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths)

6.05%

5.78%

^[2]

Kansas City Power and Light Company [Member] | Senior Notes [Member] | Senior Notes Due 2041 KCPL [Member]

400,000,000

Dec. 31, 2041

5.30%

Kansas City Power and Light Company [Member] | Unsecured Debt [Member] | EIRR Bonds Series 2007A and 2007B due 2035 [Member]

146,500,000

Variable rate (in hundredths)

Dec. 31, 2035

0.07%

^[3]

Kansas City Power and Light Company [Member] | Unsecured Debt [Member] | EIRR bonds 2.875 percent Series 2008 [Member]

23,400,000

Dec. 31, 2038

KCPL Municipal Bond Insurance Policies [Abstract]

2.875%

Kansas City Power and Light Company [Member] | Unsecured Debt [Member] | Unsecured EIRR Bonds Series 2005 [Member]

Principal outstanding covered by insurance policies

50,000,000

Additional collateral necessary due to issuance of additional mortgage bonds

50,000,000

Insurance Agreement Covenant Description

The insurance agreements contain a covenant that the indebtedness to total capitalization ratio of KCP&L and its consolidated subsidiaries will not be greater than 0.68 to 1.00.

Insurance Agreement Covenant Compliance

in compliance

Insurance Agreement Covenant Indebtedness To Total Capitalization Ratio Maximum

75.00%

Proportion Of Secured Debt To Total Indebtedness Based On Bond Ratings Maximum In Hundredths

50.00%

Aggregate Amount Of Outstanding General Mortgage Bonds As Percentage Of Total Capitalization Maximum In Hundredths

10.00%

Kansas City Power and Light Company [Member] | Other Debt [Member]

2,600,000

KCPL Greater Missouri Operations [Member] | Secured Debt [Member] | First Mortgage Bonds due through 2021 [Member]

Debt Instrument Maturity Date Range Start

9,000,000

10,100,000

Dec. 31, 2014

Debt Instrument Maturity Date Range End

Dec. 31, 2021

9.44%

KCPL Greater Missouri Operations [Member] | Senior Notes [Member] | Senior notes 8.27 percent series due 2021 [Member]

80,900,000

Dec. 31, 2021

8.27%

KCPL Greater Missouri Operations [Member] | Senior Notes [Member] | Senior Notes Series A due 2025 [Member]

125,000,000

Dec. 31, 2025

Debt Instrument, Covenant Description

3.49%

GMO Senior Notes [Abstract]

GMO is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the agreement, not greater than 0.65 to 1.00 at all times. In addition, GMO's priority debt, as defined in the agreement, cannot exceed 15% of consolidated tangible net worth, as defined in the agreement

Debt Instrument, Covenant Compliance

in compliance

KCPL Greater Missouri Operations [Member] | Senior Notes [Member] | Senior Notes Series B due 2033 [Member]

75,000,000

Dec. 31, 2033

Debt Instrument, Covenant Description

4.06%

GMO Senior Notes [Abstract]

Debt Instrument, Covenant Compliance

in compliance

KCPL Greater Missouri Operations [Member] | Senior Notes [Member] | Senior Notes Series C due 2043 [Member]

150,000,000

Dec. 31, 2043

Debt Instrument, Covenant Description

4.74%

GMO Senior Notes [Abstract]

Debt Instrument, Covenant Compliance

in compliance

KCPL Greater Missouri Operations [Member] | Medium-term Notes [Member] | Medium term notes 7.16 percent series due 2013 [Member]

6,000,000

7.16%

6,000,000

KCPL Greater Missouri Operations [Member] | Medium-term Notes [Member] | Medium term notes 7.33 percent series due 2023 [Member]

3,000,000

Dec. 31, 2023

7.33%

KCPL Greater Missouri Operations [Member] | Medium-term Notes [Member] | Medium term notes 7.17 percent series due 2023 [Member]

7,000,000

Dec. 31, 2023

7.17%

KCPL Greater Missouri Operations [Member] | Unsecured Debt [Member] | Pollution control bonds Wamego Series 1996 due 2026 [Member]

7,300,000

Variable rate (in hundredths)

Dec. 31, 2026

0.113%

^[3]

KCPL Greater Missouri Operations [Member] | Unsecured Debt [Member] | Pollution control bonds state environmental 1993 due 2028 [Member]

5,000,000

Variable rate (in hundredths)

Dec. 31, 2028

0.113%

^[3]

KCPL Greater Missouri Operations [Member] | Unsecured Debt [Member] | Pollution control bonds SJLP due 2013 [Member]

5,600,000

5.85%

5,600,000

Parent Company [Member]

Long-term debt excluding current maturities

(250,000,000)

742,400,000

743,000,000

250,000,000

Parent Company [Member] | Senior Notes [Member] | Senior notes due 2013 [Member]

250,000,000

Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths)

2.75%

3.67%

^[2]

250,000,000

Parent Company [Member] | Senior Notes [Member] | Senior notes due 2017 [Member]

100,000,000

Dec. 31, 2017

Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths)

6.875%

7.33%

^[2]

Parent Company [Member] | Senior Notes [Member] | Senior Notes Due 2021 [Member]

350,000,000

Dec. 31, 2021

Rate after amortizing gains or losses in Other Comprehensive Income (in hundredths)

4.85%

7.34%

^[2]

Parent Company [Member] | Senior Notes [Member] | Senior Notes Due 2022 [Member]

287,500,000

Dec. 31, 2022

5.292%

Other Consolidated Entities [Member]

Unarmortized discount and premium, net

(1,100,000)

(262,700,000)

4,900,000

5,400,000

Amortization of Financing Costs

$ 2,500,000

$ 2,600,000

$ 4,500,000

[1]	Weighted-average interest rates at December 31, 2013
[2]	Rate after amortizing gains/losses recognized in OCI on settlements of interest rate hedging instruments
[3]	Variable rate

Long-Term Debt Long-Term Debt Remarketed (Details) (Kansas City Power and Light Company [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Secured Debt [Member] \| Secured 1992 Series EIRR Bonds [Member]
EIRR Bonds Remarketed	$ 31.0
EIRR Bonds Remarketed Maturity Date	Dec. 31, 2017
EIRR Bonds Remarketed Interest Rate Stated Percentage	1.25%
EIRR Bonds Remarketed Interest Rate Terms	fixed rate
Secured Debt [Member] \| Secured Series 1993B EIRR Bonds Member
EIRR Bonds Remarketed No Longer Held	39.5
EIRR Bonds Remarketed Maturity Date	Dec. 31, 2023
EIRR Bonds Remarketed Interest Rate Stated Percentage	2.95%
EIRR Bonds Remarketed Interest Rate Terms	fixed rate
Secured Debt [Member] \| Secured Series 1993A Bonds [Member]
EIRR Bonds Remarketed	40.0
EIRR Bonds Remarketed Maturity Date	Dec. 31, 2023
EIRR Bonds Remarketed Interest Rate Stated Percentage	2.95%
EIRR Bonds Remarketed Interest Rate Terms	fixed rate
Unsecured Debt [Member] \| General Mortgage bonds EIRR Series 2007A-1 due 2035 [Member]
EIRR Bonds Remarketed No Longer Held	10.0
Unsecured Debt [Member] \| General Mortgage bonds EIRR series 2007A-2 due 2035 [Member]
EIRR Bonds Remarketed No Longer Held	63.3
Unsecured Debt [Member] \| Remarketed EIRR Bonds Series 2007A due 2035 [Member]
EIRR Bonds Remarketed No Longer Held	73.3
EIRR Bonds Remarketed Maturity Date	Dec. 31, 2035
EIRR Bonds Remarketed Interest Rate Terms	variable rate that will be determined weekly
Unsecured Debt [Member] \| Remarketed EIRR Bonds Series 2007B due 2035 [Member]
EIRR Bonds Remarketed	73.2
EIRR Bonds Remarketed Maturity Date	Dec. 31, 2035
EIRR Bonds Remarketed Interest Rate Terms	variable rate that will be determined weekly
Unsecured Debt [Member] \| EIRR bonds 2.875 percent Series 2008 [Member]
EIRR Bonds Remarketed	$ 23.4
EIRR Bonds Remarketed Maturity Date	Dec. 31, 2038
EIRR Bonds Remarketed Interest Rate Stated Percentage	2.875%
EIRR Bonds Remarketed Interest Rate Terms	fixed rate

Long-Term Debt Subsequent Event (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended						0 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013 Kansas City Power and Light Company [Member]	Dec. 31, 2012 Kansas City Power and Light Company [Member]	Dec. 31, 2011 Kansas City Power and Light Company [Member]	Jan. 02, 2014 KCPL Greater Missouri Operations [Member] Subsequent Event [Member] Unsecured Debt [Member] Pollution control bonds Wamego Series 1996 due 2026 [Member]	Jan. 02, 2014 KCPL Greater Missouri Operations [Member] Subsequent Event [Member] Unsecured Debt [Member] Pollution control bonds state environmental 1993 due 2028 [Member]
Subsequent Event [Line Items]
Repayments of Long-term Debt	$ 265.3	$ 513.8	$ 598.5	$ 2.6	$ 12.7	$ 263.1	$ 7.3	$ 5.0

Common Shareholders' Equity (Details) (USD $) In Billions, except Share data in Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Common Shareholders' Equity [Abstract]
Shares authorized under the Dividend Reinvestment and Direct Stock Purchase Plan (in shares)	6.0
Number of shares available for grant under the Dividend Reinvestment and Direct Stock Purchase Plan (in shares)	1.4
Shares registered under the defined contribution savings plan (in shares)	14.3
Number of shares available under the defined contribution savings plan (in shares)	1.6
Restrictions on the payment of common stock dividends	Great Plains Energy's articles of incorporation restrict the payment of common stock dividends in the event common equity is 25% or less of total capitalization. In addition, if preferred stock dividends are not declared and paid when scheduled, Great Plains Energy could not declare or pay common stock dividends or purchase any common shares. If the unpaid preferred stock dividends equal four or more full quarterly dividends, the preferred shareholders, voting as a single class, could elect the smallest number of directors necessary to constitute a majority of the full Board. Certain conditions in the MPSC and KCC orders authorizing the holding company structure require Great Plains Energy and KCP&L to maintain consolidated common equity of at least 30% and 35%, respectively, of total capitalization (including only the amount of short-term debt in excess of the amount of construction work in progress). Under the Federal Power Act, KCP&L and GMO generally can pay dividends only out of retained earnings. The revolving credit agreements of Great Plains Energy, KCP&L and GMO and the note purchase agreement for GMO's Series A, B and C Senior Notes contain a covenant requiring the respective company to maintain a consolidated indebtedness to consolidated total capitalization ratio of not more than 0.65 to 1.00.
Restricted net assets of subsidiaries	$ 2.8

Preferred Stock (Details) (USD $) In Millions, except Share data, unless otherwise specified	Dec. 31, 2013
No Par Preference Stock [Member]
Class of Stock [Line Items]
Preferred Stock, Shares Authorized	11,000,000
Cumulative Preferred Stock [Member]
Class of Stock [Line Items]
Preferred Stock, Shares Authorized	390,000
Preferred Stock, Shares Outstanding	390,000
Preferred Stock, Par or Stated Value Per Share	$ 100.00
Preferred Stock, Value, Outstanding	$ 39.0
Cumulative No Par Preferred Stock [Member]
Class of Stock [Line Items]
Preferred Stock, Shares Authorized	1,600,000
Minimum [Member] \| Cumulative Preferred Stock [Member]
Class of Stock [Line Items]
Optional Redemption Percentage of Par Value	101.00%
Maximum [Member] \| Cumulative Preferred Stock [Member]
Class of Stock [Line Items]
Optional Redemption Percentage of Par Value	103.70%

Commitments and Contingencies Commitments and Contingencies Contractual Commitments (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Lease Expense [Abstract]
Lease expense	$ 18.5	$ 21.8	$ 20.9
Operating Leases [Abstract]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	15.3
Operating Leases, Future Minimum Payments, Due in Two Years	13.6
Operating Leases, Future Minimum Payments, Due in Three Years	10.0
Operating Leases, Future Minimum Payments, Due in Four Years	9.7
Operating Leases, Future Minimum Payments, Due in Five Years	9.7
Operating Leases, Future Minimum Payments, Due Thereafter	138.6
Operating Leases, Future Minimum Payments Due, Total	196.9
Capital Leases [Abstract]
Capital Leases, Future Minimum Payments Due, Next Twelve Months	0.4
Capital Leases, Future Minimum Payments Due in Two Years	0.4
Capital Leases, Future Minimum Payments Due in Three Years	0.4
Capital Leases, Future Minimum Payments Due in Four Years	0.4
Capital Leases, Future Minimum Payments Due in Five Years	0.4
Capital Leases, Future Minimum Payments Due Thereafter	4.4
Capital Leases, Future Minimum Payments Due, Total	6.4
Total Commitments [Abstract]
Total Commitments, Due in Next Twelve Months	712.4
Total Commitments, Due within Two Years	306.0
Total Commitments, Due within Three Years	232.8
Total Commitments, Due within Four Years	206.8
Total Commitments, Due within Five Years	178.5
Total Commitments, Due Thereafter	883.9
Total Commitments Due	2,520.4
Public Utilities, Inventory, Fuel [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	381.8
Unrecorded Unconditional Purchase Obligation, Due within Two Years	195.0
Unrecorded Unconditional Purchase Obligation, Due within Three Years	143.8
Unrecorded Unconditional Purchase Obligation, Due within Four Years	142.8
Unrecorded Unconditional Purchase Obligation, Due within Five Years	117.2
Unrecorded Unconditional Purchase Obligation, Due after Five Years	90.2
Unrecorded Unconditional Purchase Obligation, Total	1,070.8
Purchased Power [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	46.4
Unrecorded Unconditional Purchase Obligation, Due within Two Years	46.4
Unrecorded Unconditional Purchase Obligation, Due within Three Years	46.4
Unrecorded Unconditional Purchase Obligation, Due within Four Years	44.8
Unrecorded Unconditional Purchase Obligation, Due within Five Years	47.3
Unrecorded Unconditional Purchase Obligation, Due after Five Years	604.1
Unrecorded Unconditional Purchase Obligation, Total	835.4
Capacity [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	3.3
Unrecorded Unconditional Purchase Obligation, Due within Two Years	3.0
Unrecorded Unconditional Purchase Obligation, Due within Three Years	1.2
Unrecorded Unconditional Purchase Obligation, Due within Four Years	0
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0
Unrecorded Unconditional Purchase Obligation, Due after Five Years	0
Unrecorded Unconditional Purchase Obligation, Total	7.5
Non-regulated natural gas transportation [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	3.5
Unrecorded Unconditional Purchase Obligation, Due within Two Years	3.5
Unrecorded Unconditional Purchase Obligation, Due within Three Years	3.5
Unrecorded Unconditional Purchase Obligation, Due within Four Years	1.0
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0
Unrecorded Unconditional Purchase Obligation, Due after Five Years	0
Unrecorded Unconditional Purchase Obligation, Total	11.5
La Cygne Environmental Project [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	205.5
Unrecorded Unconditional Purchase Obligation, Due within Two Years	7.3
Unrecorded Unconditional Purchase Obligation, Due within Three Years	0
Unrecorded Unconditional Purchase Obligation, Due within Four Years	0
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0
Unrecorded Unconditional Purchase Obligation, Due after Five Years	0
Unrecorded Unconditional Purchase Obligation, Total	212.8
Other purchase commitments [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	56.2
Unrecorded Unconditional Purchase Obligation, Due within Two Years	36.8
Unrecorded Unconditional Purchase Obligation, Due within Three Years	27.5
Unrecorded Unconditional Purchase Obligation, Due within Four Years	8.1
Unrecorded Unconditional Purchase Obligation, Due within Five Years	3.9
Unrecorded Unconditional Purchase Obligation, Due after Five Years	46.6
Unrecorded Unconditional Purchase Obligation, Total	179.1
Kansas City Power and Light Company [Member]
Lease Expense [Abstract]
Lease expense	16.0	17.7	17.0
Operating Leases [Abstract]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	13.5
Operating Leases, Future Minimum Payments, Due in Two Years	12.2
Operating Leases, Future Minimum Payments, Due in Three Years	9.9
Operating Leases, Future Minimum Payments, Due in Four Years	9.7
Operating Leases, Future Minimum Payments, Due in Five Years	9.7
Operating Leases, Future Minimum Payments, Due Thereafter	138.6
Operating Leases, Future Minimum Payments Due, Total	193.6
Capital Leases [Abstract]
Capital Leases, Future Minimum Payments Due, Next Twelve Months	0.2
Capital Leases, Future Minimum Payments Due in Two Years	0.2
Capital Leases, Future Minimum Payments Due in Three Years	0.2
Capital Leases, Future Minimum Payments Due in Four Years	0.2
Capital Leases, Future Minimum Payments Due in Five Years	0.2
Capital Leases, Future Minimum Payments Due Thereafter	2.2
Capital Leases, Future Minimum Payments Due, Total	3.2
Total Commitments [Abstract]
Total Commitments, Due in Next Twelve Months	605.2
Total Commitments, Due within Two Years	233.0
Total Commitments, Due within Three Years	186.0
Total Commitments, Due within Four Years	169.3
Total Commitments, Due within Five Years	138.5
Total Commitments, Due Thereafter	698.5
Total Commitments Due	2,030.5
Kansas City Power and Light Company [Member] \| Supply Commitment [Member]
Total Commitments [Abstract]
Capacity Sales Agreements from 2014 to 2016	5.5
Capacity Sales Agreements per Year (2017 to 2018)	1.3
Kansas City Power and Light Company [Member] \| Reimbursement Commitments [Member]
Total Commitments [Abstract]
Reimbursement by Other Owners per Year (2014 to 2015)	2.0
Reimbursements by Other Owners per Year (2016 to 2025)	0.4
Reimbursements by Other Owners Total	8.2
Kansas City Power and Light Company [Member] \| Public Utilities, Inventory, Fuel [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	294.3
Unrecorded Unconditional Purchase Obligation, Due within Two Years	148.4
Unrecorded Unconditional Purchase Obligation, Due within Three Years	113.2
Unrecorded Unconditional Purchase Obligation, Due within Four Years	117.4
Unrecorded Unconditional Purchase Obligation, Due within Five Years	90.8
Unrecorded Unconditional Purchase Obligation, Due after Five Years	90.2
Unrecorded Unconditional Purchase Obligation, Total	854.3
Kansas City Power and Light Company [Member] \| Purchased Power [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	34.8
Unrecorded Unconditional Purchase Obligation, Due within Two Years	34.8
Unrecorded Unconditional Purchase Obligation, Due within Three Years	34.8
Unrecorded Unconditional Purchase Obligation, Due within Four Years	34.8
Unrecorded Unconditional Purchase Obligation, Due within Five Years	34.8
Unrecorded Unconditional Purchase Obligation, Due after Five Years	429.4
Unrecorded Unconditional Purchase Obligation, Total	603.4
Kansas City Power and Light Company [Member] \| Capacity [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	2.9
Unrecorded Unconditional Purchase Obligation, Due within Two Years	3.0
Unrecorded Unconditional Purchase Obligation, Due within Three Years	1.2
Unrecorded Unconditional Purchase Obligation, Due within Four Years	0
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0
Unrecorded Unconditional Purchase Obligation, Due after Five Years	0
Unrecorded Unconditional Purchase Obligation, Total	7.1
Kansas City Power and Light Company [Member] \| La Cygne Environmental Project [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	205.5
Unrecorded Unconditional Purchase Obligation, Due within Two Years	7.3
Unrecorded Unconditional Purchase Obligation, Due within Three Years	0
Unrecorded Unconditional Purchase Obligation, Due within Four Years	0
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0
Unrecorded Unconditional Purchase Obligation, Due after Five Years	0
Unrecorded Unconditional Purchase Obligation, Total	212.8
Kansas City Power and Light Company [Member] \| Other purchase commitments [Member]
Purchase Commitments [Abstract]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	54.0
Unrecorded Unconditional Purchase Obligation, Due within Two Years	27.1
Unrecorded Unconditional Purchase Obligation, Due within Three Years	26.7
Unrecorded Unconditional Purchase Obligation, Due within Four Years	7.2
Unrecorded Unconditional Purchase Obligation, Due within Five Years	3.0
Unrecorded Unconditional Purchase Obligation, Due after Five Years	38.1
Unrecorded Unconditional Purchase Obligation, Total	$ 156.1

Commitments and Contingencies Environmental Matters (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013 T MW	Dec. 31, 2012
Estimates Of Environmental Financial Impact And Related Issues [Line Items]
Current estimate of capital expenditures final regulations	$ 700
Current estimate of capital expenditures for proposed regulations, minimum	600
Current estimate of capital expenditures for proposed regulations, maximum	800
Clean Air Interstate Rule (CAIR) and Cross-State Air Pollution Rule (CSAPR) [Abstract]
Number Of States Required To Reduce Emissions Under Cair	28
Mercury and Air Toxics Standards Rule [Abstract]
Capacity of electric steam generating units that fall under MACT standards (in megawatts)	25
SO2 National Ambient Air Quality Standard (NAAQS) [Abstract]
Primary one-hour sulfur dioxide standard, as revised June 2010 (in parts per million)	0.075
Primary twenty-four hour sulfur dioxide standard, prior to June 2010 (in parts per million)	0.140
Primary one-year sulfur dioxide standard, prior to June 2010 (in parts per million)	0.030
Climate Change [Abstract]
CO2 produced per year (in tons)	25,000,000
Remediation [Abstract]
Amount accrued for future investigation remediation and of GMO retained liabilities	1.4	2.0
Jeffrey Units Nos 1 and 2 [Member]
New Source Review [Abstract]
Estimated cost to install a selective catalytic reduction system at Jeffrey Energy Center pursuant to a settlement agreement	240
LaCygne Station [Member]
Best Available Retrofit Technology Rule [Abstract]
Predetermination request for environmental equipment required at LaCygne Station to comply with BART	1,230
Entity's ownership percentage in facility (in hundredths)	50.00%
Kansas City Power and Light Company [Member]
Estimates Of Environmental Financial Impact And Related Issues [Line Items]
Cash capital expenditures incurred for La Cygne environmental project	377
Current estimate of capital expenditures for proposed regulations, minimum	350
Current estimate of capital expenditures for proposed regulations, maximum	450
Climate Change [Abstract]
CO2 produced per year (in tons)	18,000,000
Minimum required renewable energy generation capacity percentage in Kansas by 2011	10.00%
Minimum required renewable energy generation capacity percentage in Kansas by 2016	15.00%
Minimum required renewable energy generation capacity percentage in Kansas by 2020	20.00%
Minimum required renewable energy generation capacity percentage in Missouri by 2011	2.00%
Minimum required renewable energy generation capacity percentage in Missouri by 2014	5.00%
Minimum required renewable energy generation capacity percentage in Missouri by 2018	10.00%
Minimum required renewable energy generation capacity percentage in Missouri by 2021	15.00%
Estimated electricity required to come from solar resources (in megawatts)	2
Remediation [Abstract]
Accrued environmental remediation expenses	0.3	0.3
Kansas City Power and Light Company [Member] \| LaCygne Station [Member]
Best Available Retrofit Technology Rule [Abstract]
Predetermination request for environmental equipment required at LaCygne Station to comply with BART	615
Entity's ownership percentage in facility (in hundredths)	50.00%
KCPL Greater Missouri Operations [Member]
Climate Change [Abstract]
Minimum required renewable energy generation capacity percentage in Missouri by 2011	2.00%
Minimum required renewable energy generation capacity percentage in Missouri by 2014	5.00%
Minimum required renewable energy generation capacity percentage in Missouri by 2018	10.00%
Minimum required renewable energy generation capacity percentage in Missouri by 2021	15.00%
Estimated electricity required to come from solar resources (in megawatts)	2
Remediation [Abstract]
Estimated amount of insurance proceeds available to cover qualified remediation expenses	$ 1.3
KCPL Greater Missouri Operations [Member] \| Jeffrey Units Nos 1 and 2 [Member]
Best Available Retrofit Technology Rule [Abstract]
Entity's ownership percentage in facility (in hundredths)	8.00%
Westar Energy Inc [Member] \| Jeffrey Units Nos 1 and 2 [Member]
Best Available Retrofit Technology Rule [Abstract]
Entity's ownership percentage in facility (in hundredths)	92.00%

Guarantees (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 140.6
Guarantor Obligations, Origin and Purpose	In the ordinary course of business, Great Plains Energy and certain of its subsidiaries enter into various agreements providing financial or performance assurance to third parties on behalf of certain subsidiaries. Such agreements include, for example, guarantees and letters of credit. These agreements are entered into primarily to support or enhance the creditworthiness otherwise attributed to a subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish the subsidiary's intended business purposes.
Direct Guarantee [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	40.7
Guarantor Obligations, Term	expire in 2014 and 2015
Guarantor Obligations, Origin and Purpose	direct guarantees to GMO counterparties
Guarantee of Indebtedness of Others [Member] \| Long-term Debt [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	99.9
Guarantor Obligations, Term	maturity dates ranging from 2014-2023
Guarantor Obligations, Origin and Purpose	guarantee of GMO long-term debt
Guarantee of Indebtedness of Others [Member] \| Commercial Paper [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 15.0
Guarantor Obligations, Origin and Purpose	guaranteed GMO's commercial paper program

Related Party Transactions and Relationships (Details) (Kansas City Power and Light Company [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
KCPL Greater Missouri Operations [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	$ 32.7	$ 26.2
KCPL employees manage GMO's business and operate its facilities at cost	223.6	207.9	202.7
KCPL net wholesale sales to GMO	25.6	29.4	18.2
KCPL Greater Missouri Operations [Member] \| Money Pool [Member]
Related Party Transaction [Line Items]
Payable to Related Party	0.2
Great Plains Energy [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	17.5	13.8
Great Plains Energy [Member] \| Money Pool [Member]
Related Party Transaction [Line Items]
Payable to Related Party		$ 3.8

Carrying amount as of the balance sheet date of obligations due all related parties. For classified balance sheets, represents the current portion of such liabilities (due within one year or within the normal operating cycle if longer).

+ References+ Details

Derivative Instruments (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Futures contracts [Member] \| Cash Flow Hedging [Member]
Price Risk Derivatives [Abstract]
Notional Contract Amount	$ 0	$ 1.0
Fair Value	0	(0.2)
Futures contracts [Member] \| Not Designated as Hedging Instrument [Member]
Price Risk Derivatives [Abstract]
Notional Contract Amount	19.3	17.9
Fair Value	(0.6)	(2.8)
Forward Contracts [Member] \| Not Designated as Hedging Instrument [Member]
Price Risk Derivatives [Abstract]
Notional Contract Amount	47.7	65.5
Fair Value	5.2	6.5
Option contracts [Member] \| Not Designated as Hedging Instrument [Member]
Price Risk Derivatives [Abstract]
Notional Contract Amount	4.8	0
Fair Value	1.2	0
Transmission Congestion Rights [Member] \| Not Designated as Hedging Instrument [Member]
Price Risk Derivatives [Abstract]
Notional Contract Amount	22.9	0
Fair Value	1.7	0
Kansas City Power and Light Company [Member] \| Futures contracts [Member] \| Cash Flow Hedging [Member]
Price Risk Derivatives [Abstract]
Notional Contract Amount	0	1.0
Fair Value	0	(0.2)
Kansas City Power and Light Company [Member] \| Futures contracts [Member] \| Not Designated as Hedging Instrument [Member]
Price Risk Derivatives [Abstract]
Notional Contract Amount	7.7	0
Fair Value	(0.2)	0
Kansas City Power and Light Company [Member] \| Transmission Congestion Rights [Member] \| Not Designated as Hedging Instrument [Member]
Price Risk Derivatives [Abstract]
Notional Contract Amount	18.0	0
Fair Value	$ 1.1	$ 0
KCPL Greater Missouri Operations [Member]
Price Risk Derivatives [Abstract]
Percentage of expected on peak natural gas and natural gas equivalent purchased power price exposure hedged year one	40.00%
Percentage of expected on peak natural gas and natural gas equivalent purchased power price exposure hedged year two	6.00%

Derivative Instruments Derivative Instruments Offsetting (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Derivative Assets [Abstract]
Derivative Asset, Fair Value, Gross Asset	$ 8.5	$ 6.5
Derivative Asset, Fair Value, Gross Amounts Offset	(0.7)	0
Derivative Assets, Fair Value, Net	7.8	6.5
Derivative, Collateral, Obligation to Return Securities	0	0
Derivative, Collateral, Obligation to Return Cash	0	0
Derivative Assets Net of Gross Amounts Offset And Not Offset	7.8	6.5
Derivative Liabilities [Abstract]
Derivative Liability, Fair Value, Gross Liability	1.0	3.0
Derivative Liability, Fair Value, Gross Amounts Offset	(0.9)	(3.0)
Derivative Liabilities, Fair Value, Net	0.1	0
Derivative, Collateral, Right to Reclaim Securities	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Fair Value, Net of Gross Amounts Offset And Not Offset	0.1	0
Kansas City Power and Light Company [Member]
Derivative Assets [Abstract]
Derivative Asset, Fair Value, Gross Asset	1.2
Derivative Asset, Fair Value, Gross Amounts Offset	(0.1)
Derivative Assets, Fair Value, Net	1.1
Derivative, Collateral, Obligation to Return Securities	0
Derivative, Collateral, Obligation to Return Cash	0
Derivative Assets Net of Gross Amounts Offset And Not Offset	1.1
Derivative Liabilities [Abstract]
Derivative Liability, Fair Value, Gross Liability	0.3	0.2
Derivative Liability, Fair Value, Gross Amounts Offset	(0.3)	(0.2)
Derivative Liabilities, Fair Value, Net	0	0
Derivative, Collateral, Right to Reclaim Securities	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Fair Value, Net of Gross Amounts Offset And Not Offset	$ 0	$ 0

Derivative Instruments Fair Value (Details) (USD $)
In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Derivative asset, fair value, amount not offset against collateral

$ 6.5

Derivative liability, fair value, amount not offset against collateral

3.0

Accumulated Other Comprehensive Income (Loss), Net of Tax

(25.3)

^[1]

(38.4)

^[1]

Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), Net of Tax

(23.8)

^[1]

(35.4)

^[1]

Kansas City Power and Light Company [Member]

Accumulated Other Comprehensive Income (Loss), Net of Tax

(20.2)

(25.8)

Kansas City Power and Light Company [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), Net of Tax

(20.2)

^[1]

(25.8)

^[1]

Current assets [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), before Tax

9.9

10.6

Current assets [Member] | Kansas City Power and Light Company [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), before Tax

9.9

10.6

Current liabilities [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), before Tax

(48.9)

(68.4)

Current liabilities [Member] | Kansas City Power and Light Company [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), before Tax

(43.1)

(52.8)

Noncurrent liabilities [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), before Tax

(0.1)

Noncurrent liabilities [Member] | Kansas City Power and Light Company [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), before Tax

(0.1)

Deferred income taxes [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), before Tax

15.2

22.5

Deferred income taxes [Member] | Kansas City Power and Light Company [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Accumulated Other Comprehensive Income (Loss), before Tax

13.0

16.5

Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Balance Sheet Location [Member]

Derivative asset, fair value, amount not offset against collateral

Derivative liability, fair value, amount not offset against collateral

0.2

Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Other Balance Sheet Location [Member] | Kansas City Power and Light Company [Member]

Derivative asset, fair value, amount not offset against collateral

Derivative liability, fair value, amount not offset against collateral

0.2

Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Balance Sheet Location [Member]

Derivative asset, fair value, amount not offset against collateral

8.5

6.5

Derivative liability, fair value, amount not offset against collateral

1.0

2.8

Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Balance Sheet Location [Member] | Kansas City Power and Light Company [Member]

Derivative asset, fair value, amount not offset against collateral

1.2

Derivative liability, fair value, amount not offset against collateral

$ 0.3

[1]	Net of tax

Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge.

+ References+ Details

Fair value of financial asset or other contract with one or more underlyings, notional amount or payment provision or both, and the contract can be net settled by means outside the contract or delivery of an asset, elected not to be offset against an obligation to return collateral under a master netting arrangement.

+ References+ Details

Fair value of financial liability or contract with one or more underlyings, notional amount or payment provision or both, and the contract can be net settled by means outside the contract or delivery of an asset, elected not to be offset against a right to receive collateral under a master netting arrangement.

+ References+ Details

Derivative Instruments by Hedging Relationship by Income Statement Location (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	$ 0	$ (0.1)
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	(11.6)	(12.6)
Cash Flow Hedging [Member] \| Kansas City Power and Light Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	0	(0.1)
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	(5.6)	(5.7)
Cash Flow Hedging [Member] \| Interest charges [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	(18.6)	(20.2)
Cash Flow Hedging [Member] \| Interest charges [Member] \| Kansas City Power and Light Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	(8.8)	(8.7)
Cash Flow Hedging [Member] \| Fuel Costs [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	(0.3)	(0.5)
Cash Flow Hedging [Member] \| Fuel Costs [Member] \| Kansas City Power and Light Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	(0.3)	(0.5)
Cash Flow Hedging [Member] \| Income tax benefit (expense) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	7.3	8.1
Cash Flow Hedging [Member] \| Income tax benefit (expense) [Member] \| Kansas City Power and Light Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	3.5	3.5
Regulatory Account [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain(Loss) Reclassified from Regulatory Account into Income	(1.9)	(6.6)
Amount of Gain (Loss) Recognized on Regulatory Account on Derivatives	2.0	(2.7)
Regulatory Account [Member] \| Fuel Costs [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain(Loss) Reclassified from Regulatory Account into Income	(1.9)	(6.6)
Interest Rate Contract [Member] \| Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	0	0
Interest Rate Contract [Member] \| Cash Flow Hedging [Member] \| Kansas City Power and Light Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	0	0
Commodity Contract [Member] \| Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	0	(0.1)
Commodity Contract [Member] \| Cash Flow Hedging [Member] \| Kansas City Power and Light Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	0	(0.1)
Commodity Contract [Member] \| Regulatory Account [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized on Regulatory Account on Derivatives	2.0	(2.7)
Income tax benefit (expense) [Member] \| Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	0	0
Income tax benefit (expense) [Member] \| Cash Flow Hedging [Member] \| Kansas City Power and Light Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	$ 0	$ 0

Fair Value Measurements Fair Value Long-Term Debt (Details) (USD $) In Billions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Fair value of financial instruments [Abstract]
Long-term Debt	$ 3.5	$ 3.0
Carrying (Reported) Amount, Fair Value Disclosure [Member] \| Kansas City Power and Light Company [Member]
Fair value of financial instruments [Abstract]
Long-term Debt	2.3	1.9
Fair Value, Inputs, Level 2 [Member] \| Estimate of Fair Value Measurement [Member]
Fair value of financial instruments [Abstract]
Long-term debt fair value	3.7	3.5
Fair Value, Inputs, Level 2 [Member] \| Estimate of Fair Value Measurement [Member] \| Kansas City Power and Light Company [Member]
Fair value of financial instruments [Abstract]
Long-term debt fair value	$ 2.5	$ 2.2

+ References+ Details

Fair Value Measurements (Details) (USD $)
In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

$ 7.8

$ 6.5

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

0.1

Kansas City Power and Light Company [Member]

Cash and cash equivalents from nuclear decommissioning trust

2.9

1.1

Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value Measurement [Member]

7.8

^[1]

6.5

^[1]

183.9

^[2]

151.8

^[2]

Self Insured Health Plan Trust Fair Value Disclosure

14.8

^[3]

18.7

^[4]

20.3

^[4]

225.2

178.6

0.1

^[1]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

0.1

Fair Value, Measurements, Recurring [Member] | Netting [Member]

Cash collateral posted with third parties as part of netting agreements

0.2

3.0

(0.7)

^[1],[5]

^[2],[5]

Self Insured Health Plan Trust Fair Value Disclosure

^[3]

^[4],[5]

(0.7)

^[5]

(0.9)

^[1],[5]

(3.0)

^[1],[5]

(0.9)

^[5]

(3.0)

^[5]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]

0.3

^[1]

152.7

^[2]

118.6

^[2]

Self Insured Health Plan Trust Fair Value Disclosure

4.8

^[3]

0.1

^[4]

0.1

^[4]

157.9

118.7

0.9

^[1]

3.0

^[1]

0.9

3.0

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

4.9

^[1]

4.2

^[1]

31.2

^[2]

33.2

^[2]

Self Insured Health Plan Trust Fair Value Disclosure

10.0

^[3]

18.6

^[4]

20.2

^[4]

64.7

57.6

0.1

^[1]

0.1

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]

3.3

^[1]

2.3

^[1]

^[2]

Self Insured Health Plan Trust Fair Value Disclosure

^[3]

^[4]

3.3

2.3

^[1]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member]

1.1

^[1]

183.9

151.8

Self Insured Health Plan Trust Fair Value Disclosure

14.8

199.8

151.8

^[1]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Equity Securities [Member]

127.7

100.1

Self Insured Health Plan Trust Fair Value Disclosure

0.9

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Debt Securities [Member]

Self Insured Health Plan Trust Fair Value Disclosure

9.3

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | US Treasury and Government [Member]

21.2

18.5

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | US Government Corporations and Agencies Securities [Member]

2.8

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | US States and Political Subdivisions Debt Securities [Member]

3.9

3.3

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Corporate Debt Securities [Member]

24.4

26.8

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Foreign Government Debt Securities [Member]

0.5

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Cash Equivalents [Member]

3.8

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Other Assets [Member]

(0.4)

0.3

Self Insured Health Plan Trust Fair Value Disclosure

1.2

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Cash and Cash Equivalents [Member]

Self Insured Health Plan Trust Fair Value Disclosure

3.4

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member]

(0.1)

^[1],[5]

^[5]

Self Insured Health Plan Trust Fair Value Disclosure

^[5]

(0.1)

^[5]

(0.3)

^[1],[5]

(0.2)

^[1],[5]

(0.3)

^[5]

(0.2)

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | Equity Securities [Member]

^[5]

Self Insured Health Plan Trust Fair Value Disclosure

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | Debt Securities [Member]

Self Insured Health Plan Trust Fair Value Disclosure

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | US Treasury and Government [Member]

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | US Government Corporations and Agencies Securities [Member]

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | US States and Political Subdivisions Debt Securities [Member]

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | Corporate Debt Securities [Member]

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | Foreign Government Debt Securities [Member]

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | Cash Equivalents [Member]

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | Other Assets [Member]

^[5]

Self Insured Health Plan Trust Fair Value Disclosure

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Netting [Member] | Cash and Cash Equivalents [Member]

Self Insured Health Plan Trust Fair Value Disclosure

^[5]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member]

0.1

^[1]

152.7

118.6

Self Insured Health Plan Trust Fair Value Disclosure

4.8

157.6

118.6

0.3

^[1]

0.2

^[1]

0.3

0.2

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member]

127.7

100.1

Self Insured Health Plan Trust Fair Value Disclosure

0.9

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Debt Securities [Member]

Self Insured Health Plan Trust Fair Value Disclosure

0.5

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | US Treasury and Government [Member]

21.2

18.5

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | US Government Corporations and Agencies Securities [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | US States and Political Subdivisions Debt Securities [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Corporate Debt Securities [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Foreign Government Debt Securities [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Cash Equivalents [Member]

3.8

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Other Assets [Member]

Self Insured Health Plan Trust Fair Value Disclosure

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member]

Self Insured Health Plan Trust Fair Value Disclosure

3.4

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member]

^[1]

31.2

33.2

Self Insured Health Plan Trust Fair Value Disclosure

10.0

41.2

33.2

^[1]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]

Self Insured Health Plan Trust Fair Value Disclosure

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]

Self Insured Health Plan Trust Fair Value Disclosure

8.8

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | US Treasury and Government [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | US Government Corporations and Agencies Securities [Member]

2.8

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | US States and Political Subdivisions Debt Securities [Member]

3.9

3.3

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Corporate Debt Securities [Member]

24.4

26.8

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Foreign Government Debt Securities [Member]

0.5

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Cash Equivalents [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Other Assets [Member]

(0.4)

0.3

Self Insured Health Plan Trust Fair Value Disclosure

1.2

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member]

Self Insured Health Plan Trust Fair Value Disclosure

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member]

1.1

^[1]

Self Insured Health Plan Trust Fair Value Disclosure

1.1

^[1]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]

Self Insured Health Plan Trust Fair Value Disclosure

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member]

Self Insured Health Plan Trust Fair Value Disclosure

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | US Treasury and Government [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | US Government Corporations and Agencies Securities [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | US States and Political Subdivisions Debt Securities [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Corporate Debt Securities [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Foreign Government Debt Securities [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Cash Equivalents [Member]

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Other Assets [Member]

Self Insured Health Plan Trust Fair Value Disclosure

Fair Value, Measurements, Recurring [Member] | Kansas City Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Cash and Cash Equivalents [Member]

Self Insured Health Plan Trust Fair Value Disclosure

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Estimate of Fair Value Measurement [Member]

6.7

^[1]

6.5

^[1]

18.7

20.3

25.4

26.8

0.1

^[1]

0.1

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Estimate of Fair Value Measurement [Member] | Equity Securities [Member]

0.1

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Estimate of Fair Value Measurement [Member] | Fixed Income Funds [Member]

18.6

20.2

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Netting [Member]

(0.6)

^[1],[5]

^[5]

(0.6)

^[5]

(0.6)

^[1],[5]

(2.8)

^[1],[5]

(0.6)

^[5]

(2.8)

^[5]

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Netting [Member] | Equity Securities [Member]

^[5]

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Netting [Member] | Fixed Income Funds [Member]

^[5]

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 1 [Member]

0.2

^[1]

0.1

0.3

0.1

0.6

^[1]

2.8

^[1]

0.6

2.8

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member]

0.1

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 1 [Member] | Fixed Income Funds [Member]

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 2 [Member]

4.9

^[1]

4.2

^[1]

18.6

20.2

23.5

24.4

0.1

^[1]

0.1

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Income Funds [Member]

18.6

20.2

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 3 [Member]

2.2

^[1]

2.3

^[1]

2.2

2.3

^[1]

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]

Fair Value, Measurements, Recurring [Member] | Other Great Plains [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Income Funds [Member]

Accumulated Other Comprehensive Income (Loss) [Line Items]

$ 0

[1]	The fair value of derivative instruments is estimated using market quotes, over-the-counter forward price and volatility curves and correlations among fuel prices, net of estimated credit risk. Derivative instruments classified as Level 1 represent exchange traded derivative instruments. Derivative instruments classified as Level 2 represent non-exchange traded derivative instruments traded in over-the-counter markets. Derivative instruments classified as Level 3 represent non-exchange traded derivatives traded in over-the-counter markets for which observable market data is not available to corroborate the valuation inputs and TCRs valued at the most recent auction price in the SPP Integrated Marketplace.
[2]	Fair value is based on quoted market prices of the investments held by the fund and/or valuation models. The total does not include $2.9 million of cash and cash equivalents at December 31, 2012.
[3]	Fair value is based on quoted market prices of the investments held by the trust. Debt securities classified as Level 1 are comprised of U.S. Treasury securities. Debt securities classified as Level 2 are comprised of corporate bonds, U.S. Agency, state and local obligations, and other asset-backed securities.
[4]	Fair value is based on quoted market prices and/or valuation models for equity securities and NAV per share for fixed income funds.
[5]	Represents the difference between derivative contracts in an asset or liability position presented on a net basis by counterparty on the consolidated balance sheets where a master netting agreement exists between the Company and the counterparty. At December 31, 2013 and 2012, Great Plains Energy netted $0.2 million and $3.0 million, respectively, of cash collateral posted with counterparties.

Fair Value Measurements Level 3 (Details) (Fair Value, Measurements, Recurring [Member], Fair Value, Inputs, Level 3 [Member], Derivative Financial Instruments, Assets [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Balance at beginning of period	$ 2.3	$ 3.1
Total realized/unrealized gains or (losses) included in non-operating income	9.5	8.2
Purchases	1.7	0
Settlements	(10.2)	(9.0)
Balance at end of period	3.3	2.3
Total unrealized gains and (losses) included in non-operating income relating to assets and liabilities still on the consolidated balance sheet at period end	(0.3)	(0.4)
Kansas City Power and Light Company [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Balance at beginning of period	0
Purchases	1.1
Balance at end of period	$ 1.1

Accumulated Other Comprehensive Income (Loss) (Details) (USD $)
In Millions, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Other comprehensive income before reclassifications

$ (38.4)

^[1]

1.2

^[1]

Amounts reclassified from accumulated other comprehensive loss

11.9

^[1]

13.1

^[1]

11.4

6.3

Accumulated Other Comprehensive Income (Loss) [Line Items]

(25.3)

^[1]

(38.4)

^[1]

Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Other comprehensive income before reclassifications

(35.4)

^[1]

^[1]

Amounts reclassified from accumulated other comprehensive loss

11.6

^[1]

11.6

^[1]

Accumulated Other Comprehensive Income (Loss) [Line Items]

(23.8)

^[1]

Accumulated Defined Benefit Plans Adjustment [Member]

Other comprehensive income before reclassifications

(3.0)

^[1]

1.2

^[1]

Amounts reclassified from accumulated other comprehensive loss

0.3

^[1]

1.5

^[1]

Accumulated Other Comprehensive Income (Loss) [Line Items]

(1.5)

^[1]

Kansas City Power and Light Company [Member]

(25.8)

5.6

5.0

Accumulated Other Comprehensive Income (Loss) [Line Items]

(20.2)

(25.8)

Kansas City Power and Light Company [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]

Amounts reclassified from accumulated other comprehensive loss

(25.8)

^[1]

5.6

^[1]

5.6

^[1]

$ (20.2)

^[1]

[1]	Net of tax

+ References+ Details

Accumulated Other Comprehensive Income (Loss) Reclassification (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest charges									$ (198.4)	$ (220.8)	$ (218.4)
Fuel									(539.5)	(539.5)	(483.8)
Utility operating and maintenance expenses									(671.4)	(647.3)	(658.2)
Income before income tax (expense) benefit and income (loss) from equity investments									379.6	304.9	259.1
Income tax (expense) benefit									(129.2)	(104.6)	(84.8)
Net income (loss)	17.5	143.1	63.6	26.0	4.7	146.4	58.1	(9.3)	250.2	199.9	174.2
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income (loss)									(11.9)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income tax (expense) benefit and income (loss) from equity investments									(18.9)
Income tax (expense) benefit									7.3
Net income (loss)									(11.6)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member] \| Interest Rate Contract [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest charges									(18.6)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member] \| Commodity Contract [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Fuel									(0.3)
Accumulated Defined Benefit Plans Adjustment [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Utility operating and maintenance expenses									(0.5)
Income before income tax (expense) benefit and income (loss) from equity investments									(0.5)
Income tax (expense) benefit									0.2
Net income (loss)									(0.3)
Kansas City Power and Light Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest charges									(125.3)	(127.6)	(115.6)
Fuel									(383.0)	(384.8)	(333.5)
Utility operating and maintenance expenses									(475.9)	(460.1)	(470.9)
Income before income tax (expense) benefit and income (loss) from equity investments									248.8	216.9	204.6
Income tax (expense) benefit									(79.8)	(75.3)	(69.1)
Net income (loss)	12.2	96.4	44.2	16.2	5.4	90.2	43.7	2.3	169.0	141.6	135.5
Kansas City Power and Light Company [Member] \| Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income tax (expense) benefit and income (loss) from equity investments									(9.1)
Income tax (expense) benefit									3.5
Net income (loss)									(5.6)
Kansas City Power and Light Company [Member] \| Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member] \| Interest Rate Contract [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest charges									(8.8)
Kansas City Power and Light Company [Member] \| Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member] \| Commodity Contract [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Fuel									$ (0.3)

Income Tax Expense (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Current income taxes
Federal	$ 0.3	$ (3.2)	$ 2.9
State	(3.0)	(6.3)	(6.0)
Foreign	0	0	(0.4)
Current Income Tax Expense (Benefit), Total	(2.7)	(9.5)	(3.5)
Deferred income taxes
Federal	109.1	96.3	90.5
State	24.9	24.9	20.7
Deferred Income Tax Expense (Benefit), Total	134.0	121.2	111.2
Noncurrent income taxes
Federal	0	(0.2)	(18.0)
State	(0.3)	(0.3)	(2.1)
Foreign	(0.4)	(4.2)	(0.6)
Noncurrent Income Tax Expense (Benefit), Total	(0.7)	(4.7)	(20.7)
Investment tax credit
Deferral	0.3	0	0
Amortization	(1.7)	(2.4)	(2.2)
Investment Tax Credit, Total	(1.4)	(2.4)	(2.2)
Total income tax expense	129.2	104.6	84.8
Effective Income Tax Rate Reconciliation, Percent [Abstract]
Federal statutory income tax (in hundredths)	35.00%	35.00%	35.00%
Differences between book and tax depreciation not normalized (in hundredths)	(0.30%)	1.20%	1.50%
Amortization of investments tax credits (in hundredths)	(0.40%)	(0.80%)	(0.80%)
Federal income tax credits (in hundredths)	(3.50%)	(3.10%)	(5.00%)
State income taxes (in hundredths)	3.80%	4.00%	4.00%
Changes in uncertain tax positions, net (in hundredths)	(0.20%)	(1.50%)	(1.70%)
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance	0.00%	0.00%	(0.80%)
Effective Income Tax Rate Reconciliation, Other Adjustments	(0.40%)	(0.50%)	0.50%
Effective Income Tax Rate, Continuing Operations, Total	34.00%	34.30%	32.70%
Kansas City Power and Light Company [Member]
Current income taxes
Federal	(0.5)	13.1	1.0
State	(0.5)	2.0	(0.6)
Current Income Tax Expense (Benefit), Total	(1.0)	15.1	0.4
Deferred income taxes
Federal	75.8	48.8	66.0
State	16.3	11.4	14.6
Deferred Income Tax Expense (Benefit), Total	92.1	60.2	80.6
Noncurrent income taxes
Federal	(9.0)	1.7	(9.3)
State	(1.5)	0.1	(1.1)
Noncurrent Income Tax Expense (Benefit), Total	(10.5)	1.8	(10.4)
Investment tax credit
Deferral	0.3	0	0
Amortization	(1.1)	(1.8)	(1.5)
Investment Tax Credit, Total	(0.8)	(1.8)	(1.5)
Total income tax expense	79.8	75.3	69.1
Effective Income Tax Rate Reconciliation, Percent [Abstract]
Federal statutory income tax (in hundredths)	35.00%	35.00%	35.00%
Differences between book and tax depreciation not normalized (in hundredths)	(0.80%)	1.30%	1.60%
Amortization of investments tax credits (in hundredths)	(0.40%)	(0.80%)	(0.70%)
Federal income tax credits (in hundredths)	(5.30%)	(4.30%)	(6.30%)
State income taxes (in hundredths)	3.70%	4.10%	3.90%
Changes in uncertain tax positions, net (in hundredths)	0.00%	0.00%	0.10%
Effective Income Tax Rate Reconciliation, Other Adjustments	(0.10%)	(0.60%)	0.20%
Effective Income Tax Rate, Continuing Operations, Total	32.10%	34.70%	33.80%
Parent Company [Member]
Deferred income taxes
Deferred Income Tax Expense (Benefit), Total	(10.5)	(4.8)	(18.6)
Investment tax credit
Total income tax expense	$ (4.2)	$ (11.6)	$ (17.1)

Taxes Deferred Income Taxes (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Deferred Tax Assets (Liabilities), Net of Valuation Allowance, Current Classification [Abstract]
Net operating loss carryforward, current	$ 76.6	$ 77.8
Deferred tax assets (liabilities), other current	5.7	12.7
Deferred tax assets (liabilities), before valuation allowance, current	82.3	90.5
Valuation allowance, current	(2.0)	(2.0)
Deferred Tax Assets (Liabilities), Net, Current	80.3	88.5
Deferred Tax Assets (Liabilities), Net of Valuation Allowance, Noncurrent Classification [Abstract]
Plant related	(1,433.8)	(1,297.2)
Income taxes on future regulatory recoveries	(136.4)	(138.3)
Derivative instruments	32.3	37.7
Pension and post-retirement benefits	(28.2)	(26.6)
SO2 emission allowance sales	28.8	29.7
Tax credit carryforwards	229.3	217.5
Customer demand programs	(27.7)	(28.7)
Net operating loss carryforward, noncurrent	446.7	439.4
Deferred Tax Liabilities, Other	(57.1)	(44.1)
Deferred tax assets (liabilities), before valuation allowance, noncurrent	(946.1)	(810.6)
Valuation allowance, noncurrent	(18.7)	(21.8)
Deferred Tax Assets (Liabilities), Net, Noncurrent	(964.8)	(832.4)
Deferred Tax Assets (Liabilities), Net	(884.5)	(743.9)
Deferred Tax Assets (Liabilities), Gross [Abstract]
Deferred Tax Assets, Gross	1,148.2	1,209.8
Deferred Tax Liabilities, Gross	(2,032.7)	(1,953.7)
Deferred Tax Assets, Net	(884.5)	(743.9)
Kansas City Power and Light Company [Member]
Deferred Tax Assets (Liabilities), Net of Valuation Allowance, Current Classification [Abstract]
Net operating loss carryforward, current	0	0
Deferred tax assets (liabilities), other current	(1.7)	4.6
Deferred tax assets (liabilities), before valuation allowance, current	(1.7)	4.6
Valuation allowance, current	0	0
Deferred Tax Assets (Liabilities), Net, Current	(1.7)	4.6
Deferred Tax Assets (Liabilities), Net of Valuation Allowance, Noncurrent Classification [Abstract]
Plant related	(1,022.9)	(930.7)
Income taxes on future regulatory recoveries	(111.0)	(114.7)
Derivative instruments	23.4	27.4
Pension and post-retirement benefits	(1.7)	(3.4)
SO2 emission allowance sales	28.8	30.4
Tax credit carryforwards	139.6	126.3
Customer demand programs	(19.4)	(19.2)
Net operating loss carryforward, noncurrent	71.6	72.4
Deferred Tax Liabilities, Other	(30.5)	(24.9)
Deferred tax assets (liabilities), before valuation allowance, noncurrent	(922.1)	(836.4)
Valuation allowance, noncurrent	0	0
Deferred Tax Assets (Liabilities), Net, Noncurrent	(922.1)	(836.4)
Deferred Tax Assets (Liabilities), Net	(923.8)	(831.8)
Deferred Tax Assets (Liabilities), Gross [Abstract]
Deferred Tax Assets, Gross	583.0	656.9
Deferred Tax Liabilities, Gross	(1,506.8)	(1,488.7)
Deferred Tax Assets, Net	$ (923.8)	$ (831.8)

Taxes Net Operating Loss Carryforwards (Details) (USD $) In Millions, unless otherwise specified			12 Months Ended
	Dec. 31, 2013 Internal Revenue Service (IRS) [Member]	Dec. 31, 2012 Internal Revenue Service (IRS) [Member]	Dec. 31, 2013 Internal Revenue Service (IRS) [Member] Minimum [Member]	Dec. 31, 2013 Internal Revenue Service (IRS) [Member] Maximum [Member]	Dec. 31, 2013 State and Local Jurisdiction [Member]	Dec. 31, 2012 State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 459.9	$ 451.1			$ 63.4	$ 66.1
Amount of Net Operating Losses related to business acquisition	304.6	304.8			44.4	47.9
Operating Loss Carryforwards, Valuation Allowance					20.3
Operating Loss Carryforwards, Expiration Date			Dec. 31, 2023	Dec. 31, 2032
Net operating losses year of origination [Abstract]
Net operating loss carryforwards originating in 2003	21.5
Net operating loss carryfowards originating in 2004	152.4
Net operating loss carryfowards originating in 2005	74.1
Net operating loss carryfowards originating in 2006	53.3
Net operating loss carryfowards originating in 2007	1.3
Net operating loss carryfowards originating in 2008	2.4
Net operating loss carryfowards originating in 2009	28.8
Net operating loss carryfowards originating in 2010	14.0
Net operating loss carryfowards originating in 2011	109.5
Net operating loss carryforwards originating in 2012	$ 2.6

Taxes Tax Credit Carryforwards (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
General Business Tax Credit Carryforward [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Amount	$ 141.1	$ 127.6
Amount of tax credit acquired in business combination	0.5
Tax Credit Carryforward, Description	relate primarily to Advanced Coal Investment Tax Credits and Wind Production tax credits	relate primarily to Advanced Coal Investment Tax Credits and Wind Production tax credits
Tax Credit Carryforward, Valuation Allowance	0.4
General Business Tax Credit Carryforward [Member] \| Minimum [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2028
General Business Tax Credit Carryforward [Member] \| Maximum [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2033
Federal Alternative Minimum Tax Credit Carryforward [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Amount	87.9	87.9
Amount of tax credit acquired in business combination	87.6	87.6
Tax Credit Carryforward, Description	These credits do not expire and can be used to reduce taxes paid in the future.	These credits do not expire and can be used to reduce taxes paid in the future.
State and Local Jurisdiction [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Amount	0.3	2.0
Tax Credit Carryforward, Description	relate primarily to the Company's Missouri affordable housing investment portfolio	relate primarily to the Company's Missouri affordable housing investment portfolio
State and Local Jurisdiction [Member] \| Minimum [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2014
State and Local Jurisdiction [Member] \| Maximum [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2016
Kansas City Power and Light Company [Member] \| General Business Tax Credit Carryforward [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Amount	$ 139.6	$ 126.3
Tax Credit Carryforward, Description	relate primarily to Advanced Coal Investment Tax Credits and Wind Production tax credits	relate primarily to Advanced Coal Investment Tax Credits and Wind Production tax credits
Kansas City Power and Light Company [Member] \| General Business Tax Credit Carryforward [Member] \| Minimum [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2028
Kansas City Power and Light Company [Member] \| General Business Tax Credit Carryforward [Member] \| Maximum [Member]
Tax Credit Carryforward [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2033

Taxes Valuation Allowance (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	$ 3.1	$ 0
Valuation Allowance, Deferred Tax Asset, Explanation of Change	tax benefit was recorded in continuing operations primarily related to state NOL carryforwards offset by an increase in deferred tax expense since a portion of state NOLs expired at December 31, 2013.

Taxes Uncertain Tax Positions (Details) (USD $)	12 Months Ended
Taxes Uncertain Tax Positions (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Uncertain Tax Positions [Line Items]
Amount expected to impact the effective tax rate if recognized	$ 6,500,000	$ 7,300,000	$ 11,800,000
Unrecognized Tax Benefits, Period Increase (Decrease)	(11,600,000)	(2,600,000)
Unrecognized tax benefit increase (decrease) related to former GMO non-regulated operations		(4,500,000)
Accrued interest related to unrecognized tax benefits	3,200,000	3,500,000	5,700,000
Accrued penalties with respect to unrecognized tax benefits	600,000	700,000	1,100,000
Interest expense related to unrecognized tax benefits	(100,000)	(2,300,000)	(900,000)
Amount of unrecognized tax benefits that may be recognized in the next twelve months due to statute expirations or settlement agreements with tax authorities	6,900,000
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	21,400,000	24,000,000	42,000,000
Additions for current year tax positions	0	3,700,000	1,400,000
Reductions for current year tax positions	(300,000)	0	0
Additions for prior year tax positions	0	0	2,400,000
Reductions for prior year tax positions	(10,500,000)	(1,800,000)	(20,900,000)
Statute expirations	(300,000)	(4,700,000)	(700,000)
Foreign currency translation adjustments	(500,000)	200,000	(200,000)
Balance at end of period	9,800,000	21,400,000	24,000,000
Kansas City Power and Light Company [Member]
Uncertain Tax Positions [Line Items]
Amount expected to impact the effective tax rate if recognized		0	200,000
Unrecognized Tax Benefits, Period Increase (Decrease)	(10,500,000)	1,800,000
Accrued interest related to unrecognized tax benefits	0	100,000	200,000
Interest expense related to unrecognized tax benefits	(100,000)	(100,000)	(1,200,000)
Uncertain tax position increase (decrease) related to temporary differences		3,600,000
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	10,500,000	8,700,000	19,100,000
Additions for current year tax positions	0	3,600,000	0
Reductions for current year tax positions	0	0	0
Additions for prior year tax positions	0	0	2,300,000
Reductions for prior year tax positions	(10,500,000)	(1,600,000)	(12,600,000)
Statute expirations	0	(200,000)	(100,000)
Foreign currency translation adjustments	0	0	0
Balance at end of period	$ 0	$ 10,500,000	$ 8,700,000

Segments and Related Information (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]
Operating revenues	$ 538.8	$ 765.0	$ 600.3	$ 542.2	$ 480.4	$ 746.2	$ 603.6	$ 479.7	$ 2,446.3	$ 2,309.9	$ 2,318.0
Depreciation and amortization									(289.7)	(272.3)	(273.1)
Interest charges									(198.4)	(220.8)	(218.4)
Income tax (expense) benefit									(129.2)	(104.6)	(84.8)
Net income (loss) attributable to Great Plains Energy					4.7	146.2	58.1	(9.1)	250.2	199.9	174.4
Assets, Total	9,795.4				9,647.3				9,795.4	9,647.3	9,118.0
Capital expenditures									669.0	610.2	456.6
Electric Utility Segment [Member] \| Electric Utility Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues									2,446.3	2,309.9	2,318.0
Depreciation and amortization									(289.7)	(272.3)	(273.1)
Interest charges									(190.5)	(197.3)	(176.9)
Income tax (expense) benefit									(135.4)	(122.0)	(109.3)
Net income (loss) attributable to Great Plains Energy									257.1	216.6	199.9
Assets, Total	10,019.6				9,910.6				10,019.6	9,910.6	9,483.4
Capital expenditures									669.0	610.2	456.6
Other [Member]
Segment Reporting Information [Line Items]
Operating revenues									0	0	0
Depreciation and amortization									0	0	0
Interest charges									(55.5)	(67.3)	(67.2)
Income tax (expense) benefit									6.2	17.4	24.5
Net income (loss) attributable to Great Plains Energy									(6.9)	(16.7)	(25.5)
Assets, Total	105.6				122.4				105.6	122.4	51.9
Capital expenditures									0	0	0
Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues									0	0	0
Depreciation and amortization									0	0	0
Interest charges									47.6	43.8	25.7
Income tax (expense) benefit									0	0	0
Net income (loss) attributable to Great Plains Energy									0	0	0
Assets, Total	(329.8)				(385.7)				(329.8)	(385.7)	(417.3)
Capital expenditures									$ 0	$ 0	$ 0

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 04

-Paragraph 20

-Article 9

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

-Publisher FASB

-Name Accounting Standards Codification

-Topic 230

-SubTopic 10

-Section 45

-Paragraph 28

-URI http://asc.fasb.org/extlink&oid=31042434&loc=d3e3602-108585

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

-Publisher FASB

-Name Accounting Standards Codification

-Glossary Other Comprehensive Income

-URI http://asc.fasb.org/extlink&oid=6519514

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

-Publisher FASB

-Name Accounting Standards Codification

-Glossary Net Income

-URI http://asc.fasb.org/extlink&oid=6518256

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

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 50

-Paragraph 1

-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

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

-Publisher FASB

-Name Accounting Standards Codification

-Topic 944

-SubTopic 225

-Section S99

-Paragraph 1

-Subparagraph (SX 210.7-04.19)

-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

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

-Publisher FASB

-Name Accounting Standards Codification

-Topic 225

-SubTopic 10

-Section S99

-Paragraph 2

-Subparagraph (SX 210.5-03.18)

-URI http://asc.fasb.org/extlink&oid=26872669&loc=d3e20235-122688

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

-Publisher FASB

-Name Accounting Standards Codification

-Topic 944

-SubTopic 225

-Section S99

-Paragraph 1

-Subparagraph (SX 210.7-04.22)

-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

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

-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 6

-URI http://asc.fasb.org/extlink&oid=28358780&loc=d3e565-108580

Reference 10: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 03

-Paragraph 19

-Article 5

+ Details

Jointly Owned Electric Utility Plants (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Jointly Owned Utility Plant Interests [Line Items]
Nuclear fuel, net	$ 62.8	$ 81.3
Jeffrey Energy Center [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	8.00%
Utility plant in service	165.7
Accumulated depreciation	75.4
Nuclear fuel, net	0
Construction work in progress	13.8
Accredited capacity (in MW's)	172
Iatan Common [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	79.00%
Utility plant in service	428.9
Accumulated depreciation	87.3
Nuclear fuel, net	0
Construction work in progress	24.4
Iatan No. 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	73.00%
Utility plant in service	1,298.0
Accumulated depreciation	319.4
Nuclear fuel, net	0
Construction work in progress	14.9
Accredited capacity (in MW's)	641
Iatan No. 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	88.00%
Utility plant in service	645.3
Accumulated depreciation	245.7
Nuclear fuel, net	0
Construction work in progress	8.1
Accredited capacity (in MW's)	627
LaCygne Station [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	50.00%
Utility plant in service	542.6
Accumulated depreciation	314.4
Nuclear fuel, net	0
Construction work in progress	390.3
Accredited capacity (in MW's)	709
Wolf Creek [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	47.00%
Utility plant in service	1,550.8
Accumulated depreciation	813.6
Nuclear fuel, net	62.8
Construction work in progress	146.4
Accredited capacity (in MW's)	547
Kansas City Power and Light Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Nuclear fuel, net	62.8	81.3
Kansas City Power and Light Company [Member] \| Iatan Common [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	61.00%
Utility plant in service	347.3
Accumulated depreciation	79.3
Nuclear fuel, net	0
Construction work in progress	3.5
Kansas City Power and Light Company [Member] \| Iatan No. 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	55.00%
Utility plant in service	987.2
Accumulated depreciation	297.5
Nuclear fuel, net	0
Construction work in progress	11.0
Accredited capacity (in MW's)	482
Kansas City Power and Light Company [Member] \| Iatan No. 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	70.00%
Utility plant in service	515.4
Accumulated depreciation	196.8
Nuclear fuel, net	0
Construction work in progress	1.8
Accredited capacity (in MW's)	499
Kansas City Power and Light Company [Member] \| LaCygne Station [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	50.00%
Utility plant in service	542.6
Accumulated depreciation	314.4
Nuclear fuel, net	0
Construction work in progress	390.3
Accredited capacity (in MW's)	709
Kansas City Power and Light Company [Member] \| Wolf Creek [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage in Wolf Creek, a nuclear generating unit (in hundredths)	47.00%
Utility plant in service	1,550.8
Accumulated depreciation	813.6
Nuclear fuel, net	62.8
Construction work in progress	$ 146.4
Accredited capacity (in MW's)	547

Quarterly Operating Results (Unaudited) (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating revenues	$ 538.8	$ 765.0	$ 600.3	$ 542.2	$ 480.4	$ 746.2	$ 603.6	$ 479.7	$ 2,446.3	$ 2,309.9	$ 2,318.0
Operating income (loss)	67.8	271.7	143.6	86.1	62.9	277.0	150.0	49.0	569.2	538.9	479.8
Net income (loss)	17.5	143.1	63.6	26.0	4.7	146.4	58.1	(9.3)	250.2	199.9	174.2
Net income (loss) attributable to Great Plains Energy					4.7	146.2	58.1	(9.1)	250.2	199.9	174.4
Earnings Per Share, Basic									$ 1.62	$ 1.36	$ 1.27
Earnings Per Share, Diluted									$ 1.62	$ 1.35	$ 1.25
Earnings Per Share, Basic and Diluted	$ 0.11	$ 0.93	$ 0.41	$ 0.17	$ 0.03	$ 0.95	$ 0.41	$ (0.07)
Kansas City Power and Light Company [Member]
Operating revenues	371.9	522.0	410.8	366.7	335.8	508.0	409.1	327.0	1,671.4	1,579.9	1,558.3
Operating income (loss)	40.0	176.8	93.4	52.3	39.4	177.8	99.9	31.6	362.5	348.7	321.2
Net income (loss)	$ 12.2	$ 96.4	$ 44.2	$ 16.2	$ 5.4	$ 90.2	$ 43.7	$ 2.3	$ 169.0	$ 141.6	$ 135.5

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

+ References+ Details

The amount of net income (loss) for the period available to each share of common stock or common unit outstanding during the reporting period and to each share or unit that would have been outstanding assuming the issuance of common shares or units for all dilutive potential common shares or units outstanding during the reporting period.

+ References+ Details

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ Details

Schedule I Financial Statements of Parent Company Statements of Income & OCI (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Expenses
General and administrative									$ 3.0	$ 7.5	$ 5.9
General taxes									194.4	179.3	170.9
Operating Income (Loss)	67.8	271.7	143.6	86.1	62.9	277.0	150.0	49.0	569.2	538.9	479.8
Non-operating income									18.4	7.3	5.9
Interest charges									(198.4)	(220.8)	(218.4)
Income before income tax (expense) benefit and income (loss) from equity investments									379.6	304.9	259.1
Income tax (expense) benefit									(129.2)	(104.6)	(84.8)
Net income (loss)	17.5	143.1	63.6	26.0	4.7	146.4	58.1	(9.3)	250.2	199.9	174.2
Preferred stock dividend requirements									1.6	1.6	1.6
Earnings (loss) available for common shareholders									248.6	198.3	172.8
Weighted Average Number of Shares Outstanding, Basic									153.5	145.5	135.6
Weighted Average Number of Shares Outstanding, Diluted									153.7	147.2	138.7
Earnings Per Share, Basic									$ 1.62	$ 1.36	$ 1.27
Earnings Per Share, Diluted									$ 1.62	$ 1.35	$ 1.25
Common Stock, Dividends, Per Share, Declared									$ 0.8825	$ 0.855	$ 0.835
Comprehensive Income
Net income (loss)	17.5	143.1	63.6	26.0	4.7	146.4	58.1	(9.3)	250.2	199.9	174.2
Other comprehensive income
Gain (loss) on derivative hedging instruments									0	(0.1)	(5.9)
Income tax benefit (expense) on derivative hedging instruments									0	0	2.3
Net gain (loss) on derivative hedging instruments									0	(0.1)	(3.6)
Reclassification to expenses, net of tax									11.6	12.6	10.4
Derivative hedging activity, net of tax									11.6	12.5	6.8
Comprehensive income (loss) attributable to Great Plains Energy									263.3	211.3	180.7
Parent Company [Member]
Operating Expenses
General and administrative									1.0	3.3	0.8
General taxes									0.6	0.7	0.9
Operating Expenses									1.6	4.0	1.7
Operating Income (Loss)									(1.6)	(4.0)	(1.7)
Equity in earnings (loss) from Subsidiaries									256.5	219.2	200.8
Non-operating income									45.8	42.7	24.7
Interest charges									(54.7)	(69.6)	(66.5)
Income before income tax (expense) benefit and income (loss) from equity investments									246.0	188.3	157.3
Income tax (expense) benefit									4.2	11.6	17.1
Net income (loss)									250.2	199.9	174.4
Preferred stock dividend requirements									1.6	1.6	1.6
Earnings (loss) available for common shareholders									248.6	198.3	172.8
Weighted Average Number of Shares Outstanding, Basic									153.5	145.5	135.6
Weighted Average Number of Shares Outstanding, Diluted									153.7	147.2	138.7
Earnings Per Share, Basic									$ 1.62	$ 1.36	$ 1.27
Earnings Per Share, Diluted									$ 1.62	$ 1.35	$ 1.25
Common Stock, Dividends, Per Share, Declared									$ 0.8825	$ 0.855	$ 0.835
Comprehensive Income
Net income (loss)									250.2	199.9	174.4
Other comprehensive income
Gain (loss) on derivative hedging instruments									0	0	(5.3)
Income tax benefit (expense) on derivative hedging instruments									0	0	2.1
Net gain (loss) on derivative hedging instruments									0	0	(3.2)
Reclassification to expenses									9.9	11.5	8.2
Income tax (benefit) expense on reclassification to expenses									(3.9)	(4.6)	(3.2)
Reclassification to expenses, net of tax									6.0	6.9	5.0
Derivative hedging activity, net of tax									6.0	6.9	1.8
Other comprehensive income from subsidiaries, net of tax									7.1	4.5	4.5
Total other comprehensive income (loss)									13.1	11.4	6.3
Comprehensive income (loss) attributable to Great Plains Energy									$ 263.3	$ 211.3	$ 180.7

Schedule I Financial Statements of Parent Company Balance Sheet (Details) (USD $)
In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Taxes receivable

$ 10.5

$ 9.5

767.0

723.7

(964.8)

(832.4)

79.4

76.9

9,795.4

9,647.3

9,118.0

Notes payable

9.0

12.0

1.1

263.1

29.7

27.1

45.4

41.5

23.5

23.9

769.8

1,449.5

1,996.5

2,062.0

2,631.1

2,624.7

Accumulated Other Comprehensive Income (Loss), Net of Tax

871.4

758.8

Treasury Stock, Value

(2.8)

(5.1)

(25.3)

^[1]

(38.4)

^[1]

3,474.4

3,340.0

2,959.9

39.0

3,515.7

2,756.8

7,029.1

6,135.8

9,795.4

9,647.3

Parent Company [Member]

Accounts receivable from subsidiaries

0.2

0.1

Notes receivable from subsidiaries, current

0.6

Money pool receivable

9.4

4.0

Taxes receivable

0.2

Other current assets

1.2

2.4

11.6

7.1

Investment in other subsidiaries

Investment in KCP&L

2,179.3

2,096.7

1,447.0

1,405.4

Notes receivable from subsidiaries, noncurrent

634.9

883.6

31.4

32.3

Total investments and other assets

6.7

7.6

4,299.3

4,425.6

4,310.9

4,432.7

Notes payable

9.0

12.0

Accounts payable to subsidiaries

250.0

33.6

34.1

0.2

0.5

4.2

6.8

1.5

2.1

48.5

305.5

6.6

5.2

2,631.1

2,624.7

Accumulated Other Comprehensive Income (Loss), Net of Tax

871.4

758.8

Treasury Stock, Value

(2.8)

(5.1)

(25.3)

(38.4)

3,474.4

3,340.0

39.0

742.4

743.0

4,255.8

4,122.0

4,310.9

4,432.7

Preferred Stock 3 Point 80 [Member]

10.0

Preferred Stock 3 Point 80 [Member] | Parent Company [Member]

10.0

Preferred Stock 4 Point 50 [Member]

10.0

Preferred Stock 4 Point 50 [Member] | Parent Company [Member]

10.0

Preferred Stock 4 Point 20 [Member]

7.0

Preferred Stock 4 Point 20 [Member] | Parent Company [Member]

7.0

Preferred Stock 4 Point 35 [Member]

12.0

Preferred Stock 4 Point 35 [Member] | Parent Company [Member]

Valuation and Qualifying Accounts Disclosure [Line Items]

$ 12.0

[1]	Net of tax

Schedule I Financial Statements of Parent Company Balance Sheet Parenthetical (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Common Stock, Shares Authorized	250,000,000	250,000,000
Common Stock, Shares, Issued	153,995,621	153,779,806
Treasury Stock, Shares	129,290	250,236
Parent Company [Member]
Common Stock, Shares Authorized	250,000,000	250,000,000
Common Stock, Shares, Issued	153,995,621	153,779,806
Treasury Stock, Shares	129,290	250,236
Preferred Stock 3 Point 80 [Member]
Preferred Stock, Par or Stated Value Per Share	$ 100.00	$ 100.00
Preferred Stock, Dividend Rate, Percentage	3.80%	3.80%
Preferred Stock, Shares Issued	100,000	100,000
Preferred Stock 3 Point 80 [Member] \| Parent Company [Member]
Preferred Stock, Par or Stated Value Per Share	$ 100.00	$ 100.00
Preferred Stock, Dividend Rate, Percentage	3.80%	3.80%
Preferred Stock, Shares Issued	100,000	100,000
Preferred Stock 4 Point 50 [Member]
Preferred Stock, Par or Stated Value Per Share	$ 100.00	$ 100.00
Preferred Stock, Dividend Rate, Percentage	4.50%	4.50%
Preferred Stock, Shares Issued	100,000	100,000
Preferred Stock 4 Point 50 [Member] \| Parent Company [Member]
Preferred Stock, Par or Stated Value Per Share	$ 100.00	$ 100.00
Preferred Stock, Dividend Rate, Percentage	4.50%	4.50%
Preferred Stock, Shares Issued	100,000	100,000
Preferred Stock 4 Point 20 [Member]
Preferred Stock, Par or Stated Value Per Share	$ 100.00	$ 100.00
Preferred Stock, Dividend Rate, Percentage	4.20%	4.20%
Preferred Stock, Shares Issued	70,000	70,000
Preferred Stock 4 Point 20 [Member] \| Parent Company [Member]
Preferred Stock, Par or Stated Value Per Share	$ 100.00	$ 100.00
Preferred Stock, Dividend Rate, Percentage	4.20%	4.20%
Preferred Stock, Shares Issued	70,000	70,000
Preferred Stock 4 Point 35 [Member]
Preferred Stock, Par or Stated Value Per Share	$ 100.00	$ 100.00
Preferred Stock, Dividend Rate, Percentage	4.35%	4.35%
Preferred Stock, Shares Issued	120,000	120,000
Preferred Stock 4 Point 35 [Member] \| Parent Company [Member]
Preferred Stock, Par or Stated Value Per Share	$ 100.00	$ 100.00
Preferred Stock, Dividend Rate, Percentage	4.35%	4.35%
Preferred Stock, Shares Issued	120,000	120,000

Schedule I Financial Statements of Parent Company Statement of Cash Flows (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash Flows from Operating Activities
Net income (loss)	$ 250.2	$ 199.9	$ 174.2
Adjustments to reconcile income to net cash from operating activities:
Deferred income taxes, net	134.0	121.2	111.2
Cash flows affected by changes in:
Accrued taxes	2.2	(7.8)	1.4
Accrued interest	3.9	(35.2)	1.5
Interest rate hedge settlement	0	0	(26.1)
Uncertain tax positions	(0.8)	(4.7)	(20.8)
Other operating activities	(15.5)	(29.8)	(24.8)
Net cash from operating activities	776.8	663.8	443.0
Cash Flows from Investing Activities
Other investing activities	(21.7)	(19.6)	(19.9)
Net cash from investing activities	(705.8)	(638.4)	(485.7)
Cash Flows from Financing Activities
Issuance of common stock	4.9	293.0	5.9
Issuance of long-term debt	762.5	0	747.1
Issuance fees	(9.0)	(2.9)	(10.7)
Repayment of long-term debt	(265.3)	(513.8)	(598.5)
Net change in short-term borrowings	(424.9)	253.1	16.0
Dividends paid	(137.3)	(125.5)	(115.1)
Other financing activities	(1.6)	(5.2)	(6.6)
Net cash from financing activities	(69.7)	(22.3)	38.1
Net Change in Cash and Cash Equivalents	1.3	3.1	(4.6)
Cash and Cash Equivalents at Beginning of Year	9.3	6.2	10.8
Cash and Cash Equivalents at End of Year	10.6	9.3	6.2
Parent Company [Member]
Cash Flows from Operating Activities
Net income (loss)	250.2	199.9	174.4
Adjustments to reconcile income to net cash from operating activities:
Amortization	10.6	12.6	11.2
Deferred income taxes, net	(10.5)	(4.8)	(18.6)
Equity in earnings from subsidiaries	(256.5)	(219.2)	(200.8)
Cash flows affected by changes in:
Accounts receivable from subsidiaries	(0.1)	(0.1)	0
Taxes receivable	(0.2)	0.9	6.3
Accounts payable to subsidiaries	(0.5)	2.3	(0.3)
Other accounts payable	0.1	0	0
Accrued taxes	(0.1)	(4.4)	5.2
Accrued interest	(2.6)	6.1	1.2
Cash dividends from subsidiaries	140.0	144.0	148.0
Interest rate hedge settlement	0	0	(26.1)
Uncertain tax positions	7.3	1.0	(3.3)
Other operating activities	6.8	1.7	5.4
Net cash from operating activities	144.5	140.0	102.6
Cash Flows from Investing Activities
Intercompany lending	248.7	(287.4)	(347.4)
Net money pool lending	(5.4)	(3.1)	1.1
Other investing activities	(0.5)	0	0
Net cash from investing activities	242.8	(290.5)	(346.3)
Cash Flows from Financing Activities
Issuance of common stock	4.9	293.0	5.9
Issuance of long-term debt	0	0	349.7
Issuance fees	(0.4)	(2.7)	(3.2)
Repayment of long-term debt	(250.0)	0	0
Net change in short-term borrowings	(3.0)	(10.0)	12.5
Dividends paid	(137.3)	(125.5)	(115.1)
Other financing activities	(1.5)	(4.3)	(6.4)
Net cash from financing activities	(387.3)	150.5	243.4
Net Change in Cash and Cash Equivalents	0	0	(0.3)
Cash and Cash Equivalents at Beginning of Year	0	0	0.3
Cash and Cash Equivalents at End of Year	$ 0	$ 0	$ 0

Schedule II Valuation and Qualifying Accounts (Details) (USD $)
In Millions, unless otherwise specified

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Allowance for Doubtful Accounts [Member]

$ 6.9

$ 6.8

$ 7.0

12.3

12.0

13.7

7.6

^[1]

7.8

^[1]

6.9

^[1]

24.3

^[2]

19.7

^[2]

20.8

^[2]

Valuation and Qualifying Accounts Disclosure [Line Items]

2.5

6.9

6.8

Allowance for Doubtful Accounts [Member] | Kansas City Power and Light Company [Member]

1.5

1.4

1.5

8.0

7.9

8.8

5.0

^[1]

5.2

^[1]

4.5

^[1]

13.4

^[2]

13.0

^[2]

13.4

^[2]

Valuation and Qualifying Accounts Disclosure [Line Items]

1.1

1.5

1.4

Legal Reserve [Member]

4.6

6.7

10.2

2.7

(0.2)

(0.1)

2.7

^[3]

1.9

^[3]

3.4

^[3]

Valuation and Qualifying Accounts Disclosure [Line Items]

4.6

6.7

Legal Reserve [Member] | Kansas City Power and Light Company [Member]

2.9

3.9

3.0

0.9

0.5

1.3

0.9

^[3]

1.5

^[3]

0.4

^[3]

Valuation and Qualifying Accounts Disclosure [Line Items]

2.9

3.9

Reserve for Environmental Costs [Member]

2.3

2.5

0.6

0.2

Valuation and Qualifying Accounts Disclosure [Line Items]

1.7

2.3

2.5

Reserve for Environmental Costs [Member] | Kansas City Power and Light Company [Member]

0.3

Valuation and Qualifying Accounts Disclosure [Line Items]

0.3

Valuation Allowance of Deferred Tax Assets [Member]

23.8

23.9

26.6

0.1

0.3

0.1

3.2

^[4]

0.4

^[4]

2.8

^[4]