UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-K

[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 20092010

or

[  ] TRANSITION REPORT PURSUANT SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from _______to_______

  Exact name of registrant as specified in its charter,  
Commission state of incorporation, address of principal I.R.S. Employer
File Number executive offices and telephone number Identification Number
     
001-32206 GREAT PLAINS ENERGY INCORPORATED 43-1916803
  (A Missouri Corporation)  
  1200 Main Street  
  Kansas City, Missouri  64105  
  (816) 556-2200  
  www.greatplainsenergy.com
   
000-51873 KANSAS CITY POWER & LIGHT COMPANY 44-0308720
  (A Missouri Corporation)  
  1200 Main Street  
  Kansas City, Missouri  64105  
  (816) 556-2200
www.kcpl.com  

Each of the following classes or series of securities registered pursuant to Section 12(b) of the Act is registered on the New York Stock Exchange:

RegistrantTitle of each class
Great Plains Energy IncorporatedCumulative Preferred Stock par value $100 per share3.80%
 Cumulative Preferred Stock par value $100 per share4.50%
 Cumulative Preferred Stock par value $100 per share4.35%
 Common Stock without par value 
 Corporate Units 

Securities registered pursuant to Section 12(g) of the Act: Kansas City Power & Light Company Common Stock without par value.

 
 
 
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Great Plains Energy IncorporatedYes
X
No_ Kansas City Power & Light CompanyYes_No
X
  
 
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
Great Plains Energy IncorporatedYes_No
X
 Kansas City Power & Light CompanyYes_No
X
  
 
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the
Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to
file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Great Plains Energy IncorporatedYes
X
No_ Kansas City Power & Light CompanyYes
X
No_  
             
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive
Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12
months (or for such shorter period that the registrant was required to submit and post such files).
Great Plains Energy Incorporated        Yes
_X
No_ Kansas City Power & Light CompanyYes_No_  
 
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained
herein, and will
not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference
reference in Part III of this Form 10-K or any amendment to the Form 10-K.
Great Plains Energy Incorporated_       Kansas City Power & Light Company
   X
     
          
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting
company.  See the definitions of "large accelerated filer," "accelerated filer," and "smaller reporting company" in Rule 12b-2 of the 
Exchange Act.
Great Plains Energy IncorporatedLarge accelerated filer
X
Accelerated filer_   
 Non-accelerated filer_Smaller reporting company_   
Kansas City Power & Light CompanyLarge accelerated filer_Accelerated filer_   
 Non-accelerated filer
X
Smaller reporting company_   
                
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Great Plains Energy IncorporatedYes_No
X
 Kansas City Power & Light CompanyYes_No
X
  
                
The aggregate market value of the voting and non-voting common equity held by non-affiliates of Great Plains Energy
Incorporated (based on the closing price of its common stock on the New York Stock Exchange on June 30, 2009)2010) was
approximately $2,101,763,626.$2,307,217,754.  All of the common equity of Kansas City Power & Light Company is held by Great Plains
Energy Incorporated, an affiliate of Kansas City Power & Light Company.
                
On February 23, 2010,22, 2011, Great Plains Energy Incorporated had 135,362,219135,690,276 shares of common stock outstanding.
On February 23, 2010,22, 2011, Kansas City Power & Light Company had one share of common stock outstanding
and held by Great Plains Energy Incorporated.
 
Kansas City Power & Light Company meets the conditions set forth in General Instruction (I)(1)(a) and (b) of
Form 10-K and is therefore filing this Form 10-K with the reduced disclosure format.
 
Documents Incorporated by Reference
Portions of the 20102011 annual meeting proxy statement of Great Plains Energy Incorporated to be filed with the Securities and
Exchange Commission are incorporated by reference in Part III of this report.
 
 
TABLE OF CONTENTS 
    Page
    Number
 Cautionary Statements Regarding Forward-Looking Information3
 Glossary of Terms4
 PART I 
Item 11.Business6
Item 1A1A.Risk Factors11
Item 1B1B.Unresolved Staff Comments22
Item 22.Properties 22
Item 3.Legal Proceedings23
Item 34.Legal Proceedings(Removed and Reserved)24
Item 4Submission of Matters to a Vote of Security Holders24 23
 PART II 
Item 55.Market for Registrant's Common Equity, Related Stockholder Matters25
  and Issuer Purchases of Equity Securities 24
Item 66.Selected Financial Data26 25
Item 77.Management's Discussion and Analysis of Financial Condition27
  and Results of Operations 26
Item 7A7A.Quantitative and Qualitative Disclosures About Market Risk49 50
Item 88.Financial Statements and Supplementary Data52 53
Item 99.Changes in and Disagreements With Accountants on Accounting137
  and Financial Disclosure 139
Item 9A9A.Controls and Procedures137 139
Item 9B9B.Other Information140 143
 PART III 
Item 1010.Directors, Executive Officers and Corporate Governance140 143
Item 1111.Executive Compensation141 144
Item 1212.Security Ownership of Certain Beneficial Owners and Management141
  and Related Stockholder Matters 144
Item 1313.Certain Relationships and Related Transactions, and Director Independence142 145
Item 1414.Principal Accounting Fees and Services142 145
 PART IV 
Item 1515.Exhibits and Financial Statement Schedules144 147
 
2
 
This combined annual report on Form 10-K is being filed by Great Plains Energy Incorporated (Great Plains Energy) and Kansas City Power & Light Company (KCP&L).  KCP&L is a wholly owned subsidiary of Great Plains Energy and represents a significant portion of its assets, liabilities, revenues, expenses and operations.  Thus, all information contained in this report relates to, and is filed by, Great Plains Energy.  Information that is specifically identified in this report as relating solely to Great Plains Energy, such as its financial statements and all information relating to Great Plains Energy’s other operations, businesses and subsidiaries, including KCP&L Greater Missouri Operations Company (GMO), does not relate to, and is not filed by, KCP&L.  KCP&L makes no representation as to that information.  Neither Great Plains Energy nor its other subsidiaries have any obligation in respect of KCP&L’s debt securities and holders of such securities should not consider Great Plains Energy’s or its other subsidiaries’ financial resources or results of operations in making a decision with respect to KCP&L’s debt securities.  Similarly, KCP&L has no obligation in respect of securities of Great Plains Energy or its other subsidiaries.
 
CAUTIONARY STATEMENTS REGARDING CERTAIN FORWARD-LOOKING INFORMATION
Statements made in this report that are not based on historical facts are forward-looking, may involve risks and uncertainties, and are intended to be as of the date when made.  Forward-looking statements include, but are not limited to, the outcome of regulatory proceedings, cost estimates of the Comprehensive Energy Plancapital projects and other matters affecting future operations.  In connection with the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, the registrantsGreat Plains Energy and KCP&L are providing a number of important factors that could cause actual results to differ materially from the provided forward-looking information.  These important factors include: future economic conditions in regional, national and international markets and their effects on sales, prices and costs, including but not limited to possible further deterioration in economic conditions and the timing and extent of any economic recovery; prices and availability of electricity in regional and national wholesale markets; market perception of the energy industry, Great Plains Energy and KCP&L; changes in business strategy, operations or development plans; effects of current or proposed state and federal legislative and regulatory actions or developments, including, but not limited to, deregulation, re-regulation and restructuring of the electric utility industry; decisions of regulators regarding rates the companiesCompanies can charge for electricity; adverse changes in applicable laws, regulations, rules, principles or practices governing tax, accounting and environmental matters including, but not limited to, air and water quality; financial market conditions and performance including, but not limited to, changes in interest rates and credit spreads and in availability and cost of capital and the effects on nuclear decommissioning trust and pension plan assets and costs; impairments of long-lived assets or goodwill; credit ratings; inflation rates; effectiveness of risk management policies and procedures and the ability of counterparties to satisfy their contractual commitments; impact of terrorist acts; increased competition including, but not limited to, retail choice in the electric utility industry and the entry of new competitors; ability to carry out marketing and sales plans; weather conditions including, but not limited to, weather-related damage and their effects on sales, prices and costs; cost, availability, quality and deliverability of fuel; the inherent uncertainties in estimating the effects of weather, economic conditions and other factors on customer consumption and financial results; ability to achieve generation planning goals and the occurrence and duration of planned and unplanned generation outages; delays in the anticipated in-service dates and cost increases of additional generating capacitygeneration, transmission, distribution or other projects; the inherent risks associated with the ownership and operation of a nuclear facility including, but not limited to, environmental, projects; nuclear operations;health, safety, regulatory and financial risks; workforce risks, including, but not limited to, increased costs of retirement, compensationhealth care and benefits costs; the timing and amount of resulting synergy savings from the GMO acquisition;other benefits; and other risks and uncertainties.
 
This list of factors is not all-inclusive because it is not possible to predict all factors.  Part I Item 1A Risk Factors included in this report should be carefully read for further understanding of potential risks for each of Great Plains Energy and KCP&L.  Other sections of this report and other periodic reports filed by each of Great Plains Energy and KCP&L with the Securities and Exchange Commission (SEC) should also be read for more information regarding risk factors.  Each forward-looking statement speaks only as of the date of the particular statement.  Great Plains Energy and KCP&L undertake no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise.
 
3
 
GLOSSARY OF TERMS
 
The following is a glossary of frequently used abbreviations or acronyms that are found throughout this report.
 
Abbreviation or Acronym Definition
   
AFUDC Allowance for Funds Used During Construction
ARO Asset Retirement Obligation
BART Best available retrofit technology
Black HillsBlack Hills Corporation
Board Great Plains Energy Board of Directors
CAIR Clean Air Interstate Rule
CAMR Clean Air Mercury Rule
Clean Air Act Clean Air Act Amendments of 1990
CO2
 Carbon Dioxidedioxide
Collaboration Agreement 
Agreement among KCP&L, the Sierra Club and the Concerned
   Citizens of Platte County
Company Great Plains Energy Incorporated and its subsidiaries
Companies
Great Plains Energy Incorporated and its consolidated subsidiaries and
   KCP&L and its consolidated subsidiaries
DOE Department of Energy
EBITDA Earnings before interest, income taxes, depreciation and amortization
ECA Energy Cost Adjustment
EIRR Environmental Improvement Revenue Refunding
EPA Environmental Protection Agency
EPS Earnings per common share
ERISA Employee Retirement Income Security Act of 1974, as amended
FAC Fuel Adjustment Clause
FASB Financial Accounting Standards Board
FELINE PRIDESSM
Flexible Equity Linked Preferred Increased Dividend Equity Securities,
   a service mark of Merrill Lynch & Co., Inc.
FERC The Federal Energy Regulatory Commission
FGIC Financial Guaranty Insurance Company
FSS Forward Starting Swaps
GAAP Generally Accepted Accounting Principles
GMO 
KCP&L Greater Missouri Operations Company, a wholly owned subsidiary of
   Great Plains Energy as of July 14, 2008
Great Plains Energy Great Plains Energy Incorporated and its subsidiaries
HSSHome Service Solutions Inc., a wholly owned subsidiary of KLT, Inc.
ISO Independent System Operator
KCC The State Corporation Commission of the State of Kansas
KCP&L
 
 
Kansas City Power & Light Company, a wholly owned subsidiary
   of Great Plains Energy
KDHE Kansas Department of Health and Environment
KLT Inc. KLT Inc., a wholly owned subsidiary of Great Plains Energy
KLT InvestmentsKLT Investments Inc., a wholly owned subsidiary of KLT Inc.
KW Kilowatt
kWh Kilowatt hour
MACT Maximum achievable control technology
MD&A Management’s Discussion and Analysis of Financial Condition and
     Results of Operations
MDNR Missouri Department of Natural Resources
MGP Manufactured gas plant
MISO Midwest Independent Transmission System Operator, Inc.
4
Abbreviation or AcronymDefinition
MPS Merchant MPS Merchant Services, Inc., a wholly owned subsidiary of GMO
MPSC Public Service Commission of the State of Missouri
4
Abbreviation or AcronymDefinition
MW Megawatt
MWh Megawatt hour
NERC North American Electric Reliability Corporation
NEIL Nuclear Electric Insurance Limited
NOx
 Nitrogen oxide
NPNS Normal Purchasespurchases and Normal Salesnormal sales
NRC Nuclear Regulatory Commission
NYMEXNew York Mercantile Exchange
OCI Other Comprehensive Income
PCB Polychlorinated biphenyls
PPAPension Protection Act of 2006
PRB Powder River Basin
QCA Quarterly Cost Adjustment
Receivables Company 
Kansas City Power & Light Receivables Company, a wholly owned
   subsidiary of KCP&L
RTO Regional Transmission Organization
SCR Selective catalytic reduction
SEC Securities and Exchange Commission
SERP Supplemental Executive Retirement Plan
Services 
Great Plains Energy Services Incorporated, a wholly owned subsidiary of
   Great Plains Energy
SO2
 Sulfur dioxide
SPP Southwest Power Pool, Inc.
STBSurface Transportation Board
Strategic Energy Strategic Energy, L.L.C.
Syncora Syncora Guarantee Inc.
T - Lock Treasury Lock
Union PacificUnion Pacific Railroad Company
WCNOC Wolf Creek Nuclear Operating Corporation
Westar Westar Energy, Inc., a Kansas utility company
Wolf Creek Wolf Creek Generating Station
 
5
 
PART I
 
ITEM 1.  BUSINESS
 
General
Great Plains Energy Incorporated and Kansas City Power & Light Company are separate registrants filing this combined annual report.report on Form 10-K.  The terms “Great Plains Energy,” “Company,” “KCP&L,” and “KCP&L”“Companies” are used throughout this report.  “Great Plains Energy” and the “Company” refer to Great Plains Energy Incorporated and its consolidated subsidiaries, unless otherwise indicated.  “KCP&L” refers to Kansas City Power & Light Company and its consolidated subsidiaries.  “Companies”“Companies” refers to Great Plains Energy Incorporated and its consolidated subsidiaries and KCP&L and its consolidated subsidiaries.
 
Information in other Items of this report as to which reference is made in this Item 1.1 is hereby incorporated by reference in this Item 1.  The use of terms such as “see” or “refer to” shall be deemed to incorporate into this Item 1.1 the information to which such reference is made.
 
GREAT PLAINS ENERGY INCORPORATED
 
Great Plains Energy, a Missouri corporation incorporated in 2001 and headquartered in Kansas City, Missouri, 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 (Receivables Company).
 
·  KCP&L Greater Missouri Operations Company (GMO) is an integrated, regulated electric utility that primarily 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 wholly owns MPS Merchant Services, Inc. (MPS Merchant), which has certain long-term natural gas contracts remaining from its former non-regulated trading operations.
 
·  Great Plains Energy Services Incorporated (Services) obtains certain goods and third-party services for its affiliated companies.
·  KLT Inc. is an intermediate holding company that primarily holds investments in affordable housing limited partnerships.
Great Plains Energy’s sole reportable business segment is electric utility.  For information regarding the revenues, income and assets attributable to the electric utility business segment, see Note 2322 to the consolidated financial statements.  Comparative financial information and discussion regarding the electric utility business segment can be found in Item 7.7 Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A).
 
The electric utility segment consists of KCP&L, a regulated utility, and, since the July 14, 2008, acquisition date of GMO, GMO’s regulated utility operations which include its Missouri Public Service and St. Joseph Light & Power divisions.  Electric utility serves over 820,000approximately 823,200 customers located in western Missouri and eastern Kansas.  Customers include approximately 724,000724,200 residences, 95,00096,300 commercial firms, and 2,3002,700 industrials, municipalities and other electric utilities.  Electric utility’s retail revenues averaged approximately 85%88% of its total operating revenues over the last three years.  Wholesale firm power, bulk power sales and miscellaneous electric revenues accounted for the remainder of electric utility’s revenues.  Electric utility is significantly impacted by seasonality with approximately one-third of its retail revenues recorded in the third quarter.  Electric utility’s total electric revenues were 100% of Great Plains Energy’s revenues over the last three years.  Electric utility’s net
6
income accounted for approximately 104%111%, 119%104% and 130%119% of Great Plains Energy’s income from continuing operations in 2010, 2009 2008 and 2007,2008, respectively.
6
Regulation
KCP&L and GMO are regulated by the Public Service Commission of the State of Missouri (MPSC), and KCP&L is also regulated by The State Corporation Commission of the State of Kansas (KCC), with respect to retail rates, certain accounting matters, standards of service and, in certain cases, the issuance of securities, certification of facilities and service territories.  KCP&L and GMO are also subject to regulation by the Federal Energy Regulatory Commission (FERC), with respect to transmission, wholesale sales and rates, and other matters, the Southwest Power Pool, Inc. (SPP) and the North American Electric Reliability Corporation (NERC).  KCP&L has a 47% ownership interest in the Wolf Creek Generating Station (Wolf Creek), which is subject to regulation by the Nuclear Regulatory Commission (NRC), with respect to licensing, operations and safety-related requirements.
 
Missouri and Kansas jurisdictional retail revenues averaged approximately 70%71% and 30%29%, respectively, of electric utility’s total retail revenues in 2009.over the last two years.  See Item 7.7 MD&A, Critical Accounting Policies section and Note 76 to the consolidated financial statements for additional information concerning regulatory matters.
In December 2009, KCP&L filed a rate increase request with KCC, with new rates expected to be effective in the fourth quarter of 2010.  See Note 7 to the consolidated financial statements for additional information.
 
Competition
Missouri and Kansas continue on the fully integrated utility model and no legislation authorizing retail choice has been introduced in Missouri or Kansas for several years.  As a result, electric utility does not compete with others to supply and deliver electricity in its franchised service territory, although other sources of energy can provide alternatives to electric utility customers.  If Missouri or Kansas were to pass and implement legislation authorizing or mandating retail choice, electric utility may no longer be able to apply regulated utility accounting principles to deregulated portions of its operations and may be required to write off certain regulatory assets and liabilities.
 
Electric utility competes in the wholesale market to sell power in circumstances when the power it generates is not required for customers in its service territory.  In this regard, electric utility competes with owners of other generating stations and other power suppliers, principally utilities in its region, on the basis of availability and price.  Electric utility’s wholesale revenues averaged approximately 13%10% of its total revenues over the last three years.
 
Power Supply
Electric utility has over 6,0006,600 MWs of generating capacity.  The projected peak summer demand for 20102011 is 5,5155,590 MW.  Electric utility expects to meet its projected capacity requirements through 20182014 with its generation assets and capacity purchases and demand-side management and efficiency programs.  As part of KCP&L’s Comprehensive Energy Plan, electric utility expects to have Iatan No. 2, a coal-fired plant, in service in the fall of 2010, which will add approximately 620 MW (electric utility’s share) to electric utility’s generating capacity.purchases.
 
KCP&L and GMO are members of the SPP.  SPP is a Regional Transmission Organization (RTO) mandated by FERC to ensure reliable supply of power, adequate transmission infrastructure and competitive wholesale prices of electricity.  As members of the SPP, KCP&L and GMO are required to maintain a capacity margin of at least 12% of their projected peak summer demand.  This net positive supply of capacity and energy is maintained through their generation assets and capacity, power purchase agreements and peak demand reduction programs.  The capacity margin is designed to ensure the reliability of electric energy in the SPP region in the event of operational failure of power generating units utilized by the members of the SPP.
7
Fuel
The principal fuel sources for electric utility’s electric generation are coal and nuclear fuel.  It is expected, with normal weather, that approximately 97% of 20102011 generation will come from these sources with the remainder provided by wind, natural gas and oil.  The actual 20092010 and estimated 20102011 fuel mix and delivered cost in cents per net kWh generated are in the following table.
                 
     Fuel cost in cents per     Fuel cost in cents per
Fuel Mix (a)
 net kWh generated
Fuel Mix (a)
 net kWh generated
Estimated Actual EstimatedActualEstimatedActual EstimatedActual
Fuel2010 2009 2010200920112010 20112010
Coal        80%         80%         1.82         1.69 82% 80%  1.89  1.69 
Nuclear        17         17          0.64         0.49 15  17   0.69  0.65 
Natural gas and oil          2           2          9.93       14.98 1  2   7.34  8.95 
Wind          1           1             -            - 2  1   -  - 
Total Generation100% 100%         1.80         1.66 100% 100%  1.80  1.65 
(a) Fuel mix based on percent of net MWhs generated.
(a) Fuel mix based on percent of net MWhs generated.
    
(a) Fuel mix based on percent of net MWhs generated.
                     
GMO’s retail rates and KCP&L’s retail rates in Kansas contain certain fuel recovery mechanisms.  KCP&L’s Missouri retail rates do not contain a fuel recovery mechanism.  To the extent the price of fuel or purchased power increases significantly, or if electric utility’s lower cost units do not meet anticipated availability levels, Great Plains Energy’s net income may be adversely affected unless and until the increased cost could be reflected in KCP&L’s Missouri retail rates.
 
Coal
During 2010,2011, electric utility’s generating units, including jointly owned units, are projected to burn approximately 17 million tons of coal.  KCP&L and GMO have entered into coal-purchase contracts with various suppliers in Wyoming's Powder River Basin (PRB), the nation's principal supply region of low-sulfur coal, and with local suppliers.  The coal to be provided under these contracts will satisfy approximately 90%80% of the projected coal requirements for 20102011 and approximately 55% for 2011, 40%45% for 2012, 35%40% for 2013 and 25% for 2014.  The remainder of the coal requirements will be fulfilled through additional contracts or spot market purchases.  KCP&L and GMO have entered into coal contracts over time at higher average prices affecting coal costs for 20102011 and beyond.
 
KCP&L and GMO have also entered into rail transportation contracts with various railroads to transport coal from the PRB to their generating units.  The transportation services to be provided under these contracts will satisfy approximately 70%almost all of the projected transportation requirements for 2010.  The remainder of coal transportation is under tariff rates.  The majority of2011 through 2013.  KCP&L’s&L and GMO’sGMO entered into new rail transportation contracts expireat the end of 2010 to replace expiring long-term contracts.  The contract rates adjust for changes in 2010.  After 2010, railrailroad costs.  Rail transportation costs are anticipated towill be significantly higher.higher under these new contracts.
 
Nuclear Fuel
KCP&L owns 47% of Wolf Creek Nuclear Operating Corporation (WCNOC), the operating company for Wolf Creek, which is electric utility’s only nuclear generating unit.  Wolf Creek purchases uranium and has it processed for use as fuel in its reactor.  This process involves conversion of uranium concentrates to uranium hexafluoride, enrichment of uranium hexafluoride and fabrication of nuclear fuel assemblies.  The owners of Wolf Creek have on hand or under contract all of the uranium and conversion services needed to operate Wolf Creek through March 2014 and approximately 80%68% after that date through September 2018.March 2020.  The owners also have under contract 100% of the uranium enrichment and fabrication required to operate Wolf Creek through March 2026.
8
Management anticipates the cost of nuclear fuel to increase significantly in 2010, after which increases are expected to be moderate.  Even with this anticipated increase, management expects nuclear fuel cost per MWh generated to remain less than the cost of generation from other fuel sources.  See Note 65 to the consolidated financial statements for additional information regarding nuclear plant.
 
Natural Gas
At December 31, 2009,2010, KCP&L had hedged approximately 68%66%, 45% and 11%22% of its 20102011, 2012 and 2011,2013, respectively, projected natural gas usage for generation requirements to serve retail load and firm MWh sales.  At December 31, 2009,2010, GMO had hedged approximately 55%67%, 45% and 3%38% of its 20102011, 2012 and 2011,2013, respectively, expected on-peak natural gas usage and natural gas equivalent purchased power.
 
Purchased Capacity and Power
KCP&L and GMO have distinct rate and dispatching areas.  As a result, KCP&L and GMO do not joint-dispatch their respective generation.  GMO has long-term purchased capacity and power agreements for approximately 235 MW.MW, which expire in 2011 through 2016.  KCP&L purchases power to meet its customers’ needs when it does not have sufficient available generation or when the cost of purchased power is less than KCP&L’s cost of generation or to satisfy firm power commitments.  Management believes electric utility will be able to obtain enough power to meet its future demands due to the coordination of planning and operations in the SPP region; however, price and availability of power purchases may be impacted during periods of high demand.  Electric utility’s purchased power, as a percentage of MWh requirements, averaged approximately 18%17%, 18% and 15% for 2010, 2009 and 7% for 2009, 2008, and 2007, respectively.
 
Environmental Matters
See Note 1615 to the consolidated financial statements for information regarding environmental matters.
 
KANSAS CITY POWER & LIGHT COMPANY
 
KCP&L, headquartered in Kansas City, Missouri, is an integrated, regulated electric utility that engages in the generation, transmission, distribution and sale of electricity.  KCP&L serves approximately 509,000510,000 customers located in western Missouri and eastern Kansas.  Customers include approximately 450,000 residences, 57,00058,000 commercial firms, and 2,000 industrials, municipalities and other electric utilities.  KCP&L’s retail revenues averaged approximately 83%85% of its total operating revenues over the last three years.  Wholesale firm power, bulk power sales and miscellaneous electric revenues accounted for the remainder of KCP&L’s revenues.  KCP&L is significantly impacted by seasonality with approximately one-third of its retail revenues recorded in the third quarter.  Missouri and Kansas jurisdictional retail revenues averaged approximately 56% and 44%, respectively, of total retail revenues.revenues over the last three years.
 
GREAT PLAINS ENERGY AND KCP&L EMPLOYEES
At December 31, 2009,2010, Great Plains Energy and KCP&L had 3,1973,188 employees, including 1,9411,933 represented by three local unions of the International Brotherhood of Electrical Workers (IBEW).  KCP&L has labor agreements with Local 1613, representing clerical employees (expires March 31, 2013), with Local 1464, representing transmission and distribution workers (expires January 31, 2012), and with Local 412, representing power plant workers (expires February 28, 2010)2013).  An agreement has been reached and submitted for ratification with Local 412.

9
Executive Officers
Great Plains Energy and KCP&L have the same executive officers.  All of the individuals in the following table have been officers or employees in a responsible position with the Company for the past five years except as noted in the footnotes.  The executive officers were reappointed to the indicated positions by the respective boards of directors, effective January 1, 2010, for a one-year term ending on January 1, 2011, unless otherwise determined byto hold such positions until their resignation, removal or the boards.appointment of their successors.  There are no family relationships between any of the executive officers, nor any
9
arrangement or understanding between any executive officer and any other person involved in officer selection.  Each executive officer holds the same position with GMO as he or she does with KCP&L.
 
  Year First
  Assumed
   an Officer
NameAgeCurrent Position(s)
Year First Assumed
an Officer Position
AgeCurrent Position(s)Position
      
Michael J. Chesser (a)
61Chairman of the Board and Chief Executive Officer – Great Plains Energy and KCP&L200362Chairman of the Board and Chief Executive Officer – Great2003
      Plains Energy and KCP&L 
William H. Downey (b)
65President and Chief Operating Officer – Great Plains Energy and KCP&L200066President and Chief Operating Officer – Great Plains Energy2000
      and KCP&L 
Terry Bassham (c)
49Executive Vice President - Finance and Strategic Development and Chief Financial Officer – Great Plains Energy and KCP&L200550Executive Vice President – Utility Operations – Great Plains2005
Barbara B. Curry (d)
55Senior Vice President – Human Resources and Corporate Secretary – Great Plains Energy and KCP&L2005
Michael L. Deggendorf (e)
48Senior Vice President – Delivery – KCP&L2005
Scott H. Heidtbrink (f)
48Senior Vice President - Supply – KCP&L2008
John R. Marshall (g)
60Executive Vice President – Utility Operations – KCP&L2005
William G. Riggins (h)
51General Counsel and Chief Legal Officer – Great Plains Energy and KCP&L2000
      Energy and KCP&L 
Michael L. Deggendorf (d)
49Senior Vice President – Delivery – KCP&L2005
Scott H. Heidtbrink (e)
49Senior Vice President – Supply – KCP&L2008
James C. Shay (f)
47Senior Vice President – Finance and Strategic Development 2010
      and Chief Financial Officer  – Great Plains Energy and 
      KCP&L 
Ellen E. Fairchild (g)
49Vice President, Corporate Secretary and Chief Compliance2010
      Officer – Great Plains Energy and KCP&L 
Heather A. Humphrey (h)
40General Counsel and Vice President – Human Resources –2010
      Great Plains Energy and KCP&L 
Lori A. Wright (i)
47Vice President and Controller – Great Plains Energy and KCP&L200248Vice President and Controller – Great Plains Energy and2002
      KCP&L 

(a)Mr. Chesser was appointed Chairman of the Board and Chief Executive Officer of Great Plains Energy in 2003.  He was appointed Chairman of the Board of KCP&L in 2003, and Chief Executive Officer of KCP&L and Chairman of the Board and Chief Executive Officer of GMO in 2008.
(b)
Mr. Downey was appointed President and Chief Operating Officer of KCP&L and GMO in 2008.  He was President and Chief Executive Officer of KCP&L (2003-2008) and GMO (2008).
(c)Mr. Bassham was appointed Executive Vice President – Utility Operations of KCP&L and GMO in 2010.  He was Executive Vice President – Finance and Strategic Development and Chief Financial Officer of Great Plains Energy (2005)(2005-2010), and of KCP&L and GMO (2009)(2009-2010).  He was Chief Financial Officer of KCP&L (2005-2008) and GMO (2008).  Prior to that, he was Executive Vice President, Chief Financial and Administrative Officer (2001-2005) of El Paso Electric Company.
(d)Ms. Curry was appointed Senior Vice President – Human Resources and Corporate Secretary of Great Plains Energy, KCP&L and GMO in 2008.  She was Senior Vice President – Corporate Services and Corporate Secretary of Great Plains Energy (2005-2008) and Corporate Secretary of KCP&L (2005-2008).
(e)Mr. Deggendorf was appointed Senior Vice President – Delivery of KCP&L and GMO in 2008.  He was Vice President – Public Affairs of Great Plains Energy (2005-2008) and Senior Director, Energy Solutions (2002-2005) of KCP&L.
(f)(e)Mr. Heidtbrink was appointed Senior Vice President – Supply of KCP&L and GMO in 2009.  He was Senior Vice President – Corporate Services of KCP&L and GMO (2008), and Vice President – Power Generation & Energy Resources (2006-2008) of GMO.  In 2005, he led GMO’s Six Sigma deployment into its utility operations.
(g)(f)Mr. MarshallShay was appointed Executive Vice President – Utility Operations of KCP&L and GMO in 2008.  He was Senior Vice President – Delivery of KCP&L (2005-2008)Finance and GMO (2008).  Prior to that, he was President of Coastal Partners, Inc., a strategy consulting company (2001-2005).
(h)Mr. Riggins was appointed General CounselStrategic Development and Chief LegalFinancial Officer of Great Plains Energy, KCP&L and GMO in 2008.2010.  He was Chief Financial Officer, with responsibilities for finance, accounting and information technology, at Northern Power Systems, Inc., a wind turbine manufacturing business (2009-2010), Managing Director, with responsibilities for business development, transaction execution and advisory work, at
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Frontier Investment Banc Corporation (2007-2008), Chief Financial Officer, with responsibilities for finance, accounting, human resources, information technology and procurement, at Machine Laboratory LLC, a manufacturer of machined parts for the automotive industry (2006-2007).  Prior to that, Mr. Shay was Chief Financial Officer, with responsibilities for finance and accounting, at General Electric Co. Environmental Services (2004-2006) after its acquisition of BHA Group Holdings, Inc., a supplier of aftermarket parts and service for industrial air pollution equipment.
(g)Ms. Fairchild was appointed Vice President, LegalCorporate Secretary and Environmental AffairsChief Compliance Officer of Great Plains Energy, KCP&L and GMO in 2010.  She was Senior Director of Investor Relations and Assistant Secretary (2010) and Director of Investor Relations (2008-2010) of Great Plains Energy, KCP&L and GMO.  Prior to that, she was an associate at Hagen and Partners (2005-2007), a public relations firm.
(h)Ms. Humphrey was appointed General Counsel and Vice President – Human Resources of Great Plains Energy, KCP&L and GMO in 2010.  She was Senior Director of Human Resources and Interim General Counsel of Great Plains Energy, KCP&L (2005-2008) and GMO (2008)(2010) and General Counsel (2000-2005)Managing Attorney of Great Plains Energy.KCP&L (2007-2010).  Prior to that, she was a shareholder of the law firm of Shughart Thomson & Kilroy (1996-2006).
(i)Ms. Wright was appointed Vice President and Controller of Great Plains Energy, KCP&L and GMO in 2009.  She was Controller of Great Plains Energy (2002-2008),and KCP&L (2002-2008) and GMO (2008).
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Available Information
Great Plains Energy’s website is www.greatplainsenergy.com and KCP&L’s website is www.kcpl.com.  Information contained on the companies’these websites is not incorporated herein.  Both companies make available, free of charge, on or through their websites, their annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended, as soon as reasonably practicable after the companies electronically file such material with, or furnish it to, the SEC.  In addition, the companiesCompanies make available on or through their websites all other reports, notifications and certifications filed electronically with the SEC.
 
The public may read and copy any materials that the companies file with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC 20549.  For information on the operation of the Public Reference Room, please call the SEC at 1-800-SEC-0330.  The SEC also maintains an Internet site at http://www.sec.gov that contains reports, proxy statements and other information regarding the companies.
 
ITEM 1A.  RISK FACTORS
 
Actual results in future periods for Great Plains Energy and KCP&L could differ materially from historical results and the forward-looking statements contained in this report.  The companies’Companies’ business is influenced by many factors that are difficult to predict, involve uncertainties that may materially affect actual results and are often beyond the companies’their control.  Additional risks and uncertainties not presently known or that the companies’Companies’ management currently believes to be immaterial may also adversely affect the companies.Companies.  This information, as well as the other information included in this report and in the other documents filed with the SEC, should be carefully considered before making an investment in the securities of Great Plains Energy andor KCP&L.  Risk factors of KCP&L are also risk factors of Great Plains Energy.
 
Utility Regulatory and Environmental Risks:
 
Complex utility and environmental regulation could adversely affect Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.
The companiesCompanies are subject to, or affected by, extensive federal and state utility regulation, including by the MPSC, KCC, FERC, NRC, SPP and NERC.  They must also comply with environmental laws, regulations, permits and agreements.  The companiesCompanies must address in their business planning and management of operations the effects of existing and proposed laws and regulations and potential changes in the regulatory framework, including initiatives by federal and state legislatures, RTOs, utility regulators and taxing authorities.  Failure of the companiesCompanies to obtain adequate rates or regulatory approvals in a timely manner, new or changed laws, regulations, standards, interpretations or other legal requirements, and increased compliance costs and potential non-compliance consequences may materially affect Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.  Certain of these risks are addressed in greater detail below.

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The outcome of retail rate proceedings could have a material impact on the business and is largely outside the companies’Companies’ control.
The rates that the companiesKCP&L and GMO are allowed to charge their customers are the single most important item influencing theirthe Companies’ results of operations, financial position and cash flows.  These rates are subject to the determination, in large part, of governmental entities outside of the companies’Companies’ control, including the MPSC, KCC (for KCP&L) and FERC.  The companies are also exposed to cost-recovery shortfalls due to the inherent “regulatory lag” in the rate-setting process, especially during periods of significant cost inflation or declining retail usage, as utility rates in Missouri and Kansas are generally based on historical information and are not subject to adjustment (other than principally for fuel and purchased power for KCP&L in Kansas and for GMO) between rate cases.
 
AsThe utility rate-setting principle generally applicable to KCP&L and GMO is that rates should provide a part of the Missourireasonable opportunity to recover expenses and Kansas stipulations approvedinvestment prudently incurred to provide utility service plus a reasonable return on such investment.  Various expenses incurred by KCP&L and GMO have been excluded from rates by the MPSC and KCC in 2005,past rate cases as not being prudently incurred or not providing utility customer benefit, and there is a risk that certain expenses incurred in the future may not be recovered in rates.  The MPSC and KCC have also excluded from rates from time to time all or a portion of the capital cost of various facilities as not being prudently incurred or not being useful in providing utility service.  For example, KCC’s November 2010 rate order for KCP&L began implementationexcluded a portion of its Comprehensive Energy Plan.  Under the Comprehensive Energy Plan,
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KCP&L agreed to undertake certain projects, including constructingcapital costs of the Iatan No. 1 environment project and Iatan No. 2 installing a new wind-powered generating facility, installing environmental upgrades to certain existing plants, infrastructure improvements and demand management, distributed generation, and customer efficiency and affordability programs.  from KCP&L’s Kansas jurisdictional rate base.
In March 2007, KCP&L entered into a Collaboration Agreement with the Sierra Club and the Concerned Citizens of Platte County that provides for increases in KCP&L’s wind generation capacity and energy efficiency initiatives, reductions in certain emission permit levels at its Iatan and LaCygne generating stations, and projects to offset certain CO2 emissions.  The wind generation, energy efficiency and emission permit reductions are conditioned on regulatory approval.  In addition to these commitments, as discussed in the “Environmental Risks”  and “Financial Risks” sections below, the Companies’ capital expenditures are expected to be substantial over the next several years for other environmental and other projects, and there is a risk that a portion of the capital costs could be excluded from rates in future rate cases.
 
In additionThe Companies are also exposed to cost-recovery shortfalls due to the Collaboration Agreementinherent “regulatory lag” in the rate-setting process, especially during periods of significant cost inflation or declining retail usage, as KCP&L’s and Comprehensive Energy Plan energy efficiency provisions, thereGMO’s utility rates are generally based on historical information and are not subject to adjustment (other than principally for fuel and purchased power for KCP&L in Kansas and for GMO) between rate cases.  These and other factors may result in under-recovery of costs, failure to earn the authorized return on investment, or both.
There are mandatory renewable energy standards in Missouri and Kansas and thereKansas.  There is the potential for future federal or state mandatory energy efficiency requirements.  The companiesKCP&L agreed to implement various energy efficiency programs as part of the Collaboration Agreement and the 2005 Comprehensive Energy Plan.  KCP&L and GMO have implemented certain energy efficiency programs, and are evaluating expanded energy efficiency programs as one of the elements to meet environmental requirements and future customer energy needs.programs.  The companiesCompanies currently recover energy efficiency program expenses on a deferred basis.  While there are ongoing regulatory proceedings in Missouri and Kansas to addressbasis with no recovery of and earnings on the investments of utilities in renewable energy and energy efficiency programs, until the rules are set and programs are approved, the effects on Great Plains Energy’s and KCP&L’s plans and future results cannot be reasonably estimated.mechanism for associated lost revenues.
 
The MPSC order approving the GMO acquisition provides that the transaction costs will not be recovered through utility rates, and that the Missouri jurisdictional portion of transition costs will be eligible for recovery through utility rates only to the extent the costs are offset by benefits resulting from the acquisition.  These costs continue to be deferred until the MPSC authorizes their rate recovery.  The KCC order approving the GMO acquisition limited KCP&L’s recovery of transition costs through Kansas rates to $10.0 million over a five year period, starting in new rates anticipated to be effective in the fourth quarter ofDecember 2010.
 
Failure to timely recover the full costinvestment costs of capital projects, under the Comprehensive Energy Plan or Collaboration Agreement, or the impact of renewable energy and energy efficiency programs, or other utility costs and expenses due to regulatory disallowances,
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regulatory lag or other factors could lead to lowered credit ratings, reduced access to capital markets, increased financing costs, lower flexibility due to constrained financial resources and increased collateral security requirements, which could materially and adversely affect Great Plains Energy’s and KCP&L’s results of operations, financial position, and cash flows.or reductions or delays in planned capital expenditures.  In response to competitive, economic, political, legislative, public perception (including, but not limited to, the Companies’ environmental reputation) and regulatory pressures, the companiesCompanies may be subject to rate moratoriums, rate refunds, limits on rate increases, lower allowed returns on investment or rate reductions, including phase-in plans designed to spread the impact of rate increases over an extended period of time for the benefit of customers.  Any or all of these could have a significant adverse effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.
 
Regulatory requirements regarding utility operations may increase costs and may expose Great Plains Energy and KCP&Lthe Companies to compliance penalties.penalties or adverse rate consequences.
The NRC extensively regulates nuclear power plants, including Wolf Creek.  The FERC, NERC and SPP have implemented and enforce an extensive set of transmission system reliability, cyber security and critical infrastructure protection standards that apply to public utilities, including the companies.KCP&L and GMO.  The MPSC and KCC have the authority to implement utility operational standards and requirements, such as vegetation management standards, facilities inspection requirements and quality of service standards.standards, and KCP&L agreed to quality of service standards in Kansas in connection with the GMO acquisition.  In addition, the Companies are also subject to health, safety and other requirements enacted by the Occupational Safety and Health Administration, the Department of Transportation, the Department of Labor and other federal and state agencies.  The costs of existing, new or modified regulations, standards and other requirements could have an adverse effect on Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows as a result of increased operations or maintenance and capital expenditures for new facilities or to repair or improve
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existing facilities.  In addition, failure to meet quality of service, reliability, cyber security, critical infrastructure protection, operational or other standards and requirements could expose Great Plains Energy or KCP&Lthe Companies to penalties, additional compliance costs, or adverse rate consequences.
 
Environmental Risks:

The companiesCompanies are subject to current and potential environmental requirements and the incurrence of environmental liabilities, any or all of which may adversely affect their business and financial results.
The companiesCompanies 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 for historical and pre-existing conditions, these laws and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions.  There is also a risk that new environmental laws and regulations, new judicial interpretations of environmental laws and regulations, or the requirements in new or renewed environmental permits could adversely affect the companies’Companies’ operations.  In addition, there is also a risk of lawsuits brought by third parties alleging violations of environmental commitments or requirements, creation of a public nuisance or other matters, and seeking injunctions or monetary or other damages and certain federal courts have held that state and local governments and private parties have standing to bring climate change tort suits seeking company-specific emission reductions and damages.
 
The companies’ environmentalEnvironmental permits are subject to periodic renewal, which may result in more stringent permit conditions and limits.  New facilities, or modifications of existing facilities, may require new environmental permits or amendments to existing permits.  Delays in the environmental permitting process, public opposition and challenges, denials of permit applications, limits or conditions imposed in permits and the associated uncertainty may materially adversely affect the cost and timing of the projects, and thus materially adversely affect Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.
 
The companiesKCP&L and GMO would seek recovery of capital costs and expenses for environmental compliance and remediation through rate increases; however, there can be no assurance that such rate increases would be granted.  
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As discussed above, Great Plains EnergyKCP&L and KCP&LGMO may be subject to materiallymaterial adverse rate treatment in response to competitive, economic, political, legislative, public perception of the companies’Companies’ environmental reputation and regulatory pressures.  The costs of compliance or noncompliance with these environmental requirements, or remediation costs, or adverse outcomes of lawsuits, or failure to timely recover environmental costs, could have a material adverse effect on Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.  Certain of these matters are discussed in more detail below.  See Note 1615 to the consolidated financial statements for additional information regarding certain significant environmental matters.
 
Air and Climate Change
 
The Company believesCompanies believe it is likely that additional federal or relevant regional, 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 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 laws or regulations could require the control or reduction of emissions of greenhouse gases, such as CO2, which are created in the combustion of fossil fuels.  These requirements could include, among other things, taxes or fees on fossil fuels or emissions, cap and trade programs, and clean or renewable energy standards.  The companies’Companies’ current generation capacity is primarily coal-fired, and is estimated to produce about one ton of CO2 per MWh, or about 2328 million tons and 1721 million tons per year for Great Plains Energy and KCP&L, respectively.  LawsMissouri law requires at least 2% of the electricity provided by certain utilities, including KCP&L and GMO, to come from renewable resources by 2011, increasing to 15% by 2021.  Kansas law requires certain utilities, including KCP&L, to have recently been passed in Missouri and Kansas, the states in which the companies’ retail electric business is operated, setting renewable energy standards,generation capacity equal to at least 10% of their three-year average Kansas peak retail demand by 2011, increasing to 15% by 2016 and management20% by 2020.  Management believes that national renewable energy standards are also likely.  While management believes additional requirements addressing these matters will probably be enacted, theThe 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.  Such requirements could have a significant financial and operational impact on the Companies.
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equipment to achieve compliance, cannot be reasonably estimated at this time.  Such requirements could have the potential for a significant financial and operational impact on Great Plains Energy and KCP&L.
Missouri law requires at least 2% of the electricity provided by certain utilities, including KCP&L and GMO, to come from renewable resources by 2011, increasing to 15% by 2021.  Kansas law requires certain 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.  The American Clean Energy and Security Act of 2009, passed by the U.S. House of Representatives, would establish a 20% renewable electricity standard by 2020, starting with an initial 6% requirement by 2012.  The American Clean Energy Leadership Act of 2009, passed by the Senate Energy and Natural Resources Committee, contains lower renewable portfolio standards.  These bills would also establish a greenhouse gas cap and trade program, requiring KCP&L, GMO and other affected entities to comply by surrendering allowances or offsets for each ton of greenhouse gas emitted.
In addition to the potential for new environmental laws, the Environmental Protection Agency (EPA) is consideringhas enacted various regulations regarding the regulationreporting and permitting of greenhouse gases, and has proposed other permitting regulations, under the existing Clean Air Act.  Among other actions, the EPA hasThese existing and proposed rules that focus on facilities emitting over 25,000 tons of greenhouse gases per year.  These proposed rules would establish new thresholds for greenhouse gas emissions, defining when Clean Air Act permits under the New Source Performance Standards, New Source Review and Title V operating permits programs would be required for new or existing industrial facilities.facilities and when the installation of best available control technology would be required.  Most of Great Plains Energy’s and KCP&L’sthe Companies’ generating facilities would be affected by these existing and proposed rules.  Additional federal and/or state legislation or regulation respecting greenhouse gas emissions may be proposed or enacted in the near future.  Further, pursuant to the Collaboration Agreement, KCP&L agreed to pursue a set of initiatives including energy efficiency, additional wind generation, lower emission permit levels at its Iatan and LaCygne stations and other initiatives designed to offset CO2 emissions.   Requirements to reduce greenhouse gas emissions may cause Great Plains Energy and KCP&Lthe Companies to incur significant costs relating to their ongoing operations (through additional environmental control equipment, retiring and replacing existing generation, or selecting more costly generation alternatives), to procure emission allowance credits, or due to the imposition of taxes, fees or other governmental charges as a result of such emissions.  
 
Rules issued by the EPA regarding emissions of mercury and other hazardous air pollutants, NOX, SO2 and particulates are also in a state of flux. ��Such rules have been overturned by the courts and remanded to the EPA to be revised consistent with the court orders.  The EPA is expected to develop proposed standards in 2010,2011, based on maximum achievable control technology (MACT), for mercury and potentially other hazardous air pollutant emissions.  In addition, the EPA has notified KCP&L that MACT determinations and schedules of compliance are required for KCP&L’s Iatan No. 2 and Hawthorn No. 5 generating units.  The Missouri and Kansas state environmental agencies have submitted to the
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EPA their determinations that the Kansas City area is an ozone nonattainment area, and must submit by 2013 implementation plans outlining how the area will meet the standards.  Additionally, the EPA has proposed to strengthen the national ambient air quality standard (NAAQS) for ozone and in February 2009,has strengthened the Circuit CourtNAAQS for the District of Columbia remanded the EPA’s fine particulate (PMSO2.52) standards.  Great Plains Energy’s and KCP&L’s.  The Companies’ current estimates of capital expenditures (exclusive of Allowance for Funds Used During Construction (AFUDC) and property taxes) to comply with the currently effective Clean Air Interstate Rule (CAIR) and with the best available retrofit technology (BART) rule is a range of approximately $0.8 billion - $0.9$1 billion.  If CAIR is replaced by the proposed Transport Rule, the Companies do not expect the required capital expenditures to exceed that amount.  However, it is unknown what requirements and standards will be imposed in the future and when the companiesCompanies may have to comply, the effects of the MACT determinations and schedules of compliance, or what costs may ultimately be required.
 
The Clean Air Act requires companies to obtain permits and, if necessary, install control equipment to reduce emissions when making a major modification or a change in operation of an existing facility if either is expected to cause a significant net increase in regulated emissions.  In 2004, the EPA notified Westar Energy, Inc. (Westar) that certain projects completed at the Jeffrey Energy Center violated certain
Water
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New Source Review permitting requirements.  GMO is an 8% owner of the facility, which is operated by Westar, and is generally responsible for its 8% share of the facility’s operating costs and capital expenditures.  In February 2009, the Attorney General of the United States filed a complaint against Westar alleging that it violated the Clean Air Act and related federal and state regulations by making major modifications to the Jeffrey Energy Center beginning in 1994 without first obtaining appropriate permits authorizing this construction and without installing and operating best available control technology to control emissions.  In January 2010, Westar entered into a settlement agreement, which is pending court approval.  If approved, the settlement agreement would require, among other things, the installation of a selective catalytic reduction (SCR) at one of the three Jeffrey Energy Center units by the end of 2014 and the payment of a $3 million civil penalty.  Depending on the NOX emission reductions attained by that SCR and attainable through the installation of other controls at the other two units, the settlement agreement requires the installation of a second SCR on one of the other two units by the end of 2016.  Westar has estimated that if both SCRs are required, the total capital cost could be up to approximately $500 million.  There is no assurance that GMO’s share of these costs would be recovered in rates, and any failure to recover such costs could have a significant effect on Great Plains Energy’s results of operations, financial position and cash flows.  
Water
The Clean Water Act and associated regulations enacted by the EPA form a comprehensive program to preserve water quality.  All of the companies’Companies’ generating facilities, and certain of their other facilities, are subject to the Clean Water Act.
 
EPA regulations regarding protection of aquatic life from being killed or injured by cooling water intake structures have been suspended, and it is engaged in further rulemaking on this matter.  At this time, management is unable to predict how the EPA will respond or how that response will impact the companies’ operations.
Previously issued EPA regulations regarding protection of aquatic life from being killed or injured by cooling water intake structures have been suspended, and the EPA is engaged in further rulemaking on this matter.  At this time, the Companies are unable to predict how the EPA will respond or how that response will impact the Companies’ operations.
KCP&L holds a permit from the Missouri Department of Natural Resources (MDNR) authorizing 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 adverse impact on KCP&L.  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.  Additionally, the EPA in September 2009 announced plans to revise the existing standards for waste water discharges from coal-fired power plants.  Until a rule is proposed and finalized, the financial and operational impacts cannot be determined.  Further, the possible effects of climate change, including potentially increased temperatures and reduced precipitation, could make it more difficult and costly to comply with the final permit requirements.
 
KCP&L holds a permit from the MDNR covering water discharge from its Hawthorn Station.  The permit authorizes KCP&L, among other things, to 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 adverse impact on KCP&L.  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.  The possible effects of climate change, including potentially increased temperatures and reduced precipitation, could make it more difficult and costly to comply with the final permit requirements.Solid Waste
In September 2009, the EPA announced plans to revise the existing standards for waste water discharges from coal-fired power plants.  Until a rule is proposed and finalized, the financial and operational impacts to the companies cannot be determined.
Solid Waste
Solid and hazardous waste generation, storage, transportation, treatment and disposal is regulated at the federal and state levels under various laws and regulations.  The companiesCompanies principally use coal in generating electricity and dispose of thecoal combustion productsresiduals (CCRs) in both on-site facilities and facilities owned by third parties.  In response to an incident at a Tennessee Valley Authority coal combustion product containment area, federal legislation has been introduced and the EPA has indicated that it will proposeproposed regulations regarding the handling and disposal of coal combustion products.CCRs, which include alternative proposals to regulate CCRs as special or hazardous wastes or as non-hazardous wastes.  If enacted, any new laws and regulations, especially if coal combustion productsCCRs are classified as hazardous waste, could
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have a material adverse effect on Great Plains Energy’s or KCP&L’sthe Companies’ results of operations, financial position and cash flows.
 
Remediation
Under current law, the companiesCompanies are also generally responsible for any liabilities associated with the environmental condition of their properties, and other properties at which the Companies arranged for the disposal or treatment of hazardous substances, including properties that they have previously owned or
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operated, such as manufactured gas plants (MGP), regardless of whether they were responsible for the contamination or whether the liabilities arose before, during or after the time they owned or operated the properties.properties or arranged for the disposal or treatment of hazardous substances.  In addition, the EPA has given advance notice of a proposed rulemaking to impose financial assurance requirements for various classes of facilities, including electric generation, transmission and distribution, that produce, transport, treat, store or dispose of certain hazardous substances.
 
Due to all of the above, Great Plains Energy’s and KCP&L’sthe Companies’ projected capital and other expenditures for environmental compliance are subject to significant uncertainties, including the timing of implementation of any new or modified environmental requirements, the emissions limits imposed by such requirements and the types and costs of the compliance alternatives selected by Great Plains Energy and KCP&L.the Companies.  As a result, costs to comply with environmental requirements cannot be estimated with certainty, and actual costs could be significantly higher than projections.  Other new environmental laws and regulations affecting the operations of the companiesCompanies may be adopted, and new interpretations of existing laws and regulations could be adopted or become applicable to the companiesCompanies or their facilities, any of which may materially adversely affect Great Plains Energy’s and KCP&L’sthe Companies’ business, adversely affect the companies’Companies’ ability to continue operating its power plants as currently done and substantially increase their environmental expenditures or liabilities in the future.
 
Financial Risks:
 
Financial market disruptions and declines in credit ratings may increase financing costs and/or limit access to the credit markets, which may adversely affect liquidity and results.
Great Plains Energy’s and KCP&L’sThe Companies’ capital requirements are expected to be substantial over the next several years.  Great Plains Energy and KCP&LThe Companies rely on access to short-term money markets, revolving credit facilities provided by financial institutions and long-term capital markets as significant sources of liquidity for capital requirements not satisfied by cash flows from operations.  Great Plains Energy and KCP&LThe Companies also rely on bank-provided credit facilities for credit support, such as letters of credit, to support operations.  The amount of credit support required for operations varies with a number of factors, including the amount and price of wholesale power purchased or sold.  
 
Great Plains Energy, KCP&L, GMO and certain of their securities are rated by Moody's Investors Service and Standard & Poor's.  These ratings impact the companies’Companies’ cost of funds and Great Plains Energy’s ability to provide credit support for its subsidiaries.  The interest rates on borrowings under KCP&L’sthe Companies’ revolving credit agreementagreements and on a substantial portion of Great Plains Energy’s and GMO’s debt are subject to increase as their respective credit ratings decrease.  The Company hasCompanies have agreed to not seek rate recovery of GMO interest costs in excess of equivalent investment-grade debt, and the MPSC approval of the GMO acquisition is conditioned on the requirement that any post-acquisition financial effects of a credit downgrade of Great Plains Energy, KCP&L or GMO occurring as a result of the acquisition would be borne by shareholders and not utility customers.  The amount of collateral or other credit support required under power supply and certain other agreements is also dependent on credit ratings.  
 
The capital and credit markets recently experienced unprecedented levels of volatility and disruption.disruption in recent years.  Though market conditions have stabilized, there is no assurance that conditions will not deteriorate in the future.  Adverse market conditions or decreases in Great Plains Energy’s, KCP&L’s or GMO’s credit ratings could have material adverse effects on the companies.Companies.  These effects could include, among others: reduced access to capital and increased cost of funds; dilution resulting from equity issuances at reduced prices; changes in the type and/or increases in the amount of collateral or other credit support obligations required to be posted with contractual counterparties; increased nuclear decommissioning trust and pension and other post-retirement benefit plan funding requirements; rate case
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disallowance of KCP&L’s or GMO’s costs of capital; reductions in or delays of capital expenditures, or reductions in Great Plains Energy’s ability to provide credit support for its subsidiaries.  Any of these results could adversely affect Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.  In addition, market disruption and volatility could have an adverse impact on Great Plains Energy’s or KCP&L’sthe Companies’ lenders, suppliers and other counterparties or customers, causing them to fail to meet their obligations.
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A sustained decline in Great Plains Energy’s stock price below book value may result in goodwill impairments that could adversely affect Great Plains Energy’s results of operations and financial position, as well as credit facility covenants.
The GMO acquisition resulted in Great Plains Energy recording $169 million in goodwill.  Accounting rules require goodwill to be tested for impairment annually and when an event occurs indicating that it is possiblethe possibility that an impairment exists.  Great Plains Energy’s stock traded at a price below carrying value throughout 2009.2010.  If the stock price continueswere to be belowdecline substantially further from its current level in relation to carrying value, the accounting rules may require Great Plains Energy to conduct additional goodwill impairment tests.  There is no assurance that the results of these additional tests will not require Great Plains Energy to recognize an impairment of goodwill.  An impairment of goodwill would reduce net income and shareholders’ equity, may adversely affect Great Plains Energy’s results of operations and financial position, and in certain circumstances could result in a breach of the debt to total capitalization covenants in Great Plains Energy’s and GMO’s revolving credit agreements.
 
Great Plains Energy has guaranteed substantially all of the outstanding debt of GMO and payments under these guarantees may adversely affect Great Plains Energy’s liquidity.
In connection with the GMO acquisition, Great Plains Energy issued guarantees covering substantially all of the outstanding debt of GMO and has guaranteed a $400GMO’s current $450 million revolving credit facility that GMO entered into subsequent to the acquisition.facility.  The guarantees were a factor in GMO receiving investment-grade ratings and the guarantees obligate Great Plains Energy to pay amounts owed by GMO directly to the holders of the guaranteed debt in the event GMO defaults on its payment obligations.  Great Plains Energy may also guarantee debt that GMO may issue in the future.  Any guarantee payments could adversely affect Great Plains Energy’s liquidity.
 
The inability of Great Plains Energy’s subsidiaries to provide sufficient dividends to Great Plains Energy, or the inability otherwise of Great Plains Energy to pay dividends to its shareholders and meet its financial obligations would have an adverse effect.
Great Plains Energy is a holding company with no significant operations of its own.  The primary source of funds for payment of dividends to its shareholders and its other financial obligations is dividends paid to it by its subsidiaries, particularly KCP&L and GMO.  The ability of Great Plains Energy’s subsidiaries to pay dividends or make other distributions, and accordingly, Great Plains Energy’s ability to pay dividends on its common stock and meet its financial obligations principally depends on the actual and projected earnings and cash flow, capital requirements and general financial position of its subsidiaries, as well as on regulatory factors, financial covenants, general business conditions and other matters.

In addition, Great Plains Energy, KCP&L and GMO are subject to certain corporate and regulatory restrictions and financial covenants that could affect their ability to pay 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 Great Plains Energy Board of Directors (Board).Directors.  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 contain a covenant requiring each company to maintain a consolidated indebtedness to consolidated total
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capitalization ratio of not more than 0.65 to 1.00.  In addition, Great Plains Energy is prohibited from paying dividends on its common and preferred stock in the event its Equity Unit contract payments or interest payments on the debt underlying the Equity Units are deferred until such deferrals have been paid.  While these corporate and regulatory restrictions and financial covenants are not expected to affect the companies’Companies’ ability to pay
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dividends at the current level in the foreseeable future, there is no assurance that adverse financial results would not trigger such restrictions or covenants and reduce or eliminate the companies’Companies’ ability to pay dividends.

Market performance, increased retirements and retirement plan regulations could significantly impact retirement plan funding requirements and associated cash needs and expenses.
Substantially all of KCP&L’sthe Companies’ and Wolf Creek Nuclear Operating Corporation’s employees participate in defined benefit retirement and post-retirement plans.  GMO’s formerFormer employees in its Missouri utility operations and certain other operations also have accrued benefits in defined benefit retirement and post-retirement plans.  The costs of these plans depend on a number of factors, including the rates of return on plan assets, the level and nature of the provided benefits, discount rates, the interest rates used to measure required minimum funding levels, changes in benefit design, changes in laws or regulations, and the Company’sCompanies’ required or voluntary contributions to the plans.  IfThe Companies currently have substantial unfunded liabilities under these plans.  Also, if the rate of retirements exceeds planned levels, or if these plans experience adverse market returns on investments, (as was the case in 2008), or if interest rates materially fall, the Company’sCompanies’ contributions to the plans could rise substantially over historical levels.  In addition, changes in accounting requirementsrules and assumptions related to future costs, returns on investments, interest rates and other actuarial assumptions, including projected retirements, could have a significant impact on Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.
 
The use of derivative contracts in the normal course of business could result in losses that could negatively impact Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.
Great Plains Energy and KCP&LThe Companies use derivative instruments, such as swaps, options, futures and forwards, to manage commodity and financial risks.  Losses could be recognized as a result of volatility in the market values of these contracts, if a counterparty fails to perform, or if the underlying transactions which the derivative instruments are intended to hedge fail to materialize.  In the absence of actively quoted market prices and pricing information from external sources, the valuation of these financial instruments can involve management’s judgment or use of estimates.  As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these contracts.
 
As a service provider to GMO, KCP&L may have exposure to GMO’s financial performance and operations.
GMO has no employees of its own.  KCP&L employees operate and manage GMO’s properties, and KCP&L charges GMO for the cost of these services.  These arrangements may pose risks to KCP&L, including possible claims arising from actions of KCP&L employees in operating GMO’s properties and providing other services to GMO.  KCP&L’s claims for reimbursement for services provided to GMO are unsecured and rank equally with other unsecured obligations of GMO.  KCP&L’s ability to be reimbursed for the costs incurred for the benefit of GMO depends on the financial ability of GMO to make such payments.
 
Customer and Weather-Related Risks:
 
Severe or unusual weather and changesChanges in customer electricity consumption due to sustained financial market disruptions, downturns or sluggishness in the economy, technological advances, weather conditions, or otherwise may adversely affect Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.
The results of operations, financial position and cash flows of Great Plains Energy and KCP&Lthe Companies can be materially affected by changes in weather and customer electricity consumption.  Great Plains Energy and KCP&LThe Companies estimate customer electricity consumption based on historical trends to procure fuel and purchased power.  Sustained downturns or sluggishness in the economy generally affect the markets in which Great Plains Energy and KCP&Lthe Companies operate.  KCP&L’s retail consumption, on both a nominal and weather-adjusted basis, declined in 2009 compared to 2008.  If financial markets or the economy worsen, overall electricity sales volumes may further decline and/or bad debt expense may increase, which could materially affect Great Plains Energy’s and KCP&L’s results of
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operations, financial position and cash flows.  Additionally, technological advances or other energy conservation measures could reduce customer consumption, which could affect Great Plains Energy’s and KCP&L’selectricity consumption.
Weather is a major driver of the Companies’ results of operations, financial position and cash flows.flow.
Weather conditions directly influence the demand for electricity and natural gas and affect the price of energy commodities.  Great Plains Energy and KCP&L are significantly impacted by seasonality, with approximately one-third of their retail electric revenues recorded in the third quarter.  Unusually mild winter or summer weather (as was experienced in 2009) can adversely affect sales.  In addition, severe weather, including but not limited to tornados, snow, rain and ice
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storms can be destructive causing outages and property damage that can potentially result in additional expenses, lower revenues and additional capital restoration costs.  Some of the companies’Companies’ stations use water from the Missouri River for cooling purposes.  Low water and flow levels, which have been experienced in past years, can increase maintenance costs at these stations and, if these levels were to get low enough, could require modifications to plant operations.  Conversely, Missouri River flooding has occurred at various times in past years, which has affected plant operations.  The possible effects of climate change (such as increased temperatures, increased occurrence of severe weather or reduced precipitation, among other possible results) could potentially increase the volatility of demand and prices for energy commodities, the frequency and impact of severe weather, andincrease the frequency of flooding or decrease water and flow levels, any of which could materially affect Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.levels.
 
Operational Risks:
 
Operations risks may adversely affect Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.
The operation of the companies’Companies’ electric generation, transmission, distribution and information systems involves many risks, including breakdown or failure of equipment, processes and personnel performance; problems that delay or increase the cost of returning facilities to service after outages, operating limitations that may be imposed by equipment conditions, environmental, safety or other regulatory requirements; fuel supply or fuel transportation reductions or interruptions; transmission scheduling constraints; and catastrophic events such as fires, explosions, terrorism, cyber-threats, severe weather or other similar occurrences.  An equipment or system outage or constraint can, among other things:
 
·  in the case of generation equipment, directly affect operating costs, increase capital requirements and costs, increase purchased power volumes and costs and reduce wholesale sales opportunities;
 
·  in the case of transmission equipment, affect operating costs, increase capital requirements and costs, require changes in the source of generation and affect wholesale sales opportunities;opportunities and the ability to meet regulatory reliability and security requirements;
 
·  in the case of distribution systems, affect revenues and operating costs, increase capital requirements and costs, and affect the ability to meet regulatory service metrics and customer expectations; and
 
·  in the case of information systems, directly affect the control and operations of generation, transmission, distribution and other business operations and processes, increase operating costs, increase capital requirements and costs, and affect the ability to meet regulatory reliability and security requirements and customer expectations.

With the exception of Hawthorn No. 5, which was substantially rebuilt in 2001, and Iatan No. 2, which was completed in 2010, all of KCP&L’s coal-fired generating units and its nuclear generating unit were constructed prior to 1986.  All of GMO’s coal-fired generating units were constructed prior to 1984.  The age of these generating units increases the risk of unplanned outages, reduced generation output and higher maintenance expense.  Training, preventive maintenance and other programs have been implemented, but there is no assurance that these programs will prevent or minimize future breakdowns or failures of the companies’Companies’ generation facilities.facilities or increased maintenance expense.
 
The companiesCompanies currently have general liability and property insurance in place to cover their facilities in amounts that management considers appropriate.  These policies, however, do not cover the companies’Companies’ transmission or distribution systems, and the cost of repairing damage to these systems may adversely affect Great Plains Energy’s or KCP&L’sthe Companies’ results of operations, financial position and cash flows.  Such policies are subject to certain limits and deductibles and do not include business interruption coverage.  Insurance coverage may not be
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available in the future at currentreasonable costs or on commercially reasonable terms, and the insurance proceeds received for any loss of, or any damage to, any of the companies’Companies’ facilities may not be sufficient to restore the loss or damage.
 
These and other operating events may reduce Great Plains Energy’s and KCP&L’sthe Companies’ revenues, increase their costs, or both, and may materially affect Great Plains Energy’s and KCP&L’stheir results of operations, financial position and cash flows.
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The cost and schedule of construction projects may materially change and expected performance may not be achieved.
Great Plains Energy’s and KCP&L’s businesses are capital intensive, and require significant capital investments to maintain existing facilities, for projected environmental projects and to add new facilities, including Iatan No. 2, an estimated 850 MW (of which electric utility’s share is 620 MW) coal-fired generating plant.facilities.  The risks of any construction project includeinclude: the possibilities that actual costs may exceed current estimates,estimated costs due to inflation or other factors; delays may occur in obtaining permits and materials,materials; suppliers and contractors may not perform as required under their contracts,contracts; there may be inadequate availability or increased cost of equipment, materials or qualified craft labor,labor; the scope, cost and timing of projects may change due to new or changed environmental requirements or other factors; and other events beyond the companies’Companies’ control may occur that may materially affect the schedule, cost and performance of these projects.
The demand for additional environmental control equipment has increased substantially with many utilities in the United States starting similar projects to address changing environmental regulations.  This demand has constrained labor and material resources for such projects, and there is a risk that such constraints may increase if new laws or regulations, including limitations on greenhouse gas emissions, are imposed. 
 
These and other risks could materially increase the estimated costs of construction projects, delay the in-service dates of projects, adversely affect the performance of the projects, and/or require the companiesCompanies to purchase additional electricity to supply their respective retail customers until the projects are completed.  The companiesCompanies currently are not permitted to start recovering the costs of these projects in rates until they are completed and put into service.  Thus, these risks may significantly affect Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.
 
Failure of one or more generation plant co-owners to pay their share of construction or operations and maintenance costs could increase Great Plains Energy’s and KCP&L’sthe Companies’ costs and capital requirements.
KCP&L owns 47% of Wolf Creek, 50% of LaCygne Station, 70% of Iatan No. 1 and 55% of Iatan No. 2.  GMO owns 18% of both Iatan units and 8% of Jeffrey Energy Center.  The remaining portions of these facilities are owned by other utilities that are contractually obligated to pay their proportionate share of capital and other costs and, in the case of Iatan No. 2, construction costs.
 
While the ownership agreements provide that a defaulting co-owner’s share of the electricity generated can be sold by the non-defaulting co-owners, there is no assurance that the revenues received will recover the increased costs borne by the non-defaulting co-owners.  The Iatan No. 2 co-owners have provided financial assurances related to their respective construction cost obligations, but there is a risk that such assurances may not be sufficient in the event of a co-owner default.  During the construction period, the Iatan No. 2 agreements provide for re-allocations of part or all of a defaulting co-owner’s share of the facility to the non-defaulting owners, which would increase the capital requirements, operations and maintenance costs of the non-defaulting owners.  Occurrence of these or other events could materially increase Great Plains Energy’s and KCP&L’sthe Companies’ costs and capital requirements.
An aging workforce and increasing demand for skilled craft labor poses operational and planning challenges.
Through 2013, approximately 22% of KCP&L employees (who manage electric utility’s operations) will be eligible to retire with full pension benefits.  This is a general industry issue, which has increased the demand for and cost of skilled craft labor for both companies and contractors.  The companies use contractors for a portion of
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their construction and maintenance work.  Failure to hire and adequately train replacement employees, including the transfer of significant internal historical knowledge and expertise to the new employees, or the future availability and cost of contract labor may adversely affect the ability to manage and operate Great Plains Energy’s and KCP&L’s businesses.
 
Commodity Price Risks:
 
Changes in commodity prices could have an adverse effect on Great Plains Energy’s and KCP&L’sthe Companies’ results of operations, financial position and cash flows.
The companiesCompanies engage in the wholesale and retail marketing of electricity and are exposed to risks associated with the price of electricity.  To the extent that exposure to the price of electricity is not successfully hedged, Great Plains Energy and KCP&Lthe Companies could experience losses associated with the changing market price for electricity.
 
Increases in fuel, fuel transportation and purchased power prices could have an adverse impact on Great Plains Energy’s and KCP&L’sthe Companies’ costs.
KCP&L’s Kansas retail rates contain an energy cost adjustment (ECA) mechanism.  KCP&L’s Missouri retail rates do not contain a similar provision.  GMO’s retail electric and steam rates contain a fuel adjustment clause (FAC) mechanism under which 95%most, but not all, of the difference between actual fuel and purchased power costs and the amount of fuel and purchased power costs provided in base rates is passed along to GMO’s customers.  GMO’s steam rates contain a quarterly cost adjustment (QCA) under which 85% of the difference between actual fuel costs and base fuel costs is passed along to GMO’s steam customers.  As a result, KCP&L and GMOthe Companies are exposed to varying degrees of risk from changes in the market prices of fuel for generation of electricity and purchased power.  Changes in the companies’Companies’ fuel mix due to electricity demand, plant availability, transportation issues, fuel prices, fuel availability and other factors can also adversely affect Great Plains Energy’s and KCP&L’sthe Companies’ fuel and purchased power costs.
 
The companiesCompanies do not hedge their respective entire exposure from fuel and transportation price volatility.  Forward prices for coal have increased, principally due to international demand, and management expects prices will continue to increase.  The majority ofConsequently, the companies’ rail transportation contracts expire in 2010 and consequently it is expected that rail transportation costs will increase significantly in 2011.  Management also expects the cost of nuclear fuel to increase significantly in 2010.  Consequently, Great Plains Energy’s and KCP&L’sCompanies’ results of operations, financial position and cash flows may be materially impacted by changes in these prices unless and until increased costs are recovered in KCP&L’s Missouri retail rates.
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Wholesale electricity sales affect revenues, creating earnings volatility.
The levels of Great Plains Energy and KCP&Lthe Companies’ wholesale sales depend on the wholesale market price, transmission availability and the availability of generation for wholesale sales, among other factors.  A substantial portion of wholesale sales are made in the spot market, and thus the companiesCompanies have immediate exposure to wholesale price changes.  Wholesale power prices can be volatile and generally increase in times of high regional demand and high natural gas prices.  While an allocated portion of wholesale sales are reflected in GMO’s FAC and KCP&L’s Kansas ECA,energy cost adjustment and GMO’s fuel adjustment mechanisms, KCP&L’s Missouri rates are set on an estimated amount of wholesale sales.  KCP&L will not recover any shortfall in non-firm wholesale electric sales margin from the level included in Missouri rates and any amount above the level reflected in Missouri retail rates will be returned to Missouri retail customers in a future rate case.  Declines in wholesale market price, availability of generation, transmission constraints in the wholesale markets, or low wholesale demand could reduce the companies’Companies’ wholesale sales.  These events could adversely affect Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.
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KCP&L is exposed to risks associated with the ownership and operation of a nuclear generating unit, which could result in an adverse effect on Great Plains Energy’s and KCP&L’sthe Companies’ business and financial results.
KCP&L owns 47% of Wolf Creek.  The NRC has broad authority under federal law to impose licensing and safety-related requirements for the operation of nuclear generation facilities, including Wolf Creek.  In the event of non-compliance, the NRC has the authority to impose fines, shut down the facilities, or both, depending upon its assessment of the severity of the situation, until compliance is achieved.  Any revised safety requirements promulgated by the NRC could result in substantial capital expenditures at Wolf Creek.
 
Wolf Creek has the lowest fuel cost per MWh of any of KCP&L's generating units.  An extended outage of Wolf Creek, whether resulting from NRC action, an incident at the plant or otherwise, could have a substantialmaterial adverse effect on KCP&L's results of operations, financial position and cash flows in the event KCP&L incurs higher replacement power and other costs that are not recovered through rates.rates or insurance.  If a long-term outage occurred, the state regulatory commissions could reduce rates by excluding the Wolf Creek investment from rate base.  As discussed in “Operational Risks”, above, Wolf Creek was constructed prior to 1986, and the age of Wolf Creek increases the risk of unplanned outages and higher maintenance costs.
 
Ownership and operation of a nuclear generating unit exposes KCP&L to risks regarding decommissioning costs at the end of the unit's life.  KCP&L contributes annually based on estimated decommissioning costs to a tax-qualified trust fund to be used to decommission Wolf Creek.  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 and may not be allowed to recover the balance through rates.
 
KCP&L is also exposed to other risks associated with the ownership and operation of a nuclear generating unit, including, but not limited to, potential liability associated with the potential harmful effects on the environment and human health resulting from the operation of a nuclear generating unit and the storage, handling, disposal and disposalpotential release (by accident, through third-party actions or otherwise) of radioactive materials.  Under the structure for insurance among owners of nuclear generating units, KCP&L is also liable for potential retrospective premium assessments (subject to a cap) per incident at any commercial reactor in the country and losses in excess of insurance coverage.  Any such risks could adversely affect Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.
 
Litigation Risks:
 
The outcome of legal proceedings cannot be predicted.  An adverse finding could have a material adverse effect on Great Plains Energy’sthe Companies’ results of operations, financial position and KCP&L’s financial condition.cash flows.
Great Plains Energy and KCP&LThe Companies are party to various material litigation and regulatory matters arising out of their business operations.  The ultimate outcome of these matters cannot presently be determined, nor, in many cases, can the liability that could potentially result from a negative outcome in each case presently be reasonably estimated.  The liability that Great Plains Energy and KCP&Lthe Companies may ultimately incur with respect to any of these cases in the event of a negative outcome may be in excess of amounts currently reserved and insured against with respect to such matters and, as a result, these matters may have a material adverse effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.matters.
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ITEM 1B.  UNRESOLVED STAFF COMMENTS
 
None.
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ITEM 2.  PROPERTIES
 
Electric Utility Generation Resources
                     
   YearEstimated 2010 Primary      YearEstimated 2011 Primary 
 Unit CompletedMW Capacity Fuel  Unit Location CompletedMW Capacity Fuel 
Base LoadBase LoadWolf Creek 1985        545(a) NuclearBase LoadIatan No. 2 Missouri 2010        465(a) Coal 
 Wolf Creek Kansas 1985        560(a) Nuclear 
 Iatan No. 1 1980        494(a) Coal Iatan No. 1 Missouri 1980        494(a) Coal 
 LaCygne No. 2 1977        341(a) Coal LaCygne No. 2 Kansas 1977        341(a) Coal 
 LaCygne No. 1 1973        368(a) Coal LaCygne No. 1 Kansas 1973        368(a) Coal 
 
Hawthorn No. 5 (b)
 1969        563  Coal 
Hawthorn No. 5 (b)
 Missouri 1969        563  Coal 
 Montrose No. 3 1964        176  Coal Montrose No. 3 Missouri 1964        176  Coal 
 Montrose No. 2 1960        164  Coal Montrose No. 2 Missouri 1960        164  Coal 
 Montrose No. 1 1958        170  Coal Montrose No. 1 Missouri 1958        170  Coal 
Peak LoadPeak LoadWest Gardner Nos. 1, 2, 3 and 4 2003        308  Natural GasPeak LoadWest Gardner Nos. 1, 2, 3 and 4 Kansas 2003        310  Natural Gas
 Osawatomie 2003          76  Natural Gas Osawatomie Kansas 2003          75  Natural Gas
 Hawthorn No. 9 2000        130  Natural Gas Hawthorn No. 9 Missouri 2000        130  Natural Gas
 Hawthorn No. 8 2000          76  Natural Gas Hawthorn No. 8 Missouri 2000          77  Natural Gas
 Hawthorn No. 7 2000          75  Natural Gas Hawthorn No. 7 Missouri 2000          77  Natural Gas
 Hawthorn No. 6 1997        136  Natural Gas Hawthorn No. 6 Missouri 1997        136  Natural Gas
 Northeast Black Start Unit 1985            2  Oil Northeast Black Start Unit Missouri 1985            2  Oil 
 Northeast Nos. 17 and 18 1977        110  Oil Northeast Nos. 17 and 18 Missouri 1977        110  Oil 
 Northeast Nos. 13 and 14 1976        105  Oil Northeast Nos. 13 and 14 Missouri 1976        105  Oil 
 Northeast Nos. 15 and 16 1975          96  Oil Northeast Nos. 15 and 16 Missouri 1975          96  Oil 
 Northeast Nos. 11 and 12 1972          99  Oil Northeast Nos. 11 and 12 Missouri 1972          98  Oil 
WindWind
Spearville Wind Energy Facility (c)
 2006          15  WindWind
Spearville 2 Wind Energy Facility (c)
 Kansas 2010            4  Wind 
 
Spearville Wind Energy Facility (d)
 Kansas 2006            8  Wind 
Total KCP&LTotal KCP&L     4,049    Total KCP&L          4,529   
Base LoadBase LoadIatan No. 1 1980        127(a) CoalBase LoadIatan No. 2 Missouri 2010        153(a) Coal 
 Iatan No. 1 Missouri 1980        127(a) Coal 
Jeffrey Energy Center Nos. 1, 2 and 31978, 1980, 1983173(a) Coal Jeffrey Energy Center Nos. 1, 2 and 3 Kansas 1978, 1980, 1983  173(a) Coal 
Sibley Nos. 1, 2 and 31960, 1962, 1969 466  Coal Sibley Nos. 1, 2 and 3 Missouri 1960, 1962, 1969   466  Coal 
 Lake Road Nos. 2 and 4 1957, 1967        126  Coal and Natural Gas Lake Road Nos. 2 and 4 Missouri 1957, 1967        125  Coal and Natural Gas
Peak LoadPeak LoadSouth Harper Nos. 1, 2 and 3 2005        314  Natural GasPeak LoadSouth Harper Nos. 1, 2 and 3 Missouri 2005        314  Natural Gas
 Crossroads Energy Center 2002        297  Natural Gas Crossroads Energy Center Mississippi 2002        297  Natural Gas
 Ralph Green No. 3 1981          71  Natural Gas Ralph Green No. 3 Missouri 1981          71  Natural Gas
 Greenwood Nos. 1, 2, 3 and 4 1975-1979        252  Natural Gas/Oil Greenwood Nos. 1, 2, 3 and 4 Missouri 1975-1979        255  Natural Gas/Oil
 Lake Road No. 5 1974          63  Natural Gas/Oil Lake Road No. 5 Missouri 1974          63  Natural Gas/Oil
 Lake Road Nos. 1 and 3 1951, 1962          22  Natural Gas/Oil Lake Road Nos. 1 and 3 Missouri 1951, 1962          33  Natural Gas/Oil
 Lake Road Nos. 6 and 7 1989, 1990          43  Oil Lake Road Nos. 6 and 7 Missouri 1989, 1990          41  Oil 
 Nevada 1974          21  Oil Nevada Missouri 1974          21  Oil 
Total GMOTotal GMO     1,975    Total GMO          2,139   
Total Great Plains EnergyTotal Great Plains Energy     6,024    Total Great Plains Energy         6,668   
(a)Share of a jointly owned unit.
(c)(a)Share of a jointly owned unit.
(b)The Hawthorn Generating Station returned to commercial operation in 2001 with a new boiler, air qualityThe Hawthorn Generating Station returned to commercial operation in 2001 with a new boiler, air quality control equipment and
control equipment and an uprated turbine following a 1999 explosion.an uprated turbine following a 1999 explosion.
(c)(a)The 100.5 MW Spearville Wind Energy Facility's accredited capacity is 15 MW pursuant to SPP reliability standards.
(c)The 48 MW Spearville 2 Wind Energy Facility's accredited capacity is 4 MW pursuant to SPP reliability standards.
(d)The 100.5 MW Spearville Wind Energy Facility's accredited capacity is 8 MW pursuant to SPP reliability standards.
 
2322
 
KCP&L owns 50% of LaCygne Nos. 1 and 2, 70% of Iatan No. 1, 55% of Iatan No. 2 and 47% of Wolf Creek.  GMO owns 18% of Iatan No.Nos. 1 and 2 and 8% of Jeffrey Energy Center Nos. 1, 2 and 3.  Electric utility expects to have Iatan No. 2, a new coal-fired plant in service in the fall of 2010, which will add approximately 620 MW to electric utility’s generating capacity.  KCP&L owns 55% and GMO owns 18% of Iatan No. 2.

Electric Utility Transmission and Distribution Resources
Electric utility’s electric transmission system interconnects with systems of other utilities for reliability and to permit wholesale transactions with other electricity suppliers.  Electric utility has over 3,000approximately 3,500 circuit miles of transmission lines, approximately 18,00015,600 circuit miles of overhead distribution lines and over 7,0006,500 circuit miles of underground distribution lines in Missouri and Kansas.  Electric utility has all material franchise rights necessary to sell electricity within its retail service territory.  Electric utility’s transmission and distribution systems are continuously monitored for adequacy to meet customer needs.  Management believes the current systems are adequate to serve customers.
 
Electric Utility General
Electric utility’s generating plants are located on property owned (or co-owned) by KCP&L or GMO, except the Spearville Wind Energy FacilityFacilities which isare located on easements and the Crossroads Energy Center and South Harper which isare contractually controlled.  Electric utility’s service centers, electric substations and a portion of its transmission and distribution systems are located on property owned or leased by electric utility.  Electric utility’s transmission and distribution systems are for the most part located above or underneath highways, streets, other public places or property owned by others.  Electric utility believes that it has satisfactory rights to use those places or properties in the form of permits, grants, easements, licenses or franchise rights; however, it has not necessarily undertaken efforts to examine the underlying title to the land upon which the rights rest.  Great Plains Energy’s and KCP&L’s headquarters are located in leased office space.
 
Substantially all of the fixed property and franchises of KCP&L, which consist principally of electric generating stations, electric transmission and distribution lines and systems, and buildings (subject to exceptions, reservations and releases), are subject to a General Mortgage Indenture and Deed of Trust dated as of December 1, 1986.  Mortgage bonds totaling $755.3 million were outstanding at December 31, 2009.2010.
 
Substantially all of the fixed property and franchises of GMO’s St. Joseph Light & Power division is subject to a General Mortgage Indenture and Deed of Trust dated as of April 1, 1946.  Mortgage bonds totaling $13.5$12.4 million were outstanding at December 31, 2009.2010.
 
ITEM 3.  LEGAL PROCEEDINGS
 
Other Proceedings
The companiesCompanies are parties to various lawsuits and regulatory proceedings in the ordinary course of their respective businesses.  For information regarding material lawsuits and proceedings, see Notes 2, 7,6, 15 and 16 and 17 to the consolidated financial statements.  Such descriptions are incorporated herein by reference.
 
ITEM 4.  SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
None.(REMOVED AND RESERVED)
 
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PART II
 
ITEM 5.  MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
 
GREAT PLAINS ENERGY
Great Plains EnergyEnergy’s common stock is listed on the New York Stock Exchange under the symbol GXP.“GXP”.  At February 23, 2010,22, 2011, Great Plains Energy’s common stock was held by 23,27322,047 shareholders of record.  Information relating to market prices and cash dividends on Great Plains Energy's common stock is set forth in the following table.
                 
                                
Common Stock Price Range (a)
 Common Stock
Common Stock Price Range (a)
 Common Stock
2009 2008 Dividends Declared2010 2009 Dividends Declared
QuarterHigh Low High Low 20102009 2008 HighLow HighLow 20112010 2009
First$20.34 $11.17 $28.85 $24.35 $0.2075 (b)$0.2075 $0.415 $19.60 $17.43  $20.34 $11.17  $0.2075(b)$0.2075  $0.2075 
Second 15.91  13.44  26.76  24.67      0.2075  0.415  19.63  16.85  15.91  13.44     0.2075   0.2075 
Third 18.17  14.81  26.20  21.92      0.2075  0.415  19.06  16.95  18.17  14.81     0.2075   0.2075 
Fourth 20.16  16.93  22.43  17.09      0.2075  0.415  19.63  18.58  20.16  16.93     0.2075   0.2075 
(a) Based on closing stock prices.
(a) Based on closing stock prices.
 
(a) Based on closing stock prices.
(b) Declared February 9, 2010, and payable March 19, 2010, to shareholders of record as of February 26, 2010.
 
(b) Declared February 8, 2011, and payable March 21, 2011, to shareholders of record as of February 28, 2011.
(b) Declared February 8, 2011, and payable March 21, 2011, to shareholders of record as of February 28, 2011.

Dividend Restrictions
For information regarding dividend restrictions, see Note 1413 to the consolidated financial statements.
 
Purchases of equity securitiesEquity Securities
The following table provides information regarding purchases by the Company of its equity securities during the fourth quarter of 2009.2010.
 
Issuer Purchases of Equity Securities
Issuer Purchases of Equity SecuritiesIssuer Purchases of Equity Securities
       Maximum Number         Maximum Number 
      Total Number of(or Approximate     Total Number of (or Approximate 
      Shares (or Units)Dollar Value) of     Shares (or Units) Dollar Value) of 
 Total  Purchased asShares (or Units) Total  Purchased as Shares (or Units) 
 Number of AveragePart of Publiclythat May Yet Be Number ofAveragePart of Publicly that May Yet Be 
 Shares Price PaidAnnouncedPurchased Under SharesPrice PaidAnnounced Purchased Under 
 (or Units) per SharePlans orthe Plans or (or Units)per SharePlans or the Plans or 
MonthMonthPurchased (or Unit)ProgramsProgramsMonthPurchased(or Unit)Programs Programs 
October 1 - 31October 1 - 31       7,105 
(1)
  $     16.81             -  N/A October 1 - 31    15,470  (1) $     16.22              -  N/A 
November 1 - 30November 1 - 30               -                -             -  N/A November 1 - 30              -              -              -  N/A 
December 1 - 31December 1 - 31               -                -             -  N/A December 1 - 31              -              -              -  N/A 
Total       7,105    $     16.81             -  N/A 
Total Total    15,470  $     16.22              -  N/A 
(1)Represents 5,451 restricted common shares surrendered to the Company following the resignation of a certainRepresents restricted common shares surrendered to the Company following the resignation of a certain officer.
officer and 1,654 common shares surrendered to the Company by an officer to pay taxes related to the vesting
of restricted common stock.

KCP&L
KCP&L is a wholly owned subsidiary of Great Plains Energy, which holds the one share of issued and outstanding KCP&L common stock.
 
Dividend Restrictions
For information regarding dividend restrictions, see Note 1413 to the consolidated financial statements.
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ITEM 6.  SELECTED FINANCIAL DATA
                     
Year Ended December 3120092008200720062005Year Ended December 3120102009200820072006
Great Plains Energy (a)(dollars in millions except per share amounts)
Great Plains Energy (a)
(dollars in millions except per share amounts)
Operating revenues$1,965 $1,670 $1,293 $1,140 $1,131 Operating revenues$2,256 $1,965 $1,670 $1,293 $1,140 
Income from continuing operations (b)
$152 $120 $121 $137 $143 
Income from continuing operations (b)
$212 $152 $120 $121 $137 
Net income attributable to Great Plains Energy$150 $155 $159 $128 $162 Net income attributable to Great Plains Energy$212 $150 $155 $159 $128 
Basic earnings per common               Basic earnings per common               
share from continuing operations$1.16 $1.16 $1.41 $1.74 $1.79 
share from continuing operations$1.55 $1.16 $1.16 $1.41 $1.74 
Basic earnings per common share$1.15 $1.51 $1.86 $1.62 $2.15 Basic earnings per common share$1.55 $1.15 $1.51 $1.86 $1.62 
Diluted earnings per common               Diluted earnings per common               
share from continuing operations$1.15 $1.16 $1.40 $1.73 $1.79 
share from continuing operations$1.53 $1.15 $1.16 $1.40 $1.73 
Diluted earnings per common share$1.14 $1.51 $1.85 $1.61 $2.15 Diluted earnings per common share$1.53 $1.14 $1.51 $1.85 $1.61 
Total assets at year end$8,483 $7,869 $4,832 $4,359 $3,842 Total assets at year end$8,818 $8,483 $7,869 $4,832 $4,359 
Total redeemable preferred stock, mandatorily               Total redeemable preferred stock, mandatorily               
redeemable preferred securities and long-               
term debt (including current maturities)$3,214 $2,627 $1,103 $1,142 $1,143 
redeemable preferred securities and long-               
term debt (including current maturities)$3,428 $3,214 $2,627 $1,103 $1,142 
Cash dividends per common share$0.83 $1.66 $1.66 $1.66 $1.66 Cash dividends per common share$0.83 $0.83 $1.66 $1.66 $1.66 
SEC ratio of earnings to fixed charges 1.81  2.26  2.53  3.50  3.09 SEC ratio of earnings to fixed charges 2.28  1.81  2.26  2.53  3.50 
                               
KCP&L               KCP&L               
Operating revenues$1,318 $1,343 $1,293 $1,140 $1,131 Operating revenues$1,517 $1,318 $1,343 $1,293 $1,140 
Net income$129 $125 $157 $149 $144 Net income$163 $129 $125 $157 $149 
Total assets at year end$5,702 $5,229 $4,292 $3,859 $3,340 Total assets at year end$6,026 $5,702 $5,229 $4,292 $3,859 
Total redeemable preferred stock, mandatorily               Total redeemable preferred stock, mandatorily               
redeemable preferred securities and long-               
term debt (including current maturities)$1,780 $1,377 $1,003 $977 $976 
redeemable preferred securities and long-               
term debt (including current maturities)$1,780 $1,780 $1,377 $1,003 $977 
SEC ratio of earnings to fixed charges 2.44  2.87  3.53  4.11  3.87 SEC ratio of earnings to fixed charges 2.86  2.44  2.87  3.53  4.11 
                               
(a)Great Plains Energy's results include GMO only from the July 14, 2008, acquisition date.
(b)This amount is before income (loss) from discontinued operations, net of income taxes, of $(1.5) million, $35.0 million,
$38.3 million and $(9.1) million in 2009 through 2006, respectively.
(a)  
Great Plains Energy’s results include GMO only from the July 14, 2008, acquisition date.
(b)  
This amount is before income (loss) from discontinued operations, net of income taxes, of $(1.5) million, $35.0 million, $38.3 million, $(9.1) million and $27.2 million in 2009 through 2005, respectively.  Additionally, the 2005 amount has been adjusted from the amount previously reported to reflect the adoption of a new accounting standard for noncontrolling interest.
 
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ITEM 7.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
 
GREAT PLAINS ENERGY INCORPORATED
 
EXECUTIVE SUMMARY
 
Description of Business
Great Plains Energy 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 direct subsidiaries with operations or active subsidiaries are KCP&L GMO, KLT Inc. and Services.GMO.  Great Plains Energy acquired GMO on July 14, 2008.  Great Plains Energy’s sole reportable business segment is electric utility for the periods presented.
 
Electric utility consists of KCP&L, a regulated utility, and GMO’s regulated utility operations, which include its Missouri Public Service and St. Joseph Light & Power divisions.  Electric utility has over 6,0006,600 MWs of generating capacity and engages in the generation, transmission, distribution and sale of electricity to over 820,000approximately 823,200 customers in the states of Missouri and Kansas.  Electric utility’s retail electricity rates are below the national average of investor-owned utilities.
 
20092010 Earnings Overview
Great Plains Energy’s 20092010 earnings available for common shareholders wereincreased to $210.1 million or $1.53 per share from $148.5 million or $1.14 per share compared to 2008 earnings available for common shareholders of $152.9 million, or $1.51 per share.  A higher number of common shares outstanding diluted 2009 earnings per share by $0.33.  Income from continuing operations increased to $151.9 million in 2009 compared to $119.7 million in 2008.  Theprimarily driven by an increase in income from continuing operations is attributablegross margin due to the inclusion of GMO for the full year, new retail rates decreased purchased power prices, anand favorable weather.  Gross margin is a financial measure that is not calculated in accordance with Generally Accepted Accounting Principles (GAAP).  See the explanation of gross margin and the reconciliation to GAAP operating revenues under Great Plains Energy’s Results of Operations for further information.
Partially offsetting the increase in gross margin was higher operations and maintenance expense driven by planned plant outages, increased depreciation and amortization expense due to additional regulatory amortization pursuant to KCP&L’s 2009 rate cases and depreciation from placing in service the Iatan No. 1 environmental equipment in 2009 and Iatan No. 2 in 2010 (Kansas jurisdiction only), increased general taxes and a decrease in the equity component of AFUDCAFUDC.  Great Plains Energy also recorded a $16.8 million pre-tax loss in 2010 representing KCP&L’s and decreased income taxes.  These increases were partially offset by unfavorable weather, a decline in weather-normalized customer usage driven by weakened economic conditions, a decrease in wholesale sales prices, increased depreciation expense due to placingGMO’s combined share of the impact of disallowed construction costs for the Iatan No. 1 environmental equipment in service and increased interest expensethe Iatan No. 2 construction project.
Additionally, 2009 reflects a $16.0 million tax benefit due to the issuancesettlement of new long-term debt in 2009.GMO’s 2003-2004 tax audit.
 
Strategic FocusKCP&L’s Comprehensive Energy Plan
Great Plains Energy is focused on completing and pursuing appropriate regulatory treatment of its investments under theKCP&L’s Comprehensive Energy Plan and development of the next strategic plan, called the Sustainable Resource Strategy.  These items, amoung others, are described in more detail as follows:
·  Comprehensive Energy Plan
In 2004, KCP&L started a strategic planning process to map its view of the future of the electric utility industry and KCP&L over the next five to ten years.  The collaborative process involved employees, community and environmental leaders and outside experts, and resulted in the Comprehensive Energy Plan.  The major elements of the Comprehensive Energy Plan included construction of Iatan No. 2, wind generation, environmental upgrades at certain coal-fired generating stations, infrastructure investments, and energy efficiency, affordability and demand response programs.  See Note 7 to the consolidated financial statements for additional information.
·  Sustainable Resource Strategy
With Iatan No. 2, scheduledwind generation, environmental upgrades at certain coal-fired generating stations, infrastructure investments, and energy efficiency, affordability and demand response programs.  With the construction of Iatan No. 2 completed in 2010, the remaining component of KCP&L’s Comprehensive Energy Plan is to be placedobtain state regulatory approval to include the cost of Iatan No. 2 in rate base and begin recovering the investment in rates.
In August 2010, Iatan No. 2 successfully completed in-service testing, which was confirmed by KCC in October 2010, but is still subject to confirmation by the fallMPSC, which is expected during the current Missouri rate cases.
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In the fourth quarter of 2010, Great Plains Energy has begunand KCP&L completed a final cost estimate for Iatan No. 2.  The final cost estimate and previous cost estimate ranges are shown in the next iterationfollowing table.  The cost estimate ranges do not include AFUDC or the cost of common facilities that were identified at the time of the start-up of the Iatan No. 1 environmental project that will be used by both Iatan No. 1 and Iatan No. 2.
             
  Final Cost Previous Estimate  
  Estimate Range Range Change
  (millions)
Great Plains Energy's 73% share of Iatan No. 2  $ 1,203 - $ 1,218  $ 1,222 - $ 1,251  $   (19) - $   (33)
KCP&L's 55% share of Iatan No. 2        905 -       917        919 -       941       (14) -      (24)
             
Kansas Regulatory Proceedings
In December 2009, KCP&L filed a request with KCC to increase retail electric annual revenues by $55.2 million.  The request was subsequently adjusted by KCP&L during the rate case proceedings to $50.9 million as the net result of updates to the case.  The request included costs related to Iatan No. 2, a new coal-fired generation unit, upgrades to the transmission and distribution system to improve reliability and overall increased costs of service.
In November 2010, KCC issued its collaborative strategic planning processorder, effective December 1, 2010, authorizing an increase in annual revenues of $21.8 million, a return on equity of 10.0%, an equity ratio of approximately 49.7% and a Kansas jurisdictional rate base of $1.781 billion.  The annual revenue increase was subsequently adjusted by KCC in a January 2011 reconsideration order to develop a successor strategy, called$22.0 million.  In February 2011, KCC issued an order granting KCP&L and another party to the Sustainable Resource Strategy.case their respective petitions for reconsideration regarding rate case expenses.  The Sustainable Resource Strategy$22.0 million annual revenue increase is a scenario-based frameworkconsidered as interim subject to develop, evaluaterefund or true-up pending the outcome of the reconsideration proceedings regarding rate case expenses.  Also in February 2011, KCP&L and implement robust long-term resource plansanother party to the case filed petitions for judicial review with the flexibility to adapt to future environmental requirements, electricity consumption, technology developments, customer preferences, economic and capital market conditions and other factors.Court of Appeals of the State of Kansas, which are stayed until conclusion of the reconsideration proceedings.  The Sustainable Resource Strategy frameworkrates authorized by KCC will be effective unless and until modified by KCC or stayed by a court.
Accounting rules state that when it becomes probable that part of the cost of a recently completed plant will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made, the estimated amount of the probable disallowance shall be deducted from the reported cost of the plant and recognized as a loss.  As a result of disallowances in the KCC order, KCP&L recognized Kansas jurisdictional losses of $4.4 million for construction costs related to Iatan No. 2 and $2.0 million for construction costs related to the Iatan No. 1 environmental project.  Management determined it is probable that the MPSC would disallow these costs as well in KCP&L’s and GMO’s pending rate cases.  Therefore, KCP&L’s Missouri jurisdictional portion and GMO’s portion of these costs were recognized as a loss in addition to the KCP&L Kansas jurisdictional portion resulting in a $16.8 million pre-tax loss representing KCP&L’s and GMO’s combined share for construction costs incurred through December 31, 2010.
27
·  SmartGrid
Missouri Regulatory Proceedings
In 2010, KCP&L will begin a five-year, $48 million SmartGrid demonstration project that includes, but is not limited to, investment in an urban core area within Kansas City that has been designated as the Green Impact Zone.  This SmartGrid demonstration project will include investments in technology including rooftop solar applications, consumer devices for monitoring and managing residential energy usage and automated meter devices that deliver real-time usage information and pricing signals.  The U.S. Department of Energy (DOE) will fund half of the project with American Recovery and Reinvestment Act funding, with the remainder of the investments being funded by KCP&L and a coalition of SmartGrid industry partners.  KCP&L expects to finalize the agreement with the DOE in the near future, which is expected to detail reporting requirements of the project and terms required to satisfy the conditions of the grant.
·  Transmission Investment Opportunities
An increasing need for new transmission assets to deliver new renewable generation, reduce congestion and improve transmission reliability is being coordinated in the companies’ region through the SPP.  This is expected to result in investment opportunities for the companies to build, own and operate new transmission assets with a resulting return on these investments.  The timing and scale of these opportunities are unknown at this time.
·  Regulatory Proceedings
The following table summarizes all recentpending requests for retail rate increases with KCCthe MPSC.
           
   Annual       
   Revenue Return on Rate-Making 
Rate JurisdictionFile DateIncrease Equity Equity Ratio 
   (millions)       
KCP&L - Missouri (a)
6/4/2010$92.1  (b) 11.00 %  (b) 46.16 %  (b)
GMO - Missouri Public Service division (a)
6/4/2010 75.8  (c) 11.00 %  (c) 46.16 %  (c)
GMO - St. Joseph Light & Power division (a)
6/4/2010 22.1  (d) 11.00 %  (d) 46.16 %  (d)
              
(a)The request includes costs related to Iatan No. 2, a new coal-fired generation unit, upgrades to the transmission
 and distribution system to improve reliability and overall increased costs of service.  For KCP&L, it also includes
 increased coal transportation costs due to the expiration in 2010 of the majority of KCP&L's current coal
 transportation contracts.  Any authorized changes to retail rates are expected to be effective in May 2011 for
 KCP&L and June 2011 for GMO.
(b)The requested increase was adjusted by KCP&L in a February 22, 2011, filing with the MPSC to $55.8 million
 mainly due to lower fuel and purchased power costs, as there is no fuel recovery mechanism, and increased
 deferred income taxes from bonus depreciation.  The lower fuel and purchased power costs were driven by more
 favorable coal transportation costs and lower actual 2010 fuel and purchased power costs than the amounts
 included in the June 4, 2010, initial request.  The requested return on equity was adjusted by KCP&L to 10.75%
 and the rate-making equity ratio was adjusted to 46.286%.
(c)The requested increase was adjusted by GMO in a February 22, 2011, filing with the MPSC to $65.2 million as
 the net result of updates to the case.  The requested return on equity was adjusted by GMO to 10.75% and the
 rate-making equity ratio was adjusted to 46.286%.
(d)The requested increase was adjusted by GMO in a February 22, 2011, filing with the MPSC to $23.2 million as
 the net result of updates to the case.  The requested return on equity was adjusted by GMO to 10.75% and the
 rate-making equity ratio was adjusted to 46.286%.

In September 2010, GMO received an order from the MPSC approving construction accounting for the Iatan No. 2 project from the Iatan No. 2 in-service date to the effective date of new rates in the current rate case.  The effect of the order is to defer GMO’s share of Iatan No. 2 operating costs, depreciation expense and carrying costs (interest) offset by Iatan No. 2’s system energy value to a regulatory asset rather than impacting the income statement until new rates are effective.  KCP&L (Missouri jurisdiction only) was granted construction accounting as part of the Comprehensive Energy Plan.
In November 2010, the MPSC staff filed its construction audit and prudence review regarding construction expenditures through June 30, 2010, for Iatan No. 2 and the MPSC.Iatan No. 1 environmental project.  The MPSC staff recommended disallowances of approximately $130 million and $70 million of the total costs incurred through June 30, 2010, for Iatan No. 2 and the Iatan No. 1 environmental project, respectively, representing all audited expenditures above the associated December 2006 control budget estimates of approximately $1.685 billion and $377 million.
 
    Effective Amount Amount 
Rate JurisdictionFile Date Date Requested Approved 
      (millions)
KCP&L - Kansas (a)
9/5/2008 8/1/2009  $        71.6  $      59.0 
KCP&L - Missouri (b)
9/5/2008 9/1/2009          101.5          95.0 
GMO - Missouri Public Service division (c)
9/5/2008 9/1/2009            66.0          48.0 
GMO - St. Joseph Light & Power division (c)
9/5/2008 9/1/2009            17.1          15.0 
GMO - steam customers in the St. Joseph, Missouri, area (d)
9/5/2008 7/1/2009              1.3            1.0 
KCP&L - Kansas (e)
12/17/2009     (e)            55.2            (e) 
 
(a)$18 million of the amount approved is treated for accounting purposes as additional amortization.  Parties may challenge the
 prudence of the Iatan Unit No. 1 environmental project and the costs of facilities used in common by Iatan Units No. 1 and No.
 2 in KCP&L’s next rate case, but the Kansas jurisdictional portion of any proposed rate base prudence disallowances will not
 exceed (i) $4.7 million for costs paid or approved for payment as of April 30, 2009, and in-service as of July 4, 2009, and (ii)
 $2.8 million for the first $56 million of costs not paid or approved for payment as of April 30, 2009.  There is no cap as to the
 amount of disallowances that may be proposed for costs above this $56 million amount.
(b)$10 million of the amount approved is treated for accounting purposes as additional amortization.  Parties may challenge the
 prudence of the Iatan Unit No. 1 environmental project and the cost of facilities used in common by Iatan Units No. 1 and No. 2
 in KCP&L’s next rate case, but the Missouri jurisdictional portion of any proposed rate base prudence disallowances will not
 exceed $30 million in aggregate.
(c)Parties may challenge the prudence of the cost of the Iatan Unit No. 1 environmental project and the cost of facilities used in
 common by Iatan Units No. 1 and No. 2 in GMO’s next rate case, but the GMO portion of any proposed rate base prudence
 disallowances will not exceed $15 million in aggregate.
(d)The order allows for the Quarterly Cost Adjustment (QCA) fuel sharing mechanism to be established at 85% above the fuel
 cost included in base rates.  The previous sharing mechanism was set at 80% above the fuel cost included in base rates.
(e)The request includes costs related to Iatan No. 2, a new coal-fired generation unit, upgrades to the transmission and
 distribution system to improve reliability and overall increased costs of service.  KCP&L requested a return on equity of
 11.25% based upon a capital structure of 46.17% equity.  Any authorized changes to retail rates are expected to be effective
 in the fourth quarter of 2010.
The MPSC staff also filed testimony in KCP&L’s and GMO’s rate cases in November 2010.  The MPSC staff’s testimony recommended a return on equity range of 8.5% to 9.5% and revenue increase/(decrease) ranges of approximately $(0.2) million to $14 million for KCP&L, approximately $0.9 million to $10.1 million for GMO’s Missouri Public Service division, and approximately $28.8 million to $32.6 million for GMO’s St. Joseph Light & Power division.  On February 22, 2011, the MPSC Staff filed updated testimony recommending the same return on equity range of 8.5% to 9.5% and revenue increase ranges of approximately $2.2 million to $17.0 million for KCP&L, approximately $29,000 to $9.2 million for GMO’s Missouri Public Service division, and approximately $14.9 million to $18.4 million for GMO’s St. Joseph Light & Power division.  The revenue recommendations reflect the MPSC staff’s proposed construction cost disallowances of all audited expenditures
 
28
 
as of October 31, 2010, above the control budget estimates, among other differences from KCP&L’s and GMO’s requests.
Hearings were held beginning in late January 2011 for KCP&L and ran through mid-February 2011 for GMO.  The MPSC Staff will file reconciliations of the differences between its February 22, 2011, recommendations and KCP&L’s and GMO’s February 22, 2011, recommendations with hearings scheduled for March 3 – 4, 2011.  New rates are expected to go into effect in May 2011 for KCP&L and June 2011 for GMO.
Transmission Investment Opportunities
In September 2010, GMO accepted a Notification to Construct from SPP for the Missouri portion of a 175-mile, 345kV transmission line in GMO’s service territory from Sibley, Missouri to Nebraska City, Nebraska.  Construction of the line is expected to occur over 2012 to 2017, with an estimated cost of about $380 million for GMO’s portion of the line.  This line is one of a number of priority projects that the SPP has developed as part of its transmission expansion plans for the region.  In June 2010, FERC approved the SPP’s proposed cost allocation method for these projects.  KCP&L has also accepted a Notification to Construct from SPP for a 30-mile, 345kV transmission line, with estimated construction costs of $54 million and an expected 2015 in-service date, from KCP&L’s Iatan generating station to KCP&L’s Nashua substation.  GMO and KCP&L have the obligation to build their separate lines, which may be done solely or with other entities, unless the obligation is transferred to another qualified transmission owner.  GMO and KCP&L have not determined which of these alternative courses of action to pursue.  SPP retains the authority to revise or withdraw existing Notifications to Construct for transmission projects based upon emerging transmission plans and the associated needs for specific projects.
RELATED PARTY TRANSACTIONS
 
See Note 1918 to the consolidated financial statements for information regarding related party transactions.
 
ENVIRONMENTAL MATTERS
 
See Note 1615 to the consolidated financial statements for information regarding environmental matters.
 
CRITICAL ACCOUNTING POLICIES
 
The preparation of financial statements in conformity with Generally Accepted Accounting Principles (GAAP)GAAP requires management to make estimates and assumptions that affect reported amounts and related disclosures.  Management considers an accounting estimate to be critical if it requires assumptions to be made that were uncertain at the time the estimate was made and changes in the estimate or different estimates that could have been used could have a material impact on Great Plains Energy’s results of operations and financial position.  Management has identified the following accounting policies as critical to the understanding of Great Plains Energy’s results of operations and financial position.  Management has discussed the development and selection of these critical accounting policies with the Audit Committee of the Great Plains Energy Board of Directors.Directors (Board).
 
Pensions
Great Plains Energy and KCP&L incur significant costs in providing non-contributory defined pension benefits.  The costs are measured using actuarial valuations that are dependent upon numerous factors derived from actual plan experience and assumptions of future plan experience.
 
Pension costs are impacted by actual employee demographics (including age, life expectancies, compensation levels and employment periods), earnings on plan assets, the level of contributions made to the plan, and plan amendments.  In addition, pension costs are also affected by changes in key actuarial assumptions, including anticipated rates of return on plan assets and the discount rates used in determining the projected benefit obligation and pension costs.
 
29
The assumed rate of return on plan assets was developed based on the weighted average of long-term returns forecast for the expected portfolio mix of investments held by the plan.  The assumed discount rate was selected based on the prevailing market rate of fixed income debt instruments with maturities matching the expected timing of the benefit obligation.  These assumptions, updated annually at the measurement date, are based on management’s best estimates and judgment; however, material changes may occur if these assumptions differ from actual events.  See Note 109 to the consolidated financial statements for information regarding the assumptions used to determine benefit obligations and net costs.
 
The following table reflects the sensitivities associated with a 0.5% increase or a 0.5% decrease in key actuarial assumptions.  Each sensitivity reflects the impact of the change based on a change in that assumption only.
        
    Impact onImpact on
    Projected2009
 Change inBenefitPension
Actuarial assumptionAssumptionObligationExpense
    (millions)
Discount rate0.5%increase$(47.8)$(3.7)
Rate of return on plan assets0.5%increase -  (2.3)
Discount rate0.5%decrease 50.9  3.7 
Rate of return on plan assets0.5%decrease -  2.3 
          
29
        
    Impact onImpact on
    Projected2010
 Change inBenefitPension
Actuarial assumptionAssumptionObligationExpense
    (millions)
Discount rate0.5%increase$(59.6)$(4.6)
Rate of return on plan assets0.5%increase -  (2.6)
Discount rate0.5%decrease 66.0  5.0 
Rate of return on plan assets0.5%decrease -  2.6 
          
Pension expense for KCP&L is recorded in accordance with rate orders from the MPSC and KCC.  The orders allow the difference between pension costs under GAAP and pension costs for ratemaking to be recorded as a regulatory asset or liability with future ratemaking recovery or refunds, as appropriate.  KCP&L recorded 20092010 pension expense of $33$40 million after allocations to the other joint owners of generating facilities and capitalized amounts in accordance with the MPSC and KCC rate orders.
 
GMO records pension expense in accordance with rate orders from the MPSC.  The difference between this expense and GAAP expense is recorded as a regulatory asset or liability.  See Note 109 to the consolidated financial statements for additional discussion of the accounting for pensions.
The Company's 2011 projected weighted average long-term rate of return on plan assets is 7.3%, a 0.7% decrease from 2010.  The reduction in the rate of return is expected to increase 2011 GAAP pension expense approximately $4 million.
 
Market conditions and interest rates significantly affect the future assets and liabilities of the plan.  It is difficult to predict future pension costs, changes in pension liability and cash funding requirements due to volatile market conditions.
 
Regulatory Matters
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 under GAAP.  Regulatory assets represent incurred costs that are probable of recovery from future revenues.  Regulatory liabilities represent: amounts imposed by rate actions of electric utility’s regulators that may requirerepresent future reductions in revenues or refunds to customers; amounts provided in current rates that are intended to recover costs that are expected to be incurred in the future for which electric utility remains accountable; or a gain or other reduction of allowable costs to be given to customers over future periods.  Future recovery of regulatory assets is not assured, but is generally subject to review by regulators in rate proceedings for matters such as prudence and reasonableness.  Future reductions in revenue or refunds for regulatory liabilities generally are not mandated, pending future rate proceedings or actions by the regulators.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 onin electric utility’s rate case filings; decisions in other regulatory proceedings, including decisions related to other companies that establish precedent on matters applicable to electric utility; 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.  Electric utility’s continued ability to meet the criteria for recording regulatory assets and liabilities may be affected in the future by restructuring and
30
deregulation in the electric industry.industry or changes in accounting rules.  In the event that the criteria no longer applied to all or a deregulated portion of electric utility’s operations, the related regulatory assets and liabilities would be written off unless an appropriate regulatory recovery mechanism is provided.  Additionally, these factors could result in an impairment on utility plant assets.  See Note 76 to the consolidated financial statements for additional information.
 
Impairments of Assets, Intangible Assets and Goodwill
Long-lived assets and intangible assets subject to amortization are required to be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable as prescribed under GAAP.
 
Goodwill isAccounting rules require goodwill to be tested for impairment at least annually and more frequently when indicators ofan event occurs indicating the possibility that an impairment exist as prescribed under GAAP which requires that ifexists.  The goodwill impairment test is a two step process.  The first step compares the fair value of a reporting unit is less thanto its carrying valueamount, including goodwill, to identify potential impairment.  If the impliedcarrying 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, must bewhich is compared with itsto the carrying valueamount of goodwill to determine the amount of impairment which is requiredloss, if any, to be recognized in the current period results of operations.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.
 
Great Plains Energy’s stock traded at a price below carrying value throughout 2009.2010.  If the stock price were to decline substantially further from its current level in relation to carrying value, accounting rules may require Great Plains Energy’s stock continuesEnergy to trade at a price below carrying value, there can beconduct additional goodwill impairment tests.  There is no assurance future market volatility with
30
declinesthat the results of extended duration and severitythese additional tests will not trigger impairment testing, which could result inrequire Great Plains Energy to recognize an impairment of goodwill prospectively.goodwill.
 
The annual impairment test for the $169.0 million of GMO acquisition goodwill was conducted inon September 2009.1, 2010.  Fair value of the reporting unit exceeded the carrying amount by over $900$700 million, including goodwill; therefore, there was no impairment of goodwill.
 
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 and net utility asset values and market prices of stock of electric and gas company regulated peers.  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, which involves a significant amount of management judgment.
 
The discounted cash flow analysis is most significantly impacted by two assumptions: estimated future cash flows and the discount rate applied to those cash flows.  Management determined the appropriate discount rate to be based on the reporting unit’s weighted average cost of capital (WACC).  The WACC takes into account both the cost of equity and after-tax cost of debt.  Estimated future cash flows are based on Great Plains Energy’s internal business plan, which assumes the occurrence of certain events in the future, such as the outcome of future rate filings, future approved rates of return on equity, anticipated earnings/returns related to future capital investments, continued recovery of cost of service and the renewal of certain contracts.  Management also makes assumptions regarding the run rate of operation,operations, maintenance and general and administrative costs based on the expected outcome of the aforementioned events.  Should the actual outcome of some or all of these assumptions differ significantly from the current assumptions, revisions to current cash flow assumptions could cause the fair value of Great Plains Energy’s reporting unit under the income approach to be significantly different in future periods and could result in a future impairment charge to goodwill.
 
The market approach analysis is most significantly impacted by management’s selection of relevant electric and gas company regulated peers as well as the determination of an appropriate control premium to be added to the calculated invested capital of the reporting unit, as control premiums associated with a controlling interest are not reflected in the quoted market price of a single share of stock.  Management determined an appropriate control
31
premium by using an average of control premiums for recent acquisitions in the industry.  Changes in results of peer companies, selection of different peer companies and future acquisitions with significantly different control premiums could result in a significantly different fair value of Great Plains Energy’s reporting unit.
 
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 investment tax credits are amortized ratably over the life of the related property.  Deferred tax assets are also recorded for net operating loss, capital loss and tax credit carryforwards.  The Company is required to estimate the amount of taxes payable or refundable for the current year and the deferred tax liabilities and assets for future tax consequences of events reflected in the Company’s consolidated financial statements or tax returns.  This process requires management to make assessments regarding the timing and probability of the ultimate tax impact.  The Company records valuation allowances on deferred tax assets if it is determined that it is more likely than not that the asset will not be realized.

Additionally, the Company establishes reserves for uncertain tax positions based upon management’s judgment regarding potential future challenges to those positions.  The accounting estimates related to the liability for uncertain tax positions require management to make judgments regarding the sustainability of each uncertain tax position based on its technical merits.  If it is determined that it is more likely than not a tax position will be sustained based on its technical merits, the impact of the position is recorded in the Company’s consolidated
31
financial statements at the largest amount that is greater than fifty percent likely of being realized upon ultimate settlement.  These estimates are updated at each reporting date based on the facts, circumstances and information available.  Management is also required to assess at each reporting date whether it is reasonably possible that any significant increases or decreases to the unrecognized tax benefits will occur during the next twelve months.  See Note 2221 to the consolidated financial statements for additional information.
 
32
GREAT PLAINS ENERGY RESULTS OF OPERATIONS
 
The following table summarizes Great Plains Energy’s comparative results of operations.  GMO’s results of operations are only included subsequent to the July 14, 2008, date of acquisition.
            
200920082007201020092008
(millions)(millions)
Operating revenues$1,965.0 $1,670.1 $1,292.7 $2,255.5 $1,965.0 $1,670.1 
Fuel (405.5) (311.4) (245.5) (430.7) (405.5) (311.4)
Purchased power (183.7) (208.9) (101.0) (213.8) (183.7) (208.9)
Transmission of electricity by others (27.4) (26.9) (22.5)
Gross margin (a)
 1,583.6  1,348.9  1,127.3 
Other operating expenses (753.5) (639.8) (523.0) (779.7) (726.6) (617.3)
Skill set realignment deferral -  -  8.9 
Depreciation and amortization (302.2) (235.0) (175.6) (331.6) (302.2) (235.0)
Operating income 320.1  275.0  256.5  472.3  320.1  275.0 
Non-operating income and expenses 42.6  21.1  3.2  24.4  42.6  21.1 
Interest charges (180.9) (111.3) (91.9) (184.8) (180.9) (111.3)
Income tax expense (29.5) (63.8) (44.9) (99.0) (29.5) (63.8)
Loss from equity investments (0.4) (1.3) (2.0) (1.0) (0.4) (1.3)
Income from continuing operations 151.9  119.7  120.9  211.9  151.9  119.7 
Income (loss) from discontinued operations (1.5) 35.0  38.3  -  (1.5) 35.0 
Net income 150.4  154.7  159.2  211.9  150.4  154.7 
Less: Net income attributable to noncontrolling interest (0.3) (0.2) -  (0.2) (0.3) (0.2)
Net income attributable to Great Plains Energy 150.1  154.5  159.2  211.7  150.1  154.5 
Preferred dividends (1.6) (1.6) (1.6) (1.6) (1.6) (1.6)
Earnings available for common shareholders$148.5 $152.9 $157.6 $210.1 $148.5 $152.9 
(a) Gross margin is a non-GAAP financial measure. See explanation of gross margin below.
(a) Gross margin is a non-GAAP financial measure. See explanation of gross margin below.
                  
2010 compared to 2009
Great Plains Energy’s 2010 earnings available for common shareholders increased to $210.1 million, or $1.53 per share, from $148.5 million, or $1.14 per share in 2009.
Electric utility’s net income increased $77.5 million in 2010 compared to 2009 primarily driven by an increase in gross margin due to new retail rates and favorable weather.  Partially offsetting the increase in gross margin were higher operations and maintenance expenses driven by planned plant outages, increased depreciation and amortization expense due to additional regulatory amortization pursuant to KCP&L’s 2009 rate cases and depreciation from placing in service the Iatan No. 1 environmental equipment during 2009 and Iatan No. 2 during 2010 (Kansas jurisdiction only), increased general taxes and a decrease in the equity component of AFUDC.  Electric utility also recorded a $16.8 million pre-tax loss in 2010 representing KCP&L’s and GMO’s combined share of the impact of disallowed construction costs for the Iatan No. 1 environmental equipment and the Iatan No. 2 construction project.
Great Plains Energy’s corporate and other activities had an additional $17.4 million loss from continuing operations in 2010 compared to 2009 primarily due to $7.1 million of after-tax write downs of affordable housing investments and an additional $6.8 million of after-tax interest expense for Equity Units issued in 2009.  Additionally, 2009 reflects a $16.0 million tax benefit due to the settlement of GMO’s 2003-2004 tax audit.  Partially offsetting these items was the recognition of $3.9 million of deferred tax credits upon the sale of GMO’s former headquarters and $2.4 million of after-tax interest income, net of fees, from an interest refund from the IRS in 2010.
33
2009 compared to 2008
Great Plains Energy’s 2009 earnings available for common shareholders decreased to $148.5 million, or $1.14 per share, from $152.9 million, or $1.51 per share in 2008.  A higher number of common shares outstanding diluted 2009 earnings per share by $0.33.  Great Plains Energy’s significant share issuances were 32.2 million common shares for the acquisition of GMO in July 2008 and 11.5 million common shares in May 2009.
 
Electric utility’s net income increased $14.7 million in 2009 compared to 2008 reflecting the inclusion of GMO for the full year in 2009.  Additionally, the impact ofan increase in gross margin reflecting new retail rates decreased purchased power prices,effective August 1, 2009, and September 1, 2009, for Kansas and Missouri, respectively, an increase in the equity component of AFUDC and decreased income taxes also increased electric utility���s net income.  ThesePartially offsetting these increases were mostly offset by unfavorable weather, a decline in customer usage driven by weakened economic conditions, a decrease in wholesale sale prices,was increased depreciation expense due to placing the Iatan environmental equipment in service and increased interest expense due to the issuance of new long-term debt in 2009.
 
Great Plains Energy’s corporate and other activities loss from continuing operations decreased $17.4 million in 2009 compared to 2008 primarily attributable to a $16.0 million tax benefit due to the settlement of GMO’s 2003-2004 tax audit in 2009 partially offset by $11.4 million of after-tax interest expense for Equity Units issued in 2009.  Additionally, 2008 reflects a $5.7 million after-tax loss for the change in fair value of interest rate hedges.
32Gross Margin
2008 compared to 2007
Gross margin is a financial measure that is not calculated in accordance with GAAP.  Gross margin, as used by Great Plains Energy’s 2008 earnings availableEnergy and KCP&L, is defined as operating revenues less fuel, purchased power and transmission of electricity by others.  Expenses for common shareholders decreasedfuel, purchased power and transmission of electricity by others, offset by wholesale sales margin, are subject to $152.9 million,recovery through cost adjustment mechanisms, except for KCP&L’s Missouri retail operations.  As a result, operating revenues increase or $1.51 per share,decrease in relation to a significant portion of these expenses.  Management believes that gross margin provides a more meaningful basis for evaluating electric utility’s operations across periods than operating revenues because gross margin excludes the revenue effect of fluctuations in these expenses.  Gross margin is used internally to measure performance against budget and in reports for management and the Board.  The Companies’ definition of gross margin may differ from $157.6 million, or $1.85 per share in 2007.  A higher number of common shares outstanding, primarily due to the issuance of 32.2 million shares for the acquisition of GMO, diluted 2008 earnings per sharesimilar terms used by $0.28.other companies.
 
Electric utility’s net income decreased $13.7 million in 2008 compared to 2007.  This decrease was primarily due to mild summer weather, a decrease in wholesale sales, higher fuel costs, higher purchased power prices and planned and unplanned plant outages which led to increased operating expenses at KCP&L.  Also, in 2007, KCP&L received authorization from the MPSC and KCC to defer $8.9 million of skill set realignment costs incurred in 2006 resulting in lower expenses in 2007.  Partially offsetting these decreases were increased retail revenues primarily due to new retail rates at KCP&L effective January 1, 2008 and an increase in AFUDC at KCP&L.  The acquisition of GMO increased electric utility’s net income $17.9 million.
Great Plains Energy’s corporate and other activities loss from continuing operations decreased $12.3 million in 2008 compared to 2007, primarily due to $3.4 million of after-tax income related to the release of a legal reserve in 2008, the reversal of $3.6 million of after-tax interest expense related to unrecognized tax benefits in 2008, a $3.8 million after-tax favorable impact from the deferral in 2008 of merger transition costs incurred in 2007 to a regulatory asset and a $4.6 million after-tax change in the fair value of Forward Starting Swaps (FSS).  The acquisition of GMO increased Great Plains Energy’s corporate and other activities loss $5.4 million.
ELECTRIC UTILITY RESULTS OF OPERATIONS
 
The following table summarizes the electric utility segment results of operations.
            
200920082007201020092008
(millions)(millions)
Operating revenues$1,965.0 $1,670.1 $1,292.7 $2,255.5 $1,965.0 $1,670.1 
Fuel (405.5) (311.4) (245.5) (430.7) (405.5) (311.4)
Purchased power (183.7) (209.9) (101.0) (213.8) (183.7) (209.9)
Transmission of electricity by others (27.4) (26.9) (22.5)
Gross margin (a)
 1,583.6  1,348.9  1,126.3 
Other operating expenses (738.9) (624.2) (500.4) (773.4) (712.0) (601.7)
Skill set realignment deferral -  -  8.9 
Depreciation and amortization (302.2) (235.0) (175.6) (331.6) (302.2) (235.0)
Operating income 334.7  289.6  279.1  478.6  334.7  289.6 
Non-operating income and expenses 37.7  21.3  4.2  23.1  37.7  21.3 
Interest charges (151.0) (96.9) (67.2) (143.1) (151.0) (96.9)
Income tax expense (63.6) (70.9) (59.3) (123.3) (63.6) (70.9)
Net income$157.8 $143.1 $156.8 $235.3 $157.8 $143.1 
(a) Gross margin is a non-GAAP financial measure. See explanation of gross margin under Great
(a) Gross margin is a non-GAAP financial measure. See explanation of gross margin under Great
Plains Energy's Results of Operations.Plains Energy's Results of Operations.
                  
34
Electric Utility Gross Margin and MWh Sales
The following tables summarize electric utility’s gross margin and MWhs sold.
           
   %  %  
Gross Margin (a)
2010Change2009
Change (b)
2008
Retail revenues(millions)
Residential$915.8  19 $772.6 NM $605.5 
Commercial 838.0  11  752.5 NM  620.7 
Industrial 193.5  13  171.9 NM  142.2 
Other retail revenues 17.5  2  17.2 NM  13.3 
Provision for rate refund (excess              
   Missouri wholesale margin) (3.7)NA  - NM  (2.9)
Fuel recovery mechanism under recovery 42.9  31  32.8 NM  30.7 
Total retail 2,004.0  15  1,747.0 NM  1,409.5 
Wholesale revenues 205.9  18  174.6 NM  230.1 
Other revenues 45.6  5  43.4 NM  30.5 
Operating revenues 2,255.5  15  1,965.0 NM  1,670.1 
Fuel (430.7) 6  (405.5)NM  (311.4)
Purchased power (213.8) 16  (183.7)NM  (209.9)
Transmission of electricity by others (27.4) 2  (26.9)NM  (22.5)
Gross margin$1,583.6  17 $1,348.9 NM $1,126.3 
(a) Gross margin is a non-GAAP financial measure.  See explanation of gross margin under Great Plains
Energy's Results of Operations.
(b) Not meaningful due to the acquisition of GMO on July 14, 2008.
               
 
   %  %  
MWh Sales2010Change2009
Change (a)
2008
Retail MWh sales(thousands)
Residential 9,459  9  8,647  NM  7,047 
Commercial 10,950  3  10,637  NM  9,227 
Industrial 3,286  5  3,143  NM  2,721 
Other retail MWh sales 111  (9) 122  NM  94 
Total retail 23,806  6  22,549  NM  19,089 
Wholesale MWh sales 6,534  16  5,626  NM  5,237 
Total MWh sales 30,340  8  28,175  NM  24,326 
(a) Not meaningful due to the acquisition of GMO on July 14, 2008.
               
Electric utility’s residential customers’ usage is significantly affected by weather.  Bulk power sales, the major component of wholesale sales, vary with system requirements, generating unit and purchased power availability, fuel costs and requirements of other electric systems.  Electric utility’s revenues contain certain fuel recovery mechanisms as follows:
 
·  KCP&L’s Kansas retail rates effective after January 1, 2008, contain an ECA tariff.  The ECA tariff reflects the projected annual amount of fuel, purchased power, emission allowances, transmission costs and asset-based off-system sales margin.  These projected amounts are subject to quarterly re-forecasts.  Any difference between the ECA revenue collected and the actual ECA amounts for a given year (which may be positive or negative) is recorded as an increase to or reduction of retail revenues and deferred as a regulatory asset or liability to be recovered from or refunded to Kansas retail customers over twelve months beginning April 1 of the succeeding year.
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·  GMO’s electric retail rates contain an FAC tariff under which 95% of the difference between actual fuel cost, purchased power costs and off-system sales margin and the amount provided in base rates for these costs is passed along to GMO’s customers.  The FAC cycle consists of an accumulation period of six months beginning in June and December with FAC rate approval requested every six months for a twelve month recovery period.  The FAC is recorded as an increase to or reduction of retail revenues and deferred as a regulatory asset or liability to be recovered from or refunded to GMO’s electric retail customers.
 
·  GMO’s steam rates contain a QCA under which 85% of the difference between actual fuel costs and base fuel costs is passed along to GMO’s steam customers.  The QCA is recorded as an increase to or reduction of other revenues and deferred as a regulatory asset or liability to be recovered from or refunded to GMO’s steam customers.
 
KCP&L’s Missouri retail rates do not contain a fuel recovery mechanism, meaning that changes in fuel and purchased power costs will not be reflected in rates until new rates are authorized by the MPSC creating a regulatory lag between the time costs change and when they are reflected in rates.  This regulatory lag applies to all costs not included in fuel recovery mechanisms as described above.  In the current rising cost environment, regulatory lag can be expected to have an adverse impact, which could be material, on Great Plains Energy’s results of operations.  Additionally, KCP&L’s retail rates in Missouri reflect a set level of non-firm wholesale electric sales margin.  KCP&L will not recover any shortfall in non-firm wholesale electric sales margin from the level included in Missouri retail rates and any amount of margin above the level reflected in Missouri retail rates will be returned to KCP&L Missouri retail customers in a future rate case.
 
Generation fuel mix can substantially changeElectric utility’s gross margin increased $234.7 million in 2010 compared to 2009 primarily due to the fuel cost per MWh generatedincrease in retail revenues driven by new retail rates effective August 1, 2009 and can be significantly impacted by plannedSeptember 1, 2009, for Kansas and unplanned plant outages.  Nuclear fuel cost per MWh generated is substantially less than the cost of coal per MWh generated.  The cost of natural gasMissouri, respectively, and oil per MWh generated is substantially higher than the cost of coal and nuclear fuel per MWh generated.  The cost per MWh for purchased power is generally significantly higher than the cost of coal and nuclear fuel per MWh generated.  Electric utility continually evaluates its system requirements, the availability of generating units, its demand-side management and efficiency programs, availability and cost of fuel supply and purchased power, and the requirements of other electric systems to provide reliable power economically.favorable weather.
 
Management anticipates the cost of nuclear fuel to increase significantlyRetail MWhs sold in 2010 after which increases are expectedincreased due to be moderate.  Evenfavorable weather, with this anticipateda 2% increase management expects nuclear fuel cost per MWh generatedin heating degree days and a 56% increase in cooling degree days.  Cooling degree days were 23% above normal based on a 30-year average.  Wholesale MWhs sold increased due to remain less thana 9% increase in generation resulting in more MWhs available for sale, partially offset by the costhigher retail load requirements.  The increase in generation was primarily a result of generation from other fuel sources.  With Iatan No. 2 scheduledbeing placed in service during 2010 and Iatan No. 1 being off-line from January through mid-April 2009 to be placed in-servicecomplete an environmental upgrade and unit overhaul, with the expenditures being capitalized and therefore not impacting operating and maintenance expenses.  The coal base load equivalent availability factor increased to 82% in the fall of 2010 management expects therecompared to be more lower-cost coal generation in the fuel mix, lower requirements79% for purchased power and more generation available for wholesale sales.  The majority of KCP&L’s and GMO’s rail transportation contracts expire in 2010.  After 2010, rail transportation costs, a substantial component of the cost of coal per MWh generated, are anticipated to be significantly higher.
34
Electric Utility Revenues and MWh Sales
           
   %  %  
 2009
Change (a)
2008
Change (a)
2007
Retail revenues(millions)
Residential$772.6  NM $605.5  NM $433.8 
Commercial 752.5  NM  620.7  NM  492.1 
Industrial 171.9  NM  142.2  NM  106.8 
Other retail revenues 17.2  NM  13.3  NM  9.9 
Provision for rate refund (excess Missouri             
wholesale margin) -  NM  (2.9) NM  (1.1)
Fuel recovery mechanism under recovery 32.8  NM  30.7  NM  - 
Total retail 1,747.0  NM  1,409.5  NM  1,041.5 
Wholesale revenues 174.6  NM  230.1  NM  234.0 
Other revenues 43.4  NM  30.5  NM  17.2 
Total revenues$1,965.0  NM $1,670.1  NM $1,292.7 
              
           
   %  %  
 2009
Change (a)
2008
Change (a)
2007
Retail MWh sales(thousands) 
Residential 8,647  NM  7,047  NM  5,597 
Commercial 10,637  NM  9,227  NM  7,737 
Industrial 3,143  NM  2,721  NM  2,161 
Other retail MWh sales 122  NM  94  NM  92 
Total retail 22,549  NM  19,089  NM  15,587 
Wholesale MWh sales 5,626  NM  5,237  NM  5,635 
Total MWh sales 28,175  NM  24,326  NM  21,222 
              
(a) Not meaningful due to the acquisition of GMO on July 14, 2008.
2009.
 
Retail revenuesElectric utility’s gross margin increased $337.5$222.6 million in 2009 compared to 2008 driven by the inclusion of GMO for a full year and an increase in retail revenues due to new retail rates effective August 1, 2009, and September 1, 2009, for Kansas and Missouri, respectively.  The increasesincrease to retail revenues werewas partially offset by a decline in weather-normalized customer usage driven by weakened economic conditions and unfavorable summer weather in 2009, with a 9% decrease in cooling degree days.  Cooling degree days were 22% below normal based on a 30-year average.
Retail revenues increased $368.0 million in 2008 compared to 2007.  The acquisition of GMO increased retail revenue $306.2 million.  New retail rates, effective January 1, 2008, at KCP&L also increased retail revenue.  These increases were partially offset by mild summer weather in 2008, with a 27% decrease in cooling degree days.
 
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The following table provides cooling degree days (CDD) and heating degree days (HDD) for the last three years at the Kansas City International Airport.  CDD and HDD are used to reflect the demand for energy to cool or heat homes and buildings.
           
 2009
%
 Change
2008
%
 Change
2007
           
CDD 1,090  (9) 1,196  (27) 1,637 
                
HDD 5,069  (9) 5,590  14  4,925 
                
Wholesale revenues decreased $55.5 million in 2009 compared to 2008 primarily due to a 38% decrease in the average market price per MWh to $28.92 at KCP&L, primarily driven by lower natural gas prices.  This decrease was partially offset by a 7% increase in MWh sales at KCP&L as more MWhs were available for wholesale sales due to a 4% decrease in load requirements for retail sales.
Wholesale revenues decreased $3.9 million in 2008 compared to 2007 due to an 11% decrease in wholesale MWh sales resulting from less generation at KCP&L due to plant outages.  This decrease was partially offset by a 9% increase in the average market price per MWh to $46.34, primarily due to higher natural gas prices.  The acquisition of GMO increased wholesale revenues $8.6 million.
Electric Utility Fuel and Purchased Power
           
   %  %  
 2009Change2008Change2007
Net MWhs Generated by Fuel Type(thousands) 
Coal 19,625 
NM(a)
  16,793 
NM(a)
  14,894 
Nuclear 4,121  3  3,994  (18) 4,873 
Natural gas and oil 293 
NM(a)
  486 
NM(a)
  544 
Wind 354  (16) 419  38  305 
Total Generation 24,393 
NM(a)
  21,692 
NM(a)
  20,616 
                
(a) Not meaningful due to the acquisition of GMO on July 14, 2008.
                
KCP&L’s coal base load equivalent availability factor in 2009 increased to 79% from 78% in 2008 and was 80% in 2007.  GMO’s coal base load equivalent availability factor was 79% in 2009 and was 66% in 2008 after the July 14, 2008, date of acquisition.  GMO’s equivalent availability factor was negatively impacted by scheduled plant outages in the last half of 2008.

KCP&L’s nuclear unit, Wolf Creek, accounts for approximately 15% of electric utility’s base load capacity.  Wolf Creek has scheduled refueling outages every 18 months.  The latest refueling outage began on October 10, 2009, and the unit came back on-line November 21, 2009.  Primarily as a result of the refueling outages in fall 2009 and spring 2008, the capacity and equivalent availability factor for Wolf Creek was 86% in 2009 and 83% for 2008, compared to 100% in 2007 when Wolf Creek did not have a refueling outage.
Fuel expense increased $94.1 million in 2009 compared to 2008 driven by the inclusion of GMO for a full year and higher coal costs partially offset by changes in the fuel mix reflecting more nuclear and coal generation, which has a significantly lower cost compared to natural gas generation.
Fuel expense increased $65.9 million in 2008 compared to 2007.  The acquisition of GMO increased fuel expense $58.1 million.  The remaining increase at KCP&L was primarily due to higher coal and coal transportation costs
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and less nuclear in the fuel mix, which has a lower cost compared to other fuel types.  These increases were partially offset by decreased MWhs generated by KCP&L, primarily due to lower system requirements.
Purchased power expense decreased $26.2 million in 2009 compared to 2008 driven by a 43% decrease in the average price per MWh as a result of lower natural gas prices.  Partially offsetting this decrease was $6.9 million in recoveries from a litigation settlement in 2008 and the inclusion of GMO for the full year in 2009.
Purchased power expense increased $108.9 million in 2008 compared to 2007.  The acquisition of GMO increased purchased power expense $90.9 million.  The remaining increase at KCP&L was primarily due to a 26% increase in the average price per MWh as a result of higher natural gas prices.  Additionally, an 8% increase in MWh purchases primarily due to the impact of the Wolf Creek refueling outage increased purchased power expense.  These increases were partially offset by $6.9 million in recoveries from a litigation settlement regarding a 2005 transformer failure.
            
   %  %   
 2010Change2009Change 2008
            
CDD 1,705  56  1,090  (9)  1,196 
                 
HDD 5,160  2  5,069  (9)  5,590 
                 
                 
Electric Utility Other Operating Expenses (including utility operating and maintenance expenses, general taxes and other)
Electric utility’s other operating expenses increased $114.7$61.4 million in 2010 compared to 2009.  Plant operating and maintenance expenses increased $17.8 million in 2010 compared to 2009 primarily driven by planned plant outages, including the impact of outages in 2009 that included capitalizable improvements and therefore did not impact operating and maintenance expenses, partially offset by $7.5 million expensed in September 2009 after KCP&L exercised its option to terminate an agreement for the construction of a wind project.  The accounting effects of the KCC rate order increased other operating expenses $5.4 million in 2010.  General taxes increased $14.8 million in 2010 compared to 2009 driven by increased gross receipts taxes on increased retail revenues and increased property taxes.
Accounting rules state that when it becomes probable that part of the cost of a recently completed plant will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made, the estimated amount of the probable disallowance shall be deducted from the reported cost of the plant and recognized as a loss.  As a result of disallowances in the KCC order, KCP&L recognized Kansas jurisdictional losses of $4.4 million for construction costs related to Iatan No. 2 and $2.0 million for construction costs related to the Iatan No. 1 environmental project.  Management determined it is probable that the MPSC would disallow these costs as well in KCP&L’s and GMO’s pending rate cases.  Therefore, KCP&L’s Missouri jurisdictional portion and GMO’s portion of these costs were recognized as a loss in addition to the KCP&L Kansas jurisdictional portion resulting in a $16.8 million pre-tax loss representing KCP&L’s and GMO’s combined share for construction costs incurred through December 31, 2010.
Electric utility’s other operating expenses increased $110.3 million in 2009 compared to 2008 driven by the inclusion of GMO for a full year,  increased employee-related costs and a $7.5 million payment to terminate an agreement for the construction of a wind project.  These increases were partially offset by increased use of internal labor on capital projects as a result of more efficient operations as well as spending reductions and the impact of realized synergies from the GMO acquisition.
 
Electric utility’s other operating expenses increased $123.8 million in 2008 compared to 2007.  The acquisition of GMO increased other operating expenses $95.9 million.  The remaining increase at KCP&L was primarily due to  increased plant operations and maintenance expenses of $12.2 million due to plant outages, increased employee-related costs of $5.5 million, increased property taxes of $3.0 million due to higher assessments and higher mill levies and increased gross receipts tax expense of $2.1 million due to the increase in revenues.

Electric Utility Skill Set Realignment
In 2007, KCP&L received authorization from the MPSC and KCC to establish $8.9 million in regulatory assets for costs originally expensed in 2006 related to a workforce realignment process and amortize them over five years for the Missouri jurisdictional portion and ten years for the Kansas jurisdictional portion effective with new rates on January 1, 2008.  Amortization of $1.4 million in 2009 and 2008 was recorded to utility operating and maintenance expense on Great Plains Energy’s consolidated income statements.

Electric Utility Depreciation and Amortization
Electric utility’s depreciation and amortization costs increased $29.4 million in 2010 compared to 2009 primarily due to $14.4 million of additional regulatory amortization pursuant to KCP&L’s 2009 rate cases.  The remaining increase was due to placing in service the Iatan No. 1 environmental equipment during 2009 and commencement of depreciation on Iatan No. 2 during 2010 (Kansas jurisdiction only), as well as normal depreciation activity for other capital additions.
Electric utility’s depreciation and amortization costs increased $67.2 million in 2009 compared to 2008 driven by the inclusion of GMO for a full year, $10.8 million of additional regulatory amortization at KCP&L pursuant to KCP&L’s 2009 rate case orders,cases, the impact of placing Iatan No. 1 and Sibley No. 3 environmental equipment in service during 2009 and normal depreciation activity for capital additions.
Electric utility’s depreciation and amortization costs increased $59.4 million in 2008 compared to 2007.  The acquisition of GMO increased depreciation and amortization $30.7 million.  The remaining increase at KCP&L was primarily due to additional amortization pursuant to rate case orders of $21.7 million combined with normal depreciation activity forother capital additions.
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Electric Utility Non-Operating Income adand Expenses
Electric utility’s non-operating income and expenses decreased $14.6 million in 2010 compared to 2009 primarily due to a decrease in the equity component of AFUDC resulting from a lower average construction work in progress balance due to KCP&L’s Comprehensive Energy Plan projects being placed in service.

Electric utility’s non-operating income and expenses increased $16.4 million in 2009 compared to 2008 primarily due to a $15.4 million increase in the equity component of AFUDC resulting from higher average construction work in progress balances and the inclusion of GMO for a full year.

Electric Utility Interest Charges
Electric utility’s non-operating income and expenses increased $17.1interest charges decreased $7.9 million in 20082010 compared to 2007.  The acquisition of GMO increased non-operating income and expenses $2.1 million.  The remaining increase at KCP&L was2009 primarily due to the deferral to a $20.0regulatory asset of construction accounting carrying costs for Iatan No. 1, Iatan No. 2 and common facilities and the maturity of $68.5 million increaseof GMO’s 7.625% Senior Notes in December 2009.  These decreases were partially offset by a decrease in the equitydebt component of AFUDC resulting from a higherlower average construction work in progress balance due to KCP&L’s Comprehensive Energy Plan projects.projects being placed in service, interest for a full year on KCP&L’s $400.0 million of 7.15% Mortgage Bonds Series 2009A issued in March 2009 and interest on an intercompany note from Great Plains Energy to GMO issued in August 2010.

Electric Utility Interest Charges
Electric utility’s interest charges increased $54.1 million in 2009 compared to 2008 driven by the inclusion of GMO for a full year, interest on KCP&L’s $400.0 million of Mortgage Bonds Series 2009A issued in March 2009 and interest for a full year on $350.0 million of unsecured Senior Notes issued in March 2008.  These increases were partially offset at KCP&L by decreased commercial paper outstanding, decreased rates on commercial paper and an increase in the debt component of AFUDC resulting from a higher average construction work in progress balance due to KCP&L’s Comprehensive Energy Plan projects.
 
Electric utility’s interest charges increased $29.7 million in 2008 compared to 2007.  The acquisition of GMO increased interest charges $24.6 million.  The remaining increase at KCP&L was primarily due to interest on $350.0 million of unsecured Senior Notes issued in March 2008, partially offset by an increase in the debt component of AFUDC resulting from a higher construction work in progress balance due to Comprehensive Energy Plan projects.
Electric Utility Income Tax Expense
Electric utility’s income tax expense increased $59.7 million in 2010 compared to 2009 due to increased pre-tax income and a $2.8 million increase in income tax expense for the cumulative change in tax treatment of the Medicare Part D subsidy under the Federal health care reform legislation signed into law in 2010.
Electric utility’s income tax expense decreased $7.3 million in 2009 compared to 2008 due to an increase in KCP&L’s deferred tax balances in 2008 of $20.3 million as a result of an increase in the composite tax rate reflecting the 2008 sale of Strategic Energy.  Additionally, 2008 reflected $6.7 million of allocated tax benefits from holding company losses.  The tax sharing agreement between Great Plains Energy and its subsidiaries was modified on July 14, 2008.  As part of the new agreement, parent company tax benefits are no longer allocated to KCP&L or other subsidiaries.  The inclusion of GMO for a full year in 2009 also partially offset the decrease in income tax expense.
 
Electric utility’s income tax expense increased $11.6 million in 2008 compared to 2007.  The acquisition of GMO increased income taxes $11.1 million.  The remaining increase at KCP&L was primarily due to an increase of $20.3 million as a result of an increase in the composite tax rate reflecting the sale of Strategic Energy, mostly offset by decreased pre-tax income and increased wind credits.  See Note 22 to the consolidated financial statements for a reconciliation of effective income tax rates for the periods.
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GREAT PLAINS ENERGY SIGNIFICANT BALANCE SHEET CHANGES (December 31, 20092010 compared to December 31, 2008)2009)

·  Great Plains Energy’s accounts receivable pledged as collateral and collateralized note payable of $95.0 million reflects the adoption on January 1, 2010, of new accounting rules for transfers of financial assets.  See Note 3 to the consolidated financial statements for additional information.
·  Great Plains Energy’s refundable income taxes decreased $11.4 million primarily due to income tax refunds received.
·  Great Plains Energy’s deferred income taxes – current assets decreased $22.5 million primarily due to a reclassification to deferred income taxes – long-term driven by a change in the expected timing of utilizing net operating loss benefits as a result of bonus depreciation available in 2011.
·  Great Plains Energy’s assets held for sale decreased $19.4 million due to the sale of two properties with book values of $11.7 million and the reclassification of the remaining properties with book values of $7.7 million to other – investments and other assets.  See Note 4 to the consolidated financial statements for additional information.
 
·  Great Plains Energy’s electric utility plant increased $908.2 million$1.7 billion primarily due to the following projects$1.3 billion, $103.0 million and $76.8 million placed in service in addition to normal plant activity:
·  $553.0 million for Iatan No. 2, Spearville 2 Wind Energy Facility and the Iatan No. 1 environmental project and certain Iatan facility common costs; and
·  $135.5 million for environmental equipment at GMO’s Sibley No. 3 and Jeffrey Energy Center.costs, respectively, in addition to normal plant activity.
 
·  Great Plains Energy’s construction work in progress decreased $150.7 million$1.2 billion primarily due to $688.5 million of electric utility projects placed in service as described above, partially offset by a $391.7 million increase related to KCP&L’s Comprehensive Energy Plan projects, $63.7 million related to GMO’s 18% share of Iatan No. 2 and $44.6 million related to a KCP&L wind project, in addition to normal plant activity.
·  Great Plains Energy’s affordable housing limited partnerships decreased $12.9 million primarily due to the write down of these investments.  See Note 20 to the consolidated financial statements for additional information.
 
·  Great Plains Energy’s notes payable increased $48.0 million due to additional borrowings for the repayment of current maturities of long-term debt.
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·  Great Plains Energy’s commercial paper decreased $193.6$242.5 million primarily due to repayment with proceeds from KCP&L’s issuance of $400.0 million of Mortgage Bonds Series 2009A, part of the $275.8 million net proceeds from Great Plains Energy’s issuance of Equity Units and part of the $204.0 million net proceeds from the issuance of common stock,$250.0 million of 2.75% Senior Notes, partially offset by a $79.1$6.9 million payment for the settlement of FSSforward starting swaps (FSS) and additional borrowings to support Comprehensive Energy Plan expenditures and other normal operating activities.
 
·  Great Plains Energy’s commercial paper increased $76.9 million primarily due to increased borrowings driven by the timing of cash payments.
·  Great Plains Energy’s accounts payable decreased $103.0$38.7 million primarily due to the timing of cash payments, and completing significant construction projects in the first half of 2009, including the Iatan No. 1 environmental project and GMO’s Sibley SCR project, and decreasespayments related to lower natural gas and purchased power prices.KCP&L’s Comprehensive Energy Plan.
 
·  Great Plains Energy’s derivative instruments – current liabilities decreased $85.9increased $20.5 million primarily due to the settlement ofmark-to-market losses on Great Plains Energy’s FSS, simultaneously with KCP&L’s issuance of $400.0 million of Mortgage Bonds Series 2009Awhich is offset in March 2009.OCI.
 
·  Great Plains Energy’s deferred tax creditsincome taxes – long-term increased $35.0$136.4 million primarily due to recognitiona $119.1 million increase in temporary differences mostly as a result of $37.2 million of advanced coal credits.  See Note 22 to the consolidated financial statements for additional information on the advanced coal credits.bonus depreciation, partially offset by a reclassification with deferred income taxes – current assets described above.
 
·  Great Plains Energy’s long-term debt decreased $270.3 million primarily to reflect GMO’s $137.3 million 7.95% Senior Notes, $197.0 million 7.75% Senior Notes and KCP&L’s $150.0 million 6.50% Senior Notes as current maturities.  Current maturities of long-term debt increased similarly.  Partially offsetting the decrease in long-term debt was Great Plains Energy’s issuance of $250.0 million of 2.75% Senior Notes in August 2010.
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CAPITAL REQUIREMENTS AND LIQUIDITY
 
Great Plains Energy operates through its subsidiaries and has no material assets other than the stock of its subsidiaries.  Great Plains Energy’s ability to make payments on its debt securities and its ability to pay dividends is dependent on its receipt of dividends or other distributions from its subsidiaries, proceeds from the issuance of its securities and borrowing under its revolving credit facility.
 
Great Plains Energy’s capital requirements are principally comprised of debt maturities and electric utility’s construction and other capital expenditures.  These items as well as additional cash and capital requirements are discussed below.
 
Great Plains Energy's liquid resources at December 31, 2009,2010, consisted of $65.9$10.8 million of cash and cash equivalents on hand and $901.9$923.6 million of unused bank lines of credit.  The unused lines consisted of $354.6$174.7 million from Great Plains Energy's revolving credit facility, $392.5$312.1 million from KCP&L's credit facilities and $154.8$436.8 million from GMO’s revolving credit facility.  At February 22, 2011, Great Plains Energy’s unused bank lines of credit decreased $201.4 million from the amount at December 31, 2010, primarily due to the repayment of GMO’s $137.3 million of 7.95% Senior Notes that matured in February 2011, in addition to the timing of cash payments driven by normal business cycles and operations.  See Note 1211 to the consolidated financial statements for more information on these agreements.credit facilities.  Generally, Great Plains Energy uses these liquid resources to meet its day-to-day cash flow requirements, and from time to time issues equity and/or long-term debt to repay short-term debt or increase cash balances.
 
Great Plains Energy intends to meet day-to-day cash flow requirements including interest payments, retirement of maturing debt, construction requirements, dividends and pension benefit plan funding requirements with a combination of internally generated funds and proceeds from the issuance of equity securities, equity-linked securities and/or short-term and long-term debt.  Great Plains Energy’s intention to meet a portion of these requirements with internally generated funds may be impacted by the effect of inflation on operating expenses, the level of retail MWh sales, regulatory actions, compliance with environmental regulations and the availability of generating units.  In addition, Great Plains Energy may issue equity, equity-linked securities and/or debt to finance growth.
 
At December 31, 2010, Great Plains Energy’s long-term debt maturities in 2011 and 2012 were $485.7 million and $513.9 million, respectively.  In February 2011, repayment of GMO’s $137.3 million of 7.95% Senior Notes that matured in February 2011 reduced the 2011 long-term debt maturities to $348.4 million.  Great Plains Energy is evaluating alternatives to refinance the remaining long-term debt, including issuing new long-term debt.  Based on current market conditions and Great Plains Energy’s unused bank lines of credit, Great Plains Energy expects to have the ability to access the markets to complete the necessary refinancing.
Cash Flows from Operating Activities
Great Plains Energy generated positive cash flows from operating activities for the periods presented.  The increase in cash flows from operating activities for Great Plains Energy in 2010 compared to 2009 is primarily due to an increase in net income, an increase in deferred income taxes from utilizing bonus depreciation, which defers the cash payment for taxes on current year income, and a decrease in cash flows for accounts payable due to the completion of significant construction projects.  On January 1, 2010, Great Plains Energy adopted new accounting rules for transfers of financial assets, which resulted in the recognition of $95.0 million of accounts receivables pledged as collateral and a corresponding short-term collateralized note payable on Great Plains Energy’s balance sheet at December 31, 2010.  See Note 3 for additional information.  As a result, cash flows from operating activities were reduced by $95.0 million and cash flow from financing activities were raised by $95.0 million with no impact to the net change in cash in 2010.  Additionally, cash flows from operating activities in 2009 reflect the payment of $79.1 million for the settlement of FSS upon the issuance of $400.0 million of 7.15% Mortgage Bonds Series 2009A.  Other changes in working capital are detailed in Note 2 to the consolidated financial statements.  The individual components of working capital vary with normal business cycles and operations.
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The decrease in cash flows from operating activities for Great Plains Energy in 2009 compared to 2008 is primarily due to a decrease in accounts payable due to the timing of cash payments and completing significant construction projects and KCP&L’sthe payment of $79.1 million for the settlement of FSS upon the issuance of $400.0 million of 7.15% Mortgage Bonds Series 2009A in 2009.  Partially offsetting these decreases was KCP&L’s 2008 payment of $41.2 million for the settlement of three Treasury Locks (T-Locks).  Additionally, 2008 cash flows from operating activities include Strategic Energy.  Great Plains Energy sold Strategic Energy in 2008.  Other changes
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in working capital are detailed in Note 32 to the consolidated financial statements.  The individual components of working capital vary with normal business cycles and operations.
The increase in cash flows from operating activities for Great Plains Energy in 2008 compared to 2007 reflects an increase in KCP&L’s cash flows due to a decrease in accounts receivable from wholesale sales and joint owners and tax refunds received in 2008 partially offset by payment of $41.2 million for the settlement of three T-Locks.  Other changes in working capital are detailed in Note 3 to the consolidated financial statements.
 
Cash Flows from Investing Activities
Great Plains Energy’s cash used for investing activities varies with the timing of utility capital expenditures and purchases of investments and nonutility property.  Investing activities are offset by the proceeds from the sale of properties and insurance recoveries.
 
Great Plains Energy’s utility capital expenditures decreased $223.1 million in 2010 compared to 2009 due to a decrease in cash utility capital expenditures primarily related to the Iatan No. 1 environmental project, Iatan No. 2 and Spearville 2 Wind Energy Facility.
Great Plains Energy’s utility capital expenditures decreased $182.6 million in 2009 compared to 2008 due to a decrease in KCP&L’s cash utility capital expenditures primarily related to Comprehensive Energy Plan projects.
Great Plains Energy’s utility capital expenditures increased $512.2 million in 2008 compared to 2007.  The acquisition of GMO increased cash utility capital expenditures $213.2 millionthe Iatan No. 1 environmental project and KCP&L’s cash utility capital expenditures increased $299.0 million due to a $285.7 million increase related to KCP&L’s Comprehensive Energy Plan projects.Iatan No. 2.
 
In 2008, Great Plains Energy completed the sale of Strategic Energy and received gross cash proceeds of $307.7 million.  At the time of the sale, Strategic Energy had $88.9 million of cash, resulting in proceeds from the sale of Strategic Energy, net of cash sold of $218.8 million.
 
On July 14, 2008, Great Plains Energy closed its acquisition of GMO.  Great Plains Energy paid cash consideration of $0.7 billion.  At the time of the acquisition, GMO had approximately $1.0 billion of cash from the sale of its electric and gas utility assets in Colorado, Kansas, Nebraska and Iowa to Black Hills.
 
Cash Flows from Financing Activities
Great Plains Energy’s cash flows from financing activities in 2010 reflect the issuance, at a discount, of $250.0 million of 2.75% Senior Notes that mature in 2013.  Great Plains Energy used the proceeds to make a three-year intercompany loan to GMO with GMO using the proceeds to repay short-term borrowings.  Also reflected is the $95.0 million impact of the short-term collateralized note payable described above under cash flows from operating activities.
Great Plains Energy’s cash flows from financing activities in 2009 reflect gross proceeds of $161.0 million from the issuance of 11.5 million shares of common stock at $14 per share and gross proceeds of $287.5 million from the issuance of 5.8 million Equity Units.  See Note 1312 to the consolidated financial statements for more information on the Equity Units.  Also reflected in the cash flows from financing activities in 2009 is KCP&L’s issuance, at a discount, of $400.0 million of Mortgage Bonds Series 2009A that mature in 2019.  Additionally, Great Plains Energy sold 3.8 million shares of common stock for $50.0 million in gross proceeds under a Sales Agency Financing Agreement with BNY Mellon Capital Markets, LLC (BNYMCM).  Great Plains Energy paid $22.8 million in 2009 for fees related to all issuances of debt and common stock.  The proceeds from these issuances were used primarily to repay short-term borrowings.
 
Great Plains Energy’s cash flows from financing activities in 2008 reflect KCP&L’s issuance of $350.0 million of unsecured Senior Notes that mature in 2018.  The proceeds were used to repay short-term borrowings.  GMO repaid $169.0 million on a credit agreement that was terminated in 2008 and subsequently borrowed $110.0 million under its new revolving credit facility.  Additionally, GMO terminated various other credit agreements and paid $12.5 million of termination fees.
 
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Impact of Credit Ratings on Liquidity
The ratings of Great Plains Energy’s, cash flows fromKCP&L’s and GMO’s securities by the credit rating agencies impact their liquidity, including the cost of borrowings under their revolving credit agreements and in the capital markets.  The Companies view maintenance of strong credit ratings as extremely important to their access to and cost of debt financing activitiesand to that end maintain an active and ongoing dialogue with the agencies with respect to results of operations, financial position, and future prospects.  While a decrease in 2007 reflect KCP&L’s repayment and issuancethese credit ratings would not cause any acceleration of Senior Notes; Great Plains Energy’s, issuance, at a discount, of $100.0 million ofKCP&L’s or GMO’s debt, it could increase interest charges under Great Plains Energy’s 6.875% Senior Notes that mature in 2017; an increase in short-term borrowingsdue 2017, GMO’s 11.875% Senior Notes due 2012, GMO’s 7.95% Senior Notes due 2011 and the $12.3 million settlement of an equity forward contract at Great Plains Energy.Energy’s, KCP&L’s cash flows from financing activitiesand GMO’s revolving credit agreements.  A decrease in 2007 reflectcredit ratings could also have, among other things, an adverse impact, which could be material, on Great Plains Energy’s, KCP&L’s repaymentand GMO’s access to capital, the cost of funds, the ability to recover actual interest costs in state regulatory proceedings, the type and amounts of collateral required under supply agreements and Great Plains Energy’s ability to provide credit support for its $225.0 million of Senior Notes at maturity, issuance, at a discount, of $250.0 million of Senior Notes that mature in 2017,subsidiaries.
At December 31, 2010, the major credit rating agencies rated Great Plains Energy’s and an increase in short-term borrowings. KCP&L’s short-term borrowings increased primarilysecurities as detailed in the following table.
Moody'sStandard
Investors Service& Poor's
Great Plains Energy
   OutlookStableStable
   Corporate Credit Rating-BBB
   Preferred StockBa2BB+
   Senior Unsecured DebtBaa3BBB-
KCP&L
   OutlookStableStable
   Senior Secured DebtA3BBB+
   Senior Unsecured DebtBaa2BBB
   Commercial PaperP-2A-2
GMO
   OutlookStableStable
   Senior Unsecured Debt (a)
Baa3BBB
(a) reflects Great Plains Energy guarantee

A securities rating is not a recommendation to support expenditures relatedbuy, sell or hold securities and may be subject to its Comprehensive Energy Plan.revision or withdrawal at any time by the assigning rating agency.
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Financing Authorization
Under stipulations with the MPSC and KCC, Great Plains Energy and KCP&L maintain common equity at not less than 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).  KCP&L’s long-term financing activities are subject to the authorization of the MPSC.  KCP&L utilized $1.25 billion of $1.4 billion of long-term debt authorization fromIn March 2010, the MPSC that expired on December 31, 2009.  In December 2009,authorized KCP&L filed an application with the MPSC requesting authorization to issue up to $650.0$450.0 million of long-term debt and to enter into interest rate hedging instruments in connection with such debt through December 31, 2011, which is pending MPSC decision.  In addition, in 2009,2011.  KCP&L received authorization from the MPSC and issued $196.5 million in mortgage bonds to insurershad not utilized any of KCP&L’s $196.5 million aggregate principalthis authorized amount as of Environmental Improvement Revenue Refunding (EIRR) Bonds Series 2005 and Series 2007, as required under the terms of the insurance agreements due to the issuance of other mortgage bonds by KCP&L.  See Note 13 to the consolidated financial statements for more information on these insurance agreements.December 31, 2010.
 
In December 2008,2010, FERC authorized KCP&L to have outstanding at any time up to a total of $1.1$1.0 billion in short-term debt instruments through December 2010.2012 conditioned on KCP&L’s borrowing costs not exceeding the greater of: (i) 4.25% over LIBOR; (ii) the greater of 2.25% over the prime rate, 2.75% over the federal funds rate, and 3.25% over LIBOR; or (iii) 4.25% over the A2/P-2 nonfinancial commercial paper rate most recently published by the Federal Reserve at the time of the borrowing.  The authorization is subject to four restrictions: (i)
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proceeds of debt backed by utility assets must be used for utility purposes; (ii) if any utility assets that secure authorized debt are divested or spun off, the debt must follow the assets and also be divested or spun off; (iii) if any proceeds of the authorized debt are used for non-utility purposes, the debt must follow the non-utility assets (specifically, if the non-utility assets are divested or spun off, then a proportionate share of the debt must follow the divested or spun off non-utility assets); and (iv) if utility assets financed by the authorized short-term debt are divested or spun off to another entity, a proportionate share of the debt must also be divested or spun off.  At December 31, 2009,2010, there was $913.4$736.5 million available under this authorization.
 
In March 2010, and modified in April 2010, FERC authorized GMO hasto have outstanding at any time up to a total of $500.0 million of FERC short-term debt authorization through April 2010,March 2012, conditioned on GMO’s borrowing costs not exceeding 4.3% over LIBOR, the prime rate or federal funds rate, as applicable, and subject to the same four restrictions as the KCP&L FERC short-term authorization discussed in the preceding paragraph.  At December 31, 2009,2010, there was $268.0$500.0 million available under this authorization.  In December 2009,July 2010, FERC authorized GMO filed an application with FERC requestingto issue up to a renewaltotal of $850.0 million of long-term debt, including intercompany debt, through July 2012 and subject to the same $500.0 million offour restrictions as the KCP&L FERC short-term debt authorization through 2012, which is pending FERC decision.  GMO has $750.0 million of FERC long-term debt authorization through Julydiscussed in the preceding paragraph.  At December 31, 2010, none of which has been utilized.there was $601.2 million available under this authorization.
 
KCP&L and GMO are also authorized by FERC to participate in the Great Plains Energy money pool.  The money pool, is an internal financing arrangement in which funds deposited into the money pool couldmay be lent on a short-term basis to KCP&L and GMO.  At December 31, 2009,2010, GMO had an outstanding payable of $12.1 million to KCP&L and KCP&L had an outstanding payable under the money pool of $0.9$2.0 million to Great Plains Energy and a receivable of $6.0 million from GMO.Energy.
 
Significant Financing Activities
Great Plains Energy
Great Plains Energy has an effective shelf registration statement for the sale of unspecified amounts of securities with the SEC that was filed and became effective in May 2009.
 
In August 2010, Great Plains Energy issued $250.0 million of 2.75% Senior Notes, maturing in 2013.  Great Plains Energy settled two FSS simultaneously with the issuance of the three-year long-term debt and paid $6.9 million in cash for the settlement.
In May 2009, Great Plains Energy issued 11.5 million shares of common stock at $14.00 per share with $161.0 million in gross proceeds and 5.8 million Equity Units with gross proceeds of $287.5 million.  See Note 1312 to the consolidated financial statements for more information on the Equity Units.
 
In August 2008, Great Plains Energy entered into a Sales Agency Financing Agreement with BNYMCM.  Under the terms of the agreement, Great Plains Energy may offer and sell up to 8.0 million shares of its common stock from time to time through BNYMCM, as agent, for a period of no more than three years.  Great Plains Energy will pay BNYMCM a commission equal to 1% of the sales price of all shares sold under the agreement.  During 2009, 3.8 million shares were sold for $49.5 million in net proceeds through BNYMCM.  During 2008, 0.2 million shares were sold for $3.5 million in net proceeds.
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KCP&L
KCP&L has an effective shelf registration statement providing for the sale of unspecified amounts of investment grade notes and general mortgage bonds with the SEC that was filed and became effective in May 2009.
 
In March 2009, KCP&L issued $400.0 million of 7.15% Mortgage Bonds Series 2009A, maturing in 2019.  KCP&L settled FSS simultaneously with the issuance of its $400.0 million 10-year long-term debt and paid $79.1 million in cash for the settlement.
 
In March 2008, KCP&L issued $350.0 million of 6.375% unsecured Senior Notes, maturing in 2018.  KCP&L settled three T-Locks simultaneously with the issuance of its $350.0 million 10-year long-term debt and paid $41.2 million in cash for the settlement.
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In May 2008, KCP&L’s Series 2008 EIRR bonds totaling $23.4 million maturing in 2038 were issued.  The bonds have an initial long-term interest rate of 4.90% until June 30, 2013.  At the end of the initial long-term interest rate period, the bonds are subject to remarketing and mandatory tender; however, KCP&L is not obligated to pay the purchase price of the bonds on the mandatory tender date.  If the bonds are not successfully remarketed, the bonds will bear interest at a daily rate equal to 10% per annum until all of the bonds are successfully remarketed.
 
Debt Agreements
See Note 1211 to the consolidated financial statements for discussion of revolving credit facilities.
 
Projected Utility Capital Expenditures
Great Plains Energy’s cash utility capital expenditures, excluding AFUDC to finance construction, were $618.0 million, $841.1 million and $1,023.7 million in 2010, 2009 and $511.5 million in 2009, 2008, and 2007, respectively.  Utility capital expenditures projected for the next three years, excluding AFUDC, are detailed in the following table.  This utility capital expenditure plan is subject to continual review and change.
        
  201020112012
  (millions)
Generating facilities (excluding Iatan No. 2)$152.0 $152.8 $138.3 
Distribution and transmission facilities 192.8  238.0  275.7 
General facilities 15.6  23.7  48.9 
Nuclear fuel 30.9  21.5  19.8 
Environmental 16.4  189.1  189.9 
Iatan No. 2 (a)
 243.9  54.1  - 
 Total utility capital expenditures$651.6 $679.2 $672.6 
           
(a)Includes $183.5 million and $40.7 million of expenditures pursuant to KCP&L's 
 Comprehensive Energy Plan in 2010 and 2011, respectively.  Includes $60.4 
 million and $13.4 million of expenditures at GMO in 2010 and 2011, respectively. 
 
 201120122013
 (millions)
Generating facilities (excluding construction of Iatan No. 2)$172.2 $174.6 $171.8 
Distribution and transmission facilities 171.0  178.9  232.2 
General facilities 29.2  63.2  44.6 
Nuclear fuel 14.8  26.2  31.5 
Environmental 63.0  171.0  219.1 
Construction of Iatan No. 2 53.1  -  - 
Total utility capital expenditures$503.3 $613.9 $699.2 
          
Pensions
The Company maintains defined benefit plans for substantially all active and inactive employees of KCP&L, GMO and WCNOC and incurs significant costs in providing the plans.  Funding of the plans follows legal and regulatory requirements with funding equaling or exceeding the minimum requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA).
In 2010 and 2009, the Company contributed $64.5 million and $42.1 million to the pension plans, respectively, and in 2011 expects to contribute $104.6 million to the plans to satisfy the ERISA funding requirements and the MPSC and KCC rate orders, and in 2008 contributed $29.3 millionwith the majority paid by KCP&L.  Additional contributions to the plans allare expected beyond 2011 in amounts at least sufficient to meet the greater of ERISA or regulatory funding requirements; however, these amounts have not yet been determined.
Additionally, the Company provides post-retirement health and life insurance benefits for certain retired employees and expects to make benefit contributions of $15.8 million under the provisions of these plans in 2011, with the majority paid by KCP&L.
 
The Company expects to contribute approximately $53.6 million to the plans in 2010 to satisfy ERISA and regulatory funding requirements, the majority of which is expected to be paid by KCP&L.
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Management believes the Company has adequate access to capital resources through cash flows from operations or through existing lines of credit to support thethese funding requirements.
Credit Ratings
At December 31, 2009, the major credit rating agencies rated Great Plains Energy’s and KCP&L’s securities as detailed in the following table.
Moody'sStandard
Investors Service& Poor's
Great Plains Energy
   OutlookNegativeNegative
   Corporate Credit Rating-BBB
   Preferred StockBa1BB+
   Senior Unsecured DebtBaa3BBB-
KCP&L
   OutlookNegativeNegative
   Senior Secured DebtA3BBB+
   Senior Unsecured DebtBaa1BBB
   Commercial PaperP-2A-3
GMO
   OutlookNegativeNegative
   Senior Unsecured Debt (a)
Baa3BBB
(a) reflects Great Plains Energy guarantee

A securities rating is not a recommendation to buy, sell or hold securities and may be subject to revision or withdrawal at any time by the assigning rating agency.  Great Plains Energy and KCP&L view maintenance of strong credit ratings as extremely important and to that end an active and ongoing dialogue is maintained with the agencies with respect to results of operations, financial position, and future prospects.  While a decrease in these credit ratings would not cause any acceleration of Great Plains Energy’s, KCP&L’s or GMO’s debt, it could increase interest charges under Great Plains Energy’s 6.875% Senior Notes due 2017, GMO’s 11.875% Senior Notes due 2012, GMO’s 7.95% Senior Notes due 2011 and Great Plains Energy’s, KCP&L’s and GMO’s revolving credit agreements.  A decrease in credit ratings could also have, among other things, an adverse impact on Great Plains Energy’s, KCP&L’s and GMO’s access to capital, the cost of funds, the ability to recover actual interest costs in state regulatory proceedings, the amounts of collateral required under supply agreements and Great Plains Energy’s ability to provide credit support for its subsidiaries.
 
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Supplemental Capital Requirements and Liquidity Information
The information in the following table is provided to summarize Great Plains Energy’s cash obligations and commercial commitments.
                                
Payment due by periodPayment due by period20102011201220132014After 2014TotalPayment due by period20112012201320142015After 2015Total
Long-term debtLong-term debt(millions)Long-term debt(millions)
Principal$1.4 $485.8 $513.8 $13.1 $1.5 $2,116.7 $3,132.3 Principal$485.7 $513.9 $263.1 $1.5 $15.5  $2,101.3  $3,381.0 
Interest 240.4  220.6  174.0  143.7  127.5  914.7  1,820.9 Interest 227.2  180.5  147.7  127.2  113.5   794.9   1,591.0 
Lease commitmentsLease commitments                     Lease commitments                       
Operating lease 15.6  16.0  15.3  14.0  13.6  151.6  226.1 Operating lease 17.9  16.8  15.0  14.3  13.5   129.4   206.9 
Capital lease 0.4  0.4  0.4  0.4  0.4  5.0  7.0 Capital lease 0.4  0.4  0.4  0.4  0.4   5.5   7.5 
Pension and other post-retirement plans (a)
Pension and other post-retirement plans (a)
 71.6 
(a)
 (a) (a) (a) (a)  71.6 
Pension and other post-retirement plans (a)
 120.4  120.4  120.4  120.4  120.4   N/A   602.0 
Purchase commitmentsPurchase commitments                     Purchase commitments                       
Fuel 197.3  113.3  103.9  100.2  85.1  138.8  738.6 Fuel 348.7  282.7  287.7  164.8  108.8   125.3   1,318.0 
Purchased capacity 33.0  19.9  14.1  13.1  4.5  6.5  91.1 Purchased capacity 20.3  13.4  12.4  4.5  4.2   2.4   57.2 
Comprehensive Energy Plan 105.3  1.4  -  -  -  -  106.7 Non-regulated natural gas                       
Non-regulated natural gas                     transportation 4.6  2.9  2.9  2.9  2.9   3.4   19.6 
transportation 6.1  5.6  3.2  3.2  3.2  7.2  28.5 Other 163.4  17.6  6.8  8.1  2.7   55.1   253.7 
Other 66.9  15.0  5.9  5.5  5.6  21.2  120.1 
Total contractual commitments (a)
Total contractual commitments (a)
$738.0 $878.0 $830.6 $293.2 $241.4 $3,361.7 $6,342.9 
Total contractual commitments (a)
$1,388.6 $1,148.6 $856.4 $444.1 $381.9  $3,217.3  $7,436.9 
                                              
(a)The Company expects to make contributions to the pension and other post-retirement plans beyond 2010 but the amountsThe Company expects to make contributions to the pension and other post-retirement plans beyond 2011 but the amounts
are not yet determined.  Total contractual commitments for years after 2010 do not reflect expected pension plan contributionsare not yet determined.  Amounts for years after 2011 are estimates based on information available in determining the amount
for periods beyond 2010.for 2011.  Actual amounts for years after 2011 could be significantly different than the estimated amounts in the table above.

Long-term debt includes current maturities.  Long-term debt principal excludes $2.5 million of discounts on senior notes.  Variable rate interest obligations are based on rates as of December 31, 2009.2010.  Equity Units subordinated notes totaling $287.5 million mature in 2042 but must be remarketed between December 15, 2011 and June 12, 2012.  In connection with a successful remarketing of the notes, Great Plains Energy may elect, without the consent of any of the holders, to modify the notes’ stated maturity to any date on or after June 15, 2014 and earlier than June 15, 2042.  If the notes have not been successfully remarketed by June 12, 2012, the holders of all notes will have the right to put their notes to Great Plains Energy on June 15, 2012, in payment of the associated common stock purchase contracts.contracts and Great Plains Energy will issue to the holders newly issued shares of the Company’s common stock.  Interest on the Equity Units subordinated notes is included up to June 15, 2014.  See Note 1312 to the consolidated financial statements for additional information.
 
Great Plains Energy has expected sublease income of $2.0 million for the years 2011-2013.  Lease commitments end in 2032 and include capital and operating lease obligations.  Lease obligations also include railcars to serve jointly-owned generating units where KCP&L is the managing partner.  KCP&L will be reimbursed by the other owners for approximately $2.0 million per year ($14.713.7 million total) of the amounts included in the table above.
 
The Company expects to contribute $71.6$120.4 million to the pension and other post-retirement plans in 2010,2011, of which the majority is expected to be paid by KCP&L.  Additional contributions to the plans are expected beyond 20102011 in amounts at least sufficient to meet the greater of ERISA andor regulatory funding requirements; however, these amounts have not yet been determined.  Amounts for years after 2011 are estimates based on information available in determining the amount for 2011.  Actual amounts for years after 2011 could be significantly different than the estimated amounts in the table above.
 
Fuel commitments consist of commitments for nuclear fuel, coal and coal transportation costs.  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 $11.2 million per year for 2010 and 2011, $6.9 million infor 2011, $3.8 million for 2012 and $1.6 million infor 2013.  Comprehensive Energy Plan represents contractual commitments for projects included in KCP&L’s Comprehensive Energy Plan including jointly owned units.  KCP&L expects to be reimbursed by other owners, including GMO, for their respective share of Iatan No. 2 and environmental retrofit costs included in theNon-regulated
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Comprehensive Energy Plan contractual commitments.  Non-regulated natural gas transportation consists of MPS Merchant’s commitments.  Other represents individual commitments entered into in the ordinary course of business.
 
At December 31, 2009,2010, the total liability for unrecognized tax benefits for Great Plains Energy was $51.4$42.0 million, which is not included in the table above.  Great Plains Energy is unable to determine reasonably reliable estimates of the period of cash settlement with the respective taxing authorities.  See Note 2221 to the consolidated financial statements for information regarding the recognition of tax benefits in the next twelve months, which is not expected to have a cash impact.
 
Great Plains Energy has other insignificant long-term liabilities recorded on its consolidated balance sheet at December 31, 2009,2010, that do not have a definitive cash payout date and are not included in the table above.
 
Off-Balance Sheet Arrangements
In the normalordinary 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 stand-by letters of credit and surety bonds.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 subsidiaries’ 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, 2009,2010, Great Plains Energy has provided $1,063.6$1,030.4 million of credit support for GMO as follows:
 
·  Great Plains Energy direct guarantees to GMO counterparties totaling $87.9$65.4 million, of which $45.4 million expire in 2010,2011 and $20.0 million expire in 2012,
 
·  Great Plains Energy letters of credit totaling $25.4 million to GMO counterparties totaling $15.8 million , which expire in 2010,2011, and
 
·  Great Plains Energy guarantees of GMO long-term debt totaling $950.3$949.2 million, which includes debt with maturity dates ranging from 2010-2023.2011-2023.

Great Plains Energy has also guaranteed GMO’s $400$450 million revolving line of credit dated September 23, 2008,August 9, 2010, with a group of banks, expiring September 23, 2011.August 9, 2013.  At December 31, 2009, there was $232.02010, GMO had no outstanding cash borrowings and had issued letters of credit totaling $13.2 million outstanding under this facility.
 
None of the guaranteed obligations are subject to default or prepayment as a result of a downgrade of GMO’s credit ratings, although such a downgrade has in the past, and could in the future, increase interest charges under GMO’s 11.875% Senior Notes due 2012 and 7.95% Senior Notes due 2011, as well as GMO’s revolving line of credit.
 
At December 31, 2009, GMO had issued letters of credit totaling $13.2 million as credit support to certain counterparties.
KCP&L is contingently liable for guaranteed energy savings under an agreement with a customer, guaranteeing an aggregate value of approximately $1.0 million over the next year.  A subcontractor would indemnify KCP&L for any payments made by KCP&L under this guarantee.  Additionally, at December 31, 2009,2010, KCP&L had issued letters of credit totaling $20.9$24.4 million as credit support to certain counterparties.
 
KCP&L has guarantees related to bond insurance policies for its secured 1992 series EIRR bonds totaling $31.0 million, Series 1993A and 1993B EIRR bonds totaling $79.5 million, EIRR Bond Series 2005 totaling $85.9 million and EIRR Bonds Series 2007A and 2007B totaling $146.5 million.  The insurance agreement between KCP&L and the issuer of the bond insurance policies provides for reimbursement by KCP&L for any amounts the
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insurer pays under the bond insurance policies.  As the insurers’ credit ratings are below KCP&L’s credit ratings, the bonds are rated at KCP&L’s credit ratings.
 
New Accounting Standards
See Note 26 to the consolidated financial statements for information regarding new accounting standards.
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KANSAS CITY POWER & LIGHT COMPANY
 
MANAGEMENT’S NARRATIVE ANALYSIS OF RESULTS OF OPERATIONS
 
The following discussion of KCP&L results of operations includes KCP&L, an integrated, regulated electric utility and for 2007 includes Home Service Solutions Inc. (HSS), formerly an unregulated subsidiary of KCP&L, which was transferred from KCP&L to KLT Inc. on January 2, 2008.  HSS’ results in 2007 were insignificant.
The following table summarizes KCP&L's consolidated comparative results of operations.
            
200920082007201020092008
(millions)(millions)
Operating revenues$1,318.2 $1,343.0 $1,292.7 $1,517.1 $1,318.2 $1,343.0 
Fuel (251.3) (253.3) (245.5) (278.8) (251.3) (253.3)
Purchased power (70.8) (119.0) (101.0) (78.9) (70.8) (119.0)
Transmission of electricity by others (15.0) (12.3) (11.1)
Gross margin (a)
 1,144.4  983.8  959.6 
Other operating expenses (534.3) (528.3) (500.6) (576.6) (522.0) (517.2)
Skill set realignment deferral -  -  8.9 
Depreciation and amortization (229.6) (204.3) (175.6) (256.4) (229.6) (204.3)
Operating income 232.2  238.1  278.9  311.4  232.2  238.1 
Non-operating income and expenses 28.5  19.2  4.3  19.1  28.5  19.2 
Interest charges (84.9) (72.3) (67.2) (85.7) (84.9) (72.3)
Income tax expense (46.9) (59.8) (59.3) (81.6) (46.9) (59.8)
Net income$128.9 $125.2 $156.7 $163.2 $128.9 $125.2 
(a) Gross margin is a non-GAAP financial measure. See explanation of gross margin under Great
(a) Gross margin is a non-GAAP financial measure. See explanation of gross margin under Great
Plains Energy's Results of Operations.Plains Energy's Results of Operations.
                  
KCP&L RevenuesGross Margin and MWh Sales
The following tables summarize KCP&L’s gross margin and MWhs sold.
          
  %  %   % % 
2009Change2008Change2007
Gross Margin (a)
2010Change2009Change2008
Retail revenues(millions)(millions)
Residential$472.2  2 $463.0  7 $433.8 $564.5  20 $472.2  2 $463.0 
Commercial 542.7  4  521.1  6  492.1  604.3  11  542.7  4  521.1 
Industrial 108.8  (1) 109.9  3  106.8  122.8  13  108.8  (1) 109.9 
Other retail revenues 10.9  2  10.6  8  9.9  11.7  9  10.9  2  10.6 
Provision for rate refund (excess                              
Missouri wholesale margin) - NM  (2.9)NM  (1.1) (3.7)NA  - NA  (2.9)
Kansas ECA (over) under recovery (0.7)NM  1.6 NA  -  8.7 NM  (0.7)NM  1.6 
Total retail 1,133.9  3  1,103.3  6  1,041.5  1,308.3  15  1,133.9  3  1,103.3 
Wholesale revenues 166.2  (25) 221.5  (5) 234.0  188.9  14  166.2  (25) 221.5 
Other revenues 18.1  (1) 18.2  7  17.2  19.9  10  18.1  (1) 18.2 
KCP&L revenues$1,318.2  (2)$1,343.0  4 $1,292.7 
Operating revenues 1,517.1  15  1,318.2  (2) 1,343.0 
Fuel (278.8) 11  (251.3) (1) (253.3)
Purchased power (78.9) 11  (70.8) (40) (119.0)
Transmission of electricity by others (15.0) 22  (12.3) 11  (11.1)
Gross margin$1,144.4  16 $983.8  3 $959.6 
(a) Gross margin is a non-GAAP financial measure. See explanation of gross margin under Great
(a) Gross margin is a non-GAAP financial measure. See explanation of gross margin under Great
Plains Energy's Results of Operations.Plains Energy's Results of Operations.
                              
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  %  %    %  %  
2009Change2008Change2007
MWh Sales2010Change2009Change2008
Retail MWh sales(thousands)(thousands)
Residential 5,203  (4) 5,413  (3) 5,597  5,719  10  5,203  (4) 5,413 
Commercial 7,506  (3) 7,704  -  7,737  7,705  3  7,506  (3) 7,704 
Industrial 1,884  (9) 2,061  (5) 2,161  1,956  4  1,884  (9) 2,061 
Other retail MWh sales 88  9  80  (14) 92  87  -  88  9  80 
Total retail 14,681  (4) 15,258  (2) 15,587  15,467  5  14,681  (4) 15,258 
Wholesale MWh sales 5,381  7  5,030  (11) 5,635  6,051  12  5,381  7  5,030 
KCP&L MWh sales 20,062  (1) 20,288  (4) 21,222 
Total MWh sales 21,518  7  20,062  (1) 20,288 
                              
RetailKCP&L’s gross margin increased $160.6 million in 2010 compared to 2009 primarily due to the increase in retail revenues driven by new retail rates effective August 1, 2009, and September 1, 2009, for Kansas and Missouri, respectively, and favorable weather.
KCP&L’s retail MWhs sold in 2010 increased $30.6due to favorable weather, with a 2% increase in heating degree days and a 56% increase in cooling degree days.  Cooling degree days were 23% above normal based on a 30-year average.  Wholesale MWhs sold increased due to a 9% increase in generation resulting in more MWhs available for sale, partially offset by the higher retail load requirements.  The increase in generation was a result of Iatan No. 2 being placed in service during 2010 and Iatan No. 1 being off-line from January through mid-April 2009 to complete an environmental upgrade and unit overhaul, with the expenditures being capitalized and therefore not impacting operating and maintenance expenses.  As a result, KCP&L’s coal base load equivalent availability factor increased to 81% in 2010 compared to 79% in 2009.
KCP&L’s gross margin increased $24.2 million in 2009 compared to 2008 primarily due to new retail rates effective August 1, 2009, and September 1, 2009, for Kansas and Missouri, respectively, partially offset by a decline in weather-normalized customer usage driven by weakened economic conditions and unfavorable summer weather in 2009, with a 9% decrease in cooling degree days.  Cooling degrees days were 22% below normal based on a 30-year average.
 
Retail revenues increased $61.8 million in 2008 compared to 2007 primarily due to new retail rates effective January 1, 2008, partially offset by mild summer weather in 2008, with a 27% decrease in cooling degree days.
Wholesale revenues decreased $55.3 million in 2009 compared to 2008 due to a 38% decrease in the average market price per MWh to $28.92, primarily driven by lower natural gas prices.  This decrease was partially offset by a 7% increase in MWh sales as more MWhs were available for wholesale sales due to a 4% decrease in load requirements for retail sales.
Wholesale revenues decreased $12.5 million in 2008 compared to 2007 due to an 11% decrease in wholesale MWh sales resulting from less generation due to plant outages, partially offset by a 9% increase in the average market price per MWh to $46.34, primarily due to higher natural gas prices.
KCP&L Fuel and Purchased Power
           
   %  %  
 2009Change2008Change2007
Net MWhs Generated by Fuel Type(thousands) 
Coal 14,507  (1) 14,646  (2) 14,894 
Nuclear 4,121  3  3,994  (18) 4,873 
Natural gas and oil 229  (39) 378  (31) 544 
Wind 354  (16) 419  38  305 
Total Generation 19,211  (1) 19,437  (6) 20,616 
                
KCP&L’s coal base load equivalent availability factor for 2009 increased to 79% from 78% in 2008 and was 80% in 2007.

KCP&L’s nuclear unit, Wolf Creek, accounts for approximately 19% of its base load capacity.  Wolf Creek has scheduled refueling outages every 18 months.  The latest refueling outage began on October 10, 2009, and the unit came back on-line November 21, 2009.  Primarily as a result of the refueling outages in fall 2009 and spring 2008, the capacity and equivalent availability factor for Wolf Creek decreased to 86% in 2009 and 83% for 2008, compared to 100% in 2007 when Wolf Creek did not have a refueling outage.
Fuel expense decreased $2.0 million in 2009 compared to 2008 primarily due to changes in the fuel mix with more nuclear, which has a lower cost compared to other fuel types, and less coal and natural gas in the fuel mix.  Additionally, lower natural gas prices offset the impact of higher coal costs.
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Fuel expense increased $7.8 million in 2008 compared to 2007 primarily due to higher coal and coal transportation costs and less nuclear in the fuel mix.  These increases were partially offset by decreased MWhs generated primarily due to lower system requirements.
Purchased power expense decreased $48.2 million in 2009 compared to 2008 primarily due to a 50% decrease in the average price per MWh as a result of lower natural gas prices, partially offset by a 1% increase in MWh purchases and $6.9 million in recoveries from a litigation settlement in 2008.
Purchased power expense increased $18.0 million in 2008 compared to 2007 primarily due to a 26% increase in the average price per MWh as a result of higher natural gas prices.  Additionally, an 8% increase in MWh purchases due to the impact of plant outages in the first half of the year increased purchased power expense.  These increases were partially offset by $6.9 million in recoveries from a litigation settlement regarding a 2005 transformer failure.
KCP&L Other Operating Expenses (including operating and maintenance expenses, general taxes and other)
KCP&L’s other operating expenses increased $6.0$54.6 million in 2010 compared to 2009.  Plant operating and maintenance expenses increased $13.6 million in 2010 compared to 2009 primarily driven by planned plant outages, including the impact of outages in 2009 that included capitalizable improvements and therefore did not impact operating and maintenance expenses, partially offset by $7.5 million expensed in September 2009 after KCP&L exercised its option to terminate an agreement for the construction of a wind project.  The accounting effects of the KCC rate order increased other operating expenses $5.4 million in 2010.  General taxes increased $10.6 million in 2010 compared to 2009 driven by increased gross receipts taxes on increased retail revenues and increased property taxes.
Accounting rules state that when it becomes probable that part of the cost of a recently completed plant will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made, the estimated amount of the probable disallowance shall be deducted from the reported cost of the plant and recognized as a loss.  As a result of disallowances in the KCC order, KCP&L recognized Kansas jurisdictional losses of $4.4 million for construction costs related to Iatan No. 2 and $2.0 million for construction costs related to the Iatan No. 1 environmental project.  Management determined it is probable that the MPSC would disallow these costs as well in KCP&L’s pending rate case.  Therefore, KCP&L’s Missouri jurisdictional portion of these costs was recognized as a loss in addition to the KCP&L Kansas jurisdictional portion resulting in a $13.0 million loss for KCP&L’s construction costs incurred through December 31, 2010.
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KCP&L’s other operating expenses increased $4.8 million in 2009 compared to 2008 primarily due to increased employee-related costs and $7.5 million expensed in September 2009 after KCP&L exercised its option to terminate an agreement for the construction of a wind project.  These increases were partially offset by increased use of internal labor on capital projects as a result of more efficient operations as well as spending reductions and realized synergies from the GMO acquisition.
 
KCP&L’s other operating expenses increased $27.7 million in 2008 compared to 2007 primarily due to increased plant operations and maintenance expenses of $12.2 million due to plant outages, increased employee-related costs of $5.5 million, increased property taxes of $3.0 million due to higher assessments and higher mill levies and increased gross receipts tax expense of $2.1 million due to the increase in revenues.
KCP&L Skill Set Realignment
In 2007, KCP&L received authorization from the MPSC and KCC to establish $8.9 million in regulatory assets for costs originally expensed in 2006 related to a workforce realignment process and amortize them over five years for the Missouri jurisdictional portion and ten years for the Kansas jurisdictional portion effective with new rates on January 1, 2008.  Amortization of $1.4 million in 2009 and 2008 was recorded to utility operating and maintenance expense on KCP&L’s income statements.
KCP&L Depreciation and Amortization
KCP&L’s depreciation and amortization costs increased $26.8 million in 2010 compared to 2009 primarily due to $14.4 million of additional regulatory amortization pursuant to KCP&L’s 2009 rate cases.  The remaining increase was due to placing in service the Iatan No. 1 environmental equipment during 2009 and commencement of depreciation on Iatan No. 2 during 2010 (Kansas jurisdiction only), as well as normal depreciation activity for other capital additions.  KCP&L’s depreciation and amortization costs increased $25.3 million in 2009 compared to 2008 primarily due to $10.8 million of additional regulatory amortization pursuant to KCP&L’s 2009 rate case orders,cases, placing the Iatan No. 1 environmental project in service during 2009 and normal depreciation activity for capital additions.  KCP&L’s depreciation and amortization costs increased $28.7 million in 2008 compared to 2007 primarily due to additional amortization pursuant to rate case orders of $21.7 million combined with normal depreciation activity forother capital additions.
 
KCP&L Non-operating Income and Expenses
KCP&L’s non-operating income and expenses decreased $9.4 million in 2010 compared to 2009 primarily due to a decrease in the equity component of AFUDC resulting from a lower average construction work in progress balance due to KCP&L’s Comprehensive Energy Plan projects being placed in service.  KCP&L’s non-operating income and expenses increased $9.3 million in 2009 compared to 2008 primarily due to an increase in the equity component of AFUDC resulting from a higher average construction work in progress balance due to Comprehensive Energy Plan projects.  KCP&L’s non-operating income and expenses increased $14.9 million in 2008 compared to 2007 primarily due to an increase in the equity component of AFUDC resulting from a higher construction work in progress balance due to Comprehensive Energy Plan projects.

KCP&L Interest Charges
KCP&L’s interest charges increased $0.8 million in 2010 compared to 2009 primarily due to interest for a full year on $400.0 million of 7.15% Mortgage Bonds Series 2009A issued in March 2009 and a decrease in the debt component of AFUDC resulting from a lower average construction work in progress balance due to KCP&L’s Comprehensive Energy Plan projects being placed in service, mostly offset by the deferral to a regulatory asset of construction accounting carrying costs for Iatan No. 1, Iatan No. 2 and common facilities.  KCP&L’s interest charges increased $12.6 million in 2009 compared to 2008 primarily due to interest on $400.0 million of Mortgage Bonds Series 2009A issued in March 2009 and interest for a full year on $350.0 million of unsecured Senior Notes issued in March 2008, partially offset by decreased commercial paper outstanding, decreased rates on commercial paper and an increase in the debt component of AFUDC resulting from a higher construction work in progress balance due to Comprehensive Energy Plan projects.  KCP&L’s interest charges increased $5.1 million in 2008
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compared to 2007 primarily due to interest on $350.0 million of 6.375% unsecured Senior Notes issued in March 2008, partially offset by an increase in the debt component of AFUDC resulting from a higher construction work in progress balance due to Comprehensive Energy Plan projects.
 
KCP&L Income Tax Expense
KCP&L’s income tax expense increased $34.7 million in 2010 compared to 2009 primarily due to increased pre-tax income and a $2.8 million increase in income tax expense for the cumulative change in tax treatment of the Medicare Part D subsidy under the Federal health care reform legislation signed into law in the first quarter of 2010.
KCP&L’s income tax expense decreased $12.9 million in 2009 compared to 2008 primarily due to an increase in deferred tax balances in 2008 of $20.3 million as a result of an increase in the composite tax rate reflecting Great Plains Energy’s 2008 sale of Strategic Energy.  Additionally, 2008 reflected $6.7 million of allocated tax benefits from holding company losses.  The tax sharing agreement between Great Plains Energy and its subsidiaries was modified on July 14, 2008.  As part of the new agreement, parent company tax benefits are no longer allocated to KCP&L or other subsidiaries.
 
KCP&L’s income tax expense increased $0.5 million in 2008 compared to 2007 primarily due to an increase of $20.3 million as a result of an increase in the composite tax rate reflecting Great Plains Energy’s sale of Strategic Energy, mostly offset by decreased pre-tax income and increased wind credits.  See Note 22 to the consolidated financial statements for a reconciliation of effective income tax rates for the periods.
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ITEM 7A.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
 
In the ordinary course of business, Great Plains Energy and KCP&L face risks that are either non-financial or non-quantifiable.  Such risks principally include business, legal, operations and credit risks and are not represented in the following analysis.  See Item 1A. Risk Factors and Item 7. MD&A for further discussion of risk factors.
 
Great Plains Energy and KCP&L are exposed to market risks associated with commodity price and supply, interest rates and equity prices.  Management has established risk management policies and strategies to reduce the potentially adverse effects the volatility of the markets may have on its operating results.  During the ordinary course of business, under the direction and control of an internal risk management committee, Great Plains Energy’s and KCP&L’s hedging strategies are reviewed to determine the hedging approach deemed appropriate based upon the circumstances of each situation.  Though management believes its risk management practices to beare effective, it is not possible to identify and eliminate all risk.  Great Plains Energy and KCP&L could experience losses, which could have a material adverse effect on its results of operations or financial position, due to many factors, including among others, unexpectedly large or rapid movements or disruptions in the energy markets, from regulatory-driven market rule changes and/or bankruptcy or non-performance of customers or counterparties, and/or failure of underlying transactions that have been hedged to materialize.
 
Hedging Strategies
Derivative instruments are frequently utilized to execute risk management and hedging strategies.  Derivative instruments, such as futures, forward contracts, swaps or options, derive their value from underlying assets, indices, reference rates or a combination of these factors.  These derivative instruments include negotiated contracts, which are referred to as over-the-counter derivatives, and instruments listed and traded on an exchange.
 
Interest Rate Risk
Great Plains Energy and KCP&L manage interest expense and short and long-term liquidity through a combination of fixed and variable rate debt.  Generally, the amount of each type of debt is managed through market issuance, but interest rate swap and cap agreements with highly rated financial institutions may also be used to achieve the desired combination.  At December 31, 2009,2010, less than 1% and none, respectively, of Great Plains Energy’s and KCP&L’s long-term debt was variable rate debt.  KCP&L had no variable rate long-term debt at December 31, 2010.  Interest rates impact the fair value of long-term debt.  A change in interest rates would impact Great Plains Energy and KCP&L to the extent they redeemed any of their outstanding long-term debt.  Great Plains Energy’s and KCP&L’s book values of long-term debt were each below fair value by 6%8% and 9%, respectively, at December 31, 2009.2010.
 
Great Plains Energy had $252.0$9.5 million of notes payable outstanding at December 31, 2009.2010.  The principal amount of the notes payable, which will vary during the year, drives Great Plains Energy’s notes payable interest
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expense.  Assuming that $252.0$9.5 million of notes payable was outstanding for all of 2010,2011, a hypothetical 10% increase in interest rates associated with short-term variable rate debt would result in an immaterial increase of $0.4 million in interest expense for 2010.2011.
 
KCP&L had $186.6$263.5 million of commercial paper outstanding at December 31, 2009.2010.  The principal amount of the commercial paper, which will vary during the year, drives KCP&L’s commercial paper interest expense.  Assuming that $186.6$263.5 million of commercial paper was outstanding for all of 2010,2011, a hypothetical 10% increase in commercial paper rates would result in an immaterial increase of $0.1 million in interest expense for 2010.2011.  Assuming that $263.5 million of commercial paper was outstanding for all of 2011, a hypothetical 100 basis point increase in commercial paper rates would result in a $2.6 million increase in interest expense for 2011.
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Commodity Risk
Great Plains Energy and KCP&L engage in the wholesale and retail marketing of electricity and are exposed to risk associated with the price of electricity and commodities.electricity.  Exposure to these risks is affected by a number of factors including the quantity and availability of fuel used for generation and the quantity of electricity customers consume.  Customers'Customers’ electricity usage could also vary from year to year based on the weather or other factors.  Quantities of fossil fuel used for generation vary from year to year based on the availability, price and deliverability of a given fuel type as well as planned and scheduled outages at facilities that use fossil fuels.
 
KCP&L's wholesale operations include the physical delivery and marketing of power obtained through its generation capacity and long, intermediate and short-term capacity or power purchase agreements.  The agreements contain penalties for non-performance to limit KCP&L’s energy price risk on the contracted energy.capacity.  KCP&L also enters into additional power purchase agreementstransactions with the objective of obtaining the most economical energy to meet its physical delivery obligations to customers.  KCP&L is required to maintain a capacity margin of at least 12% of its peak summer demand.  This net positive supply of capacity and energy is maintained through itsKCP&L’s generation assets and capacity and power purchase agreements to protect itKCP&L from the potential operational failure of one of its power generating units.  KCP&L continually evaluates the need for additional risk mitigation measures in order to minimize its financial exposure to, among other things, spikes in wholesale power prices during periods of high demand.
 
KCP&L's sales include the sales of electricity to its retail customers and bulk power sales of electricity in the wholesale market.  KCP&L continually evaluates its system requirements, the availability of generating units, availability and cost of fuel supply, the availability and cost of purchased power and the requirements of other electric systems; therefore, the impact of the hypothetical amounts that follow could be significantly reduced depending on the system requirements and market prices at the time of the increases.  A hypothetical 10% increase in the market price of power could result in a $2.3$0.7 million increasedecrease in operating income for 2011 related to purchased power expense for 2010.power.  In 2010,2011, approximately 75%78% of KCP&L’s net MWhs generated are expected to be coal-fired.  KCP&L currently has 94%81% of its coal requirements for 20102011 under contract.  A hypothetical 10% increase in the market price of coal could result in less than a $1.9$6.5 million increase in fuel expense for 2010.2011.  KCP&L has also implemented price risk mitigation measures to reduce its exposure to high natural gas prices.  A hypothetical 10% increase in natural gas and oil market prices could result in an increase of $0.1 million in fuel expense for 2010.2011.  At December 31, 2009,2010, KCP&L had hedged approximately 68%66%, 45% and 11%22% of its 20102011, 2012 and 2011, respectively, projected natural gas usage for generation requirements to serve retail load and firm MWh sales.  At December 31, 2008, KCP&L had hedged approximately 31% and 3% of its 2009 and 2010,2013, respectively, projected natural gas usage for generation requirements to serve retail load and firm MWh sales.  KCP&L’s Kansas ECA allows for the recovery of increased fuel and purchased power costs from Kansas retail customers.  KCP&L’s Missouri retail rates do not contain a fuel recovery mechanism, meaning that changes in fuel costs will not be reflected in rates until new rates are authorized by the MPSC creatingcreate a regulatory lag between the time costs change and when they are reflected in rates.lag.
 
In the GMO regulated electric operations in 2009,2010, approximately 60%59% of the power sold was generated and the remaining 40%41% was purchased through long-term contracts or in the open market.  GMO has aan FAC that allows itGMO to adjust retail electric rates based on 95% of the difference between actual fuel and purchased power costs and the amount of fuel and purchased power costs provided in base rates.
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Several measures have been taken to mitigate commodity price risk exposure in GMO’s electric utility operations.  One of these measures is contracting for a diverse supply of coal to meet 80%78% and 37%49% of its 20102011 and 2011,2012, respectively, native load fuel requirements of coal-fired generation.  The price risk associated with natural gas and on-peak spot market purchased power requirements is also mitigated through a hedging plan using New York Mercantile Exchange (NYMEX) futures contracts and options.  AsA hypothetical 10% increase in natural gas  market prices could result in an increase of $1.1 million in fuel expense for 2011.  At December 31, 2009,2010, GMO had financial contracts in place to hedge approximately 55%67%, 45% and 3%38% of expected on-peak natural gas and natural gas equivalent purchased power price exposure for 20102011, 2012 and 2011,2013, respectively.  The mark-to-market value of these contracts at December 31, 2009,2010, was a liability of $0.9$2.5 million.
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Credit Risk – MPS Merchant
MPS Merchant is exposed to credit risk.  Credit risk is measured by the loss that would be recorded if counterparties failed to perform pursuant to the terms of the contractual obligations less the value of any collateral held.  MPS Merchant’s counterparties are not externally rated.  Credit exposure to counterparties at December 31, 2009,2010, was $29.5 million, net of $2.0 million of collateral.$21.0 million.
 
Investment Risk
KCP&L maintains trust funds, as required by the NRC, to fund its share of decommissioning the Wolf Creek nuclear power plant.  As of December 31, 2009,2010, these funds were invested primarily in domestic equity securities and fixed income securities and are reflected at fair value on KCP&L’s balance sheets.  The mix of securities is designed to provide returns to be used to fund decommissioning and to compensate for inflationary increases in decommissioning costs; however, the equity securities in the trusts are exposed to price fluctuations in equity markets and the value of fixed rate fixed income securities are exposed to changes in interest rates.  A hypothetical increase in interest rates resulting in a hypothetical 10% decrease in the value of the fixed income securities would have resulted in a $3.7$4.1 million reduction in the value of the decommissioning trust funds at December 31, 2009.2010.  A hypothetical 10% decrease in equity prices would have resulted in a $4.5an $8.5 million reduction in the fair value of the equity securities at December 31, 2009.  At December 31, 2009, KCP&L was also holding short-term investments in the decommissioning trust fund, which were invested in equity securities in early 2010.  KCP&L's exposure to investment risk associated with the decommissioning trust funds is in large part mitigated due to the fact that KCP&L is currently allowed to recover its decommissioning costs in its rates.  If the actual return on trust assets is below the anticipated level, KCP&L could be responsible for the balance of funds required to decommission Wolf Creek; 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.
 
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
  Page
  Number
Great Plains Energy Incorporated 
Consolidated Statements of Income5354
Consolidated Balance Sheets5455
Consolidated Statements of Cash Flows5657
Consolidated Statements of Common Shareholders’ Equity5758
Consolidated Statements of Comprehensive Income5859
 
    
Kansas City Power & Light Company 
Consolidated Statements of Income5960
Consolidated Balance Sheets6061
Consolidated Statements of Cash Flows6263
Consolidated Statements of Common Shareholder’s Equity6364
Consolidated Statements of Comprehensive Income6465
 
    
Combined Notes to Consolidated Financial Statements for Great Plains Energy Incorporated
 and Kansas City Power & Light Company
 
Note 1:Summary of Significant Accounting Policies6566
Note 2:    GMO Acquisition71
Note 3:    Supplemental Cash Flow Information7472
Note 4:    3:Receivables7674
Note 5:    4:Assets Held For Sale7775
Note 6:    5:Nuclear Plant7875
Note 7:    6:Regulatory Matters8178
Note 8:7:Goodwill and Intangible Assets8583
Note 9:    8:Asset Retirement Obligations8584
Note 10:  9:Pension Plans and Other Employee Benefits and Skill Set Realignment Costs8685
Note 11:  10:Equity Compensation9394
Note 12:  11:Short-Term Borrowings and Short-Term Bank Lines of Credit9798
Note 13:  12:Long-Term Debt9899
Note 14:  13:Common Shareholders’ Equity101102
Note 15:  14:Preferred Stock102103
Note 16:  15:Commitments and Contingencies102103
Note 17:  16:Legal Proceedings111114
Note 18:  17:Guarantees113115
Note 19:  18:Related Party Transactions and Relationships114116
Note 20:  19:Derivative Instruments114117
Note 21:  20:Fair Value Measurements120122
Note 22:  21:Taxes124128
Note 23:  22:Segments and Related Information130133
Note 24:  23:Discontinued Operations132134
Note 25:  24:Jointly Owned Electric Utility Plants133135
Note 26:  New Accounting Standards133
Note 27:  25:Quarterly Operating Results (Unaudited)134136
 
    
Report of Independent Registered Public Accounting Firm
 
Great Plains Energy Incorporated135137
 
Kansas City Power & Light Company136138
 
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GREAT PLAINS ENERGY INCORPORATED 
Consolidated Statements of Income 
  
          
Year Ended December 31 2009 2008 2007
Operating Revenues (millions, except per share amounts)
Electric revenues $1,965.0  $1,670.1  $1,292.7 
Operating Expenses            
Fuel  405.5   311.4   245.5 
Purchased power  183.7   208.9   101.0 
Utility operating and maintenance expenses  599.3   499.7   387.5 
Skill set realignment deferral (Note 10)  -   -   (8.9)
Depreciation and amortization  302.2   235.0   175.6 
General taxes  139.8   128.1   114.4 
Other  14.4   12.0   21.1 
Total  1,644.9   1,395.1   1,036.2 
Operating income  320.1   275.0   256.5 
Non-operating income  49.5   31.9   8.8 
Non-operating expenses  (6.9)  (10.8)  (5.6)
Interest charges  (180.9)  (111.3)  (91.9)
Income from continuing operations before income tax expense and            
loss from equity investments  181.8   184.8   167.8 
Income tax expense  (29.5)  (63.8)  (44.9)
Loss from equity investments, net of income taxes  (0.4)  (1.3)  (2.0)
Income from continuing operations  151.9   119.7   120.9 
Income (loss) from discontinued operations, net of income taxes (Note 24)  (1.5)  35.0   38.3 
Net income  150.4   154.7   159.2 
Less:  Net income attributable to noncontrolling interest  (0.3)  (0.2)  - 
Net income attributable to Great Plains Energy  150.1   154.5   159.2 
Preferred stock dividend requirements  1.6   1.6   1.6 
Earnings available for common shareholders $148.5  $152.9  $157.6 
             
Average number of basic common shares outstanding  129.3   101.1   84.9 
Average number of diluted common shares outstanding  129.8   101.2   85.2 
             
Basic earnings (loss) per common share            
Continuing operations $1.16  $1.16  $1.41 
Discontinued operations  (0.01)  0.35   0.45 
Basic earnings per common share $1.15  $1.51  $1.86 
             
Diluted earnings (loss) per common share            
Continuing operations $1.15  $1.16  $1.40 
Discontinued operations  (0.01)  0.35   0.45 
Diluted earnings per common share $1.14  $1.51  $1.85 
             
Cash dividends per common share $0.83  $1.66  $1.66 
             
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.     
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GREAT PLAINS ENERGY INCORPORATED
Consolidated Balance Sheets
     
     
 December 31
 20092008
ASSETS(millions, except share amounts)
Current Assets    
Cash and cash equivalents$65.9 $61.1 
Funds on deposit 4.4  10.8 
Receivables, net 230.5  242.3 
Fuel inventories, at average cost 85.0  87.0 
Materials and supplies, at average cost 121.3  99.3 
Deferred refueling outage costs 19.5  12.4 
Refundable income taxes 13.5  26.0 
Deferred income taxes 36.8  28.6 
Assets held for sale (Note 5) 19.4  16.3 
Derivative instruments 1.5  4.8 
Prepaid expenses and other assets 14.7  15.2 
Total 612.5  603.8 
Utility Plant, at Original Cost      
Electric 8,849.0  7,940.8 
Less-accumulated depreciation 3,774.5  3,582.5 
Net utility plant in service 5,074.5  4,358.3 
Construction work in progress 1,508.4  1,659.1 
Nuclear fuel, net of amortization of $106.0 and $110.8 68.2  63.9 
Total 6,651.1  6,081.3 
Investments and Other Assets      
Affordable housing limited partnerships 13.2  13.9 
Nuclear decommissioning trust fund 112.5  96.9 
Regulatory assets 822.2  824.8 
Goodwill 169.0  156.0 
Derivative instruments 7.9  13.0 
Other 94.4  79.6 
Total 1,219.2  1,184.2 
Total$8,482.8 $7,869.3 
       
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
GREAT PLAINS ENERGY INCORPORATED
Consolidated Statements of Income
       
       
Year Ended December 31201020092008
Operating Revenues(millions, except per share amounts)
Electric revenues$2,255.5 $1,965.0 $1,670.1 
Operating Expenses         
Fuel 430.7  405.5  311.4 
Purchased power 213.8  183.7  208.9 
Transmission of electricity by others 27.4  26.9  22.5 
Utility operating and maintenance expenses 602.5  572.4  477.2 
Depreciation and amortization 331.6  302.2  235.0 
General taxes 155.1  139.8  128.1 
Other 22.1  14.4  12.0 
Total 1,783.2  1,644.9  1,395.1 
Operating income 472.3  320.1  275.0 
Non-operating income 43.9  49.5  31.9 
Non-operating expenses (19.5) (6.9) (10.8)
Interest charges (184.8) (180.9) (111.3)
Income from continuing operations before income tax expense and         
loss from equity investments 311.9  181.8  184.8 
Income tax expense (99.0) (29.5) (63.8)
Loss from equity investments, net of income taxes (1.0) (0.4) (1.3)
Income from continuing operations 211.9  151.9  119.7 
Income (loss) from discontinued operations, net of income taxes (Note 23) -  (1.5) 35.0 
Net income 211.9  150.4  154.7 
Less:  Net income attributable to noncontrolling interest (0.2) (0.3) (0.2)
Net income attributable to Great Plains Energy 211.7  150.1  154.5 
Preferred stock dividend requirements 1.6  1.6  1.6 
Earnings available for common shareholders$210.1 $148.5 $152.9 
          
Average number of basic common shares outstanding 135.1  129.3  101.1 
Average number of diluted common shares outstanding 136.9  129.8  101.2 
          
Basic earnings (loss) per common share         
Continuing operations$1.55 $1.16 $1.16 
Discontinued operations -  (0.01) 0.35 
Basic earnings per common share$1.55 $1.15 $1.51 
          
Diluted earnings (loss) per common share         
Continuing operations$1.53 $1.15 $1.16 
Discontinued operations -  (0.01) 0.35 
Diluted earnings per common share$1.53 $1.14 $1.51 
          
Cash dividends per common share$0.83 $0.83 $1.66 
          
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
 
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GREAT PLAINS ENERGY INCORPORATED
Consolidated Balance Sheets
     
     
 December 31
 20092008
LIABILITIES AND CAPITALIZATION(millions, except share amounts)
Current Liabilities    
Notes payable$252.0 $204.0 
Commercial paper 186.6  380.2 
Current maturities of long-term debt 1.3  70.7 
Accounts payable 315.0  418.0 
Accrued taxes 27.9  27.7 
Accrued interest 72.5  72.4 
Accrued compensation and benefits 45.1  29.7 
Pension and post-retirement liability 4.6  4.7 
Derivative instruments 0.3  86.2 
Other 53.0  43.8 
Total 958.3  1,337.4 
Deferred Credits and Other Liabilities      
Deferred income taxes 381.9  387.1 
Deferred tax credits 140.5  105.5 
Asset retirement obligations 132.6  124.3 
Pension and post-retirement liability 440.4  445.6 
Regulatory liabilities 237.8  209.4 
Derivative instruments 0.5  - 
Other 145.1  112.8 
Total 1,478.8  1,384.7 
Capitalization      
Great Plains Energy common shareholders' equity      
Common stock-250,000,000 shares authorized without par value      
135,636,538 and 119,375,923 shares issued, stated value 2,313.7  2,118.4 
Retained earnings 529.2  489.3 
Treasury stock-213,423 and 120,677 shares, at cost (5.5) (3.6)
Accumulated other comprehensive loss (44.9) (53.5)
Total 2,792.5  2,550.6 
Noncontrolling interest 1.2  1.0 
Total 2,793.7  2,551.6 
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 (Note 13) 3,213.0  2,556.6 
Total 6,045.7  5,147.2 
Commitments and Contingencies (Note 16)      
Total$8,482.8 $7,869.3 
       
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
  
GREAT PLAINS ENERGY INCORPORATED
Consolidated Balance Sheets
     
     
 December 31
 20102009
ASSETS(millions, except share amounts)
Current Assets    
Cash and cash equivalents$10.8 $65.9 
Funds on deposit 5.2  4.4 
Receivables, net 241.7  230.5 
Accounts receivable pledged as collateral 95.0  - 
Fuel inventories, at average cost 85.1  85.0 
Materials and supplies, at average cost 132.8  121.3 
Deferred refueling outage costs 9.6  19.5 
Refundable income taxes 2.1  13.5 
Deferred income taxes 14.3  36.8 
Assets held for sale (Note 4) -  19.4 
Derivative instruments 1.1  1.5 
Prepaid expenses and other assets 13.9  14.7 
Total 611.6  612.5 
Utility Plant, at Original Cost      
Electric 10,536.9  8,849.0 
Less-accumulated depreciation 4,031.3  3,774.5 
Net utility plant in service 6,505.6  5,074.5 
Construction work in progress 307.5  1,508.4 
Nuclear fuel, net of amortization of $131.1 and $106.0 79.2  68.2 
Total 6,892.3  6,651.1 
Investments and Other Assets      
Affordable housing limited partnerships 0.3  13.2 
Nuclear decommissioning trust fund 129.2  112.5 
Regulatory assets 924.0  822.2 
Goodwill 169.0  169.0 
Derivative instruments 7.8  7.9 
Other 84.0  94.4 
Total 1,314.3  1,219.2 
Total$8,818.2 $8,482.8 
       
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 
 
55
 
GREAT PLAINS ENERGY INCORPORATED
Consolidated Statements of Cash Flows
         
         
Year Ended December 312009 2008 2007
Cash Flows from Operating Activities(millions)
Net income$150.4 $154.7 $159.2 
Adjustments to reconcile income to net cash from operating activities:         
Depreciation and amortization 302.2  238.3  183.8 
Amortization of:         
Nuclear fuel 16.1  14.5  16.8 
Other (10.1) (1.9) 7.4 
Deferred income taxes, net (3.6) 44.1  23.8 
Investment tax credit amortization (2.2) (1.8) (1.5)
Loss from equity investments, net of income taxes 0.4  1.3  2.0 
Fair value impacts from interest rate hedging -  9.2  17.9 
Fair value impacts from energy contracts - Strategic Energy -  (189.1) (52.8)
Loss on sale of Strategic Energy -  116.2  - 
Other operating activities (Note 3) (117.8) 52.4  (24.4)
Net cash from operating activities 335.4  437.9  332.2 
Cash Flows from Investing Activities         
Utility capital expenditures (841.1) (1,023.7) (511.5)
Allowance for borrowed funds used during construction (37.7) (31.7) (14.4)
Payment to Black Hills for asset sale working capital adjustment (7.7) -  - 
Proceeds from sale of Strategic Energy, net of cash sold -  218.8  - 
GMO acquisition, net cash received -  271.9  - 
Purchases of nuclear decommissioning trust investments (99.0) (49.1) (58.0)
Proceeds from nuclear decommissioning trust investments 95.3  45.4  54.3 
Other investing activities (7.4) (10.7) (17.4)
Net cash from investing activities (897.6) (579.1) (547.0)
Cash Flows from Financing Activities         
Issuance of common stock 219.9  15.3  10.5 
Issuance of long-term debt 700.7  363.4  495.6 
Issuance fees (22.8) (5.3) (5.7)
Repayment of long-term debt (70.7) (169.9) (372.5)
Net change in short-term borrowings (145.6) 118.4  251.4 
Dividends paid (110.5) (172.0) (144.5)
Credit facility termination fees -  (12.5) - 
Equity forward settlement -  -  (12.3)
Other financing activities (4.0) (2.2) (2.4)
Net cash from financing activities 567.0  135.2  220.1 
Net Change in Cash and Cash Equivalents 4.8  (6.0) 5.3 
Cash and Cash Equivalents at Beginning of Year (includes $43.1 million
         
and $45.8 million of cash included in assets of discontinued operations in         
2008 and 2007, respectively) 61.1  67.1  61.8 
Cash and Cash Equivalents at End of Year (includes $43.1 million of cash
         
included in assets of discontinued operations in 2007)$65.9 $61.1 $67.1 
          
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
  
GREAT PLAINS ENERGY INCORPORATED
Consolidated Balance Sheets
     
     
 December 31
 20102009
LIABILITIES AND CAPITALIZATION(millions, except share amounts)
Current Liabilities    
Notes payable$9.5 $252.0 
Collateralized note payable 95.0  - 
Commercial paper 263.5  186.6 
Current maturities of long-term debt 485.7  1.3 
Accounts payable 276.3  315.0 
Accrued taxes 26.6  27.9 
Accrued interest 75.4  72.5 
Accrued compensation and benefits 46.8  45.1 
Pension and post-retirement liability 4.1  4.6 
Derivative instruments 20.8  0.3 
Other 35.6  53.0 
Total 1,339.3  958.3 
Deferred Credits and Other Liabilities      
Deferred income taxes 518.3  381.9 
Deferred tax credits 133.4  140.5 
Asset retirement obligations 143.3  132.6 
Pension and post-retirement liability 427.5  440.4 
Regulatory liabilities 258.2  237.8 
Derivative instruments -  0.5 
Other 129.4  145.1 
Total 1,610.1  1,478.8 
Capitalization      
Great Plains Energy common shareholders' equity      
Common stock-250,000,000 shares authorized without par value      
136,113,954 and 135,636,538 shares issued, stated value 2,324.4  2,313.7 
Retained earnings 626.5  529.2 
Treasury stock-400,889 and 213,423 shares, at cost (8.9) (5.5)
Accumulated other comprehensive loss (56.1) (44.9)
Total 2,885.9  2,792.5 
Noncontrolling interest 1.2  1.2 
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 (Note 12) 2,942.7  3,213.0 
Total 5,868.8  6,045.7 
Commitments and Contingencies (Note 15)      
Total$8,818.2 $8,482.8 
       
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 
 
56
 
GREAT PLAINS ENERGY INCORPORATED
Consolidated Statements of Common Shareholders' Equity
              
              
Year Ended December 31 200920082007
  SharesAmountSharesAmountSharesAmount
Common Stock (millions, except share amounts)
Beginning balance 119,375,923 $2,118.4  86,325,136 $1,065.9  80,405,035 $896.8 
Issuance of common stock 15,883,948  220.1  32,962,723  1,042.0  5,571,574  174.1 
Common stock issuance fees -  (7.0) -  -  -  - 
Issuance of restricted common stock 376,667  5.4  88,064  2.3  348,527  11.1 
Equity compensation expense, net of forfeitures    0.8     5.9     2.1 
Equity forward settlement    -     -     (12.3)
Unearned Compensation                  
Issuance of restricted common stock    (5.4)    (2.3)    (11.1)
Forfeiture of restricted common stock    1.1     -     0.2 
Compensation expense recognized    3.8     5.6     4.8 
Equity Units allocated fees and expenses and the                
present value of contract adjustment payments    (22.5)    -     - 
Other    (1.0)    (1.0)    0.2 
Ending balance 135,636,538  2,313.7  119,375,923  2,118.4  86,325,136  1,065.9 
Retained Earnings                  
Beginning balance    489.3     506.9     493.4 
Cumulative effect of a change in accounting principle  -     (0.1)    (0.9)
Net income attributable to Great Plains Energy    150.1     154.5     159.2 
Dividends:                  
Common stock    (108.9)    (170.4)    (142.9)
Preferred stock - at required rates    (1.6)    (1.6)    (1.6)
Performance shares    (0.1)    -     (0.3)
Performance shares amendment    0.4     -     - 
Ending balance    529.2     489.3     506.9 
Treasury Stock                  
Beginning balance (120,677) (3.6) (90,929) (2.8) (53,499) (1.6)
Treasury shares acquired (132,593) (2.9) (39,856) (1.1) (37,430) (1.2)
Treasury shares reissued 39,847  1.0  10,108  0.3  -  - 
Ending balance (213,423) (5.5) (120,677) (3.6) (90,929) (2.8)
Accumulated Other Comprehensive Income (Loss)                
Beginning balance    (53.5)    (2.1)    (46.7)
Derivative hedging activity, net of tax    5.3     (47.5)    43.2 
Change in unrecognized pension expense, net of tax  3.3     (3.9)    1.4 
Ending balance    (44.9)    (53.5)    (2.1)
Total Great Plains Energy Common Shareholders' Equity  2,792.5     2,550.6     1,567.9 
Noncontrolling Interest                  
Beginning balance    1.0     -     - 
GMO acquisition July 14, 2008    -     0.8       
Net income attributable to noncontrolling interest  0.3     0.2     - 
Distribution    (0.1)    -     - 
Ending balance    1.2     1.0     - 
Total   $2,793.7    $2,551.6    $1,567.9 
 
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
GREAT PLAINS ENERGY
Consolidated Statements of Cash Flows
       
       
Year Ended December 31201020092008
Cash Flows from Operating Activities(millions)
Net income$211.9 $150.4 $154.7 
Adjustments to reconcile income to net cash from operating activities:       
Depreciation and amortization 331.6  302.2  238.3 
Amortization of:         
Nuclear fuel 25.1  16.1  14.5 
Other (4.7) (10.1) (1.9)
Deferred income taxes, net 123.8  (3.6) 44.1 
Investment tax credit amortization (2.9) (2.2) (1.8)
Loss from equity investments, net of income taxes 1.0  0.4  1.3 
Fair value impacts from interest rate hedging -  -  9.2 
Fair value impacts from energy contracts - Strategic Energy -  -  (189.1)
Loss on sale of Strategic Energy -  -  116.2 
Other operating activities (Note 2) (133.7) (117.8) 52.4 
Net cash from operating activities 552.1  335.4  437.9 
Cash Flows from Investing Activities         
Utility capital expenditures (618.0) (841.1) (1,023.7)
Allowance for borrowed funds used during construction (28.5) (37.7) (31.7)
Payment to Black Hills for asset sale working capital adjustment -  (7.7) - 
Proceeds from sale of Strategic Energy, net of cash sold -  -  218.8 
GMO acquisition, net cash received -  -  271.9 
Purchases of nuclear decommissioning trust investments (83.3) (99.0) (49.1)
Proceeds from nuclear decommissioning trust investments 79.6  95.3  45.4 
Other investing activities (7.5) (7.4) (10.7)
Net cash from investing activities (657.7) (897.6) (579.1)
Cash Flows from Financing Activities         
Issuance of common stock 6.2  219.9  15.3 
Issuance of long-term debt 249.9  700.7  363.4 
Issuance fees (12.1) (22.8) (5.3)
Repayment of long-term debt (1.3) (70.7) (169.9)
Net change in short-term borrowings (165.6) (145.6) 118.4 
Net change in collateralized short-term borrowings 95.0  -  - 
Dividends paid (114.2) (110.5) (172.0)
Credit facility termination fees -  -  (12.5)
Other financing activities (7.4) (4.0) (2.2)
Net cash from financing activities 50.5  567.0  135.2 
Net Change in Cash and Cash Equivalents (55.1) 4.8  (6.0)
Cash and Cash Equivalents at Beginning of Year (includes $43.1 million
       
in assets of discontinued operations in 2008) 65.9  61.1  67.1 
Cash and Cash Equivalents at End of Year$10.8 $65.9 $61.1 
          
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 
 
57
 
GREAT PLAINS ENERGY INCORPORATED
Consolidated Statements of Comprehensive Income
       
       
       
       
Year Ended December 31200920082007
 (millions)
Net income$150.4 $154.7 $159.2 
Other comprehensive income (loss)         
Gain (loss) on derivative hedging instruments (0.4) 27.0  (8.4)
Income tax benefit (expense) 0.1  (12.5) 2.4 
Net gain (loss) on derivative hedging instruments (0.3) 14.5  (6.0)
Reclassification to expenses, net of tax (Note 20) 5.6  (62.0) 49.2 
Derivative hedging activity, net of tax 5.3  (47.5) 43.2 
Defined benefit pension plans         
Net gain (loss) arising during period 5.0  (6.7) 2.0 
Less:  amortization of net gain included in net         
periodic benefit costs 0.4  0.3  0.4 
Prior service costs arising during the period -  -  (0.3)
Less:  amortization of prior service costs included in net         
periodic benefit costs -  0.1  0.1 
Income tax benefit (expense) (2.1) 2.4  (0.8)
Net change in unrecognized pension expense 3.3  (3.9) 1.4 
Comprehensive income 159.0  103.3  203.8 
Less:  comprehensive income attributable to noncontrolling interest (0.3) (0.2) - 
Comprehensive income attributable to Great Plains Energy$158.7 $103.1 $203.8 
          
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
GREAT PLAINS ENERGY INCORPORATED
Consolidated Statements of Common Shareholders' Equity and Noncontrolling Interest
             
             
Year Ended December 31201020092008
 SharesAmountSharesAmountSharesAmount
Common Stock(millions, except share amounts)
Beginning balance 135,636,538 $2,313.7  119,375,923 $2,118.4  86,325,136 $1,065.9 
Issuance of common stock 347,279  6.6  15,883,948  220.1  32,962,723  1,042.0 
Common stock issuance fees -  -  -  (7.0) -  - 
Issuance of restricted common stock 130,137  2.3  376,667  5.4  88,064  2.3 
Equity compensation expense, net of forfeitures    1.0     0.8     5.9 
Unearned Compensation                  
Issuance of restricted common stock    (2.3)    (5.4)    (2.3)
Forfeiture of restricted common stock    0.8     1.1     - 
Compensation expense recognized    2.2     3.8     5.6 
Equity Units allocated fees and expenses and the                  
present value of contract adjustment payments    -     (22.5)    - 
Other    0.1     (1.0)    (1.0)
Ending balance 136,113,954  2,324.4  135,636,538  2,313.7  119,375,923  2,118.4 
Retained Earnings                  
Beginning balance    529.2     489.3     506.9 
Cumulative effect of a change in accounting principle  -     -     (0.1)
Net income attributable to Great Plains Energy    211.7     150.1     154.5 
Dividends:                  
Common stock    (112.6)    (108.9)    (170.4)
Preferred stock - at required rates    (1.6)    (1.6)    (1.6)
Performance shares    (0.2)    (0.1)    - 
Performance shares amendment    -     0.4     - 
Ending balance    626.5     529.2     489.3 
Treasury Stock                  
Beginning balance (213,423) (5.5) (120,677) (3.6) (90,929) (2.8)
Treasury shares acquired (188,383) (3.4) (132,593) (2.9) (39,856) (1.1)
Treasury shares reissued 917  -  39,847  1.0  10,108  0.3 
Ending balance (400,889) (8.9) (213,423) (5.5) (120,677) (3.6)
Accumulated Other Comprehensive Income (Loss)                
Beginning balance    (44.9)    (53.5)    (2.1)
Derivative hedging activity, net of tax    (10.6)    5.3     (47.5)
Change in unrecognized pension expense, net of tax  (0.6)    3.3     (3.9)
Ending balance    (56.1)    (44.9)    (53.5)
Total Great Plains Energy Common Shareholders' Equity $2,885.9    $2,792.5    $2,550.6 
                   
Noncontrolling Interest                  
Beginning balance   $1.2    $1.0    $- 
GMO acquisition July 14, 2008    -     -     0.8 
Net income attributable to noncontrolling interest  0.2     0.3     0.2 
Distribution (0.2)    (0.1)    - 
Ending balance   $1.2    $1.2    $1.0 
 
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
 
58
 



KANSAS CITY POWER & LIGHT COMPANY
 
Consolidated Statements of Income 
          
          
Year Ended December 31 2009 2008 2007
Operating Revenues (millions) 
Electric revenues $1,318.2  $1,343.0  $1,292.7 
Operating Expenses            
Fuel  251.3   253.3   245.5 
Purchased power  70.8   119.0   101.0 
Operating and maintenance expenses  415.6   409.2   386.7 
Skill set realignment deferral (Note 10)  -   -   (8.9)
Depreciation and amortization  229.6   204.3   175.6 
General taxes  118.7   118.9   113.7 
Other  -   0.2   0.2 
Total  1,086.0   1,104.9   1,013.8 
Operating income  232.2   238.1   278.9 
Non-operating income  33.2   25.9   8.0 
Non-operating expenses  (4.7)  (6.7)  (3.7)
Interest charges  (84.9)  (72.3)  (67.2)
Income before income tax expense  175.8   185.0   216.0 
Income tax expense  (46.9)  (59.8)  (59.3)
Net income $128.9  $125.2  $156.7 
             
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial
Statements are an integral part of these statements.
GREAT PLAINS ENERGY INCORPORATED
Consolidated Statements of Comprehensive Income
       
       
       
       
Year Ended December 31201020092008
 (millions)
Net income$211.9 $150.4 $154.7 
Other comprehensive income (loss)         
Gain (loss) on derivative hedging instruments (28.0) (0.4) 27.0 
Income tax benefit (expense) 10.8  0.1  (12.5)
Net gain (loss) on derivative hedging instruments (17.2) (0.3) 14.5 
Reclassification to expenses, net of tax (Note 19) 6.6  5.6  (62.0)
Derivative hedging activity, net of tax (10.6) 5.3  (47.5)
Defined benefit pension plans         
Net gain (loss) arising during period (1.3) 5.0  (6.7)
Less:  amortization of net gain included in net         
periodic benefit costs 0.3  0.4  0.3 
Less:  amortization of prior service costs included in net         
periodic benefit costs -  -  0.1 
Income tax benefit (expense) 0.4  (2.1) 2.4 
Net change in unrecognized pension expense (0.6) 3.3  (3.9)
Comprehensive income 200.7  159.0  103.3 
Less:  comprehensive income attributable to noncontrolling interest (0.2) (0.3) (0.2)
Comprehensive income attributable to Great Plains Energy$200.5 $158.7 $103.1 
          
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
 
59
 
KANSAS CITY POWER & LIGHT COMPANY
Consolidated Balance Sheets
     
     
 December 31
 20092008
ASSETS(millions, except share amounts)
Current Assets    
Cash and cash equivalents$17.4 $5.4 
Funds on deposit 0.1  - 
Receivables, net 161.7  161.6 
Fuel inventories, at average cost 45.6  51.7 
Materials and supplies, at average cost 84.8  68.3 
Deferred refueling outage costs 19.5  12.4 
Refundable income taxes -  11.9 
Deferred income taxes 0.3  4.9 
Derivative instruments 0.2  0.6 
Prepaid expenses and other assets 11.0  11.8 
Total 340.6  328.6 
Utility Plant, at Original Cost      
Electric 6,258.5  5,671.4 
Less-accumulated depreciation 2,899.0  2,738.8 
Net utility plant in service 3,359.5  2,932.6 
Construction work in progress 1,144.1  1,148.5 
Nuclear fuel, net of amortization of $106.0 and $110.8 68.2  63.9 
Total 4,571.8  4,145.0 
Investments and Other Assets      
Nuclear decommissioning trust fund 112.5  96.9 
Regulatory assets 612.1  609.1 
Other 65.3  49.2 
Total 789.9  755.2 
Total$5,702.3 $5,228.8 
       
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements
are an integral part of these statements.
KANSAS CITY POWER & LIGHT COMPANY
Consolidated Statements of Income
       
       
Year Ended December 31201020092008
Operating Revenues(millions)
Electric revenues$1,517.1 $1,318.2 $1,343.0 
Operating Expenses         
Fuel 278.8  251.3  253.3 
Purchased power 78.9  70.8  119.0 
Transmission of electricity by others 15.0  12.3  11.1 
Operating and maintenance expenses 434.3  403.3  398.1 
Depreciation and amortization 256.4  229.6  204.3 
General taxes 129.3  118.7  118.9 
Other 13.0  -  0.2 
Total 1,205.7  1,086.0  1,104.9 
Operating income 311.4  232.2  238.1 
Non-operating income 24.7  33.2  25.9 
Non-operating expenses (5.6) (4.7) (6.7)
Interest charges (85.7) (84.9) (72.3)
Income before income tax expense 244.8  175.8  185.0 
Income tax expense (81.6) (46.9) (59.8)
Net income$163.2 $128.9 $125.2 
          
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements
are an integral part of these statements.
 
60
 
KANSAS CITY POWER & LIGHT COMPANY
Consolidated Balance Sheets
     
     
 December 31
 20092008
LIABILITIES AND CAPITALIZATION(millions, except share amounts)
Current Liabilities    
Commercial paper$186.6 $380.2 
Current maturities of long-term debt 0.2  - 
Accounts payable 237.9  299.3 
Accrued taxes 23.7  20.5 
Accrued interest 26.7  18.1 
Accrued compensation and benefits 45.1  29.7 
Pension and post-retirement liability 3.2  1.6 
Derivative instruments -  80.3 
Other 26.1  9.1 
Total 549.5  838.8 
Deferred Credits and Other Liabilities      
Deferred income taxes 559.4  596.2 
Deferred tax credits 135.7  99.9 
Asset retirement obligations 119.8  111.9 
Pension and post-retirement liability 421.2  410.6 
Regulatory liabilities 126.9  115.8 
Other 78.2  56.8 
Total 1,441.2  1,391.2 
Capitalization      
Common shareholder's equity      
Common stock-1,000 shares authorized without par value      
1 share issued, stated value 1,563.1  1,315.6 
Retained earnings 410.1  353.2 
Accumulated other comprehensive loss (41.5) (46.9)
Total 1,931.7  1,621.9 
Long-term debt (Note 13) 1,779.9  1,376.9 
Total 3,711.6  2,998.8 
Commitments and Contingencies (Note 16)      
Total$5,702.3 $5,228.8 
       
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements
are an integral part of these statements.
     
KANSAS CITY POWER & LIGHT COMPANY
Consolidated Balance Sheets
     
     
 December 31
 20102009
ASSETS(millions, except share amounts)
Current Assets    
Cash and cash equivalents$3.6 $17.4 
Funds on deposit 0.4  0.1 
Receivables, net 169.4  161.7 
Accounts receivable pledged as collateral 95.0  - 
Fuel inventories, at average cost 44.9  45.6 
Materials and supplies, at average cost 94.4  84.8 
Deferred refueling outage costs 9.6  19.5 
Refundable income taxes 9.0  - 
Deferred income taxes 5.6  0.3 
Derivative instruments -  0.2 
Prepaid expenses and other assets 10.0  11.0 
Total 441.9  340.6 
Utility Plant, at Original Cost      
Electric 7,540.9  6,258.5 
Less-accumulated depreciation 3,104.4  2,899.0 
Net utility plant in service 4,436.5  3,359.5 
Construction work in progress 227.6  1,144.1 
Nuclear fuel, net of amortization of $131.1 and $106.0 79.2  68.2 
Total 4,743.3  4,571.8 
Investments and Other Assets      
Nuclear decommissioning trust fund 129.2  112.5 
Regulatory assets 679.6  612.1 
Other 32.3  65.3 
Total 841.1  789.9 
Total$6,026.3 $5,702.3 
       
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements
are an integral part of these statements.
 
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KANSAS CITY POWER & LIGHT COMPANY
Consolidated Statements of Cash Flows
  
       
Year Ended December 31200920082007
Cash Flows from Operating Activities(millions)
Net income$128.9 $125.2 $156.7 
Adjustments to reconcile income to net cash from operating activities:       
Depreciation and amortization 229.6  204.3  175.6 
Amortization of:         
Nuclear fuel 16.1  14.5  16.8 
Other 19.0  11.1  4.6 
Deferred income taxes, net (38.2) (7.5) 19.7 
Investment tax credit amortization (1.4) (1.4) (1.5)
Fair value impacts from interest rate hedging -  -  1.4 
Other operating activities (Note 3) (66.1) 72.8  (18.5)
Net cash from operating activities 287.9  419.0  354.8 
Cash Flows from Investing Activities         
Utility capital expenditures (626.5) (810.5) (511.5)
Allowance for borrowed funds used during construction (31.1) (23.6) (14.4)
Purchases of nuclear decommissioning trust investments (99.0) (49.1) (58.0)
Proceeds from nuclear decommissioning trust investments 95.3  45.4  54.3 
Net money pool lending (6.0) -  - 
Other investing activities (0.6) (8.5) (7.6)
Net cash from investing activities (667.9) (846.3) (537.2)
Cash Flows from Financing Activities         
Issuance of long-term debt 413.2  363.4  396.1 
Repayment of long-term debt -  -  (372.0)
Net change in short-term borrowings (193.6) 14.4  209.4 
Net money pool borrowings 0.9  -  - 
Dividends paid to Great Plains Energy (72.0) (144.0) (140.0)
Equity contribution from Great Plains Energy 247.5  200.0  94.0 
Issuance fees (4.0) (4.3) (3.7)
Net cash from financing activities 392.0  429.5  183.8 
Net Change in Cash and Cash Equivalents 12.0  2.2  1.4 
Cash and Cash Equivalents at Beginning of Year 5.4  3.2  1.8 
Cash and Cash Equivalents at End of Year$17.4 $5.4 $3.2 
          
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements are 
an integral part of these statements. 
     
KANSAS CITY POWER & LIGHT COMPANY
Consolidated Balance Sheets
     
     
 December 31
 20102009
LIABILITIES AND CAPITALIZATION(millions, except share amounts)
Current Liabilities    
Collateralized note payable$95.0 $- 
Commercial paper 263.5  186.6 
Current maturities of long-term debt 150.3  0.2 
Accounts payable 201.7  237.9 
Accrued taxes 21.3  23.7 
Accrued interest 26.2  26.7 
Accrued compensation and benefits 46.8  45.1 
Pension and post-retirement liability 2.6  3.2 
Other 7.8  26.1 
Total 815.2  549.5 
Deferred Credits and Other Liabilities      
Deferred income taxes 692.0  559.4 
Deferred tax credits 129.4  135.7 
Asset retirement obligations 129.7  119.8 
Pension and post-retirement liability 407.3  421.2 
Regulatory liabilities 141.3  126.9 
Other 76.7  78.2 
Total 1,576.4  1,441.2 
Capitalization      
Common shareholder's equity      
Common stock-1,000 shares authorized without par value      
1 share issued, stated value 1,563.1  1,563.1 
Retained earnings 478.3  410.1 
Accumulated other comprehensive loss (36.4) (41.5)
Total 2,005.0  1,931.7 
Long-term debt (Note 12) 1,629.7  1,779.9 
Total 3,634.7  3,711.6 
Commitments and Contingencies (Note 15)      
Total$6,026.3 $5,702.3 
       
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements 
are an integral part of these statements. 
 
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KANSAS CITY POWER & LIGHT COMPANY
Consolidated Statements of Common Shareholder's Equity
             
             
             
Year Ended December 31200920082007
 SharesAmountSharesAmountSharesAmount
Common Stock(millions, except share amounts)
Beginning balance 1 $1,315.6  1 $1,115.6  1 $1,021.6 
Equity contribution from Great Plains Energy    247.5     200.0     94.0 
Ending balance 1  1,563.1  1  1,315.6  1  1,115.6 
Retained Earnings                  
Beginning balance    353.2     371.3     354.8 
Cumulative effect of a change in accounting principle    -     -     (0.2)
Net income    128.9     125.2     156.7 
Transfer of HSS to KLT Inc.    -     0.7     - 
Dividends:                  
Common stock held by Great Plains Energy    (72.0)    (144.0)    (140.0)
Ending balance    410.1     353.2     371.3 
Accumulated Other Comprehensive Income (Loss)                  
Beginning balance    (46.9)    (7.5)    6.7 
Derivative hedging activity, net of tax    5.4     (39.4)    (14.2)
Ending balance    (41.5)    (46.9)    (7.5)
Total Common Shareholder's Equity   $1,931.7    $1,621.9    $1,479.4 
                   
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements are an integral part of
these statements.
KANSAS CITY POWER & LIGHT COMPANY
Consolidated Statements of Cash Flows
       
       
Year Ended December 31201020092008
Cash Flows from Operating Activities(millions)
Net income$163.2 $128.9 $125.2 
Adjustments to reconcile income to net cash from operating activities:       
Depreciation and amortization 256.4  229.6  204.3 
Amortization of:         
Nuclear fuel 25.1  16.1  14.5 
Other 24.2  19.0  11.1 
Deferred income taxes, net 83.2  (38.2) (7.5)
Investment tax credit amortization (2.1) (1.4) (1.4)
Other operating activities (Note 2) (127.8) (66.1) 72.8 
Net cash from operating activities 422.2  287.9  419.0 
Cash Flows from Investing Activities         
Utility capital expenditures (463.1) (626.5) (810.5)
Allowance for borrowed funds used during construction (22.4) (31.1) (23.6)
Purchases of nuclear decommissioning trust investments (83.3) (99.0) (49.1)
Proceeds from nuclear decommissioning trust investments 79.6  95.3  45.4 
Net money pool lending (6.1) (6.0) - 
Other investing activities (13.4) (0.6) (8.5)
Net cash from investing activities (508.7) (667.9) (846.3)
Cash Flows from Financing Activities         
Issuance of long-term debt -  413.2  363.4 
Repayment of long-term debt (0.2) -  - 
Net change in short-term borrowings 76.9  (193.6) 14.4 
Net change in collateralized short-term borrowings 95.0  -  - 
Net money pool borrowings 1.1  0.9  - 
Dividends paid to Great Plains Energy (95.0) (72.0) (144.0)
Equity contribution from Great Plains Energy -  247.5  200.0 
Issuance fees (5.1) (4.0) (4.3)
Net cash from financing activities 72.7�� 392.0  429.5 
Net Change in Cash and Cash Equivalents (13.8) 12.0  2.2 
Cash and Cash Equivalents at Beginning of Year 17.4  5.4  3.2 
Cash and Cash Equivalents at End of Year$3.6 $17.4 $5.4 
          
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements are
an integral part of these statements.
 
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KANSAS CITY POWER & LIGHT COMPANY
Consolidated Statements of Comprehensive Income
       
       
       
       
Year Ended December 31200920082007
 (millions)
Net income$128.9 $125.2 $156.7 
Other comprehensive income (loss)         
Gain (loss) on derivative hedging instruments 0.2  (65.0) (22.1)
Income tax benefit (expense) (0.1) 25.4  8.3 
Net gain (loss) on derivative hedging instruments 0.1  (39.6) (13.8)
Reclassification to expenses, net of tax (Note 20) 5.3  0.2  (0.4)
Derivative hedging activity, net of tax 5.4  (39.4) (14.2)
Comprehensive income$134.3 $85.8 $142.5 
          
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements are an
integral part of these statements.
KANSAS CITY POWER & LIGHT COMPANY
Consolidated Statements of Common Shareholder's Equity
             
             
             
Year Ended December 31201020092008
 SharesAmountSharesAmountSharesAmount
Common Stock(millions, except share amounts)
Beginning balance 1 $1,563.1  1 $1,315.6  1 $1,115.6 
Equity contribution from Great Plains Energy    -     247.5     200.0 
Ending balance 1  1,563.1  1  1,563.1  1  1,315.6 
Retained Earnings                  
Beginning balance    410.1     353.2     371.3 
Net income    163.2     128.9     125.2 
Transfer of HSS to KLT Inc.    -     -     0.7 
Dividends:                  
Common stock held by Great Plains Energy    (95.0)    (72.0)    (144.0)
Ending balance    478.3     410.1     353.2 
Accumulated Other Comprehensive Income (Loss)                  
Beginning balance    (41.5)    (46.9)    (7.5)
Derivative hedging activity, net of tax    5.1     5.4     (39.4)
Ending balance    (36.4)    (41.5)    (46.9)
Total Common Shareholder's Equity   $2,005.0    $1,931.7    $1,621.9 
                   
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements are an integral part of these
statements.
 
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KANSAS CITY POWER & LIGHT COMPANY
Consolidated Statements of Comprehensive Income
       
       
       
       
Year Ended December 31201020092008
 (millions)
Net income$163.2 $128.9 $125.2 
Other comprehensive income (loss)         
Gain (loss) on derivative hedging instruments (0.9) 0.2  (65.0)
Income tax benefit (expense) 0.3  (0.1) 25.4 
Net gain (loss) on derivative hedging instruments (0.6) 0.1  (39.6)
Reclassification to expenses, net of tax (Note 19) 5.7  5.3  0.2 
Derivative hedging activity, net of tax 5.1  5.4  (39.4)
Comprehensive income$168.3 $134.3 $85.8 
          
The disclosures regarding KCP&L included in the accompanying Notes to Consolidated Financial Statements are an
integral part of these statements.
65
GREAT PLAINS ENERGY INCORPORATED
KANSAS CITY POWER & LIGHT COMPANY
 
Notes to Consolidated Financial Statements
 
The notes to consolidated financial statements that follow are a combined presentation for Great Plains Energy Incorporated and Kansas City Power & Light Company, both registrants under this filing.  The terms “Great Plains Energy,” “Company,” “KCP&L,” and “KCP&L”“Companies” are used throughout this report.  “Great Plains Energy” and the “Company” refer to Great Plains Energy Incorporated and its consolidated subsidiaries, unless otherwise indicated.  “KCP&L” refers to Kansas City Power & Light Company and its consolidated subsidiaries.  “Companies” refers to Great Plains Energy Incorporated and its consolidated subsidiaries and KCP&L and its consolidated subsidiaries.
 
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 (Receivables Company).
 
·  KCP&L Greater Missouri Operations Company (GMO) is an integrated, regulated electric utility that primarily 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 wholly owns MPS Merchant Services, Inc. (MPS Merchant), which has certain long-term natural gas contracts remaining from its former non-regulated trading operations.  Great Plains Energy acquired GMO on July 14, 2008.  See Note 2 to the consolidated financial statements for additional information.
 
·  Great Plains Energy Services Incorporated (Services) obtains certain goods and third-party services for its affiliated companies.
·  KLT Inc. is an intermediate holding company that primarily holds investments in affordable housing limited partnerships.
Each of Great Plains Energy’s and KCP&L’s consolidated financial statements includes the accounts of their subsidiaries.  All intercompany transactions have been eliminated.
 
Great Plains Energy’s sole reportable business segment is electric utility.  See Note 2322 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.

 
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Fair Value of Financial Instruments
The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value.
Affordable housing limited partnerships – The fair value of KLT Investments Inc.’s (KLT Investments) affordable housing limited partnership total portfolio, based on the discounted cash flows generated by tax credits, tax deductions and sale of properties, approximates book value.
 
Nuclear decommissioning trust fund – KCP&L’s nuclear decommissioning trust fund assets are recorded at fair value.  Fair value is based on quoted market prices of the investments held by the fund and/or valuation models.
 
Rabbi trust -– GMO’s rabbi trusts related to its Supplemental Executive Retirement Plans (SERP) are recorded at fair value, which are based on quoted market prices of the investments held by the trusts and/or valuation models.  The rabbi trusts are included in Other – Investments and Other Assets on Great Plains Energy’s consolidated balance sheets.
 
Long-term debt – Fair value is based on quoted market prices, with the incremental borrowing rate for similar debt used to determine fair value if quoted market prices were not available. At December 31, 2010, the book value and fair value of Great Plains Energy’s long-term debt, including current maturities, was $3.4 billion and $3.7 billion, respectively.  At December 31, 2010, the book value and fair value of KCP&L’s long-term debt, including current maturities, was $1.8 billion and $1.9 billion, respectively.  At December 31, 2009, the book value and fair value of Great Plains Energy’s long-term debt, including current maturities, was $3.2 billion and $3.4 billion, respectively.  At December 31, 2009, the book value and fair value of KCP&L’s long-term debt, including current maturities, was $1.8 billion and $1.9 billion, respectively.  At December 31, 2008, the book value and fair value of Great Plains Energy’s long-term debt, including current maturities, was $2.6 billion and $2.2 billion, respectively.  At December 31, 2008, the book value and fair value of KCP&L’s long-term debt was $1.4 billion and $1.1 billion, respectively.
 
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.  KCP&L uses a five-year smoothing of assets to determine fair value for regulatory reporting purposes.
 
Derivative Instruments
The Company records derivative instruments on the balance sheet at fair value in accordance with Generally Accepted Accounting Principles (GAAP).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 2019 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.
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Investments in Affordable Housing Limited Partnerships
At December 31, 2009, KLT Investments had $13.2 million of investments in affordable housing limited partnerships.  Approximately 91% of these investments were recorded at cost; the equity method was used for the remainder.  A change in accounting principle relating to investments made after May 19, 1995, requires the use of the equity method when a company owns more than 5% in a limited partnership investment.  Of the investments recorded at cost, $11.7 million exceed this 5% level but were made before May 19, 1995.  The investments generate future cash flows from tax credits and tax losses of the partnerships.  The investments also generate cash flows from the sales of the properties.  For most investments, tax credits are received over ten years.  Tax expense is reduced in the year tax credits are generated.  Management does not anticipate making additional investments in affordable housing limited partnerships at this time.  The properties underlying the partnership investments are subject to certain risks inherent in real estate ownership and management.
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 and Accounting for Planned Major Maintenance).  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 6.8% in 2010, 7.6% in 2009, and 7.1% in 2008 and 6.3% in 2007 for KCP&L and for GMO averaged 4.6% in 2010, 5.4% in 2009 and 4.9% in 2008 subsequent to its acquisition on July 14, 2008.
 
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 2009  2008 
Utility Plant, at original cost (millions) 
     Production (23 - 60 years) $4,892.3  $4,171.2 
     Transmission (27 - 76 years)  660.4   655.8 
     Distribution (8 - 75 years)  2,708.3   2,588.1 
     General (5 - 50 years)  588.0   525.7 
Total (a)
 $8,849.0  $7,940.8 
(a) Includes $96.3 million and $78.4 million at December 31,
     2009 and 2008, respectively, of land and other assets that
     are not depreciated.
Great Plains Energy
December 31 2010  2009 
Utility Plant, at original cost (millions)
 Production (20 - 60 years) $6,369.4  $4,892.3 
 Transmission (15 - 70 years)  716.9   660.4 
 Distribution (8 - 66 years)  2,813.4   2,708.3 
 General (5 - 50 years)  637.2   588.0 
Total (a)
 $10,536.9  $8,849.0 
(a)Includes $103.0 million and $96.3 million at December 31, 
 2010 and 2009, respectively, of land and other assets that 
  are not depreciated. 


KCP&L
December 31 2010  2009 
Utility Plant, at original cost (millions)
 Production (20 - 60 years) $4,886.2  $3,742.6 
 Transmission (15 - 70 years)  408.7   371.3 
 Distribution (8 - 55 years)  1,776.4   1,709.5 
 General (5 - 50 years)  469.6   435.1 
Total (a)
 $7,540.9  $6,258.5 
(a)Includes $59.9 million and $56.1 million at December 31, 
 2010 and 2009, respectively, of land and other assets that 
 are not depreciated. 
 
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KCP&L      
December 31 2009  2008 
Utility Plant, at original cost (millions) 
     Production (23 - 60 years) $3,742.6  $3,249.8 
     Transmission (27 - 76 years)  371.3   404.7 
     Distribution (8 - 75 years) 1,709.5   1,638.6 
     General (5 - 50 years)  435.1   378.3 
Total (a)
 $6,258.5  $5,671.4 
(a) Includes $56.1 million and $56.0 million at December 31,
     2009 and 2008, 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 $243.6 million, $228.9 million, and $175.1 million for 2010, 2009, and $140.9 million for 2009, 2008, and 2007, respectively.  KCP&L’s depreciation expense was $170.9 million, $158.4 million, and $145.4 million for 2010, 2009 and $140.9 million for 2009, 2008, and 2007, respectively.  Great Plains Energy’s and KCP&L’s depreciation and amortization expense includes $72.6 million, $58.2 million, and $47.4 million for 2010, 2009 and $25.7 million for 2009, 2008, and 2007, respectively, of additional amortization to help maintain cash flow levels during KCP&L’s Comprehensive Energy Plan pursuant to orders of the Public Service Commission of the State of Missouri (MPSC) and The State Corporation Commission of the State of Kansas (KCC).
 
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 sheet 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 98 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 of 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 76 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.  
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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 $54.3 million, $46.8 million and $45.9 million in 2010, 2009 and $44.7 million in 2009, 2008, and 2007, respectively.  These taxes from KCP&L’s Kansas customers and GMO’s customers are recorded net in operating revenues on Great Plains Energy’s statementstatements 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.
 
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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 sales of assets, businesses and 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 animpairment at least annually and more frequently when indicators of impairment exist.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
Great Plains Energy has recognized deferred taxes for temporary book to tax differences using the liability method.  The liability method requires that deferred tax balances be adjusted to reflect enacted tax rates that are anticipated to be in effect when the temporary differences 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.
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Great Plains Energy and its subsidiaries file consolidated federal and combined and separate state income tax returns.  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.
 
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Basic and Diluted Earnings (Loss) per Common Share Calculation
To determine basic EPS, preferred stock dividend requirements and net income attributable to noncontrolling interest are deducted from income from continuing operations and net income before dividing by the average number of common shares outstanding.  The earnings (loss) per share impact of discontinued operations is determined by dividing income (loss) from discontinued operations, net of income taxes, 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, a forward sale agreement and FELINE PRIDESSM.Units.

The following table reconciles Great Plains Energy’s basic and diluted EPS from continuing operations.
         
 2009  2008  2007  2010 2009 2008
Income (millions, except per share amounts) (millions, except per share amounts)
Income from continuing operations $151.9  $119.7  $120.9  $211.9  $151.9  $119.7 
Less: net income attributable to noncontrolling interest  0.3   0.2   -   0.2   0.3   0.2 
Less: preferred stock dividend requirements  1.6   1.6   1.6   1.6   1.6   1.6 
Income from continuing operations available for common shareholders $150.0  $117.9  $119.3  $210.1  $150.0  $117.9 
Common Shares Outstanding                        
Average number of common shares outstanding  129.3   101.1   84.9   135.1   129.3   101.1 
Add: effect of dilutive securities  0.5   0.1   0.3   1.8   0.5   0.1 
Diluted average number of common shares outstanding  129.8   101.2   85.2   136.9   129.8   101.2 
Basic EPS from continuing operations $1.16  $1.16  $1.41  $1.55  $1.16  $1.16 
Diluted EPS from continuing operations $1.15  $1.16  $1.40  $1.53  $1.15  $1.16 
                        
The computation of diluted EPS for 2010 excludes anti-dilutive shares consisting of 340,690 performance shares, 251,526 restricted stock shares and 196,137 stock options.

The computation of diluted EPS for 2009 excludes anti-dilutive shares consisting of 150,895 performance shares, 438,281 restricted stock shares and 231,670 stock options.

The computation of diluted EPS for 2008 excludes anti-dilutive shares consisting of 364,217 performance shares, 530,398 restricted stock shares and 455,469 stock options.

The computation of diluted EPS for 2007 excludes anti-dilutive shares consisting of 128,716 performance shares and 381,451 restricted stock shares.  In 2007, there were no anti-dilutive shares applicable to FELINE PRIDES, stock options or a forward sale agreement.  FELINE PRIDES settled in the first quarter of 2007 and the forward sale agreement settled in the second quarter of 2007.
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Dividends Declared
In February 2010,2011, Great Plains Energy’s Board of Directors (Board) declared a quarterly dividend of $0.2075 per share on Great Plains Energy’s common stock.  The common dividend is payable March 19, 2010,21, 2011, to shareholders of record as of February 26, 2010.28, 2011.  The Board also declared regular dividends on Great Plains Energy’s preferred stock, payable June 1, 2010,2011, to shareholders of record as of May 10, 2010.2011.
 
In February 2011, KCP&L’s Board of Directors declared a cash dividend payable to Great Plains Energy of $25 million payable on March 17, 2011.
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2.  GMO ACQUISITIONSUPPLEMENTAL CASH FLOW INFORMATION

Great Plains Energy Other Operating Activities         
  2010 2009 2008
Cash flows affected by changes in: (millions)
Receivables $(12.6) $7.9  $61.9 
Accounts receivable pledged as collateral  (95.0)  -   - 
Fuel inventories  (0.1)  2.0   (16.7)
Materials and supplies  (11.5)  (22.0)  (3.7)
Accounts payable  12.8   (70.9)  56.2 
Accrued taxes  6.7   42.2   73.2 
Accrued interest  2.9   2.9   17.8 
Deferred refueling outage costs  9.9   (7.1)  (5.9)
Accrued plant maintenance costs  1.7   2.9   2.1 
Fuel adjustment clauses  2.7   7.8   (18.0)
Pension and post-retirement benefit obligations  (10.2)  18.4   3.1 
Allowance for equity funds used during construction  (26.0)  (39.6)  (24.2)
Write down of affordable housing investments  11.2   -   - 
Iatan Nos. 1 and 2 impact of disallowed construction costs  16.8   -   - 
Deferred acquisition costs  -   -   (15.8)
Interest rate hedge settlements  (6.9)  (79.1)  (41.2)
Other  (36.1)  16.8   (36.4)
Total other operating activities $(133.7) $(117.8) $52.4 
Cash paid during the period:            
Interest $237.7  $211.9  $95.0 
Income taxes $0.9  $5.1  $27.1 
Non-cash investing activities:            
Liabilities assumed for capital expenditures $44.9  $82.8  $104.7 
             



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KCP&L Other Operating Activities         
  2010 2009 2008
Cash flows affected by changes in: (millions)
Receivables $(4.1) $(7.6) $50.9 
Accounts receivable pledged as collateral  (95.0)  -   - 
Fuel inventories  0.7   6.1   (16.0)
Materials and supplies  (9.6)  (16.5)  (4.3)
Accounts payable  0.8   (54.3)  57.3 
Accrued taxes  (15.7)  51.8   81.3 
Accrued interest  (0.5)  8.6   8.5 
Deferred refueling outage costs  9.9   (7.1)  (5.9)
Pension and post-retirement benefit obligations  7.9   39.3   (5.1)
Allowance for equity funds used during construction  (21.9)  (30.6)  (22.5)
Kansas Energy Cost Adjustment  (8.8)  2.2   (1.6)
Iatan Nos. 1 and 2 impact of disallowed construction costs  13.0   -   - 
Interest rate hedge settlements  -   (79.1)  (41.2)
Other  (4.5)  21.1   (28.6)
Total other operating activities $(127.8) $(66.1) $72.8 
Cash paid during the period:            
Interest $101.1  $77.2  $63.0 
Income taxes $18.2  $31.9  $23.5 
Non-cash investing activities:            
Liabilities assumed for capital expenditures $37.4  $75.5  $90.8 
             
Significant Non-Cash Items
On January 1, 2010, Great Plains Energy and KCP&L adopted new accounting guidance for transfers of financial assets, which resulted in the recognition of $95.0 million of accounts receivables pledged as collateral and a corresponding short-term collateralized note payable on Great Plains Energy’s and KCP&L’s balance sheets at December 31, 2010.  See Note 3 for additional information.  As a result, cash flows from operating activities were reduced by $95.0 million and cash flows from financing activities were raised by $95.0 million with no impact to the net change in cash at December 31, 2010.
 
On July 14, 2008, Great Plains Energy closed its acquisition of GMO.  The total purchase price of the acquisition was approximately $1.7 billion.  The fair value of the 32.2 million shares of Great Plains Energy common stock issued was approximately $1.0 billion.  Great Plains Energy paid approximately $0.7 billion of cash consideration.  Immediately prior to Great Plains Energy’s acquisition of GMO, Black Hills Corporation (Black Hills) acquired GMO’s electric utility assets in Colorado and its gas utility assets in Colorado, Kansas, Nebraska and Iowa.  Following the closing of the acquisition, Great Plains Energy wholly owns GMO, including its Missouri-based utility operations consisting of the Missouri Public Service and St. Joseph Light & Power divisions.  GMO is included in Great Plains Energy’s consolidated financial statements beginning as of July 14, 2008.
The regulatory approval order from the MPSC was received on July 1, 2008.  Certain parties filed appeals and a motion to stay the order with the Cole County, Missouri, Circuit Court, which affirmed the order in June 2009.  This decision has been appealed.  The order remains in effect unless reversed by the courts.
The MPSC order provided for the deferral of transition costs to be amortized over a five-year period to the extent that synergy savings exceed amortization.  The Company settled its first post-transaction rate cases and the settlement agreements were silent with respect to transition costs.  The Company will continue to defer transition costs until amortization is ordered by the MPSC.  KCC order approved the deferral of up to $10.0 million of transition costs to be amortized over a five-year period beginning with rates expected to be effective in 2010.  At December 31, 2009, Great Plains Energy had $51.5 million of regulatory assets related to transition costs, which included $29.3 million at KCP&L and $22.2 million at GMO.
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The acquisition was accounted for under the purchase method of accounting.  As a result, the assets and liabilities of GMO were recorded at their estimated fair values as of July 14, 2008.  The following table shows the allocation of the purchase price to the assets acquired and liabilities assumed at the date of the acquisition.
    
       July 14      
  2008        
Purchase Price Allocation (millions)      
Cash $677.7 
Common stock (32.2 million shares)  1,026.1  (a)
Stock options (0.5 million options)  2.7  (b)
Transaction costs   35.6 
Total purchase price  1,742.1 
     
Cash and cash equivalents  949.6 
Receivables  159.1 
Deferred income taxes  511.0 
Other current assets  131.4 
Utility plant, net  1,627.4 
Nonutility property and investments  131.4 
Regulatory assets  146.6 
Other long-term assets   76.0 
Total assets acquired  3,732.5 
Current liabilities  311.8 
Regulatory liabilities  115.9 
Deferred income taxes  241.5 
Long-term debt  1,334.2 
Other long-term liabilities   156.0 
Net assets acquired  1,573.1 
     
Goodwill $169.0 
(a)  The fair value was based on the average closing price of Great Plains Energy common stock
     of $31.88, the average during the period beginning two trading days before and ending two
     trading days after February 7, 2007, the announcement of the acquisition, net of issuing costs.
(b)  The fair value was calculated by multiplying the stock options outstanding at July 14,
     2008, by the option exchange ratio of 0.1569, calculated as defined in the merger agreement.

Great Plains Energy recorded $169.0 million of goodwill, all of which is included in the electric utility segment.  None of the goodwill is tax deductible.  The factors that contributed to a purchase price that resulted in goodwill were strategic considerations and significant cost savings and synergies including: expanded regulated electric utility business; adjacent regulated electric utility territories; increased GMO financial strength and flexibility; improved reliability and customer service and disposition of non-strategic gas operations.  Changes to the initial allocation of the purchase price consisted primarily of additional fair value adjustments to certain real estate properties, increased unrecognized tax benefits related to prior year tax positions on GMO tax returns, adjustment to regulatory assets due to the settlement of regulatory treatment and net operating loss valuation allowance adjustments.
Goodwill is required to be tested for impairment at least annually and more frequently when indicators of impairment exist.  The goodwill impairment test is a two step process, the first step of which is the comparison of 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
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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.  The annual impairment test for the GMO acquisition goodwill was conducted on September 1, 2009.  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 and net utility asset values and market prices of stock of electric and gas company regulated peers.  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.
The following table provides unaudited pro forma results of operations for Great Plains Energy for December 31, 2008 and 2007, as if the acquisition had occurred on January 1 of those years, respectively.  Pro forma results are not necessarily indicative of the actual results that would have resulted had the acquisition actually occurred on January 1, 2008, or January 1, 2007.
       
  December 31 
  2008  2007 
 (millions, except per share amounts)
Operating revenues $2,013.6  $1,944.3 
Income from continuing operations $121.1  $119.2 
Net income $156.1  $157.5 
Earnings available for common shareholders $154.5  $155.9 
         
Basic and diluted earnings per common share from        
continuing operations $1.18  $1.00 
Basic and diluted earnings per common share $1.53  $1.33 
         
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3.  SUPPLEMENTAL CASH FLOW INFORMATION
Great Plains Energy Other Operating Activities         
  2009  2008  2007 
Cash flows affected by changes in: (millions) 
Receivables $7.9  $61.9  $(80.0)
Fuel inventories  2.0   (16.7)  (9.3)
Materials and supplies  (22.0)  (3.7)  (4.2)
Accounts payable  (70.9)  56.2   43.3 
Accrued taxes  42.2   73.2   17.3 
Accrued interest  2.9   17.8   (0.7)
Deferred refueling outage costs  (7.1)  (5.9)  7.4 
Accrued plant maintenance costs  2.9   2.1   - 
Fuel adjustment clauses  7.8   (18.0)  - 
Pension and post-retirement benefit obligations  18.4   3.1   17.6 
Allowance for equity funds used during construction  (39.6)  (24.2)  (2.5)
Deferred acquisition costs  -   (15.8)  (18.3)
Proceeds from the sale of SO2 emission allowances
  0.1   0.4   24.0 
Forward Starting Swaps proceeds (settlement)  (79.1)  -   3.3 
T-Lock settlement  -   (41.2)  (4.5)
Other  16.7   (36.8)  (17.8)
Total other operating activities $(117.8) $52.4  $(24.4)
Cash paid during the period:            
Interest $211.9  $95.0  $91.8 
Income taxes $5.1  $27.1  $33.6 
Non-cash investing activities:            
Liabilities assumed for capital expenditures $82.8  $104.7  $72.5 
             
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KCP&L Other Operating Activities         
  2009  2008  2007 
Cash flows affected by changes in: (millions) 
Receivables $(7.6) $50.9  $(60.0)
Fuel inventories  6.1   (16.0)  (9.3)
Materials and supplies  (16.5)  (4.3)  (4.2)
Accounts payable  (54.3)  57.3   20.6 
Accrued taxes  51.8   81.3   5.9 
Accrued interest  8.6   8.5   (2.9)
Deferred refueling outage costs  (7.1)  (5.9)  7.4 
Pension and post-retirement benefit obligations  39.3   (5.1)  15.4 
Allowance for equity funds used during construction  (30.6)  (22.5)  (2.5)
Proceeds from the sale of SO2 emission allowances
  0.1   0.4   24.0 
Kansas Energy Cost Adjustment  2.2   (1.6)  - 
Forward Starting Swaps proceeds (settlement)  (79.1)  -   3.3 
T-Lock settlement  -   (41.2)  - 
Other  21.0   (29.0)  (16.2)
Total other operating activities $(66.1) $72.8  $(18.5)
Cash paid during the period:            
Interest $77.2  $63.0  $68.3 
Income taxes $31.9  $23.5  $39.8 
Non-cash investing activities:            
Liabilities assumed for capital expenditures $75.5  $90.8  $72.4 
             
Significant Non-Cash Items
On July 14, 2008, Great Plains Energy closed its acquisition of GMO.  The total purchase price of the acquisition was approximately $1.7 billion.  The fair value of the 32.2 million shares of Great Plains Energy common stock issued was approximately $1.0 billion.  Great Plains Energy paid approximately $0.7 billion of cash consideration.  See Note 2 for additional information.
 
In May 2008, KCP&L’s Series 2008 Environmental Improvement Revenue Refunding (EIRR) bonds totaling $23.4 million maturing in 2038 were issued.  The proceeds were deposited with a trustee pending KCP&L’s submission of qualifying expenses for reimbursement.  At December 31, 2008, KCP&L had received $13.4 million in cash proceeds and had a $10.0 million short-term receivable for the proceeds that were deposited with the trustee.  In 2009, KCP&L received the remaining $10.0 million in cash.
 
In 2008, KCP&L recorded a $12.6 million net increase in AROs, consisting of a $14.2 million increase as a result of changes in cost estimates and timing used to compute the present value of asbestos AROs for KCP&L’s generating stations, with a corresponding increase in net utility plant and a decrease of $1.6 million resulting from an update to the cost estimates to decommission Wolf Creek, with a corresponding increase in regulatory liabilities.  This activity had no impact on Great Plains Energy’s or KCP&L’s 2008 cash flows.  See Note 9 for additional information.
 
In February 2007, Great Plains Energy issued 5.2 million shares of common stock in satisfaction of the FELINE PRIDES stock purchase contracts and the redemption of the $163.6 million FELINE PRIDES Senior Notes.
 
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4.3.  RECEIVABLES
 
Great Plains Energy’s and KCP&L’s receivables are detailed in the following table.

            
 December 31  December 31
 2009  2008  2010 2009
Great Plains Energy (millions)  (millions)
Customer accounts receivable - billed $47.3  $61.3  $62.0  $47.3 
Customer accounts receivable - unbilled  77.9   69.9   82.3   77.9 
Allowance for doubtful accounts  (2.8)  (3.5)  (2.7)  (2.8)
Other receivables  108.1   114.6   100.1   108.1 
Total $230.5  $242.3  $241.7  $230.5 
KCP&L                
Customer accounts receivable - billed $-  $15.5  $6.5  $- 
Customer accounts receivable - unbilled  44.6   41.7   50.1   44.6 
Allowance for doubtful accounts  (1.7)  (1.2)  (1.5)  (1.7)
Intercompany receivables  42.4   28.5   43.2   42.4 
Other receivables  76.4   77.1   71.1   76.4 
Total $161.7  $161.6  $169.4  $161.7 
                
Great Plains Energy’s and KCP&L’s other receivables at December 31, 20092010 and 2008,2009, consisted primarily of receivables from partners in jointly owned electric utility plants and wholesale sales receivables.

Sale of Accounts Receivable – KCP&L
KCP&L sells all of its retail electric accounts receivable to its wholly owned subsidiary, Receivables Company, which in turn sells an undivided percentage ownership interest in the accounts receivable to Victory Receivables Corporation, an independent outside investor.  In accordance with GAAPOn January 1, 2010, Great Plains Energy and KCP&L adopted new accounting guidance for transfers and servicing of financial assets, which resulted in the sales under these agreements qualify as a sale under which the creditors of Receivables Company are entitled to be satisfied out of the assets of Receivables Company prior to any value being returned to KCP&L or its creditors.  See Note 26 for information regarding a new accounting standard for financial asset transfers effective January 1, 2010.  Accountsundivided percentage ownership interest in accounts receivable sold by Receivables Company tono longer meeting the outside investor under this revolving agreement totaledcriteria for derecognition and now being accounted for as a secured borrowing.  As a result, $95.0 million of accounts receivables pledged as collateral are recognized with a corresponding short-term collateralized note payable on Great Plains Energy’s and $70.0 millionKCP&L’s balance sheets at December 31, 2009 and 2008, respectively.  2010.
KCP&L sells its receivables at a fixed price based upon the expected cost of funds and charge-offs.  These costs comprise KCP&L’s loss on the sale of accounts receivable.  KCP&L services the receivables and receives an annual servicing fee of 1.5% to 2.5% of the outstanding principal amount of the receivables sold to Receivables Company.  KCP&L does not recognize a servicing asset or liability because management determined the collection agent fee earned by KCP&L approximates market value.  TheIn February 2011, the agreement expires in July 2010 and it is expectedwas amended to be renewed.extend the expiration date of the agreement from May 2011 to October 2011.
 
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Information regarding KCP&L’s sale of accounts receivable to Receivables Company is reflected in the following tables.
          
     Receivables  Consolidated 
2009 KCP&L  Company  KCP&L 
  (millions) 
Receivables (sold) purchased $(1,172.4) $1,172.4  $- 
Gain (loss) on sale of accounts receivable (a)
  (14.8)  14.6   (0.2)
Servicing fees  2.0   (2.0)  - 
Fees to outside investor  -   (1.2)  (1.2)
             
Cash flows during the period            
Cash from customers transferred to Receivables Company  (1,167.6)  1,167.6   - 
Cash paid to KCP&L for receivables purchased  1,153.0   (1,153.0)  - 
Servicing fees  2.0   (2.0)  - 
Interest on intercompany note  0.4   (0.4)  - 
             
         
    Receivables  Consolidated    Receivables Consolidated
2008 KCP&L  Company  KCP&L 
2010 KCP&L Company KCP&L
 (millions)  (millions)
Receivables (sold) purchased $(1,147.3) $1,147.3  $-  $(1,341.0) $1,341.0  $- 
Gain (loss) on sale of accounts receivable (a)
  (14.5)  14.4   (0.1)  (17.0)  16.8   (0.2)
Servicing fees  1.7   (1.7)  -   3.2   (3.2)  - 
Fees to outside investor  -   (2.6)  (2.6)  -   (1.2)  (1.2)
                        
Cash flows during the period                        
Cash from customers transferred to Receivables Company  (1,142.1)  1,142.1   -   (1,337.4)  1,337.4   - 
Cash paid to KCP&L for receivables purchased  1,127.8   (1,127.8)  -   1,320.7   (1,320.7)  - 
Servicing fees  1.7   (1.7)  -   3.2   (3.2)  - 
Interest on intercompany note  1.9   (1.9)  -   0.5   (0.5)  - 
(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.
            

      
     ReceivablesConsolidated 
2009 KCP&L Company KCP&L
  (millions)
Receivables (sold) purchased $(1,172.4) $1,172.4  $- 
Gain (loss) on sale of accounts receivable (a)
  (14.8)  14.6  (0.2)
Servicing fees  2.0   (2.0) - 
Fees to outside investor  -   (1.2) (1.2)
            
Cash flows during the period           
Cash from customers transferred to Receivables Company  (1,167.6)  1,167.6  - 
Cash paid to KCP&L for receivables purchased  1,153.0   (1,153.0) - 
Servicing fees  2.0   (2.0) - 
Interest on intercompany note  0.4   (0.4) - 
(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.
5.4.  
ASSETS HELD FOR SALESALE
 
On July 14, 2008, As of December 31, 2009, Great Plains Energy closed its acquisition of GMO.  GMO hashad several real estate properties that will not be used.  Asproperties a result, these real estate properties are availablevailable for immediate sale in their present condition and management iswas actively marketing these properties.  The carrying amounts for these assets arewere presented at fair value less estimated selling cost and arewere included in assets held for sale on Great Plains Energy’s consolidated balance sheets.  Of the $19.4 millionsheets as of assets held for sale at December 31, 2009, $15.12009.  In March 2010, one of the properties with a book value of $0.6 million iswas sold resulting in an insignificant loss on the sale.  In October 2010, one of the properties included in the electric utility segment andwith a book value of $11.1 million was sold resulting in an insignificant gain on the sale.  As of December 31, 2010, management determined that the sale of the remaining $4.3properties was no longer considered probable.  Accordingly, the $7.7 million is included inof properties were reclassified from assets held for sale to other-investments and other assets on the other category.consolidated balance sheet as of December 31, 2010.
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6.5.  NUCLEAR PLANT
 
KCP&L owns 47% of Wolf Creek, its only nuclear generating unit.  Wolf Creek is regulated by the Nuclear Regulatory Commission (NRC), with respect to licensing, operations and safety-related requirements.
 
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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 FebruaryMarch 2010, the DOE announced its intentfiled a motion to withdraw its 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, which would bring the licensing process to an end.  An NRC board denied the DOE’s motion to withdraw its application in June 2010, and the DOE appealed that decision to the full NRC in early July 2010.  The NRC has not yet decided that appeal.  The question of the DOE’s legal authority to withdraw its license application also is pending in multiple lawsuits filed with a federal appellate court.  Oral argument to the court is set for late March 2011.  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.  See Note 1716 for a related legal proceeding.
 
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.
In late 2009,  Wolf Creek has contracted with a waste processor that will process, take title and store 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 yearsyears’ generation of Classes B and C waste.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 MPSC and 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 2008 and is the basis for the current cost of decommissioning estimates in the table below.  KCC issued its order in August 2009 approving the 2008 decommissioning cost study, and approved funding levels will be addressed in KCP&L’s current rate case, which was filed with KCCits order issued in December 2009.November 2010.  The MPSC does not explicitly approve or disapprove of the decommissioning cost study and issued its order approving the funding levels in May 2009.
      
  Total KCP&L's  TotalKCP&L's
  Station 47% Share  Station47% Share
  (millions)   (millions)
Current cost of decommissioning (in 2008 dollars)Current cost of decommissioning (in 2008 dollars)  $       594  $       279 Current cost of decommissioning (in 2008 dollars)  $       594 $       279
Future cost of decommissioning (in 2045-2053 dollars) (a)
Future cost of decommissioning (in 2045-2053 dollars) (a)
        2,575        1,210 
Future cost of decommissioning (in 2045-2053 dollars) (a)
        2,575       1,210
          
Annual escalation factorAnnual escalation factor3.73%Annual escalation factor 3.73%
Annual return on trust assets (b)
Annual return on trust assets (b)
6.48%
Annual return on trust assets (b)
 6.83%
(a)  Total future cost over an eight year decommissioning period.  Total future cost over an eight year decommissioning period.   
(b)  The 6.48% rate of return is through 2025.  The rate then systematically decreases through 2053 to 2.82%The 6.83% rate of return is through 2025.  The rate then systematically decreases through 2053 to 1.87% 
  based on the assumption that the fund's investment mix will become increasingly more conservative asbased on the assumption that the fund's investment mix will become increasingly more conservative 
  the decommissioning period approaches.as the decommissioning period approaches. 
 
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Nuclear Decommissioning Trust Fund
In 2010 and 2009,KCP&L currently contributescontributed approximately $3.7 million annually  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
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below the anticipatedprojected levelor 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 decommissioning trust fund.
            
December 31 2009  2008  2010 2009
Decommissioning Trust (millions)  (millions)
Beginning balance $96.9  $110.5 
Beginning balance January 1 $112.5  $96.9 
Contributions  3.7   3.7   3.7   3.7 
Earned income, net of fees  2.8   3.3   2.0   2.8 
Net realized gains/(losses)  (5.5)  (8.2)  6.7   (5.5)
Net unrealized gains/(losses)  14.6   (12.4)
Net unrealized gains  4.3   14.6 
Ending balance $112.5  $96.9  $129.2  $112.5 
                
The decommissioning trust is reported at fair value on the balance sheets and is invested in assets as detailed in the following table.  At December 31, 2009, KCP&L was holding short-term investments in the decommissioning trust fund, which were invested in equity securities in early 2010 as a result of a change in the asset allocation of the trust to a higher proportion of equity securities given the 20-year extension of Wolf Creek’s operating license approved by the NRC in November 2008.
                
             December 31
 December 31 2010 2009
 2009 2008   Gross Gross     Gross Gross  
 Fair Unrealized Fair Unrealized Cost Unrealized Unrealized Fair Cost Unrealized Unrealized Fair
 Value Gains/(Losses) Value Gains/(Losses) Basis Gains Losses Value Basis Gains Losses Value
 (millions) (millions)
Equity securities $44.5  $8.2  $34.6  $(5.3)  $     73.4  $     13.1  $     (1.0)  $     85.5  $     36.3  $       8.9  $     (0.7)  $     44.5
Debt securities  37.4   2.1   59.9   1.0          38.1           2.6         (0.1)         40.6         35.3           2.1               -         37.4
Other  30.6   -   2.4   -            3.1               -               -           3.1         30.6               -               -         30.6
Total $112.5  $10.3  $96.9  $(4.3)  $   114.6  $     15.7  $     (1.1)  $   129.2  $   102.2  $     11.0  $     (0.7)  $   112.5
                

The weighted average maturity of debt securities held by the trust at December 31, 2009,2010, was approximately 47.6 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 by the nuclear decommissioning trust fund.
                  
 2009  2008  2007  2010 2009 2008
 (millions)  (millions)
Realized Gains $2.8  $2.7  $6.1  $7.3  $2.8  $2.7 
Realized Losses  (8.3)  (10.9)  (2.8)  (0.6)  (8.3)  (10.9)
                        
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, regardless of the number of acts 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
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Limited (NEIL), the Owners’ insurance provider, exists for property claims, including accidental outage power
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costs for acts of terrorism affecting Wolf Creek or any other nuclear energy facility property policy within twelve months from the date of the first act.  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 adverse 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 $12.5$12.6 billion.  This limit of liability consists of the maximum available commercial insurance of $0.3$0.4 billion and the remaining $12.2 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 $117.5 million ($55.2 million, KCP&L’s 47% share) per incident at any commercial reactor in the country, payable at no more than $17.5 million ($8.2 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 $25.2$26.2 million ($11.912.3 million, KCP&L’s 47% share) per policy year.
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7.6.  REGULATORY MATTERS
 
KCP&L’s Comprehensive Energy Plan
KCP&L’s Comprehensive Energy Plan included construction of Iatan No. 2, wind generation, environmental upgrades at certain coal-fired generating stations, infrastructure investments, and energy efficiency, affordability and demand response programs.  With the construction of Iatan No. 2 completed in 2010, the remaining component of KCP&L’s Comprehensive Energy Plan is to obtain state regulatory approval to include the cost of Iatan No. 2 in rate base and begin recovering the investment in rates.
In August 2010, Iatan No. 2 successfully completed in-service testing, which was confirmed by KCC in October 2010, but is still subject to confirmation by the MPSC, which is expected during the current Missouri rate cases.
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In the fourth quarter of 2010, Great Plains Energy and KCP&L completed a final cost estimate for Iatan No. 2.  The final cost estimate and previous cost estimate ranges are shown in the following table.  The cost estimate ranges do not include AFUDC or the cost of common facilities that were identified at the time of the start-up of the Iatan No. 1 environmental project that will be used by both Iatan No. 1 and Iatan No. 2.
             
  Final Cost Previous Estimate  
  Estimate Range Range Change
  (millions)
Great Plains Energy's 73% share of Iatan No. 2  $  1,203 - $  1,218  $  1,222 - $  1,251  $     (19) - $     (33)
KCP&L's 55% share of Iatan No. 2         905 -        917         919 -        941         (14) -        (24)
             
Kansas Regulatory Proceedings
In December 2009, KCP&L filed a request with KCC to increase retail electric annual revenues by $55.2 million.  The request was subsequently adjusted by KCP&L during the rate case proceedings to $50.9 million as the net result of updates to the case.  The request included costs related to Iatan No. 2, a new coal-fired generation unit, upgrades to the transmission and distribution system to improve reliability and overall increased costs of service.
In November 2010, KCC issued its order, effective December 1, 2010, authorizing an increase in annual revenues of $21.8 million, a return on equity of 10.0%, an equity ratio of approximately 49.7% and a Kansas jurisdictional rate base of $1.781 billion.  The annual revenue increase was subsequently adjusted by KCC in a January 2011 reconsideration order to $22.0 million.  In February 2011, KCC issued an order granting KCP&L and another party to the case their respective petitions for reconsideration regarding rate case expenses.  The $22.0 million annual revenue increase is considered as interim subject to refund or true-up pending the outcome of the reconsideration proceedings regarding rate case expenses.  Also in February 2011, KCP&L and another party to the case filed petitions for judicial review with the Court of Appeals of the State of Kansas, which are stayed until conclusion of the reconsideration proceedings.  The rates authorized by KCC will be effective unless and until modified by KCC or stayed by a court.
Accounting rules state that when it becomes probable that part of the cost of a recently completed plant will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made, the estimated amount of the probable disallowance shall be deducted from the reported cost of the plant and recognized as a loss.  As a result of disallowances in the KCC order, KCP&L recognized Kansas jurisdictional losses of $4.4 million for construction costs related to Iatan No. 2 and $2.0 million for construction costs related to the Iatan No. 1 environmental project.  Management determined it is probable that the MPSC would disallow these costs as well in KCP&L’s and GMO’s pending rate cases.  Therefore, KCP&L’s Missouri jurisdictional portion and GMO’s portion of these costs were recognized as a loss in addition to the KCP&L Kansas jurisdictional portion resulting in a $16.8 million pre-tax loss representing KCP&L’s and GMO’s combined share for construction costs incurred through December 31, 2010.
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Missouri Regulatory Proceedings
The following table summarizes recentpending requests for retail rate increases with KCCthe MPSC.
           
   Annual       
   Revenue Return on Rate-Making 
Rate JurisdictionFile DateIncrease Equity Equity Ratio 
   (millions)       
KCP&L - Missouri (a)
6/4/2010$92.1  (b) 11.00 %  (b) 46.16 %  (b)
GMO - Missouri Public Service division (a)
6/4/2010 75.8  (c) 11.00 %  (c) 46.16 %  (c)
GMO - St. Joseph Light & Power division (a)
6/4/2010 22.1  (d) 11.00 %  (d) 46.16 %  (d)
              
(a)The request includes costs related to Iatan No. 2, a new coal-fired generation unit, upgrades to the transmission
 and distribution system to improve reliability and overall increased costs of service.  For KCP&L, it also includes
 increased coal transportation costs due to the expiration in 2010 of the majority of KCP&L's current coal
 transportation contracts.  Any authorized changes to retail rates are expected to be effective in May 2011 for
 KCP&L and June 2011 for GMO.
(b)The requested increase was adjusted by KCP&L in a February 22, 2011, filing with the MPSC to $55.8 million
 mainly due to lower fuel and purchased power costs, as there is no fuel recovery mechanism, and increased
 deferred income taxes from bonus depreciation.  The lower fuel and purchased power costs were driven by more
 favorable coal transportation costs and lower actual 2010 fuel and purchased power costs than the amounts
 included in the June 4, 2010, initial request.  The requested return on equity was adjusted by KCP&L to 10.75%
 and the rate-making equity ratio was adjusted to 46.286%.
(c)The requested increase was adjusted by GMO in a February 22, 2011, filing with the MPSC to $65.2 million as
 the net result of updates to the case.  The requested return on equity was adjusted by GMO to 10.75% and the
 rate-making equity ratio was adjusted to 46.286%.
(d)The requested increase was adjusted by GMO in a February 22, 2011, filing with the MPSC to $23.2 million as
 the net result of updates to the case.  The requested return on equity was adjusted by GMO to 10.75% and the
 rate-making equity ratio was adjusted to 46.286%.
In September 2010, GMO received an order from the MPSC approving construction accounting for the Iatan No. 2 project from the Iatan No. 2 in-service date to the effective date of new rates in the current rate case.  The effect of the order is to defer GMO’s share of Iatan No. 2 operating costs, depreciation expense and carrying costs (interest) offset by Iatan No. 2’s system energy value to a regulatory asset rather than impacting the income statement until new rates are effective.  KCP&L (Missouri jurisdiction only) was granted construction accounting as part of the Comprehensive Energy Plan.
In November 2010, the MPSC staff filed its construction audit and prudence review regarding construction expenditures through June 30, 2010, for Iatan No. 2 and the MPSC.
 
    Effective Amount Amount 
Rate JurisdictionFile Date Date Requested Approved 
      (millions)
KCP&L - Kansas (a)
9/5/2008 8/1/2009  $        71.6  $      59.0 
KCP&L - Missouri (b)
9/5/2008 9/1/2009          101.5          95.0 
GMO - Missouri Public Service division (c)
9/5/2008 9/1/2009            66.0          48.0 
GMO - St. Joseph Light & Power division (c)
9/5/2008 9/1/2009            17.1          15.0 
GMO - steam customers in the St. Joseph, Missouri, area (d)
9/5/2008 7/1/2009              1.3            1.0 
KCP&L - Kansas (e)
12/17/2009     (e)            55.2            (e) 
 
(a)$18 million of the amount approved is treated for accounting purposes as additional amortization.  Parties may challenge the
 prudence of the Iatan Unit No. 1 environmental project and the costs of facilities used in common by Iatan Units No. 1 and No.
 2 in KCP&L’s next rate case, but the Kansas jurisdictional portion of any proposed rate base prudence disallowances will not
 exceed (i) $4.7 million for costs paid or approved for payment as of April 30, 2009, and in-service as of July 4, 2009, and (ii)
 $2.8 million for the first $56 million of costs not paid or approved for payment as of April 30, 2009.  There is no cap as to the
 amount of disallowances that may be proposed for costs above this $56 million amount.
(b)$10 million of the amount approved is treated for accounting purposes as additional amortization.  Parties may challenge the
 prudence of the Iatan Unit No. 1 environmental project and the cost of facilities used in common by Iatan Units No. 1 and No. 2
 in KCP&L’s next rate case, but the Missouri jurisdictional portion of any proposed rate base prudence disallowances will not
 exceed $30 million in aggregate.
(c)Parties may challenge the prudence of the cost of the Iatan Unit No. 1 environmental project and the cost of facilities used in
 common by Iatan Units No. 1 and No. 2 in GMO’s next rate case, but the GMO portion of any proposed rate base prudence
 disallowances will not exceed $15 million in aggregate.
(d)The order allows for the Quarterly Cost Adjustment (QCA) fuel sharing mechanism to be established at 85% above the fuel
 cost included in base rates.  The previous sharing mechanism was set at 80% above the fuel cost included in base rates.
(e)The request includes costs related to Iatan No. 2, a new coal-fired generation unit, upgrades to the transmission and
 distribution system to improve reliability and overall increased costs of service.  KCP&L requested a return on equity of
 11.25% based upon a capital structure of 46.17% equity.  Any authorized changes to retail rates are expected to be effective
 in the fourth quarter of 2010.
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KCP&L’s Comprehensive Energy PlanIatan No. 1 environmental project.  The MPSC staff recommended disallowances of approximately $130 million and Collaboration Agreement
In 2009, KCP&L completed$70 million of the total costs incurred through June 30, 2010, for Iatan No. 2 and the Iatan No. 1 environmental project, respectively, representing all audited expenditures above the associated December 2006 control budget estimates of approximately $1.685 billion and certain Iatan common facilities.$377 million.
The MPSC staff also filed testimony in KCP&L’s and GMO’s rate cases in November 2010.  The MPSC staff’s testimony recommended a return on equity range of 8.5% to 9.5% and revenue increase/(decrease) ranges of approximately $(0.2) million to $14 million for KCP&L, continuesapproximately $0.9 million to make progress on$10.1 million for GMO’s Missouri Public Service division, and approximately $28.8 million to $32.6 million for GMO’s St. Joseph Light & Power division.  On February 22, 2011, the construction of Iatan No. 2 and is entering the start-up phase of the project.  The start-up of any power plant this size, which uses advanced generation technology, is a very complex and difficult process.  It involves a high degree of interaction and coordination from major vendors as well as internal construction and operational teams.  In January 2010, KCP&L announced that the expected in-service date of Iatan No. 2 would be delayed about two months to the fall of 2010.  AtMPSC Staff filed updated testimony recommending the same time,return on equity range of 8.5% to 9.5% and revenue increase ranges of approximately $2.2 million to $17.0 million for KCP&L, announced that it was commencing aapproximately $29,000 to $9.2 million for GMO's Missouri Public Service division, and approximately $14.9 million to $18.4 million for GMO's St. Joseph Light & Power division.  The revenue
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recommendations reflect the MPSC staff’s proposed construction cost and schedule reforecast fordisallowances of all audited expenditures as of October 31, 2010, above the Iatan No. 2 project, with completion expected by the end of the first quarter of 2010.  The following table summarizes the current costcontrol budget estimates, for Iatan No. 2, exclusive of AFUDC, based upon the last cost and schedule reforecast completed in the second quarter of 2009.
     
  Current Estimate
  Range
  (millions)
Great Plains Energy's 73% share of Iatan No. 2  $ 1,153 - $ 1,201
KCP&L's 55% share of Iatan No. 2        868 -       904
     
In March 2007, KCP&L, the Sierra Club and the Concerned Citizens of Platte County entered into a Collaboration Agreement that resolved disputes among the parties.  KCP&L agreed in the Collaboration Agreement to pursue initiatives, including energy efficiency, designed to offset CO2 emissions.  Great Plains Energy and KCP&L are also evaluating energy efficiency projects as one of the elements to meet future customer energy needs.  The companies currently recover energy efficiency program expenses on a deferred basis.  While there are ongoing regulatory proceedings in Missouri and Kansas to address recovery of and earnings on the investments of utilities in energy efficiency programs, until these rules are set and programs are approved, the effects on Great Plains Energy’s andother differences from KCP&L’s plans and future results cannot be reasonably estimated.  However, management views this as a positive development in establishing a regulatory framework for energy efficiency programs and potentially allowing energy efficiency costs to be recovered through rates similar to the recovery of generation resource costs.GMO’s requests.  
 
In the Collaboration Agreement,Hearings were held beginning in late January 2011 for KCP&L agreed to pursue other initiatives including additional wind generation, lower emission permit levels at its Iatan and LaCygne generating stations and other initiatives designed to offset CO2 emissions.  KCP&L also agreed to offset an additional 711,000 tons of CO2 by the end of 2012.  KCP&L currently expects to achieve this offsetran through a number of alternatives, including improving the efficiency of its coal-fired units, equipping certain gas-fired unitsmid-February 2011 for winter operation and, if necessary, possibly reducing output of, or retiring, one or more coal-fired units.  Full implementationGMO.  The MPSC Staff will file reconciliations of the terms of the Collaboration Agreement will necessitate approval from the appropriate authorities, as some of the initiativesdifferences between its February 22, 2011, recommendations and KCP&L's and GMO's February 22, 2011, recommendations with hearings scheduled for March 3 - 4, 2011.  New rates are expected to go into effect in the agreement require regulatory approval.May 2011 for KCP&L and June 2011 for GMO.
 
KCP&L agreed in the Collaboration Agreement to pursue increasing its wind generation capacity by 100MW by the end of 2010 and by an additional 300MW of wind generation capacity by the end of 2012, subject to regulatory approval.  In 2009, KCP&L purchased thirty-two turbines for a purchase price of approximately $68 million, plus approximately $17 million for various third party development and assignment costs.  In December 2009, KCP&L issued requests for proposals to add up to 300MW of wind generation in the 2010 – 2011 timeframe under purchase power agreements and/or the combination of purchase power agreements and arrangements where KCP&L would own and operate the facilities after development and construction.  KCP&L expects that the thirty-two turbines purchased in 2009 will be utilized in one of the projects under proposal.  KCP&L is evaluating the proposals and anticipates securing the rights to 100MWs of wind resources by the end of 2010.
SPP and NERC Audits
In November 2009, the Southwest Power Pool, Inc. (SPP) and the North American Electric Reliability Corporation (NERC) conducted scheduled audits of KCP&L and GMO regarding compliance with NERC
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reliability and critical infrastructure protection standards.  KCP&L and GMO received the final audit report alleging violation of certain standards and management anticipates paying a penalty that will have an immaterial impact to cash flows and results of operations.  The SPP also conducted a compliance inquiry regarding a transmission system outage that occurred in the St. Joseph, Missouri area in the summer of 2009.  NERC isalso is looking intoinvestigating the circumstances surrounding this transmission system outage.  The inquiries regardingoutcome of the outage are at a preliminary stage and their outcomeinquiry cannot be predicted at this time.
 
Energy Efficiency
Great Plains Energy and KCP&L have implemented various energy efficiency programs.  KCP&L also agreed in the Collaboration Agreement to pursue initiatives, including energy efficiency, designed to offset CO2 emissions.  The Companies currently recover energy efficiency program expenses on a deferred basis with no recovery mechanism for associated lost revenues.  An MPSC rulemaking proceeding in Missouri to address recovery of and earnings on investments in energy efficiency programs is near completion with final rules expected to be effective in the second quarter of 2011.  Great Plains Energy and KCP&L will evaluate alternatives for future energy efficiency programs under these new rules.
MPSC Regulatory Approval of the GMO Acquisition
Appeals of the MPSC order approving the GMO acquisition were filed with the Cole County, Missouri, Circuit Court, which affirmed the order in June 2009.  That decision was appealed and the Missouri Court of Appeals, Western District, upheld the MPSC order in August 2010.  The case was transferred to the Missouri Supreme Court in December 2010.
GMO Missouri 2007 Rate Case Appeal
Appeals of the May 2007 MPSC order approving an approximate $59 million increase in annual revenues were filed in July and August of 2007 with the Circuit Court of Cole County, Missouri, by the Office of Public Counsel, AG Processing, Sedalia Industrial Energy Users’ Association and AARP seeking to set aside or remand the order of the MPSC.  In February 2009, the Circuit Court affirmed the MPSC order.  The Circuit Court’s decision was affirmed by the Court of Appeals in August 2009, and2009.  The case was transferred to the appellants have sought Missouri Supreme Court review.  The order remains in effect unless reversed byAugust 2010.  In December 2010, the courts.

GMO RTO Application
GMO’s application to transfer functional control of its transmission systemMissouri Supreme Court re-transferred the case to the Midwest Independent Transmission System Operator, Inc. (MISO) RTO was denied by the MPSC in October 2008.  In December 2008, GMO submitted a request to FERC to withdraw from MISO based on this MPSC denial.  GMOCourt of Appeals, Western District, which re-adopted its opinion and MISO negotiated an agreement regarding this exit under which GMO would pay an insignificant amount of exit fees to MISO.  This agreement was approved by FERC in May 2009.
In November 2008, GMO requested MPSC authorization to transfer functional control of its transmission system to the Southwest Power Pool, Inc. (SPP).  On February 4, 2009, the MPSC approved a Stipulation and Agreement between GMO and several parties authorizing the transfer of functional control.  GMO transferred functional control of its transmission system to the SPP effective April 15, 2009.  In September 2009, GMO entered the SPP energy imbalance market.
Great Plains Energy’s Acquisition of GMO
See Note 2 for a discussion of the pending appeals ofre-affirmed the MPSC order authorizing the acquisition.on January 4, 2011.  The Company does not currently expect any further action with respect to this matter.

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 companiesCompanies were not regulated.  Regulatory assets represent incurred costs that are probable of recovery from future revenues.  Regulatory liabilities represent: amounts imposed by rate actions of regulators that may requirerepresent future reductions in revenues or refunds to customers; amounts provided in current rates that are intended to recover costs that are expected to be incurred in the future for which the companies remain accountable; or a gain or other reduction of allowable costs to be given to customers over future periods.  Future recovery of regulatory assets is not assured, but is generally subject to review by regulators in rate proceedings for matters such as prudence and reasonableness.  Future reductions in revenue or refunds for regulatory liabilities generally are not mandated, pending future rate proceedings or actions by the regulators.customers.
 
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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 onin 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;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’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.industry or changes in accounting rules.  In the event that the criteria no longer applied to a deregulated portionany or all of the companies’Companies’ operations, the related regulatory assets and liabilities would be written off unless an appropriate regulatory recovery mechanism is provided.  Additionally, these factors could result in an impairment on utility plant assets.
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Great Plains Energy’s and KCP&L’s regulatory assets and liabilities are detailed in the following tables.
                     
         Great       Great
December 31, 2009 KCP&L   GMO   Plains Energy
December 31, 2010 KCP&L GMO Plains Energy
Regulatory Assets (millions)  (millions)
Taxes recoverable through future rates $77.6   $22.9 
 (a)
 $100.5  $117.2   $25.3   $142.5 
Loss on reacquired debt
  5.3 
 (b)
  0.3 
 (b)
  5.6 
Loss on reacquired debt  5.0 
 (a)
  0.7 
 (a)
  5.7 
Cost of removal  7.9    -    7.9   8.5    -    8.5 
Asset retirement obligations  23.8    11.9    35.7   27.5    12.8    40.3 
Pension settlements  13.5 
 (c)
  -    13.5   9.0 
 (b)
  -    9.0 
Pension and post-retirement costs  395.0 
 (d)
  84.5 
 (d)
  479.5   377.1 
 (c)
  106.7 
 (c)
  483.8 
Deferred customer programs  35.6 
 (e)
  7.1    42.7   44.7 
 (d)
  15.6    60.3 
Rate case expenses  7.4 
 (f)
  1.5 
 (f)
  8.9   12.3 
 (e)
  3.3 
 (e)
  15.6 
Skill set realignment costs  6.1 
 (g)
  -    6.1   4.8 
 (f)
  -    4.8 
Under-recovery of energy costs  0.7 
 (f)
  47.5 
 (f)
  48.2 
Fuel adjustment clauses  8.4 
 (e)
  37.1 
 (e)
  45.5 
Acquisition transition costs  29.3 
 (h)
  22.2 
 (h)
  51.5   29.3 
 (g)
  22.5 
 (g)
  51.8 
St. Joseph Light & Power acquisition  -    3.1 
 (i)
  3.1   -    2.6 
 (h)
  2.6 
Storm damage  -    4.8 
 (j)
  4.8   -    3.2 
 (i)
  3.2 
Derivative instruments  -    2.1 
 (k)
  2.1   -    3.1 
 (j)
  3.1 
Iatan No. 1 and Common facilities depreciation and carrying costs  15.1 
 (k)
  4.3 
 (l)
  19.4 
Iatan No. 2 construction accounting costs  17.2 
 (l)
  6.5 
 (l)
  23.7 
Other  9.9 
 (l)
  2.2 
 (l)
  12.1   3.5 
 (m)
  0.7 
 (m)
  4.2 
Total $612.1   $210.1   $822.2  $679.6   $244.4   $924.0 
Regulatory Liabilities                            
Emission allowances $86.2   $0.8   $87.0  $85.9   $0.5   $86.4 
Asset retirement obligations  33.4    -    33.4   44.9    -    44.9 
Pension  -    34.0    34.0   -    37.1    37.1 
Cost of removal  -    62.5 
 (m)
  62.5   -    62.8 
 (n)
  62.8 
Other  7.3    13.6    20.9   10.5    16.5    27.0 
Total $126.9   $110.9   $237.8  $141.3   $116.9   $258.2 
                            
(a)In GMO’s most recent rate case, GMO agreed not to seek recovery of the regulatory asset for previously flowed-through tax benefits on cost of removal timing deductions, which resulted in GMO recording a $28.9 million decrease in the regulatory asset, offset by deferred taxes of $11.1 million and goodwill of $17.8 million.
(b)  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)(b)  $7.45.0 million not included in rate base and amortized through 2012.
(d)(c)  Represents the funded status of the pension plans more than offset by related liabilities.  Also represents financial and regulatory accounting method differences not included in rate base that will be eliminated over the life of the pension plans.
(e)(d)  $13.113.2 million not included in rate base and amortized over various periods.
(f)(e)  Not included in rate base and amortized over various periods.
(g)(f)  $3.22.8 million not included in rate base and amortized through 2017.
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(g)  Not included in rate base.  The MPSC order provided for the deferral of transition costs to be amortized over a five-year period to the extent that synergy savings exceed transition cost amortization.  The Company settled its first post-transaction rate cases and the settlement agreements did not address transition costs.  The Company will continue to defer transition costs until amortization is ordered by the MPSC.  KCC order approved the deferral of up to $10.0 million of transition costs to be amortized over a five-year period beginning with rates effective in December 2010.
(h)  Not included in rate base and amortized through 2015.
(i)  Not included in rate base and amortized through 2015.2012.
(j)Not included in rate base and amortized through 2012.
(k)  Represents the fair value of derivative instruments for commodity contracts.  Settlements of the contracts are recognized in fuel expense and included in GMO’s fuel adjustment clause (FAC).
(k)  $11.6 million not included in rate base and under consideration in the pending Missouri rate case.
(l)Not included in rate base and under consideration in the pending Missouri rate cases.
(m)  Certain insignificant items are not included in rate base and amortized over various periods.
(m)(n)  Estimated cumulative net provision for future removal costs.
          
      Great
December 31, 2009 KCP&L GMO Plains Energy
Regulatory Assets (millions)
Taxes recoverable through future rates $77.6  $22.9  $100.5 
Loss on reacquired debt  5.3   0.3   5.6 
Cost of removal  7.9   -   7.9 
Asset retirement obligations  23.8   11.9   35.7 
Pension settlements  13.5   -   13.5 
Pension and post-retirement costs  395.0   84.5   479.5 
Deferred customer programs  35.6   7.1   42.7 
Rate case expenses  7.4   1.5   8.9 
Skill set realignment costs  6.1   -   6.1 
Fuel adjustment clauses  0.7   47.5   48.2 
Acquisition transition costs  29.3   22.2   51.5 
St. Joseph Light & Power acquisition  -   3.1   3.1 
Storm damage  -   4.8   4.8 
Derivative instruments  -   2.1   2.1 
Iatan No. 1 and Common facilities depreciation and carrying costs  4.6   1.4   6.0 
Other  5.3   0.8   6.1 
Total $612.1  $210.1  $822.2 
Regulatory Liabilities            
Emission allowances $86.2  $0.8  $87.0 
Asset retirement obligations  33.4   -   33.4 
Pension  -   34.0   34.0 
Cost of removal  -   62.5   62.5 
Other  7.3   13.6   20.9 
Total $126.9  $110.9  $237.8 
             
7.  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, 2010.  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
 
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        Great
December 31, 2008 KCP&L  GMO  Plains Energy
Regulatory Assets (millions) 
Taxes recoverable through future rates $71.6  $46.8  $118.4 
Loss on reacquired debt  5.7   0.3   6.0 
Cost of removal  9.6   -   9.6 
Asset retirement obligations  21.1   12.0   33.1 
Pension settlements  18.0   -   18.0 
Pension and post-retirement costs  417.6   63.0   480.6 
Deferred customer programs  22.6   0.4   23.0 
Rate case expenses  2.9   0.6   3.5 
Skill set realignment costs  7.5   -   7.5 
Under-recovery of energy costs  1.6   52.0   53.6 
Acquisition transition costs  25.5   17.6   43.1 
St. Joseph Light & Power acquisition  -   3.6   3.6 
Storm damage  -   6.4   6.4 
Derivative instruments  -   9.7   9.7 
Other  5.4   3.3   8.7 
Total $609.1  $215.7  $824.8 
Regulatory Liabilities            
Emission allowances $86.5  $1.0  $87.5 
Asset retirement obligations  22.7   -   22.7 
Pension  -   25.0   25.0 
Cost of removal  -   58.1   58.1 
Other  6.6   9.5   16.1 
Total $115.8  $93.6  $209.4 
             
8.  INTANGIBLE ASSETS
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 and net utility asset values and market prices of stock of electric and gas company regulated peers.  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, 2009 December 31, 2008 December 31, 2010  December 31, 2009
 Gross Carrying Accumulated Gross Carrying Accumulated Gross CarryingAccumulated  Gross CarryingAccumulated
 Amount Amortization Amount Amortization Amount Amortization  Amount Amortization
KCP&L  (millions) (millions)
Computer software $147.0  $(106.3) $136.7  $(95.4) $168.2  $(118.0)  $147.0  $(106.3)
Transmission line  5.8   -    -   - 
                                 
Great Plains Energy                                 
Computer software $170.8  $(117.8) $160.5  $(106.0) $201.1  $(137.3)  $170.8  $(117.8)
Transmission line upgrades  22.1   (3.7)  22.1   (3.3)
Transmission line and upgrades  27.9   (4.4)   22.1   (3.7)
Organization start-up costs  0.1   -   0.1   -   0.1   -    0.1   - 
                 
Great Plains Energy’s and KCP&L’s amortization expense related to intangible assets is detailed in the following table.
       
  2010 2009
  (millions)
Great Plains Energy $13.1  $10.9 
KCP&L  12.2   10.4 
         
The following table provides the estimated amortization expense related to Great Plains Energy’s and KCP&L’s intangible assets for 2011 through 2015 for the intangible assets included in the consolidated balance sheets at December 31, 2010.
                
  2011 2012 2013 2014 2015
  (millions)
Great Plains Energy $12.7  $10.8  $8.4  $5.0  $2.9 
KCP&L  11.9   10.0   7.6   4.3   2.3 
                     
9.8.  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 and 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.
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In 2008, KCP&L recorded a $1.6 million reductionhas AROs related to its ARO to decommissiondecommissioning Wolf Creek, which reflects a 2008 updatesite remediation of its Spearville Wind Energy Facilities, asbestos abatement and for removal of storage tanks, an ash pond and landfill.  GMO has AROs related to the decommissioning study cost estimates.asbestos abatement, an ash pond and landfill and removal of storage tanks and communication towers.
 
Asbestos abatement activity has occurred on certain generating units at KCP&L’s Hawthorn Station resulting in a revision in timing used to compute the original present value of the asbestos ARO.  Management was able to perform an analysis to update prior cost estimates determining an increase in comparison to previous estimates used in computing the original asbestos ARO.  As a result of the increased costs experienced in the project at KCP&L’s Hawthorn station, management updated prior cost estimates for KCP&L’s Montrose and LaCygne Stations, determining an increase in comparison to previous estimates.  As a result of these changes, KCP&L recorded a $14.2 million increase in the ARO for asbestos abatement with a corresponding increase in asset retirement costs in 2008.
In addition, management has identified an additional asbestos ARO.  TheCertain wiring used in generating stations includes 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, a fair value of the obligation 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.
 
KCP&L also has AROs related to decommissioning and site remediation of its Spearville Wind Energy Facility and for removal of storage tanks, an ash pond and landfill.  GMO has AROs related to asbestos in certain plants and buildings, an ash pond and landfill and removal of storage tanks and communication towers.
The following table summarizes the change in Great Plains Energy’s and KCP&L’s AROs.
             
 Great Plains Energy KCP&L Great Plains Energy  KCP&L
 2009 2008 2009 2008 2010  2009 2010 2009
 (millions)  (millions)
Beginning balance $124.3  $94.5  $111.9  $94.5  $132.6   $124.3  $119.8  $111.9 
Additions  1.2   1.4   0.6   1.4   2.0    1.2   2.0   0.6 
Revision in timing and/or estimates  (1.0)  12.6   -   12.6   -    (1.0)  -   - 
GMO acquisition  -   11.7   -   - 
Settlements  -   (3.2)  -   (3.2)
Accretion  8.1   7.3   7.3   6.6   8.7    8.1   7.9   7.3 
Ending balance $132.6  $124.3  $119.8  $111.9  $143.3   $132.6  $129.7  $119.8 
                 
10.9.  PENSION PLANS AND OTHER EMPLOYEE BENEFITS AND SKILL SET REALIGNMENT COSTS
 
Pension Plans and Other Employee Benefits
The CompanyGreat Plains Energy maintains defined benefit pension plans for substantially all active and inactive employees, including officers, of KCP&L, GMO, and WCNOCWolf Creek Nuclear Operating Corporation (WCNOC) and incurs significant costs in providing the plans.  Pension benefits under these plans reflect the employees’ compensation, years of service and age at retirement.
 
KCP&L and GMO record pension expense in accordance with rate orders from the MPSC and KCC that allow the difference between pension costs under GAAP and pension 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 pension plans.
 
In addition to providing pension benefits, the CompanyGreat Plains Energy provides certain post-retirement health care and life insurance benefits for substantially all retired employees of KCP&L, GMO, and WCNOC.  The cost of post-retirement benefits charged to KCP&L and GMO are accrued during an employee's years of service and recovered through rates.
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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.  KCP&L uses a five-year smoothing of assets to determine fair value for regulatory reporting purposes.  As a result of the GMO acquisition on July 14, 2008, the Company’s 2008 pension and post-retirement expenses under GAAP increased $2.4 million and $1.1 million, respectively.  The underfunded status of the pension and other post-retirement benefit plans transferred at the date of acquisition was $48.9 million.  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
  2009 2008 2009 2008
Change in projected benefit obligation (PBO) (millions) 
PBO at beginning of year $772.5  $512.9  $135.4  $73.7 
Service cost  29.1   20.8   4.1   1.7 
Interest cost  47.3   37.6   8.3   5.7 
Contribution by participants  -   -   5.3   3.0 
Amendments  5.7   -   3.4   18.7 
Actuarial loss  33.1   42.9   3.9   1.2 
Benefits paid  (49.3)  (37.1)  (11.5)  (7.0)
Early measurement adjustment  -   1.0   -   0.3 
GMO acquisition  -   194.4   -   38.1 
Settlements  (2.1)  -   -   - 
PBO at end of plan year $836.3  $772.5  $148.9  $135.4 
Change in plan assets                
Fair value of plan assets at beginning of year $418.7  $400.1  $38.9  $14.0 
Actual return on plan assets  75.1   (145.6)  0.7   (3.8)
Contributions by employer and participants  42.1   28.7   22.0   11.0 
Benefits paid  (47.7)  (36.6)  (9.6)  (5.7)
Early measurement adjustment  -   4.0   -   7.9 
GMO acquisition  -   168.1   -   15.5 
Fair value of plan assets at end of plan year $488.2  $418.7  $52.0  $38.9 
Funded status at end of year $(348.1) $(353.8) $(96.9) $(96.5)
Amounts recognized in the consolidated balance sheets                
Current pension and other post-retirement liability $(3.7) $(3.9) $(0.9) $(0.8)
Noncurrent pension liability and other post-retirement liability  (344.4)  (349.9)  (96.0)  (95.7)
Net amount recognized before regulatory treatment  (348.1)  (353.8)  (96.9)  (96.5)
Accumulated OCI or regulatory asset/liability  386.2   420.2   74.0   59.1 
Net amount recognized at December 31 $38.1  $66.4  $(22.9) $(37.4)
Amounts in accumulated OCI or regulatory asset/liability                
not yet recognized as a component of net periodic cost:                
Actuarial loss $227.8  $273.3  $19.3  $19.1 
Prior service cost  19.4   17.9   51.3   33.4 
Transition obligation  0.1   0.2   4.3   4.4 
Other  138.9   128.8   (0.9)  2.2 
Net amount recognized at December 31 $386.2  $420.2  $74.0  $59.1 
                 

 
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  Pension Benefits Other Benefits
  2010 2009 2010 2009
Change in projected benefit obligation (PBO) (millions)
PBO at beginning of year $836.3  $772.5  $148.9  $135.4 
Service cost  30.3   29.1   3.8   4.1 
Interest cost  49.3   47.3   8.8   8.3 
Contribution by participants  -   -   5.6   5.3 
Amendments  0.5   5.7   -   3.4 
Actuarial (gain) loss  55.1   33.1   (12.5)  3.9 
Benefits paid  (60.1)  (49.3)  (11.0)  (11.5)
Settlements  -   (2.1)  -   - 
PBO at end of plan year $911.4  $836.3  $143.6  $148.9 
Change in plan assets                
Fair value of plan assets at beginning of year $488.2  $418.7  $52.0  $38.9 
Actual return on plan assets  62.7   75.1   0.5   0.7 
Contributions by employer and participants  64.5   42.1   23.9   22.0 
Benefits paid  (57.8)  (47.7)  (10.6)  (9.6)
Fair value of plan assets at end of plan year $557.6  $488.2  $65.8  $52.0 
Funded status at end of year $(353.8) $(348.1) $(77.8) $(96.9)
Amounts recognized in the consolidated balance sheets                
Current pension and other post-retirement liability $(3.1) $(3.7) $(1.0) $(0.9)
Noncurrent pension liability and other post-retirement liability  (350.7)  (344.4)  (76.8)  (96.0)
Net amount recognized before regulatory treatment  (353.8)  (348.1)  (77.8)  (96.9)
Accumulated OCI or regulatory asset/liability  403.2   386.2   54.8   74.0 
Net amount recognized at December 31 $49.4  $38.1  $(23.0) $(22.9)
Amounts in accumulated OCI or regulatory asset/liability                
not yet recognized as a component of net periodic cost:                
Actuarial loss $219.5  $227.8  $8.5  $19.3 
Prior service cost  15.3   19.4   44.1   51.3 
Transition obligation  -   0.1   3.0   4.3 
Other  168.4   138.9   (0.8)  (0.9)
Net amount recognized at December 31 $403.2  $386.2  $54.8  $74.0 
                 
                   
  Pension Benefits  Other Benefits 
  2009  2008  2007  2009  2008  2007 
Components of net periodic benefit costs (millions) 
Service cost $29.1  $20.8  $18.4  $4.1  $1.7  $1.2 
Interest cost  47.3   37.6   29.8   8.3   5.7   3.9 
Expected return on plan assets  (32.4)  (38.6)  (29.5)  (1.6)  (1.0)  (0.7)
Prior service cost  4.2   4.2   4.3   6.9   2.7   2.1 
Recognized net actuarial (gain) loss  36.3   32.3   35.3   (0.4)  0.6   0.5 
Transition obligation  0.1   0.1   0.1   1.3   1.2   1.2 
Special termination benefits  -   -   1.5   -   -   0.2 
Settlement charges  0.1   -   -   -   -   - 
Net periodic benefit costs before                        
regulatory adjustment  84.7   56.4   59.9   18.6   10.9   8.4 
Regulatory adjustment  (28.4)  (3.5)  (9.1)  (0.3)  -   (0.1)
Net periodic benefit costs  56.3   52.9   50.8   18.3   10.9   8.3 
Other changes in plan assets and benefit                        
obligations recognized in OCI or                        
regulatory assets/liabilities (a)
                        
Current year net (gain) loss  (9.2)  227.1   (23.4)  (0.2)  6.0   2.7 
Amortization of gain (loss)  (36.3)  (39.9)  (35.3)  0.4   (0.7)  (0.5)
Prior service cost (credit)  5.7   -   (0.9)  24.8   18.7   19.6 
Amortization of prior service cost  (4.2)  (5.2)  (4.3)  (6.9)  (3.4)  (2.1)
Transition obligation  -   -   -   1.2   -   - 
Amortization of transition obligation  (0.1)  -   (0.1)  (1.3)  (1.4)  (1.2)
Other regulatory activity  10.1   52.8   9.1   (3.1)  2.1   0.1 
Total recognized in OCI or regulatory asset/liability (34.0)  234.8   (54.9)  14.9   21.3   18.6 
Total recognized in net periodic benefit costs                        
and OCI or regulatory asset/liability $22.3  $287.7  $(4.1) $33.2  $32.2  $26.9 
(a) 2008 includes the effect of the remeasurement adjustment
86
 
 
  Pension Benefits Other Benefits
  2010 2009 2008 2010 2009 2008
Components of net periodic benefit costs (millions)
Service cost $30.3  $29.1  $20.8  $3.8  $4.1  $1.7 
Interest cost  49.3   47.3   37.6   8.8   8.3   5.7 
Expected return on plan assets  (36.6)  (32.4)  (38.6)  (2.1)  (1.6)  (1.0)
Prior service cost  4.6   4.2   4.2   7.2   6.9   2.7 
Recognized net actuarial (gain) loss  37.4   36.3   32.3   (0.1)  (0.4)  0.6 
Transition obligation  0.1   0.1   0.1   1.3   1.3   1.2 
Settlement charges  -   0.1   -   -   -   - 
Net periodic benefit costs before                        
regulatory adjustment  85.1   84.7   56.4   18.9   18.6   10.9 
Regulatory adjustment  (32.3)  (28.4)  (3.5)  -   (0.3)  - 
Net periodic benefit costs  52.8   56.3   52.9   18.9   18.3   10.9 
Other changes in plan assets and benefit                        
obligations recognized in OCI or                        
regulatory assets/liabilities (a)
                        
Current year net (gain) loss  29.1   (9.2)  227.1   (10.9)  (0.2)  6.0 
Amortization of gain (loss)  (37.4)  (36.3)  (39.9)  0.1   0.4   (0.7)
Prior service cost  0.5   5.7   -   -   24.8   18.7 
Amortization of prior service cost  (4.6)  (4.2)  (5.2)  (7.2)  (6.9)  (3.4)
Transition obligation  -   -   -   -   1.2   - 
Amortization of transition obligation  (0.1)  (0.1)  -   (1.3)  (1.3)  (1.4)
Other regulatory activity  29.5   10.1   52.8   0.1   (3.1)  2.1 
Total recognized in OCI or regulatory asset/liability  17.0   (34.0)  234.8   (19.2)  14.9   21.3 
Total recognized in net periodic benefit costs                        
and OCI or regulatory asset/liability $69.8  $22.3  $287.7  $(0.3) $33.2  $32.2 
(a) 2008 includes the effect of the remeasurement adjustment

For financial reporting purposes, the estimated prior service cost, net loss and transition costs for the defined benefit plans that will be amortized from accumulated OCI or a regulatory asset into net periodic benefit cost in 20102011 are $4.6$4.5 million, $37.4$38.5 million and $0.1 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 20102011 are $7.2 million, $0.1$(1.0) million and $1.3 million, respectively.

 
8887
 
The accumulated benefit obligation (ABO) for all defined benefit pension plans was $741.4$808.8 million and $675.7$741.4 million at December 31, 20092010 and 2008,2009, respectively.  The PBO, ABO and the fair value of plan assets at plan year-end are aggregated by funded and under funded plans in the following table.
            
 2009  2008  2010 2009
Pension plans with the ABO in excess of plan assets (millions)  (millions)
Projected benefit obligation $836.3  $772.5  $911.4  $836.3 
Accumulated benefit obligation  741.4   675.7   808.8   741.4 
Fair value of plan assets  488.2   418.7   557.6   488.2 
Pension plans with plan assets in excess of the ABO                
Projected benefit obligation $-  $-  $-  $- 
Accumulated benefit obligation  -   -   -   - 
Fair value of plan assets  -   -   -   - 
                
The GMO SERP is reflected as an unfunded ABO of $20.1$21.1 million.  The Company has segregated approximately $22.8$21.5 million of assets for this plan as of December 31, 2009,2010, and expects to fund future benefit payments from these assets.
 
The expected long-term rate of return on plan assets represents the Company’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 determinePension Benefits Other Benefits Pension BenefitsOther Benefits
the benefit obligation at plan year-end2009 2008 2009 2008 2010200920102009
Discount rate5.92% 6.11% 5.87% 6.10% 5.54%5.92%5.50%5.87%
Rate of compensation increase4.26% 4.27% 4.25% 4.25% 4.08%4.26%4.06%4.25%
                
                
Weighted average assumptions used to determinePension Benefits Other Benefits Pension BenefitsOther Benefits
net costs for years ended at December 312009 2008 2009 2008 2010200920102009
Discount rate6.11% 6.23% 6.10% 6.23% 5.92%6.11%5.87%6.10%
Expected long-term return on plan assets8.00% 8.25% 4.00%*4.00%*8.00%    4.25% *    4.00% *
Rate of compensation increase4.27% 4.22% 4.25% 4.25% 4.26%4.27%4.25%
* after tax                

For pension benefits, the Company's 2011 projected weighted average long-term rate of return on plan assets is 7.3%, a 0.7% decrease from 2010.  The reduction in the rate of return is expected to increase 2011 GAAP pension expense approximately $4 million.
The Company expects to contribute $53.6$104.6 million to the pension plans in 20102011 to meet ERISAEmployee Retirement Income Security Act of 1974 (ERISA) funding requirements and regulatory orders, the majority of which is expected to be paid by KCP&L.  The Company’s funding policy is to contribute amounts sufficient to meet the ERISA minimum funding requirements and MPSC and KCC rate orders plus additional amounts as considered appropriate; therefore, actual contributions may differ from expected contributions.  The Company also expects to contribute $18.0$15.8 million to other post-retirement benefit plans in 2010,2011, the majority of which is expected to be paid by KCP&L.
 
8988
 
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid through 2019.2020.
            
 Pension Other Pension Other
 Benefits Benefits Benefits Benefits
 (millions)  (millions)
2010 $70.7  $15.2 
2011  58.6   17.0  $71.4  $8.4 
2012  64.8   18.7   66.9   8.3 
2013  61.6   20.7   66.2   8.4 
2014  63.6   22.7   65.3   8.6 
2015-2019  346.9   143.4 
2015  67.9   8.6 
2016-2020  370.0   47.7 
                
Pension plan assets are managed in accordance with “prudent investor” guidelines contained in the Employee Retirement Income Security Act of 1974 (ERISA)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 35%28% U.S. large cap and small cap equity securities, 20%22% international equity securities, 32%37% fixed income securities, 7% real estate and 6% commodities.  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.
 
9089
 
The fair values of the Company’s pension plan assets at December 31, 2010 and 2009, by asset category are in the following table.tables.
              
      Fair Value Measurements Using 
Description 
December 31 
2009
 
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)
 $188.8  $102.9  $85.9  $- 
 
International (b)
  75.2   18.4   56.8   - 
 Limited partnerships  0.1   -   -   0.1 
 
Real estate (c)
  26.8   -   -   26.8 
 
Commodities (d)
  17.6   -   17.6   - 
 Fixed income securities                
 
Fixed income funds (e)
  117.9   3.0   114.9   - 
 U.S. Treasury notes  1.3   1.3   -   - 
 U.S. Agency, state and local obligations  18.7   -   18.7   - 
 
U.S. corporate bonds (f)
  25.5   0.9   24.6   - 
 Foreign corporate bonds  1.2   -   1.2   - 
 Hedge fund  2.4   -   -   2.4 
 Total  $475.5   $126.5   $319.7   $29.3 
 Cash equivalents - money market funds  12.7             
 Total Pension Plans $488.2             
                  
(a)This category is comprised of $102.9 million of traded mutual funds valued at daily listed prices and $85.9 million of
 institutional common/collective trust funds valued at daily Net Asset Values (NAV) per share.
(b)This category is comprised of $18.4 million of traded mutual funds valued at daily listed prices and $56.8 million 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)This category is comprised of $3.0 million of traded mutual funds valued at daily listed prices and $114.9 million of
 institutional common/collective trust funds valued at daily NAV per share.
(f)This category is comprised of $13.0 million of corporate bonds, $9.3 million of collateralized mortgage obligations and $3.2
 million of other asset-backed securities.
             
     Fair Value Measurements Using 
Description 
December 31 
2010
 
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)
 $158.5  $90.5  $68.0  $- 
International (b)
  122.4   39.4   83.0   - 
Limited partnerships  0.1   -   -   0.1 
Real estate (c)
  30.3   -   -   30.3 
Commodities (d)
  37.0   -   37.0   - 
Fixed income securities                
Fixed income funds (e)
  148.7   23.0   125.7   - 
U.S. Treasury notes  1.8   1.8   -   - 
U.S. Agency, state and local obligations  14.8   -   14.8   - 
U.S. corporate bonds (f)
  24.2   -   24.2   - 
Foreign corporate bonds  1.5   -   1.5   - 
Hedge funds (g)
  8.4   -   -   8.4 
Total $547.7  $154.7  $354.2  $38.8 
Cash equivalents - money market funds  9.9             
Total Pension Plans $557.6             
                 



90

              
      Fair Value Measurements Using 
Description 
December 31
2009
 
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)
 $188.8  $102.9  $85.9  $- 
 
International (b)
  75.2   18.4   56.8   - 
 Limited partnerships  0.1   -   -   0.1 
 
Real estate (c)
  26.8   -   -   26.8 
 
Commodities (d)
  17.6   -   17.6   - 
 Fixed income securities                
 
Fixed income funds (e)
  117.9   3.0   114.9   - 
 U.S. Treasury notes  1.3   1.3   -   - 
 U.S. Agency, state and local obligations  18.7   -   18.7   - 
 
U.S. corporate bonds (f)
  25.5   0.9   24.6   - 
 Foreign corporate bonds  1.2   -   1.2   - 
 Hedge fund  2.4   -   -   2.4 
 Total $475.5  $126.5  $319.7  $29.3 
 Cash equivalents - money market funds  12.7             
 Total Pension Plans $488.2             
                  
(a)At December 31, 2010 and 2009, this category is comprised of $90.5 million and $102.9 million, respectively, of traded 
 mutual funds valued at daily listed prices and $68.0 million and $85.9 million, respectively, of institutional common/collective 
 trust funds valued at daily Net Asset Values (NAV) per share. 
(b)At December 31, 2010 and 2009, this category is comprised of $39.4 million and $18.4 million, respectively, of traded mutual 
 funds valued at daily listed prices and $83.0 million and $56.8 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, 2010 and 2009, this category is comprised of $23.0 million and $3.0 million, respectively, of traded mutual 
 funds valued at daily listed prices and $125.7 million and $114.9 million, respectively, of institutional common/collective trust 
 funds valued at daily NAV per share. 
(f)At December 31, 2010 and 2009, this category is comprised of $13.9 million and $13.0 million, respectively, of corporate 
 bonds, $8.0 million and $9.3 million, respectively, of collateralized mortgage obligations and $2.3 million and $3.2 million, 
 respectively, of other asset-backed securities. 
(g)This category is comprised of closely-held limited partnerships valued at NAV on a quarterly basis.     
 
91
 
The following table reconcilestables reconcile the beginning and ending balances for all level 3 pension plan assets measured at fair value on a recurring basis for 2010 and 2009.
             
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)    
          
  Real Hedge Limited  
Description Estate Fund Partnerships Total
  (millions)
Balance January 1, 2010 $26.8  $2.4  $0.1  $29.3 
Actual return on plan assets                
Relating to assets still held  2.5   (0.2)  -   2.3 
Relating to assets sold  -   (0.7)  -   (0.7)
Purchase, issuances, and settlements  1.0   6.9   -   7.9 
Transfers in and/or out of Level 3  -   -   -   - 
Balance December 31, 2010 $30.3  $8.4  $0.1  $38.8 
                 

             
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)    
          
  Real  Hedge  Limited    
Description Estate  Fund  Partnerships  Total 
  (millions)
Balance January 1, 2009 $36.9  $6.6  $0.5  $44.0 
Actual return on plan assets                
Relating to assets still held  (10.2)  0.1   0.2   (9.9)
Relating to assets sold  0.1   (1.3)  -   (1.2)
Purchase, issuances, and settlements  -   (3.0)  (0.6)  (3.6)
Transfers in and/or out of Level 3  -   -   -   - 
Balance December 31, 2009 $26.8  $2.4  $0.1  $29.3 
                 
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 entirely 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.
 
92
The fair values of the Company’s other post-retirement plan assets at December 31, 2010 and 2009, by asset category are in the following table.tables.

             
     Fair Value Measurements Using 
Description 
December 31
2010
 
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            
Fixed income            
U.S. Treasury $12.1  $12.1  $-  $- 
U.S. Agency  21.7   -   21.7   - 
State and local obligations  0.5   -   0.5   - 
Corporate bonds (a)
  11.4   -   11.4   - 
Foreign corporate bonds  1.0   -   1.0   - 
Mutual funds  0.1   0.1   -   - 
Total $46.8  $12.2  $34.6  $- 
Cash and cash equivalents - money market funds  19.0             
Total Other Post-Retirement Benefit Plans $65.8             
                 
 (a)  This category is comprised of $9.2 million of corporate bonds, $0.9 million of collateralized mortgage obligations and $1.3 million 
      of other asset-backed securities.     
             
     Fair Value Measurements Using 
Description 
December 31
 2009
  
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            
Fixed income            
U.S. Treasury $0.8  $0.8  $-  $- 
U.S. Agency  0.6   -   0.6   - 
Corporate bonds  1.0   -   1.0   - 
Mutual funds  0.1   0.1   -   - 
Total  $2.5   $0.9   $1.6   $- 
Cash and cash equivalents - money market funds  49.5             
Total Other Post-Retirement Benefit Plans $52.0             
                 
 
 
      Fair Value Measurements Using 
Description 
December 31
2009
 
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            
 Fixed income            
 U.S. Treasury $0.8  $0.8  $-  $- 
 U.S. Agency  0.6   -   0.6   - 
 Corporate bonds  1.0   -   1.0   - 
 Mutual funds  0.1   0.1   -   - 
 Total $2.5  $0.9  $1.6  $- 
 Cash and cash equivalents - money market funds  49.5             
 Total Other Post-Retirement Benefit Plans $52.0             
                  



93
Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans.  The cost trend assumed for 20092010 and 2011 was 7.5% and is 8% for 2010,8.0%, 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 the Company.
92
The effects of a one-percentage point change in the assumed health care cost trend rates, holding all other assumptions constant, at December 31, 2009,2010, are detailed in the following table.  The results reflect the increase in the Medicare Part D employer subsidy which is assumed to increase with the medical trend and employer caps on post-65 plans.
            
 Increase Decrease Increase Decrease
 (millions)  (millions)
Effect on total service and interest component $0.3  $(0.3) $0.2  $(0.3)
Effect on post-retirement benefit obligation  0.8   (0.9)  2.2   (2.1)
                
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 $8.9 million, $8.8 million and $6.9 million in 2010, 2009 and $5.0 million in 2009, 2008, and 2007, respectively.  KCP&L’s annual cost of the plans was approximately $6.5 million, $6.5 million and $5.8 million and $4.3 million in 2009, 2008 and 2007, respectively.
Skill Set Realignment Deferral
In 2007, KCP&L received authorization from the MPSC and KCC to defer $8.9 million in regulatory assets for costs originally expensed in 2006 related to a workforce realignment process and amortize them over five years for the Missouri jurisdictional portion and ten years for the Kansas jurisdictional portion effective with new rates on January 1, 2008.  Amortization of $1.4 million in both2010, 2009, and 2008, respectively, was recorded to utility operating and maintenance expense on KCP&L’s income statements.respectively.
 
11.10.  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, stock options, 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 5.0 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 on account of withholding taxes and held in treasury, or both, and does not expect to repurchase common shares during 2010,2011 to satisfy performance share payments, stock option exercises 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 associated income tax benefits.
                  
 2009  2008  2007  2010 2009 2008
Great Plains Energy (millions)  (millions)
Compensation expense $6.3  $9.0  $6.4  $4.3  $6.3  $9.0 
Income tax benefits  1.6   2.7   2.1   1.0   1.6   2.7 
KCP&L                        
Compensation expense  4.3   5.5   4.3   3.0   4.3   5.5 
Income tax benefits  0.8   2.0   1.4   0.5   0.8   2.0 
                        


 
9394
 
Amendment to Performance Shares
In May 2009, the independent members of the Board approved amendments to certain outstanding performance share agreements (Original Agreements) for the 2007-2009 and 2008-2010 performance periods.  The Original Agreements, as so amended, are referred to as the Amended Agreements.  Due to changes in economic and financial market conditions since the Original Agreements were entered into, the Compensation and Development Committee (Committee) and Board determined that the Original Agreements no longer provided meaningful incentives.
The Original Agreements granted performance shares based on a single performance metric – the Company’s total shareholder return (TSR) as compared to the Edison Electric Institute TSR index for electric utility companies over the relevant performance periods.  The Amended Agreements provide for a combination of performance shares and time-based restricted stock.  In calculating the number of performance shares and restricted stock under the Amended Agreements, the value of the performance shares granted under the Original Agreements (determined as of the date of the original awards) was first reduced by two-thirds (for the 2007-2009 performance awards) and one-third (for the 2008-2010 performance awards).  The resulting amounts were then divided by the fair market value (as defined in the Long-Term Incentive Plan) of Great Plains Energy stock on the amendment date to arrive at a number of shares, which was then divided equally between performance shares and restricted stock.  The two equally weighted performance share award metrics under the Amended Agreements are funds from operations as a percentage of total adjusted debt and EPS, with the number of shares of common stock ultimately issued varying depending on Great Plains Energy’s performance over stated performance periods.
The performance shares under the Amended Agreements will be re-measured at fair value each reporting period, with compensation cost to be recorded at the greater of the grant-date fair value of the Original Agreements or the fair value of the Amended Agreements for the portion for which the requisite service has been rendered.  The amendment resulted in an insignificant amount of incremental compensation cost for Great Plains Energy and KCP&L.
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 Great Plains Energy’s Board of Directors.  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 and Great Plains Energy’s stock price atfollowing the end of the performance period as compared to the stock price on the grant date.  Compensation expense for performance shares issued subsequent to the amendment discussed abovebelow 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 a Monte Carlo simulation technique that uses the closing stock price at the valuation date and 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 commensurate withbased upon the remaining life of the performance period of the grant based on the zero-coupon government bonds in effectrate at the time of the valuation.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 the most recent valuation,shares granted in 2010, inputs for expected volatility, dividend yield and risk-free rates ranged from 29.97% to 36.48%were 31%, 4.64%4.65%, and 0.40% to 0.95%1.2%, respectively.
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Performance share activity for 20092010 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 stated performance periods.periods and Great Plains Energy’s stock price following the end of the performance period as compared to the stock price on the grant date.
          
 Performance Grant Date Performance Grant Date
 Shares Fair Value* Shares Fair Value*
Beginning balance  314,511  $28.47        294,641  $       13.62
Performance adjustment  (88,056)           (21,674)  
Granted  196,431   15.04        231,598           23.37
Amendment effect  (101,589)  24.23 
Earned         (8,433)           10.87
Forfeited  (26,656)  22.05        (64,348)           20.54
Ending balance  294,641   13.62        431,784           18.01
* weighted-average            

At December 31, 2009,2010, the remaining weighted-average contractual term was 1.51.3 years.  The weighted-average grant-date fair value of shares granted was $23.37, $15.04 and $26.22 in 2010, 2009 and $32.00 in 2009, 2008, and 2007, respectively.  At December 31, 2009,2010, there was $5.0$2.5 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 2010 was insignificant.  There were no performance shares earned and paid during 2009.  The fair value of common stock issued related to performance shares earned and paid during 2009.2008 was $1.6 million.

Amendment to Performance Shares
In May 2009, the independent members of the Board approved amendments to certain outstanding performance share agreements (Original Agreements) for the 2007-2009 and 2008-2010 performance periods.  The Original Agreements, as amended, are referred to as the Amended Agreements.  Due to changes in economic and financial market conditions since the Original Agreements were entered into, the Compensation and Development Committee (Committee) and Board determined that the Original Agreements no longer provided meaningful incentives.
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The Original Agreements granted performance shares based on a single performance metric – the Company’s total shareholder return (TSR) as compared to the Edison Electric Institute TSR index for electric utility companies over the relevant performance periods.  The Amended Agreements provide for a combination of performance shares and time-based restricted stock.  In calculating the number of performance shares and restricted stock under the Amended Agreements, the value of the performance shares granted under the Original Agreements (determined as of the date of the original awards) was first reduced by two-thirds (for the 2007-2009 performance awards) and one-third (for the 2008-2010 performance awards).  The resulting amounts were then divided by the fair market value (as defined in the Long-Term Incentive Plan) of Great Plains Energy stock on the amendment date to arrive at a number of shares, which was then divided equally between performance shares and restricted stock.  The two equally weighted performance share award metrics under the Amended Agreements are funds from operations as a percentage of total adjusted debt and EPS, with the number of shares of common stock ultimately issued related tovarying depending on Great Plains Energy’s performance over stated performance periods.
The performance shares was $1.6 millionunder the Amended Agreements will be re-measured at fair value each reporting period, with compensation cost to be recorded at the greater of the grant-date fair value of the Original Agreements or the fair value of the Amended Agreements for the portion for which the requisite service has been rendered.  The amendment resulted in an insignificant amount of incremental compensation cost for Great Plains Energy and $1.3 million during 2008 and 2007, respectively.KCP&L.

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 for 20092010 is summarized in the following table.
`      
    
 Nonvested Grant Date Nonvested Grant Date
 Restricted stock Fair Value* Restricted Stock Fair Value*
Beginning balance  458,796  $30.54         612,587  $       20.24
Amendment effect  106,443   14.35 
Granted and issued  268,651   14.36         130,137           17.80
Vested  (177,990)  30.41         (291,787)           25.00
Forfeited  (43,313)  26.51           (44,280)           17.99
Ending balance  612,587   20.24         406,657           16.23
* weighted-average            

At December 31, 2009,2010, the remaining weighted-average contractual term was 1.11.2 years.  The weighted-average grant-date fair value of shares granted was $17.80, $14.36, and $26.09 during 2010, 2009 and $31.93 during 2009, 2008, and 2007, respectively.  At December 31, 2009,2010, there was $3.3$2.8 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 $7.3 million, $5.4 million, and $2.2 million in 2010, 2009 and $1.1 million in 2009, 2008, and 2007, respectively.
 
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Stock Options
Granted Under Long-Term Incentive Plan
Stock options were granted under the plan during 2001-2003 at market value of the shares on the grant date.  The options vested three years after the grant date and expire in ten years if not exercised.  The fair value for the stock options was estimated at the date of grant using the Black-Scholes option-pricing model.  Compensation expense and accrued dividends related to stock options were recognized over the stated vesting period.

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GMO Acquisition
Outstanding GMO stock options outstanding on the July 14, 2008, acquisition date of GMO, were converted to Great Plains Energy stock options upon acquisition.
 
Stock option activity under all plans for 20092010 is summarized in the following table.  All stock options are fully vested at December 31, 2009.2010.
          
    Exercise   Exercise
Stock Options Shares Price* Shares Price*
Beginning balance  520,829  $76.10       244,610  $      36.73
Exercised  (39,847)  11.53             (917)            9.21
Forfeited or expired  (236,372)  127.73        (44,912)          55.97
Outstanding and exercisable at December 31  244,610   36.73 
Outstanding and exercisable at December 31, 2010Outstanding and exercisable at December 31, 2010     198,781          32.51
* weighted-average            

The weighted-average grant-date fair value of options exercised for 2010 and 2009 was $9.21 and 2008 was $11.53, and $20.61, respectively, per share.respectively.  The aggregate intrinsic value and cash received for options exercised in 20092010 and 20082009 was insignificant.  At December 31, 2010, there were no in the money outstanding and exercisable options.  The following table summarizes all outstanding and exercisable stock options as of December 31, 2009.2010.

Outstanding and Exercisable Options
      Weighted Average    
      Remaining  Weighted 
Exercise  Number of Contractual Life  Average 
Price Range  Shares in Years  Exercise Price 
$9.21   917   0.2  $    9.21             
$23.91 - $27.73   224,384   2.0     24.56             
$121.90 - $181.11   11,524   0.6   150.50             
$221.82 - $251.86   7,785   1.3   222.24             
Total   244,610   1.9     
 
At December 31, 2009, the aggregate intrinsic value of in the money outstanding and exercisable options was insignificant.
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Outstanding and Exercisable Options    
    Weighted Average  
    RemainingWeighted
Exercise Number of Contractual LifeAverage
Price Range Shares in YearsExercise Price
$23.91 - $27.73       189,852 1.0 $  24.44
$181.11           3,998 0.1   181.11
$221.82 - $251.86           4,931 0.3   222.48
Total       198,781 0.9     32.51
        
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.  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 20092010 and 2008.2009.  Director Deferred Share Units activity for 20092010 is summarized in the following table.
          
 Share  Grant Date Share Grant Date
 Units  Fair Value* Units Fair Value*
Beginning balance  7,588  $27.94    21,443 $         22.36
Issued  13,855   19.30    17,620           17.21
Ending balance  21,443   22.36    39,063           20.04
* weighted-average            


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12.11.  SHORT-TERM BORROWINGS AND SHORT-TERM BANK LINES OF CREDIT
 
Great Plains Energy’s $400$200 Million Revolving Credit Facility
Great Plains Energy’s $400$200 million revolving credit facility with a group of banks expires in May 2011.August 2013.  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 $25.0$50.0 million is a default under the facility.  Under the terms of this agreement,facility, Great Plains Energy is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the agreement,facility, not greater than 0.65 to 1.00 at all times.  At December 31, 2009,2010, Great Plains Energy was in compliance with this covenant.  At December 31, 2010, Great Plains Energy had $9.5 million of outstanding cash borrowings with a weighted-average interest rate of 3.06% and had issued letters of credit totaling $15.8 million under the credit facility.  At December 31, 2009, Great Plains Energy had $20.0 million of outstanding cash borrowings with a weighted-average interest rate of 0.68% and had issued letters of credit totaling $25.4 million under the credit facility.  At December 31, 2008, Great Plains Energy had $30.0 million of outstanding cash borrowings with a weighted-average interest rate of 1.22% and had issued letters of credit totaling $34.9 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 to provide support for its issuance of commercial paper and other general corporate purposes expires in May 2011.August 2013.  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 $25.0$50.0 million is a default under the facility.  Under the terms of the agreement,this facility, KCP&L is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the agreement,facility, not greater than 0.65 to 1.00 at all times.  At December 31, 2009,2010, KCP&L was in compliance with this covenant.  At December 31, 2010, KCP&L had $263.5 million of commercial paper outstanding, at a weighted-average interest rate of 0.41%, $24.4 million of letters of credit outstanding and no outstanding cash borrowings under the facility.  At December 31, 2009, KCP&L had $186.6 million of commercial paper outstanding, at a weighted-average interest rate of 0.58%, $20.9 million of letters of credit outstanding and no outstanding cash borrowings under the facility.  At December 31, 2008, KCP&L had $380.2 million of commercial paper outstanding, at a weighted-average interest rate of 5.34%, $11.9 million of letters of credit outstanding and no outstanding cash borrowings under the facility.
 
GMO’s $400$450 Million Revolving Credit Facility
GMO’s $400$450 million revolving credit facility with a group of banks expires in September 2011.August 2013.  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, Great Plains Energy or any of its significant subsidiaries on other indebtedness totaling more than $25.0$50.0 million is a default under the facility.  Under the terms of this agreement,facility, GMO is required to maintain a consolidated indebtedness to consolidated capitalization ratio, as defined in the agreement,facility, not greater than 0.65 to 1.00 at all times.  At December 31, 2009,2010, GMO was in compliance with this covenant.  At December 31, 2010, GMO had no outstanding cash borrowings and had issued letters of credit totaling $13.2 million under the credit facility.  At December 31, 2009, GMO had $232.0 million of outstanding cash borrowings with a weighted-average interest rate of 1.50%, and had issued letters of credit totaling $13.2 million under the credit facility.  At December 31, 2008, GMO had $110.0 million of outstanding cash borrowings with a weighted-average interest rate of 1.22%, and had issued letters of credit totaling $1.2 million under the credit facility.

 
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13.12.  LONG-TERM DEBT
 
Great Plains Energy’s and KCP&L’s long-term debt is detailed in the following table.
                  
    December 31    December 31
 Year Due  2009 2008 Year Due  2010 2009
KCP&L    (millions)    (millions)
General Mortgage Bonds                  
4.90%* EIRR bonds 2012-2035  $158.8  $158.8   2012-2035  $158.8  $158.8 
7.15% Series 2009A (8.59% rate**) 2019   400.0   -   2019   400.0   400.0 
4.65% EIRR Series 2005 2035   50.0   -   2035   50.0   50.0 
5.125% EIRR Series 2007A-1 2035   63.3   -   2035   63.3   63.3 
5.00% EIRR Series 2007A-2 2035   10.0   - 
2.625% EIRR Series 2007A-2  2035   10.0   10.0 
5.375% EIRR Series 2007B 2035   73.2   -   2035   73.2   73.2 
Senior Notes                      
6.50% Series 2011   150.0   150.0   2011   150.0   150.0 
5.85% Series (5.72% rate**) 2017   250.0   250.0   2017   250.0   250.0 
6.375% Series (7.49% rate**) 2018   350.0   350.0   2018   350.0   350.0 
6.05% Series (5.78% rate**) 2035   250.0   250.0   2035   250.0   250.0 
EIRR Bonds                      
4.65% Series 2005     -   50.0 
5.125% Series 2007A-1     -   63.3 
5.00% Series 2007A-2     -   10.0 
5.375% Series 2007B     -   73.2 
4.90% Series 2008 2038   23.4   23.4   2038   23.4   23.4 
Other 2010-2018   3.5   -   2011-2018   3.3   3.5 
Current maturities     (0.2)  -      (150.3)  (0.2)
Unamortized discount     (2.1)  (1.8)     (2.0)  (2.1)
Total KCP&L     1,779.9   1,376.9      1,629.7   1,779.9 
                      
GMO           
First Mortgage Bonds           
Other Great Plains Energy           
GMO First Mortgage Bonds           
9.44% Series 2010-2021   13.5   14.6   2011-2021   12.4   13.5 
Pollution Control Bonds           
GMO Pollution Control Bonds           
5.85% SJLP Pollution Control 2013   5.6   5.6   2013   5.6   5.6 
0.285%*** Wamego Series 1996 2026   7.3   7.3 
2.683%*** State Environmental 1993 2028   5.0   5.0 
Senior Notes           
7.625% Series     -   68.5 
0.298%*** Wamego Series 1996  2026   7.3   7.3 
0.650%*** State Environmental 1993  2028   5.0   5.0 
GMO Senior Notes           
7.95% Series 2011   137.3   137.3   2011   137.3   137.3 
7.75% Series 2011   197.0   197.0   2011   197.0   197.0 
11.875% Series 2012   500.0   500.0   2012   500.0   500.0 
8.27% Series 2021   80.9   80.9   2021   80.9   80.9 
Fair Value Adjustment     84.5   117.5      49.9   84.5 
Medium Term Notes           
GMO Medium Term Notes           
7.16% Series 2013   6.0   6.0   2013   6.0   6.0 
7.33% Series 2023   3.0   3.0   2023   3.0   3.0 
7.17% Series 2023   7.0   7.0   2023   7.0   7.0 
Other     -   1.1 
Great Plains Energy 2.75% Senior Notes (3.67% rate**)  2013   250.0   - 
Great Plains Energy 6.875% Senior Notes (7.33% rate**)  2017   100.0   100.0 
Great Plains Energy 10.00% Equity Units Subordinated Notes  2042   287.5   287.5 
Current maturities     (1.1)  (70.7)     (335.4)  (1.1)
Total GMO     1,046.0   1,080.1 
           
Other Great Plains Energy           
6.875% Senior Notes (7.33% rate**) 2017   100.0   100.0 
10.00% Equity Units Subordinated Notes 2042   287.5   - 
Unamortized discount     (0.4)  (0.4)     (0.5)  (0.4)
Total Great Plains Energy excluding current maturitiesTotal Great Plains Energy excluding current maturities  $3,213.0  $2,556.6     $2,942.7  $3,213.0 
* Weighted-average interest rates at December 31, 2009.
* Weighted-average interest rates at December 31, 2010* Weighted-average interest rates at December 31, 2010
** Rate after amortizing gains/losses recognized in OCI on settlements of interest rate hedging instruments** Rate after amortizing gains/losses recognized in OCI on settlements of interest rate hedging instruments** Rate after amortizing gains/losses recognized in OCI on settlements of interest rate hedging instruments
*** Variable rate*** Variable rate*** Variable rate


 
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Amortization of Debt Expense
Great Plains Energy’s and KCP&L’s amortization of debt expense is detailed in the following table.
                  
 2009  2008  2007  2010 2009 2008
 (millions)   (millions)
KCP&L $2.0  $1.6  $1.6  $2.8  $2.0  $1.6 
Other Great Plains Energy  2.4   1.0   1.0   3.6   2.4   1.0 
Total Great Plains Energy $4.4  $2.6  $2.6  $6.4  $4.4  $2.6 
                        
KCP&L General Mortgage Bonds and EIRR Bonds
KCP&L has issued mortgage bonds under the General Mortgage Indenture and Deed of Trust dated December 1, 1986, as supplemented.supplemented (Indenture).  The Indenture creates a mortgage lien on substantially all of KCP&L’s utility plant.  Mortgage bonds totaling $755.3 million and $158.8 million were outstanding at December 31, 20092010 and 2008, respectively.2009.
 
In connection with the issuanceMarch 2010, KCP&L remarketed its 5.00% EIRR Series 2007A-2 general mortgage bonds maturing in 2035 totaling $10.0 million to a new fixed rate of 2.625% from April 1, 2010, through March 2009 of KCP&L’s $400.0 million 7.15% Mortgage Bonds Series 2009A, KCP&L concurrently issued $50.0 million of Mortgage Bonds Series 2005 EIRR Insurer due 2035 (2005 Insurer Bonds) to Syncora Guarantee Inc. (Syncora) and $146.5 million of Mortgage Bonds Series 2007 EIRR Insurer due 2035 (2007 Insurer Bonds) to Financial Guaranty Insurance Company (FGIC), as required under the applicable insurance agreements described below.  The 2005 and 2007 Insurer Bonds are not incremental debt for KCP&L, but collateralize Syncora’s and FGIC’s claims on KCP&L if Syncora or FGIC were required to meet their obligations under the insurance agreements.31, 2011.
 
KCP&L Municipal Bond Insurance Policies
KCP&L’s EIRR Bonds Series 2007A-1, 2007A-2 and 2007B totaling $146.5 million are covered by a municipal bond insurance policy issued by FGIC.Financial Guaranty Insurance Company (FGIC).  The insurance agreement between KCP&L and FGIC provides for reimbursement by KCP&L for any amounts that FGIC pays under the municipal bond insurance policy.  The insurance policy is in effect for the term of the bonds.  The policy also restricts the amount of secured debt KCP&L may issue.  Because KCP&L issued debt secured by liens not permitted by the agreement or resulting in the aggregate amount of outstanding general mortgage bonds exceeding 10% of total capitalization, KCP&L was required to issue and deliver collateral to FGIC, in the form of first mortgage bonds, equal in principal amount to the principal amount of the EIRR Bonds Series 2007A-1, 2007A-2 and 2007B then outstanding.  In 2009, KCP&L issued $146.5 million of Mortgage Bonds Series 2007 EIRR Insurer due 2035 to FGIC.  The bonds are not incremental debt for KCP&L but collateralize FGIC’s claim on KCP&L if FGIC was required to meet its obligation under the insurance agreement.
 
KCP&L’s secured 1992 Series EIRR bonds totaling $31.0 million, secured Series 1993A and 1993B EIRR bonds totaling $79.5 million, and secured and unsecured EIRR Bonds Series 2005 totaling $35.9 million and $50.0 million, respectively, are covered by a municipal bond insurance policy between KCP&L and Syncora.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 policies are in effect for the term of the bonds.  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, 2009,2010, 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 EIRR Bond Series 2005 also required KCP&L to provide collateral to Syncora in the form of $50.0 million of general mortgage bondsMortgage 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) resulting 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.
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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 $13.5$12.4 million and $14.6$13.5 million, respectively, were outstanding at December 31, 20092010 and 2008.2009.

GMO Senior Notes
The fair value adjustment for GMO represents the $133.3 million purchase accounting adjustment to record GMO’s debt related to the 11.875% series and 7.75% series Senior Notes that are not fully reflected in electric retail rates as of the July 14, 2008, acquisition date, at estimated fair value, with the offset recorded to goodwill.  The fair value adjustment is being amortized as a reduction to interest expense over the remaining life of the individual debt issues.  Amortization for 2010, 2009 and 2008 was $34.6 million, $33.0 million and $15.8 million, respectively.  Amortization for 2010, 2011 and 2012 is estimated at $34.6 million, $33.8 million and $16.1 million, respectively.

Other Great Plains Energy Long-Term Debt2.75% Senior Notes
In August 2010, Great Plains Energy issued $250.0 million of 2.75% unsecured Senior Notes, maturing in 2013.  As a result of amortizing the loss recognized in Other Comprehensive Income (OCI) on Great Plains Energy’s Forward Starting Swaps (FSS), the effective interest rate is 3.67%.
Great Plains Energy 10.00% Equity Units Subordinated Notes
In May 2009, Great Plains Energy issued $287.5 million of Equity Units.  Equity Units, each with a stated amount of $50, initially consist of a 5% undivided beneficial interest in $1,000 principal amount of 10.00% subordinated notes due June 15, 2042, and a purchase contract requiring the holder to purchase the Company’s common stock by June 15, 2012 (the settlement date).  Each purchase contract obligates the holder of the purchase contract to purchase, and Great Plains Energy to sell, no later than June 15, 2012, for $50 in cash, newly issued shares of the Company’s common stock equal to the settlement rate.  The purchase contracts may be settled earlier at the option of the holder subject to certain conditions, including but not limited to, the occurrence of a fundamental change (as defined in the agreement) at least 20 business days prior to June 15, 2012.  The settlement rate will vary according to the applicable market value of the Company’s common stock at the settlement date.  ApplicableThe applicable market value will be measured by the average of the closing price per share of the Company’s common stock on each of the 20 consecutive trading days ending on the third trading day immediately preceding June 15, 2012.  The settlement rate will be applied to the 5,750,000 Equity Units at the settlement date to issue a number of common shares determined as described in the following table.
 
ApplicableSettlement rate Market value
market value(in common shares) 
per Equity Unit (a)
$16.80 or greater2.9762 to 1 Greater than $50 per Equity Unit
    
$16.80 to $14.00$50 divided by the applicable Equal to $50 per Equity Unit
 market value to 1  
    
$14.00 or less3.5714 to 1 Less than $50 per Equity Unit
(a)Assumes that the market price of the Company's common stock on June 15, 2012,
 is the same as the applicable market value.

Great Plains Energy makes quarterly contract adjustment payments at the rate of 2.00% per year of the stated amount of $50 per Equity Unit and interest payments at the rate of 10.00% per year on the subordinated notes.  Great Plains Energy must attempt to remarket the subordinated notes, in whole but not in part, between December 15, 2011, and June 12, 2012.  In connection with a successful remarketing of the notes, Great Plains Energy may elect, without the consent of any of the holders, to modify the notes’ stated maturity to any date on or after June
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15, 2014 and earlier than June 15, 2042.  The proceeds from a successful remarketing will be used to satisfy the holders’ obligation under the purchase contract.  If the notes have not been successfully remarketed by June 12, 2012, the holders of all notes will have the right to put their notes to Great Plains Energy on June 15, 2012, in satisfaction of the holders’ obligation under the purchase contracts.contracts and Great Plains Energy will issue to the holders newly issued shares of the Company’s common stock equal to the settlement rate.
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The May 2009 present value of the contract adjustment payments of $15.1 million was recorded as a liability in other current liabilities and other deferred credits and other liabilities with a corresponding amount recorded as capital stock premium and expense on Great Plains Energy’s consolidated balance sheet.  The liability will beis being relieved as Great Plains Energy makes quarterly contract adjustment payments.  Expenses incurred with the offering of $4.3 million have been deferred and are being recognized as interest expense through 2012 when the holders can put the debt to Great Plains Energy and $7.4 million was recorded as capital stock premium and expense.
 
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.
 2010  2011  2012  2013  2014  2011 2012 2013 2014 2015
       (millions)        (millions)
Great Plains Energy $1.4  $485.8  $513.8  $13.1  $1.5  $485.7  $513.9  $263.1  $1.5  $15.5 
KCP&L  0.2   150.3   12.7    0.4   0.4   150.3   12.7   0.4   0.4   14.4 
At December 31, 2010, Great Plains Energy’s long-term debt maturities in 2011 and 2012 were $485.7 million and $513.9 million, respectively.  In February 2011, repayment of GMO’s $137.3 million of 7.95% Senior Notes that matured in February 2011 reduced the 2011 long-term debt maturities to $348.4 million.  Great Plains Energy is evaluating alternatives to refinance the remaining long-term debt, including issuing new long-term debt.  Based on current market conditions and Great Plains Energy’s unused bank lines of credit, Great Plains Energy expects to have the ability to access the markets to complete the necessary refinancing.
14.13.  COMMON SHAREHOLDERS’ EQUITY
At the May 5, 2009, annual shareholders meeting, the Great Plains Energy common stock shareholders approved an amendment to the articles of incorporation, increasing the authorized number of shares of common stock, no par value, to 250 million from 150 million.
 
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 was filed and became effective in May 2009.
In May 2009, Great Plains Energy issued 11.5 million shares of common stock at $14.00 per share with $161.0 million in gross proceeds and issuance costs of $6.5 million.
 
In August 2008, Great Plains Energy entered into a Sales Agency Financing Agreement with BNY Mellon Capital Markets, LLC (BNYMCM).  Under the terms of the agreement, Great Plains Energy may offer and sell up to 8.0 million shares of its common stock from time to time through BNYMCM, as agent, for a period of no more than three years.  Great Plains Energy will pay BNYMCM a commission equal to 1% of the sales price of all shares sold under the agreement.  No shares were sold during 2010.  During 2009, 3.8 million shares were sold for $49.5 million in net proceeds through BNYMCM.proceeds.  During 2008, 0.2 million shares were sold for $3.5 million in net proceeds.
 
Great Plains Energy has 5.0 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.plan.  At December 31, 2009, 1.02010, 0.8 million shares remained available for future issuances.
 
Great Plains Energy has 12.3 million shares of common stock registered with the SEC for a defined contribution savings plan.  Shares issued under the plans may be either newly issued shares or shares purchased in the open market.  At December 31, 2009, 2.42010, 1.9 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.
 
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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
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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 contain a covenant requiring each company to maintain a consolidated indebtedness to consolidated total capitalization ratio of not more than 0.65 to 1.00.  In addition, Great Plains Energy is prohibited from paying dividends on its common and preferred stock in the event its Equity Unit contract payments or interest payments on the debt underlying the Equity Units are deferred until such deferrals have been paid.
 
As of December 31, 2009,2010, 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, 2009.2010.  The restrictions are not expected to affect the companies’Companies’ ability to pay dividends at the current level in the foreseeable future.
 
15.14.  PREFERRED STOCK
 
At December 31, 2009,2010, 1.6 million shares of Cumulative No Par Preferred Stock, 390,000 shares of Cumulative Preferred Stock, $100 par value and 11.0 million shares of no par Preference Stock were authorized under Great Plains Energy’s Articles of Incorporation.  All of the 390,000 authorized shares of Cumulative Preferred Stock are issued and outstanding.  Great Plains Energy has the option to redeem the $39.0 million of issued Cumulative Preferred Stock at prices ranging from 101% to 103.7% of par value.  If Great Plains Energy voluntarily files for dissolution or liquidation, the Cumulative Preferred Stock holders are entitled to receive the redemption prices.  If a proceeding for dissolution or liquidation is filed against Great Plains Energy, the Cumulative Preferred Stock holders are entitled to receive the $100 par value per share plus accrued and unpaid dividends.
 
16.15.  COMMITMENTS AND CONTINGENCIES
 
Environmental Matters
Great Plains Energy and KCP&L are subject to extensive regulation by federal, state and local authorities with regard to environmental matters primarily through their utility operations.  In addition to imposing extensive and continuing compliance obligations, 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 adverse effect on Great Plains Energy and KCP&L.
 
The following discussion groups environmental and certain associated matters into the broad categories of air and climate change, water, solid waste and remediation.
 
Air and Climate Change
The Clean Air Act and associated regulations enacted by the Environmental Protection Agency (EPA) form a comprehensive program to preserve 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.
 
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Great Plains Energy’s and KCP&L’s current estimatesestimate of capital expenditures (exclusive of AFUDC and property taxes) to comply with the currently effective Clean Air Interstate Rule (CAIR) and with the best available retrofit technology (BART) rule is a range of approximately $0.8 billion - $0.9$1 billion.  As discussed below, CAIR has been remanded to the EPA, but remains in effect until the EPA issues final rules consistent with the court’s order or until the court takes further action.  ItIn July 2010, the EPA proposed the Transport Rule to replace CAIR.  However, due to uncertainties regarding the proposal (discussed below), it is not possible to predict what the final rules the EPA may issue as a result of this remand,be, when the rules may be issued, or the costs associated with such rules.  The actual cost of compliance with any future rules, and with BART, may be significantly different from the cost estimatesestimate provided.
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The potential capital costs of the Collaboration Agreement provisions (discussed below and in Note 7)below) relating to NOx, SO2 and particulate emission limits at the LaCygne generating station are within the disclosed overall capital cost estimate of approximately $1 billion (discussed above).  However, the estimated capital cost ranges.  However, the range doescosts do not reflect potential costs relating to requirements enacted in the future, including potential requirements regarding climate change and control of mercury emissions (discussed below), and also do not reflect costs relating to additional wind generation, energy efficiency and other CO2 emission offsets contemplated by the Collaboration Agreement or that may be required under the Missouri or Kansas renewable energy standards, which are discussed below.  The ranges doestimate does not reflect the non-capital costs the companiesCompanies incur on an ongoing basis to comply with environmental laws, which may increase in the future due to the implementation of KCP&L’s Comprehensive Energy Plan and the companies’Companies’ ongoing compliance with current or future environmental laws.  KCP&L expects to seek recovery of the costs associated with the Collaboration Agreement and the companiesCompanies 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 companiesCompanies may be subject to materially adverse rate treatment in response to competitive, economic, political, legislative or regulatory pressures and/or public perception of the companies’Companies’ environmental reputation and regulatory pressures.reputation.
 
Clean Air Interstate Rule (CAIR) and Transport Rule
The CAIR requires reductions in SO2 and NOx emissions in 28 states, including Missouri.  The reduction in both SO2 and NOx emissions is set to be accomplished through establishment of permanent statewide caps for NOx effective January 1, 2009, and SO2 effective January 1, 2010..  More restrictive caps are scheduled to become effective January 1, 2015.  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.
 
On July 11, 2008, the D.C. Circuit Court of Appeals vacated CAIR in its entirety and remanded the matter to the EPA to promulgate a new rule consistent with its opinion.  On December 23, 2008, the Court issued an order remanding CAIR to the EPA to revise the rule consistent with its July 2008 order.  The CAIR thus remains in effect pending future EPA or court action.action, including the proposed Transport Rule discussed below.

The EPA’s future revisions to CAIR could result in a rule that requires greater emission reductions, imposes an earlier compliance deadline, changes or eliminates the NOx fuel factor adjustment, includes additional states (including Kansas), does not allow for emissions reductions to be obtained through interstate allowance trading or the use of the Acid Rain Program SO2 allowances, or imposes other requirements not yet known.  Great Plains Energy and KCP&L cannot predict the outcome of the EPA’s revisions to CAIR, but such revisions could have a significant effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.

Great Plains Energy and KCP&L expect to meet the emissions reductions currently required by CAIR at their Missouri plants through a combination of pollution control capital projects and the purchase of emission allowances as needed.  CAIR currently establishes a market-based cap-and-trade program with an emission allowance allocation.  Facilities demonstrate compliance with CAIR by holding sufficient allowances for each ton of SO2 and NOx emitted in any given year.  KCP&L and GMO are currently allowed to utilize unused SO2 emission allowances that they have either accumulated during previous years of the Acid Rain Program or purchased to meet the more stringent CAIR requirements.  At December 31, 2009,2010, KCP&L had accumulated unused SO2 emission allowances sufficient to support over 110,000135,000 tons of SO2 emissions (enough to support expected requirements under the current CAIR for the foreseeable future) under the provisions of the Acid Rain program, which are recorded in inventory at zero cost.  KCP&L is permitted to sell excess SO2 emission allowances in accordance with KCP&L’s Comprehensive Energy Plan as approved by the MPSC and KCC.  At December 31, 2009,2010, GMO had accumulated unused SO2 emission allowances sufficient to support just over 16,00013,000 tons of SO2 emissions (enough to support expected requirements under the current CAIR through 2011), which it has received under the Acid Rain Program or purchased, whichand are recorded in inventory at average cost.  KCP&L and GMO purchase NOx allowances as needed.

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In 2009, KCP&L completed environmental upgrades at Iatan No. 1 for compliance with the current CAIR rule as part of its Comprehensive Energy Plan.  Analysis of the current CAIR rule indicates that NOx and SO2 control may be required for KCP&L’s Montrose Station and GMO’s Sibley and Lake Road Stations in Missouri, and control may be achieved through a combination of pollution control equipment and the use or purchase of emission allowances as needed.
In July 2010, the EPA proposed the Transport Rule to replace the current CAIR.  The Transport Rule, like CAIR, will require the states within its scope to reduce power plant SO2 and NOx emissions that contribute to ozone and fine particle nonattainment in other states.  The geographical scope of the Transport Rule is broader than CAIR, and includes Kansas in addition to Missouri and other states.  The Transport Rule would also impose more stringent emissions limitations than CAIR and, unlike CAIR, would not utilize Acid Rain Program allowances for compliance.  The EPA is proposing a preferred approach and is taking comment on two alternatives.  In the EPA’s preferred approach, the EPA would set an emissions budget for each of the affected states and the District of Columbia.  The preferred approach would allow limited interstate emissions allowance trading among power plants; however, it would not permit trading of SO2 allowances between the Companies’ Kansas and Missouri power plants.  In the first alternative, the EPA is proposing to set an emissions budget for each state and allow emissions allowance trading only among power plants within a state.  In the second alternative, the EPA is proposing to set an emissions budget for each state, specify the allowable emission limit for each power plant and allow some averaging.  Compliance with the Transport Rule would begin in 2012.  There would be additional reductions in SO2 allowances allocable to the Companies’ Missouri power plants taking effect in 2014 pursuant to the preferred approach.  There is no such additional reduction in SO2 allowances allocable to the Companies’ Kansas power plants.

In January 2011, the EPA supplemented the record supporting the proposed Transport Rule.  The EPA made available additional information relevant to the rulemaking, including, among other things, unit-level allowances for existing units calculated using two alternative methodologies and data supporting those calculations.

The proposed Transport Rule is complex and, as noted, contains alternative approaches.  Great Plains Energy and KCP&L are continuingunable to evaluate compliance optionspredict when the Transport Rule (or other rule replacing CAIR) might be adopted, or the actual requirements of such rule.  Preliminary analysis of the Transport Rule has raised various questions regarding the emission allowances allocation to, and the allowable emission rates for, the Companies’ power plants pursuant to the preferred approach and alternatives, which the Companies addressed during the rule’s comment period.  Regardless of the resolution of those questions, the Companies project that they may not be allocated sufficient SO2 or NOX emissions allowances to cover their currently expected operations starting in light2012 pursuant to the preferred approach.  Any shortfall in allocated allowances would need to be addressed through permissible allowance trading, installing additional emission control equipment, changes in plant operation, purchasing additional power in the wholesale market, or a combination of developing potential legislativethese and regulatory environmental requirements.other alternatives.  While Great Plains Energy and KCP&L cannot reasonably predict at this time the impacts of the final Transport Rule, if it were finalized as currently proposed, the Companies expect that any required capital expenditures would not exceed the $1 billion estimate of capital expenditures (exclusive of AFUDC and property taxes) to comply with the currently effective CAIR and BART rule disclosed above.  Any final rule could have a significant adverse effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.

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Best Available Retrofit Technology (BART) Rule (BART)
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 LaCygne 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)’s Jeffrey Unit Nos. 1 and 2 in Kansas, in which GMO has an 8% interest.  Initially, in Missouri, compliance with CAIR will be compliance with BART for individual sources.  NeitherBoth Missouri and Kansas have submitted BART plans to the EPA but neither Missouri nor Kansas has received EPA approval for their BART plans.
 
Mercury and Other Hazardous Air Pollutant Emissions
In January 2009, the EPA issued a memorandum stating that new electric steam generating units (EGUs) that began construction while the Clean Air Mercury Rule (CAMR) was effective are subject to a new source maximum achievable control technology (MACT) determination on a case-by-case basis.
 
In July 2009, the EPA sent letters notifying KCP&L that MACT determinations and schedules of compliance are required for coal and oil-fired EGUs that began actual construction or reconstruction after December 15, 2000, and identified Iatan No. 2 and Hawthorn No. 5 as affected EGUs.  This was an outcome of the D.C. Court of Appeals’ vacatur of both the CAMR and the contemporaneously promulgated rule removing EGUs from MACT requirements.  KCP&L believes that Hawthorn No. 5 is not an affected EGU based on the reconstruction dates of the unit, and provided supporting documentation to the Missouri Department of Natural Resources (MDNR).  It is not currently known how MACT determinations and schedules of compliance will impact the permitting or operating requirements for these two units, but it is possible a MACT determination may ultimately require additional emission control equipment and permit limits at Iatan No. 2, Hawthorn No. 5, or both.
 
In October 2009,April 2010, the EPA, reachedin a proposedcourt approved settlement, agreed to develop MACTdevelop MACT standards for mercury and potentially other hazardous air pollutant emissions.  TheIn the settlement agreement, the EPA has indicated it willagreed to propose MACT standards in 2010March 2011 with final standards by November 2011.  These MACT standards, if adopted, could impact both KCP&L’s and GMO’s new and existing facilities.
 
The estimated required environmental expenditures of $0.8 billion - $0.9 billion to comply with CAIR and BART, discussed above, do not reflect any amounts for compliance with MACT determinations and future MACT standards because managementManagement cannot predict the outcome of further judicial, administrative or regulatory actions or their financial or operational effects on Great Plains Energy and KCP&L.  However, suchSuch actions could have a significant effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.  Some of the control technology for SO2 and NOx could also aid in the control of mercury.
 
Industrial Boiler Rule
In April 2010, the EPA issued a proposed rule that would set MACT standards for hazardous air pollutants from industrial boilers.  The proposed rule would establish emission limits for KCP&L’s and GMO’s new and existing units that produce steam other than for the generation of electricity.  This proposed 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 EPA finalized the rule in late February 2011.  The financial and operational impacts to Great Plains Energy and KCP&L, which could be material, are being evaluated but cannot be determined at this time.
New Source Review
The Clean Air Act 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 May 2008, KCP&L received a subpoena from a federal grand jury seeking documents relating to capital projects at Iatan No. 1.  In September 2009,
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KCP&L was informed by the Department of Justice that it did not expect to seek criminal charges under the Clean Air Act in connection with repair work, maintenance or modifications at Iatan No. 1.
In January 2004, Westar received notification from the EPA alleging that it had violated new source review requirements and Kansas environmental regulations by making modifications to the Jeffrey Energy Center without obtaining the proper permits.  The Jeffrey Energy Center consists of three coal-fired units located in Kansas that 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.  In February 2009, the Attorney General of the United States filed a complaint against Westar alleging that it violated the Clean Air Act and related federal and state regulations by making major modifications to the Jeffrey Energy Center beginning in 1994 without first obtaining appropriate permits authorizing this construction and without installing and operating best available control technology to control emissions.  The Jeffrey Energy Center consists of three coal-fired units located in Kansas that 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.  In January 2010, Westar entered into a settlement agreement, which is pendingwas approved by the court approval.  If approved, thein March 2010.  The settlement agreement would require,requires, among other things, the installation of an SCRa selective catalytic reduction (SCR) system at one of the Jeffrey Energy Center units by the end of 2014 and the payment of a $3 million civil penalty.  Westar has preliminarily estimated the cost of this SCR at approximately $240 million.  This amount could materially change depending on final engineering and design.  Depending on the NOx emission reductions attained by that SCR and attainable through the installation of other controls at the other two units, the settlement agreement requiresmay require the installation of a second SCR system on one of the other two units by the end of 2016.  Westar has estimated that if both SCRs are required, the total capital cost could be up to approximately $500 million.  There is no assurance that GMO’s share of these costs would be recovered in rates and failure to recover such costs could have a significant adverse effect on Great Plains Energy’s results of operations, financial position and cash flows.
 
Collaboration Agreement
As discussed in Note 7,In March 2007, KCP&L, the Sierra Club and the Concerned Citizens of Platte County entered into a Collaboration Agreement under which KCP&L agreed to pursue a set of initiatives including energy efficiency, additional wind generation, lower emission permit levels at its Iatan and LaCygne generating stations and other initiatives designed to offset CO2 emissions.  Full implementation of the terms of the Collaboration Agreement will necessitate approval from the appropriate authorities, as some of the initiatives in the agreement require regulatory approval.
In 2006, KCP&L installed 100MW of wind generation at its Spearville wind site.  KCP&L agreed in the Collaboration Agreement to pursue increasing its wind generation capacity to 500MW in total by the end of 2012 with 100MW to be added by the end of 2010 and the remainder added by the end of 2012, subject to regulatory approval.  In 2010, KCP&L completed a 48MW wind project adjacent to its existing Spearville wind site with wind turbines it already owned and also secured 52MW of renewable energy credits.  KCP&L issued requests for proposals to add up to 100MW of wind generation in 2012 and is evaluating the proposals.  KCP&L is evaluating alternatives to meet the remaining wind generation capacity requirement, including the purchase of renewable energy credits, power purchase agreements, KCP&L-built installations or some combination thereof.
 
KCP&L agreed in the Collaboration Agreement to seek a consent agreement, which it has done, with the Kansas Department of Health and Environment (KDHE) incorporating limits for stack particulate matter emissions, as well as limits for NOx and SO2 emissions at its LaCygne 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 LaCygne Station prior to the required compliance date under BART, but in no event later than June 1, 2015.  Also as provided inKCP&L has issued requests for proposals for environmental equipment required to comply with BART at the LaCygne Station and is evaluating the responses.  In February 2011, KCP&L filed a request with KCC for predetermination of the ratemaking treatment that will apply to the recovery of costs for its 50% share of the environmental equipment required to comply with BART at the LaCygne Station.  The request for predetermination includes an estimated total project cost of $1.23 billion.  KCP&L’s 50% share of the estimated cost is $615 million.
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In the Collaboration Agreement, KCP&L issued, in 2008, requestsalso agreed to offset an additional 711,000 tons of CO2 by the end of 2012.  KCP&L currently expects to achieve this offset through a number of alternatives, including improving the efficiency of its coal-fired units, equipping certain gas-fired units for proposals for equipment required to comply with BART.  KCP&L is continuing to evaluate compliance options in lightwinter operation and, if necessary, possibly reducing output of, developing potential legislative and regulatory environmental requirements.or retiring, one or more coal-fired units.
 
Climate Change
The Companies are subject to existing greenhouse gas reporting regulations and, as discussed below, will be subject to certain greenhouse gas permitting requirements starting in 2011.  Management believes it is likely 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 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’Companies’ current generation capacity is primarily coal-fired and is estimated to produce about one ton of CO2 per MWh, or approximately 2328 million tons and 1721 million tons per year for Great Plains Energy and KCP&L, respectively.
Laws have recently been passed in Missouri and Kansas, the states in which the companies’Companies’ retail electric businesses are operated, setting renewable energy standards, and management believes that national clean or renewable energy standards are also likely.  While management believes additional requirements addressing these
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matters will probably 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.  In addition, certain federal courts have held that state and local governments and private parties have standing to bring climate change tort suits seeking company-specific emission reductions and monetary or other damages.  The U.S. Supreme Court has agreed to hear an appeal of one of those suits.  While the companies’Companies are not a party to any climate change tort suit, there is no assurance that such suits may not be filed in the future or the outcome if such suits are filed.  Such requirements or litigation outcomes could have the potential for a significant financial and operational impact on Great Plains Energy and KCP&L.  The companies’Companies would seek recovery of capital costs and expenses for compliance through rate increases; however, there can be no assurance that such rate increases would be granted.
 
Legislation concerning the reduction of emissions of greenhouse gases, including CO2, is being considered at the federal and state levels,levels.  The timing and some initial steps toward definitive regulation have been taken, all with various compliance dates and reduction strategies.  Greenhouse gas regulation has the potential of having significant financial and operational impacts on Great Plains Energy and KCP&L, including with respect to 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 legislation is passed or regulations enacted.  Management will continue to monitor the progress of relevant bills and regulations.
The American Clean Energy and Security Act of 2009 (House Bill) passed the U.S. House of Representatives in June 2009.  The House Bill would establish a 20% renewable electricity standard (Federal RES) by 2020, starting with an initial 6% requirement by 2012.  The House Bill would also establish a greenhouse gas cap and trade program, requiring Great Plains Energy, KCP&L and other affected entities to comply by surrendering allowances or offsets for each ton of greenhouse gas emitted.  The number of allowances would be initially set and then reduced over time, with the projected effect of reducing greenhouse gas emissions below 2005 levels by 3%, 17%, 42%, and 83% by 2012, 2020, 2030, and 2050, respectively.  In addition, the House Bill would establish CO2 emission performance standards for new coal-fired units that receive an initial permit after January 1, 2009.  In September 2009, the Senate Environmental and Public Works Committee voted out the Clean Energy Jobs and American Power Act (Senate Bill).  The Senate Bill closely mirrors many elements of the House Bill, but differs in respects as well.  The Senate Bill features a more aggressive 20% reduction target by 2020 from 2005 levels compared to the House Bill.
Both the House and Senate Bills are complex, and there are many aspects of the Bills that cannot be reasonably estimated, including the availability and price of allowances and offsets in the market to be established by the Bills.  It is also not possible to reasonably project the provisions of greenhouse gas legislation that may ultimately be enacted by Congress.  The level of uncertainty regarding the prospects for these Bills has increased in recent months, and no legislation or substantially different legislation may be enacted.  Subject to these qualifications and uncertainties and assuming the House Bill becomes law and there is no change in operations, management currently projects that KCP&L and GMO would be allocated up to approximately 60% and 50%, respectively, fewer allowances than needed to cover their projected 2012 CO2 emissions.  The companies would be required to reduce emissions, purchase allowances or offsets, or a combination of both.  The companies would seek recovery of compliance costs in rates; however, there is no assurance regarding the timing or amount of compliance costs recovery.  The ultimate annual cost of compliance with the Federal RES and the cap and trade program cannot be estimated at this time, but could be in an initial range of about $300 million to $800 million for Great Plains Energy, including $200 million to $600 million for KCP&L.  These potential costs could require electric rate increases initially aggregating about 15% to 45% for Great Plains Energy, including 20% to 50% for KCP&L.  As the number of allowances is reduced, and the Federal RES increases over time, the costs and resulting electric rates would increase as well.  Additional greenhouse gas bills may be
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introduced in Congress, but the provisionseffects of any legislation that may be enacted, including when and to what extent such legislation will regulate CO2 emissions, cannot be determined at this time.
Even if there are no  In the absence of new Congressional mandates, the EPA is consideringproceeding with the regulation of greenhouse gases under the existing Clean Air Act.  In 2007, the U.S. Supreme Court determined that greenhouse gases are air pollutants covered by the Clean Air Act.  The Court held that the EPA must determine whether or not emissions of greenhouse gases from new motor vehicles cause or contribute to air pollution which may reasonably be anticipated to endanger public health or welfare.  In December 2009, the EPA finalized two distinct findings regarding greenhouse gases under the Clean Air Act.  In the first finding, referred to as the endangerment finding, the EPA found that the current and projected concentrations of the mix of six greenhouse gases, including CO2, in the atmosphere threaten the public health and welfare of current and future generations.  In the second finding, referred to as the cause or contribute finding, the EPA found that the combined emissions of greenhouse gases from new motor vehicles and motor vehicle engines contribute to the atmospheric concentrations of these greenhouse gases and therefore, contribute to the threat of climate change.  The EPA indicated that the findings do not themselves impose any requirements on industry; however, the action is a prerequisite to finalizing the EPA’s proposed greenhouse gas emission standards for light-duty vehicles which was proposed by the EPA in September 2009.  The EPA indicated that the finalization of the greenhouse gas emission standards for light-duty vehicles would trigger Federal Prevention of Significant Deterioration (PSD) or Title V permitting programs applicability for stationary sources such as Great Plains Energy’s and KCP&L’s generating facilities.
 
In December 2008, the EPA issued an interpretive memo declaring that CO2 is not currently subject to regulation under the PSD program; however, in September 2009, the EPA announced that it plans to reconsider the interpretive memo and is seeking comments on various interpretations of when a pollutant is subject to regulation under the Clean Air Act for the purposes of triggering the PSD permitting requirements.  In September 2009,May 2010, the EPA issued a final rule for mandatory greenhouse gas reporting from largeaddressing greenhouse gas emissions from stationary sources which would include most of Great Plains Energy’s and KCP&L’s generating facilities.  In addition, in September 2009,under the EPA announced a proposedClean Air Act permitting programs.  This final rule that focuses on large facilities emitting over 25,000 tons of greenhouse gas emissions per year.  The proposed rule would establish newsets thresholds for greenhouse gas emissions definingthat define when permits under the Prevention of Significant Deterioration (PSD) and Title V Operating Permit programs are required for new and existing industrial facilities.  The EPA phased in the Clean Air Act permits underpermitting requirements for greenhouse gas emissions in two initial steps.  In step 1, which started January 2, 2011, only sources currently subject to the New Source Review andPSD permitting program (i.e., those that are newly-constructed or modified in a way that significantly increases emissions of a pollutant other than greenhouse gas) are subject to Title V operating permits programs would be requiredor PSD permitting requirements, respectively, for their greenhouse gas emissions.  For these projects, only projects with new or existing industrial facilities.increases of greenhouse gas emissions of 75,000 tons per year or more of total greenhouse gases, on a CO2 equivalent basis, need to determine the best available control technology for their greenhouse gas emissions.  In February 2010,addition, sources subject to the EPA indicated no facility will be requiredTitle V Operating Permit Program need to address greenhouse gas emissions in Clean Air Actas those permits are applied
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for or renewed.  In step 2, starting July 1, 2011, Title V and PSD permitting ofrequirements will cover, for the first time, new construction or modifications before 2011.projects that emit greenhouse gas emissions of at least 100,000 tons per year even if they do not exceed the permitting thresholds for any other pollutant.  In addition, the EPA announced it is also considering raising the 25,000 tons ofmodifications at such existing facilities that increase greenhouse gas threshold announced in the proposed rule.  Mostemissions by at least 75,000 tons per year will be subject to permitting requirements, even if they do not significantly increase emissions of any other pollutant.  Great Plains Energy’s and KCP&L’s generating facilities wouldthat trigger these thresholds for new installations, modifications or Title V operating permits will be subject to this rule.
In December 2010, the EPA announced it entered into a proposed New Source Review program greenhouse gas provisions.  The EPA could also propose rulemaking specificsettlement agreement to New Source Performance Standards or other programs as identified in the EPA’s July 2008 advanced notice of proposed rulemaking on the ramifications of regulatingissue a rule that will address greenhouse gas emissions underfrom EGUs.  The rule would establish new source performance standards for new and modified EGUs and emission guidelines for existing EGUs.  Under the Clean Air Act.  Thesesettlement agreement, the EPA would commit to issuing proposed regulations by July 2011, and potential rules may ultimately regulate greenhouse gas emissions, which may include such emissions from Great Plains Energy’s and KCP&L’s facilities.final regulations by May 2012.
 
At the state level, a Kansas law enacted in May 2009 requires 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.  The percentage increases to 15% by 2016 and 20% by 2020.  A Missouri law enacted in November 2008 requires 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 MW2MW in 2011 for each of KCP&L and GMO in 2011)GMO) required to come from solar resources.  Regulations implementing these laws are being drafted by the MPSC
KCP&L and KCC, and the ultimate impacts on the companies cannot be reasonably
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estimated at this time.  However, there is a potentialGMO project that KCP&L could be required to add up to 115 MW in additionaltheir current renewable resources (including accumulated renewable energy resources, including 2 MWcredits) will be sufficient for compliance with the Missouri requirements, exclusive of the solar requirement, through 2017 and 2015, respectively.  KCP&L and GMO project that the purchase of solar resources, by 2011, which could be satisfied through ownership, purchase power agreements or renewable energy credits.  In December 2009,credits will be sufficient for compliance with the Missouri requirements through 2011.  The Companies have issued requests for proposals for compliance with the solar requirement beyond 2011 and are evaluating the proposals.  KCP&L and GMO continue to evaluate options for compliance beyond these years.
KCP&L also projects that its current renewable resources (including accumulated renewable energy credits) combined with the 48MW wind project and 52MW of renewable energy credits discussed above will be sufficient for compliance with the 2011 Kansas requirements.  KCP&L issued requests for proposals to add up to 300MW100MW of wind generation in the 2010 – 2011 timeframe under purchase power agreements and/or the combination of purchase power agreements2012 and arrangements where KCP&L would own and operate the facilities after development and construction.  KCP&L is evaluating the proposals and anticipates securing the rights to 100MWs of wind resources by the end of 2010.  Subject to the final MPSC regulations, GMO expects that its existing renewable resources will achieve compliance with the Missouri standards until 2014, except for the solar resources requirement.  KCP&L and GMO issued a request for proposals for solar resources, and are evaluating the responses.  proposals.
Additionally, in November 2007, governors from six Midwestern states, including Kansas, signed the Midwestern Greenhouse Gas Reduction Accord, which has established the goal of reducing member states’ greenhouse gas emissions to 15% to 20% below 2005 levels by 2020, and 60% to 80% below 2005 levels by 2050.
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, regulations are issued or, with respect to those regulations that have been issued, additional guidance is provided.  Management will continue to monitor the progress of relevant legislation and regulations.
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Ozone NAAQS 
In June 2007, monitor data indicated that the Kansas City area violated the 1997 primary eight-hour ozone national ambient air quality standard (NAAQS).  Missouri and Kansas have implemented the responses established in the maintenance plans for control of ozone.  The responses in both states do not require additional controls at Great Plains Energy’s and KCP&L’s generation facilities beyond the currently proposed controls for CAIR and BART.  The EPA has various options over and above the implementation of the maintenance plans for control of ozone to address the violation but has not yet acted.  At this time, management is unable to predict how the EPA will respond or how that response will impact Great Plains Energy’s and KCP&L’s operations.  However, the EPA’s response could have a significant effect on Great Plains Energy's and KCP&L's results of operations, financial position and cash flows.
 
In March 2008, the EPA significantly strengthened its NAAQS for ground-level ozone.  The EPA revised the primary eight-hour ozone standard, designed to protect public health, to a level of 0.075 parts per million (ppm).  The EPA also strengthened the secondary eight-hour ozone standard to the level of 0.075 ppm making it identical to the revised primary standard.  The previous primary and secondary standards, set in 1997, were effectively 0.084 ppm.
 
In March 2009, the MDNR and KDHE submitted to the EPA their determinations that the Kansas City area is a nonattainment area under the 2008 primary eight-hour ozone standard.  The EPA will make final designations of attainment and nonattainment areas.  By 2013, states must submit state implementation plans outlining how states will reduce ozone to meet the standards in nonattainment areas.  Although the impact on Great Plains Energy’s and KCP&L’s operations will not be known until after the final nonattainment designations and the state implementation plans are submitted, it could have a significant effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.
 
In January 2010, the EPA proposed to reconsider and further strengthen the 2008 NAAQS for ground-level ozone.  The EPA proposed to strengthen the primary eight-hour ozone standard to a level within the range of 0.060-0.070 ppm.  The EPA also proposed to establish a distinct cumulative, seasonal secondary standard, designed to protect sensitive vegetation and ecosystems, to within the range of 7-15 ppm-hours.  In December 2010, the EPA filed a motion requesting court approval for additional time, until July 2011, to finalize the rule.
 
SO2 NAAQS
In November 2009,June 2010, the EPA proposed to strengthenstrengthened the primary NAAQS for SO2.  The EPA is proposing to reviserevised the primary SO2 standard toby establishing a new 1-hour standard at a level between 0.050 and 0.100 ppm measured over 1-hour.of 0.075 ppm.  The EPA revoked the two existing primary standards wereof 0.140 ppm measuredevaluated over 24-hours and 0.030 ppm measuredevaluated over an entire year.  The EPA also is taking comment on alternative levels for the 1-hour standard up to 0.150 ppm.  Although the impact on Great Plains Energy’s and KCP&L’s operations will not be known until after the final rules
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are promulgated, nonattainment designations are approved and the state implementation plans submitted, it could have a significant effect on Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.
 
Montrose Station Notice of Violation
In June 2009, KCP&L received notification from the MDNR alleging that its Montrose Station had excess particulate matter emissions in 2008.  KCP&L is working with the MDNR to resolve this issue and management believes the outcome will have an insignificant impact to Great Plains Energy’s and KCP&L’s results of operations, financial position and cash flows.
 

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Water
The Clean Water Act and associated regulations enacted by the EPA form a comprehensive program to 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.
 
Section 316(b) of the Clean Water Act is designed to protect aquatic life from being killed or injured by cooling water intake structures.  The EPA had previously issued regulations pursuant to Section 316(b) of the Clean Water Act regarding cooling water intake structures.  Subsequent to an appellate court ruling, the EPA suspended the regulations and is engaged in further rulemaking on this matter.  In December 2010, in a court approved settlement, the EPA agreed to propose a new rule in March 2011 and to finalize it in July 2012.  At this time, management is unable to predict how the EPA will respond or how that response will impact Great Plains Energy’s and KCP&L’s operations.
 
KCP&L holds a permit from the MDNR covering water discharge from its Hawthorn Station.  The permit authorizes KCP&L to, among other things, to 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.  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.
 
InAdditionally, in September 2009, the EPA announced plans to revise the existing standards for water discharges from coal-fired power plants.  In November 2010, the EPA filed a motion requesting court approval of a consent agreement in which the EPA agreed to propose a rule in July 2012 and to finalize it in January 2014.  Until a rule is proposed and finalized, the financial and operational impacts to Great Plains Energy and KCP&L cannot be determined.
 
Solid Waste
Solid and hazardous waste generation, storage, transportation, treatment and disposal is regulated at the federal and state levels under various laws and regulations.  Since an incident at an ash containment area in December 2008 at a Tennessee Valley Authority site, federal legislation has been introducedIn May 2010, the EPA proposed to regulate coal combustion residuals (CCRs) under the Resource Conservation and information requests issued regardingRecovery Act (RCRA) to address the handling andrisks from the disposal of CCRs generated from the combustion of coal combustion products.  In addition,at electric generating facilities.  The EPA is considering two options in this proposal.  Under the first proposal, the EPA has indicated it will issue proposed federal regulationswould regulate CCRs as special wastes subject to regulation under subtitle C of RCRA (hazardous), when they are destined for coal combustion product disposal.disposal in landfills or surface impoundments.  Under the second proposal, the EPA would regulate disposal of CCRs under subtitle D of RCRA (non-hazardous).  The companiesCompanies principally use coal in generating electricity and dispose of the combustion productsCCRs in both on-site facilities and facilities owned by third parties.  Coal combustion product-related legislation or regulation, especially if coal combustion products are classified as hazardous waste,The proposed CCR rule has the potential of having a significant financial and operational impact on Great Plains Energy and KCP&L in connection with achieving compliance with the requirements that may be established.proposed requirements.  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 legislationregulation is passed or regulations enacted.
 
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Remediation
Certain federal and state laws, including the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) hold current and previous owners or operators of real property, and any person who arranges for the disposal or treatment of hazardous substances at a property, liable on a joint and several basis for the costs of cleaning up contamination at or migrating from such real property, even if they did not know of and
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were not responsible for such contamination.  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 two disposal sites for polychlorinated biphenyls (PCBs), 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, 20092010 and 2008,2009, KCP&L had $0.3 million accrued for environmental remediation expenses, which covers ground water monitoring at a former MGP site.  At December 31, 2010 and 2009, Great Plains Energy had $0.4 million accrued for environmental remediation expenses, which includes the $0.3 million at KCP&L, and additional potential remediation and ground water monitoring costs relating to two GMO sites.  The amounts accrued were established on an undiscounted basis and Great Plains Energy and KCP&L do not currently have an estimated time frame over which the accrued amounts may be paid.
 
In addition to the $0.4 million accrual above, at December 31, 2009,2010, Great Plains Energy had $2.0$2.1 million accrued for the future investigation and remediation of certain additional GMO identified MGP sites, PCB 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.
 
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 $2.2$2.3 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.
 
In January 2010, the EPA announced an advance notice of proposed rulemaking under CERCLA identifying classes of facilities for which the EPA will develop financial assurance requirements, including the electric power generation, transmission and distribution industry.  The CERCLA financial assurance would be for risks associated with Great Plains Energy’s and KCP&L’s production, transportation, treatment, storage or disposal of CERCLA hazardous substances.  The impact on Great Plains Energy and KCP&L cannot be determined until the regulations are finalized.
 
In April 2010, the EPA announced an advance notice of proposed rulemaking for the use and distribution in commerce of certain PCBs, PCB items and certain other areas of the PCB regulations.  The EPA is reassessing the use, distribution in commerce, marking, and storage for reuse of liquid PCBs in electric and non-electric equipment and the use of the 50 ppm level for excluded PCB products among other things.  The impact on Great Plains Energy and KCP&L cannot be determined until the regulations are finalized.
Contractual Commitments
Great Plains Energy’s and KCP&L’s expenses related to lease commitments are detailed in the following table.
         
 2009  2008  2007  2010 2009 2008
 (millions)  (millions)
Great Plains Energy $23.4  $20.7  $18.6  $17.2  $23.4  $20.7 
KCP&L $19.3  $18.1  $17.3  $13.2  $19.3  $18.1 
            


 
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Great Plains Energy’s and KCP&L’s contractual commitments at December 31, 2009,2010, excluding pensions and long-term debt, are detailed in the following tables.

Great Plains Energy                     
  2011 2012 2013 2014 2015 After 2015 Total
Lease commitments (millions) 
Operating lease $17.9  $16.8  $15.0  $14.3  $13.5  $129.4  $206.9 
Capital lease  0.4   0.4   0.4   0.4   0.4   5.5   7.5 
Purchase commitments                            
Fuel  348.7   282.7   287.7   164.8   108.8   125.3   1,318.0 
Purchased capacity  20.3   13.4   12.4   4.5   4.2   2.4   57.2 
Non-regulated natural gas                            
transportation  4.6   2.9   2.9   2.9   2.9   3.4   19.6 
Other  163.4   17.6   6.8   8.1   2.7   55.1   253.7 
Total contractual commitments $555.3  $333.8  $325.2  $195.0  $132.5  $321.1  $1,862.9 
                             

KCP&L                     
  2011 2012 2013 2014 2015 After 2015 Total
Lease commitments (millions)
Operating lease $14.1  $13.1  $12.7  $12.5  $12.1  $129.4  $193.9 
Capital lease  0.2   0.2   0.2   0.2   0.2   3.2   4.2 
Purchase commitments                            
Fuel  296.8   241.5   249.1   144.4   104.9   125.3   1,162.0 
Purchased capacity  5.5   4.7   3.7   2.9   3.0   1.2   21.0 
Other  127.5   15.0   6.0   7.3   1.9   40.8   198.5 
Total contractual commitments $444.1  $274.5  $271.7  $167.3  $122.1  $299.9  $1,579.6 
                             
Great Plains Energy                     
  2010  2011  2012  2013  2014 After 2014 Total 
Lease commitments (millions) 
Operating lease $15.6  $16.0  $15.3  $14.0  $13.6  $151.6  $226.1 
Capital lease  0.4   0.4   0.4   0.4   0.4   5.0   7.0 
Purchase commitments                            
Fuel  197.3   113.3   103.9   100.2   85.1   138.8   738.6 
Purchased capacity  33.0   19.9   14.1   13.1   4.5   6.5   91.1 
Comprehensive Energy Plan105.3   1.4   -   -   -   -   106.7 
Non-regulated natural gas                            
transportation  6.1   5.6   3.2   3.2   3.2   7.2   28.5 
Other  66.9   15.0   5.9   5.5   5.6   21.2   120.1 
Total contractual commitments$424.6  $171.6  $142.8  $136.4  $112.4  $330.3  $1,318.1 
                             
KCP&L                     
  2010  2011  2012  2013  2014 After 2014 Total 
Lease commitments (millions) 
Operating lease $12.0  $12.8  $12.2  $12.0  $12.0  $141.6  $202.6 
Capital lease  0.2   0.2   0.2   0.2   0.2   3.2   4.2 
Purchase commitments                            
Fuel  135.5   91.1   81.8   76.8   66.1   138.8   590.1 
Purchased capacity  6.3   4.7   4.7   3.7   2.9   4.2   26.5 
Comprehensive Energy Plan105.3   1.4   -   -   -   -   106.7 
Other  60.8   14.5   5.9   5.5   5.6   21.2   113.5 
Total contractual commitments$320.1  $124.7  $104.8  $98.2  $86.8  $309.0  $1,043.6 
                             

Great Plains Energy has expected sublease income of $4.2$2.0 million for the years 2010-2014 and $0.2 million in total thereafter.2011-2013.  Lease commitments end in 2032.  Operating lease commitments include rail cars to serve jointly-owned generating units where KCP&L is the managing partner.  KCP&L will be reimbursed by the other owners for approximately $2.0 million per year ($14.713.7 million total) of the amounts included in the table above.
 
Fuel commitments consist of commitments for nuclear fuel, coal and coal transportation.  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 $11.2 million per year for 2010 and 2011, $6.9 million infor 2011, $3.8 million for 2012, and $1.6 million infor 2013.  Comprehensive Energy Plan represents contractual commitments for projects included in KCP&L’s Comprehensive Energy Plan including jointly owned units.  KCP&L expects to be reimbursed by other owners, including GMO, for their respective share of Iatan No. 2 and environmental retrofit costs included in the Comprehensive Energy Plan contractual commitments.  Non-regulated natural gas transportation consists of MPS Merchant’s commitments.  Other represents individual commitments entered into in the ordinary course of business.
 

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17.16.  LEGAL PROCEEDINGS
Kansas City Power & Light Company v. Union Pacific Railroad Company
In October 2005, KCP&L filed a rate complaint case with the Surface Transportation Board (STB) charging that Union Pacific Railroad Company’s (Union Pacific) rates for transporting coal from the Powder River Basin (PRB) in Wyoming to KCP&L’s Montrose Station were unreasonably high.  On May 16, 2008, the STB found that the rates Union Pacific charged on coal movement from the PRB to KCP&L’s Montrose Station exceeded the
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maximum reasonable rate of 180% of variable costs.  Consequently, the STB prescribed a maximum reasonable rate of 180% of variable costs until the end of 2015.  Additionally, the STB ordered reparations to be paid, with interest, for coal deliveries made from January 1, 2006 through the date a new rate is established.  Union Pacific did not appeal the decision.  KCP&L has received approximately $3.5 million for reparations and interest for 2006, 2007 and the first half of 2008 coal deliveries.  In August 2009, KCP&L and Union Pacific executed a joint stipulation that defines a methodology for calculating future rates, which replaces the STB reparation process.
 
KCP&L Hawthorn No. 5 Litigation
KCP&L received reimbursement for the 1999 Hawthorn No. 5 boiler explosion under a property damage insurance policy with Travelers Property Casualty Company of America (Travelers).  Travelers filed suit in the U.S. District Court for the Eastern District of Missouri in November 2005, against National Union Fire Insurance Company of Pittsburgh, Pennsylvania, (National Union) and KCP&L was added as a defendant in June 2006.  The case was subsequently transferred to the U.S. District Court for the Western District of Missouri.  Travelers sought recovery of $10 million that KCP&L recovered through subrogation litigation.  On July 24, 2008, the Court held that Travelers is not entitled to any recovery from KCP&L.  Travelers appealed this decision on March 11, 2009, to the Court of Appeals for the Eighth Circuit.  In September 2010, the Court of Appeals affirmed the District Court’s decision.  The Company does not currently expect any further action with respect to this matter.
 
KCP&L Spent Nuclear Fuel and Radioactive Waste
In January 2004, KCP&L and the other two Wolf Creek owners havefiled a lawsuit pending against the United States in the U.S. Court of Federal Claims seeking $14.1 million of damages resulting from the government’s failure to begin accepting spent nuclear fuel for disposal in January 1998, as the government was required to do by the Nuclear Waste Policy Act of 1982.  Approximately seventy other similar cases were filed with that court, a few of which have settled.  To date, the court has rendered final decisions in several of the cases, most of which are on appeal now.  The Wolf Creek case is set for trialwas tried before a U.S. Court of Federal Claims judge in June 2010.  Another2010, and a decision was issued in November 2010, granting KCP&L and the other two Wolf Creek owners $10.6 million ($5.0 million KCP&L share) in damages.  In January 2011, KCP&L and the other two Wolf Creek owners as well as the United States filed appeals of the decision of the U.S. Court of Federal appellate court has already determined thatClaims to the government breached its obligation to begin accepting spent fuelU.S. Court of Appeals for disposal.  The questions now before the court in the pending cases are whether and to what extent the utilities are entitled to monetary damages for that breach.Federal Circuit.
 
KCP&L Advanced Coal Credit Arbitration
In July 2009, KCP&L was served a notice to arbitrate by The Empire District Electric Company (Empire), Kansas Electric Cooperative, Inc. (KEPCO) and Missouri Joint Municipal Electric Utility Commission (MJMEUC), the non-Company joint owners of Iatan No. 2.  TheThese joint owners asserted that they arewere entitled to receive proportionate shares (or the monetary equivalent) of approximately $125 million of qualifying advance coal project creditcredits for Iatan No. 2.  As independent entities, the joint owners are taxed separately and the non-Company joint owners do not dispute that they did not, in fact, apply for the credits themselves.  Notwithstanding this, the joint owners contendthey contended that they should receive proportional shares of the credit.  This matter was heard by an arbitration panel in November 2009.  On December 30, 2009, thean arbitration panel issued its order denying the KEPCO and MJMEUC claims but ordering KCP&L and Empire to jointly seek a reallocation of the tax credit from the IRS giving Empire its representative percentage of the total tax credit, worth approximately $17.7 million.  The order further specifiesspecified that if the IRS denies the parties’ reallocation request or if Empire is allocated less than its proportionate share of the tax credits, KCP&L will be responsible for paying Empire the full value of its representative percentage of the tax credits (less the amount of tax credits, if any, Empire ultimately receives) in cash.  In September 2010, the IRS issued an amended memorandum of understanding to reallocate $17.7 million of the original $125 million of the advanced coal project credits to Empire, meeting the requirements of the arbitration order issued on December 30, 2009.  KCP&L has recordedsubsequently dismissed its March 31, 2010, appeal of the arbitration order.  In 2010, KCP&L reversed a $17.7 million liability previously recorded in other current liabilities for this matter.  The parties have 90 days to appeal the arbitrators’ decision.

Iatan Levee Litigation
On May 22, 2009, several farmers filed suit against Great Plains Energy and KCP&L in the Circuit Court of Platte County, Missouri, alleging negligence, private nuisance, trespass and violations of the Missouri Crop Protection Act and seeking unspecified compensatory and punitive damages.  These allegations stem from flooding at or near the Iatan Station in 2007 and 2008.  The farmers allege the flooding was a result of maintenance of a nearby levee.  The petition seeks class certification from the courts.  Written discovery and depositions are underway.  This matter is set for trial in October 2011.  Management cannot predict the outcome of this matter.
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GMO Price Reporting Litigation
In response to complaints of manipulation of the California energy market, in 2002July 2001, FERC issued an order 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.refunds through settlements with certain sellers of power.  MPS Merchant estimates that it is entitled to approximately $10$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.  However, in December 2001, various parties appealed the FERC order to the United States Court of Appeals for the Ninth Circuit seeking review of a number of issues, including changing the refund period to include periods prior to October 2, 2000.  MPS Merchant was a net seller of power during the period prior to October 2, 2000.  On August 2, 2006, the U.S. Court of Appeals for 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 period prior to October 2, 2000, and imposing a remedy for any such violations.  The court remanded the matter to FERC to determine whether tariff violations occurred and, if so, the appropriate remedy.  In March 2008, FERC issued an order declining to order refunds for the period prior to October 2, 2000.  That order has been appealed to the U.S. Court of Appeals for the Ninth Circuit.  If FERC ultimately includes thatthe period prior to October 2, 2000, MPS Merchant could be found to owe refunds.
 
FERC initiated a separate docket, generally referred to as the Pacific Northwest refund proceeding, to determine if any refunds were warranted related to the potential impact of the California market issues on buyers in the Pacific Northwest between December 25, 2000, and June 20, 2001.  FERC rejected the refund requests, but its decision was remanded by the Court of Appeals for FERC to consider whether any acts of market manipulation support the imposition of refunds.  Claims against MPS Merchant total $5.1 million.million for the period addressed under the Pacific Northwest refund proceedings.
 
OnIn October 6, 2006, the MPSC filed suit in the Circuit Court of Jackson County, Missouri against 18 companies, including GMO and MPS Merchant alleging that the companies manipulated natural gas prices through the misreporting of natural gas trade data and, therefore, violated Missouri antitrust laws.  The suit does not specify alleged damages and was filed on behalf of all local distribution gas companies in Missouri who bought and sold natural gas from June 2000 to October 2002.  The defendants’ motions to dismiss the case were granted in January 2009.  TheIn February 2009, the MPSC has appealed the dismissal to the Missouri Court of Appeals for the Western District of Missouri.  In December 2009, the courtMissouri Court of Appeals affirmed the dismissal and the MPSC filed a request for rehearing or, in the alternative, transfer to the Missouri Supreme Court.
The ultimate outcomeMissouri Supreme Court accepted the transfer in April 2010, but in September 2010, transferred the case back to the Court of these matters cannot be predicted.
Everest Minority Shareholder Litigation
On October 11, 2006, minority shareholders of a former subsidiary of GMO brought suit against GMO in Circuit Court in St. Charles County, Missouri, asserting that they are entitledAppeals, which then reaffirmed its earlier opinion.  The Company does not currently expect any further action with respect to put their shares to GMO for approximately $5 million because the subsidiary failed to obtain 30,000 customers by the end of 2004.  In October 2009, the parties settled this case.  The settlement did not have a significant impact to Great Plains Energy’s results of operations or financial position.matter.
 
18.17.  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 indemnification of 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 subsidiaries’ 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.

 
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At December 31, 2009,2010, Great Plains Energy has provided $1,063.6$1,030.4 million of credit support for GMO as follows:
 
·  Great Plains Energy direct guarantees to GMO counterparties totaling $87.9$65.4 million, of which $45.4 million expire in 2010,2011 and $20.0 million expire in 2012,
 
·  Great Plains Energy letters of credit totaling $25.4 million to GMO counterparties totaling $15.8 million , which expire in 2010,2011, and
 
·  Great Plains Energy guarantee of GMO long-term debt totaling $950.3$949.2 million, which includes debt with maturity dates ranging from 2010-2023.2011-2023.

Great Plains Energy has also guaranteed GMO’s $400$450 million revolving line of credit dated September 23, 2008,August 9, 2010, with a group of banks, expiring September 23, 2011.August 9, 2013.  At December 31, 2009, there was $232.02010, GMO had no outstanding cash borrowings and had issued letters of credit totaling $13.2 million outstanding under this facility.
 
At December 31, 2009, KCP&L had guaranteed, with a maximum potential of $1.0 million, energy savings under an agreement with a customer that expires over the next year.  A subcontractor would indemnify KCP&L for any payments made by KCP&L under this guarantee.  This guarantee was entered into before December 31, 2002; therefore, a liability was not recorded.
19.18.  RELATED PARTY TRANSACTIONS AND RELATIONSHIPS
 
KCP&L employees manage GMO’s business and operate its facilities at cost.  These costs totaled $100.9 million for 2010, $102.7 million for 2009 and $41.0 million infor 2008, subsequent to the July 14, 2008, acquisition of GMO.  Additionally, KCP&L and GMO engage in wholesale electricity transactions with each other.  Prior to 2009, KCP&L and GMO received various support and administrative services from Services.  These costs totaled $13.0 million and $14.9 million for 2008 and 2007, respectively, for KCP&L and $2.4 million in 2008 for GMO.  In December 2008, employees and assets of Services were transferred to KCP&L.  KCP&L and GMO are also authorized to participate in the Great Plains Energy money pool.  The money pool, is an internal financing arrangement in which funds deposited into the money pool may be lent on a short-term basis to KCP&L and GMO.  The following table summarizes KCP&L’s related party receivables and payables.
      
 December 31
 2010 2009
 (millions)
Receivable from GMO $    29.6 $26.4 
Payable to Great Plains Energy Services Incorporated            -  (0.2) 
Receivable from Great Plains Energy       13.3      15.1 
Receivable from MPS Merchant         0.3     0.9 
      




        
   December 31
  2009 2008
  (millions) 
Receivable from GMO $26.4   $23.7 
Receivable (payable) from/to Services  (0.2)   4.8 
Receivable (payable) from/to Great Plains Energy  15.1    (1.2)
Receivable (payable) from/to MPS Merchant  0.9    (3.4)
          
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20.19.  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.  Commodity risk management activities, including the use of certain derivative instruments, are subject to the management, direction and control of an internal risk management committee.  Management’s interest rate risk management strategy uses derivative instruments to adjust Great Plains Energy’s and KCP&L’s liability portfolio to optimize the mix of fixed and floating rate debt within an established range.  In addition, Great Plains Energy and KCP&L use derivative instruments to hedge against future interest rate fluctuations on anticipated debt issuances.  Management maintains commodity price risk management strategies that use derivative instruments to reduce the effects of fluctuations in fuel expense caused by commodity price volatility.  Counterparties to commodity derivatives and interest rate swap agreements 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
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market rates.  Derivative instruments, excluding those instruments that qualify for the normal purchase normal sale 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 GMO utility operations hedges 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 normalordinary course of business, for the aggregate fair value of all derivative instruments with credit risk-related contingent features that are in a liability position.  IfAt December 31, 2010, Great Plains Energy and KCP&L have posted collateral in excess of the aggregate fair value of its 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 an insignificant amount ofadditional collateral to its counterparties.
 
The Dodd-Frank Wall Street Reform and Consumer Protection Act, signed into law in July 2010, includes provisions related to the swaps and over-the-counter derivative markets.  The Companies currently expect that their commodity and interest rate hedges will be exempt from mandatory clearing and exchange trading requirements.  Capital and margin requirements for these hedges are expected to be determined over the next year as regulatory agencies implement rules.  While the Companies currently do not anticipate this law and the associated regulatory rules to have a material impact on their financial condition, the ultimate impact cannot be reasonably determined until the final rules are issued.
Interest Rate Risk Management
In August 2010, Great Plains Energy issued $250.0 million of long-term debt and settled two FSS simultaneously with the issuance of the long-term fixed rate debt.  Great Plains Energy had entered into the two FSS with notional amounts of $125.0 million to hedge against interest rate fluctuations on a portion of the August 2010 debt issuance.  The two FSS were treated as cash flow hedges with no ineffectiveness recorded in 2010 or 2009.  A pre-tax loss of $6.9 million was recorded to OCI and is being reclassified to interest expense over the life of the three-year debt.  At December 31, 2010, $0.9 million of the loss has been reclassified from OCI to interest expense.
In December 2009 and January 2010, Great Plains Energy entered into a Forward Starting Swap (FSS)five FSS with atotal notional amountamounts of $100.0$350.0 million to hedge against interest rate fluctuations on debt anticipated to be issued in 2010.2011.  The five FSS removesremove a portion of the interest rate variability on $100.0$350.0 million of the debt expected to be issued thereby enabling Great Plains Energy to predict with greater assurance its future interest costs on that debt.  The five FSS isare treated as a cash flow hedgehedges with no ineffectiveness recorded as of December 31,in 2010 or 2009.  At December 31, 2009,2010, a $0.2$20.8 million loss was recorded in OCI for the five FSS.  In January 2010, Great Plains Energy entered into another FSS with a notional amount of $25.0 million to hedge against interest rate fluctuations on the same debt anticipated to be issued in 2010.
Also in December 2009, Great Plains Energy entered into three FSS with a total notional amount of $262.5 million to hedge against interest rate fluctuations on debt anticipated to be issued in 2011.  The FSS removes a portion of the interest rate variability on $262.5 million of the debt expected to be issued thereby enabling Great Plains Energy to predict with greater assurance its future interest costs on that debt.  The FSS is treated as a cash flow hedge with no ineffectiveness as of December 31, 2009.  At December 31, 2009, a $0.5 million loss was recorded in OCI for the FSS.  In January 2010, Great Plains Energy entered into two additional FSS with a notional amount of $87.5 million to hedge against interest rate fluctuations on the same debt anticipated to be issued in 2011.
In March 2009, KCP&L issued $400.0 million of long-term debt and settled three FSSwill settle simultaneously with the issuance of thisthe underlying long-term fixed rate debt.  No ineffectiveness was recordeddebt expected to be issued.  Any gain or loss on the three FSS in 2009 or 2008.  A pre-tax loss of $53.4 million wassettlement will be recorded to OCI and is being reclassified to interest expense over the life of the ten-year debt.  Year to date December 31, 2009, $4.0 million of the loss has been reclassified from OCI to interest expense.
 
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Commodity Risk Management
KCP&L’s risk management policy is to use derivative instruments 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.  At December 31, 2009,2010, KCP&L has hedged 68%66%, 45% and 11%22%, respectively, of the 20102011, 2012 and 20112013 projected natural gas usage for retail load and firm MWh sales, primarily by utilizing futures contracts and financial instruments.  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.  KCP&L has not recorded any ineffectiveness on natural gas hedges in 2009, 2008 or 2007.
KCP&L uses derivative instruments to mitigate its exposure to market price fluctuations on a portion of the projected fuel oil purchases to meet the startup requirements for Iatan No. 2.  At December 31, 2009, KCP&L has hedged 24% of the projected fuel oil purchases for the startup of Iatan No. 2 utilizing futures contracts.  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
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fair market value would be recorded as a cost of the construction of Iatan No. 2.  KCP&L has not recorded any ineffectiveness on fuel oil hedges in2010, 2009 or 2008.
 
GMO’s risk management policy is to use derivative instruments to mitigate price exposure to natural gas price volatility in the market.  The fair value of the portfolio relates to financial contracts that will settle against actual purchases of natural gas and purchased power.  At December 31, 2009,2010, GMO had financial contracts in place to hedge approximately 55%67%, 45% and 3%38% of the expected on-peak natural gas and natural gas equivalent purchased power price exposure for 20102011, 2012 and 2011,2013, respectively.  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 Missouri FAC.  A regulatory asset has been recorded to reflect the change in the timing of recognition authorized by the MPSC.  To the extent that recovery of actual costs incurred is allowed, amounts will not impact earnings, but will impact cash flows due to the timing of the recovery mechanism.
 
MPS Merchant manages the daily delivery of its remaining contractual commitments with economic hedges (non-hedging derivative)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 both physical and financial, as derivative assets or liabilities with an offsetting entry to the consolidated statements of income.

 
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The notional and recorded fair values of the companies’ 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 
  2009  2008 
  Notional     Notional    
  Contract  Fair  Contract  Fair 
  Amount  Value  Amount  Value 
Great Plains Energy (millions) 
Swap contracts            
Cash flow hedges $-  $-  $0.7  $(0.2)
Non-hedging derivatives  -   -   46.2   (7.4)
Futures contracts                
Cash flow hedges  3.2   -   4.5   0.6 
Non-hedging derivatives  29.8   (0.9)  -   - 
Forward contracts                
Non-hedging derivatives  234.4   9.1   317.3   7.8 
Option contracts                
Cash flow hedges  2.3   0.2   -   - 
Non-hedging derivatives  -   -   28.2   0.2 
Anticipated debt issuance                
Forward starting swaps  362.5   (0.7)  250.0   (80.1)
KCP&L                
Swap contracts                
Cash flow hedges  -   -   0.7   (0.2)
Future contracts                
Cash flow hedges  3.2   -   4.5   0.6 
Option contracts                
Cash flow hedges  2.3   0.2   -   - 
Anticipated debt issuance                
Forward starting swap  -   -   250.0   (80.1)
                 
             
  December 31
  2010 2009
  Notional   Notional  
  Contract Fair Contract Fair
  Amount Value Amount Value
Great Plains Energy (millions)
Futures contracts            
Cash flow hedges $4.0  $-  $3.2  $- 
Non-hedging derivatives  59.5   (2.5)  29.8   (0.9)
Forward contracts                
Non-hedging derivatives  202.8   8.9   234.4   9.1 
Option contracts                
Cash flow hedges  -   -   2.3   0.2 
Non-hedging derivatives  0.2   -   -   - 
Anticipated debt issuance                
Forward starting swaps  350.0   (20.8)  362.5   (0.7)
KCP&L                
Futures contracts                
Cash flow hedges  4.0   -   3.2   - 
Option contracts                
Cash flow hedges  -   -   2.3   0.2 
                 
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The fair value of Great Plains Energy’s and KCP&L’s open derivative positions are summarized in the following tables.  The tables contain derivative instruments designated as hedging instruments as well as derivative instruments not designated as hedging instruments (non-hedging derivatives) under GAAP.  The fair values below are gross values before netting agreements and netting of cash collateral.
 
Great Plains Energy
        Balance SheetAsset DerivativesLiability Derivatives
December 31, 2010       ClassificationFair ValueFair Value
Derivatives Designated as Hedging Instruments   (millions)
Commodity contracts Derivative instruments $       0.1 $         0.1
Interest rate contracts Derivative instruments             -          20.8
Derivatives Not Designated as Hedging Instruments    
Commodity contracts Derivative instruments          9.4            3.0
Total Derivatives   $       9.5 $       23.9
     
December 31, 2009    
Derivatives Designated as Hedging Instruments   
Commodity contracts Derivative instruments $       0.4 $         0.2
Interest rate contracts Derivative instruments             -            0.7
Derivatives Not Designated as Hedging Instruments    
Commodity contracts Derivative instruments          9.9            1.7
Total Derivatives   $     10.3 $         2.6
 



Great Plains Energy       
   Balance Sheet Asset DerivativesLiability Derivatives
December 31, 2009 Classification Fair ValueFair Value
Derivatives Designated as Hedging Instruments    (millions)
Commodity contracts Derivative instruments $    0.4  $      0.2 
Interest rate contracts Derivative instruments -  0.7 
Derivatives Not Designated as Hedging Instruments      
Commodity contracts Derivative instruments        9.9             1.7 
Total Derivatives    $  10.3  $      2.6 
         
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KCP&L       
   Balance Sheet Asset DerivativesLiability Derivatives
December 31, 2009 Classification Fair ValueFair Value
Derivatives Designated as Hedging Instruments    (millions)
Commodity contracts Derivative instruments $    0.4  $      0.2 
         

KCP&L
        Balance SheetAsset DerivativesLiability Derivatives
December 31, 2010       ClassificationFair ValueFair Value
Derivatives Designated as Hedging Instruments  (millions)
Commodity contracts Derivative instruments $       0.1 $         0.1
     
December 31, 2009    
Derivatives Designated as Hedging Instruments   
Commodity contracts Derivative instruments $       0.4 $         0.2
 
The following tables summarize the amount of gain (loss) recognized in OCI or earnings for interest rate and commodity hedges.
        
Great Plains EnergyGreat Plains Energy
Derivatives in Cash Flow Hedging Relationship
    Gain (Loss) Reclassified from   Gain (Loss) Reclassified from
    Accumulated OCI into Income   Accumulated OCI into Income
    (Effective Portion)   (Effective Portion)
  Amount of Gain     Amount of Gain  
  (Loss) Recognized     (Loss) Recognized   
  in OCI on DerivativesIncome Statement   in OCI on Derivatives      Income Statement 
Great Plains Energy (Effective Portion)Classification Amount
 (Effective Portion)          ClassificationAmount
2010   (millions)  (millions)
Interest rate contracts    $   (27.1)  Interest charges $   (10.1)
Commodity contracts           (0.9)  Fuel        (0.5)
Income tax benefit (expense)          10.8  Income tax benefit (expense)        4.0
Total    $   (17.2) Total $     (6.6)
     
2009  (millions)   (millions)     
Interest rate contractsInterest rate contracts      $       0.4  Interest charges $     (8.0)             $       0.4  Interest charges $     (8.0)
Commodity contractsCommodity contracts               (0.8)   Fuel      (1.1)                      (0.8)  Fuel        (1.1)
Income tax benefit (expense)Income tax benefit (expense)                0.1   Income tax benefit (expense)3.5                        0.1  Income tax benefit (expense)        3.5
Total         $      (0.3)  Total  $     (5.6)               $      (0.3) Total $     (5.6)
        
KCP&L        
2009        
Interest rate contracts      $        1.0  Interest charges  $     (7.5)         
Commodity contracts                (0.8)  Fuel         (1.1)         
Income tax benefit (expense)                (0.1)  Income tax benefit (expense)          3.3          
Total       $        0.1 Total  $     (5.3)         



 
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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      Income Statement 
  (Effective Portion)         ClassificationAmount
2010   (millions)  (millions)
Interest rate contracts    $          -  Interest charges $     (8.8)
Commodity contracts           (0.9)  Fuel        (0.5)
Income tax benefit (expense)            0.3  Income tax benefit (expense)        3.6
Total    $     (0.6) Total $     (5.7)
      
2009     
Interest rate contracts   $      1.0  Interest charges $     (7.5)
Commodity contracts           (0.8)  Fuel        (1.1)
Income tax benefit (expense)           (0.1)  Income tax benefit (expense)        3.3
Total   $      0.1 Total $     (5.3)
 

The following tables summarizetable summarizes the amount of gain (loss) recognized in a regulatory balance sheet account 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 EnergyGreat Plains Energy      
Derivatives in Regulatory Account RelationshipDerivatives in Regulatory Account Relationship     Derivatives in Regulatory Account Relationship
    Gain (Loss) Reclassified from    Gain (Loss) Reclassified from
    Regulatory Account    Regulatory Account
  Amount of Gain (Loss)       Amount of Gain (Loss)  
  Recognized in Regulatory       Recognized on Regulatory  
  Account on Derivatives Income Statement   Account on Derivatives      Income Statement 
Great Plains Energy (Effective Portion) ClassificationAmount
  (Effective Portion)         ClassificationAmount
  (millions)  (millions)
2010      
Commodity contractsCommodity contracts  $     (8.2)  Fuel $     (7.2)
Total   $     (8.2) Total $     (7.2)
      
2009  (millions)    (millions)      
Commodity contractsCommodity contracts  $   (12.8)  Fuel  $   (20.5)Commodity contracts  $   (12.8)  Fuel $   (20.5)
Total   $   (12.8) Total  $   (20.5)   $   (12.8) Total $   (20.5)
        
Great Plains Energy’s income statement reflects gainsa loss for the change in fair value of the MPS Merchant commodity contract derivatives not designated as hedging instruments of $0.2 million for 2010 and a gain of $1.6 million for 2009.
 

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The amounts recorded in accumulated OCI related to the cash flow hedges are summarized in the following table.
                        
 Great Plains Energy  KCP&L  Great Plains Energy KCP&L
 December 31  December 31  December 31 December 31
 2009  2008  2009  2008  2010 2009 2010 2009
 (millions)  (millions)
Current assets $13.3  $13.7  $13.3  $13.7  $12.0  $13.3  $12.0  $13.3 
Current liabilities  (84.9)  (94.6)  (81.2)  (90.5)  (101.5)  (84.9)  (71.6)  (81.2)
Noncurrent liabilities  (0.5)  -   -   -   -   (0.5)  -   - 
Deferred income taxes  28.0   31.5   26.4   29.9   34.8   28.0   23.2   26.4 
Total $(44.1) $(49.4) $(41.5) $(46.9) $(54.7) $(44.1) $(36.4) $(41.5)
                                
Great Plains Energy’s accumulated OCI in the table above at December 31, 2009,2010, includes $10.4$15.6 million that is expected to be reclassified to expenses over the next twelve months.  KCP&L’s accumulated OCI includes $8.4$8.8 million that is expected to be reclassified to expense over the next twelve months.
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The amounts reclassified to expenses for 2008 are summarized in the following table.
            
 2009  2008  2007  2008
Great Plains Energy (millions)  (millions)
Fuel expense $1.1  $(2.3) $-  $(2.3)
Interest expense  8.0   2.8   (0.4)  2.8 
Income tax benefit (expense)  (3.5)  (0.2)  0.1 
Income tax expense  (0.2)
Income (loss) from discontinued operations                
Purchased power expense  -   (106.1)  83.7   (106.1)
Income taxes  -   43.8   (34.2)  43.8 
OCI $5.6  $(62.0) $49.2  $(62.0)
KCP&L                
Fuel expense $1.1  $(2.3) $-  $(2.3)
Interest expense  7.5   2.5   (0.6)  2.5 
Income tax benefit (expense)  (3.3)  -   0.2 
OCI $5.3  $0.2  $(0.4) $0.2 
                
21.20.  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.  Assets categorized within this level consist of Great Plains Energy’s and KCP&L’s various exchange traded derivative instruments and equity and U.S. Treasury securities that are actively traded within KCP&L’s decommissioning trust fund and GMO’s SERP rabbi trust fund.
 
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.  Assets and liabilities categorized within this level consist of Great Plains Energy’s and KCP&L’s various non-exchange traded derivative instruments traded in
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over-the-counter markets and certain debt securities within KCP&L’s decommissioning trust fund and GMO’s SERP rabbi trust fund.
 
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.  Assets categorized within this level consist of Great Plains Energy’s various non-exchange traded derivative instruments traded in over-the-counter markets and certain debt securities within KCP&L’s decommissioning trust fund for which sufficiently observable market data is not available to corroborate the valuation inputs.
 
120123
 
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 at December 31, 20092010 and 2008.2009.
               
       Fair Value Measurements Using                
                Fair Value Measurements Using 
Description
December 31 
2009
 
Netting(c)
  
Quoted Prices in Active Markets for Identical Assets
(Level 1)
  
Significant Other Observable Inputs
(Level 2)
  
Significant Unobservable Inputs
(Level 3)
  
December 31
2010
 
Netting(d)
  
Quoted Prices in Active Markets for Identical Assets
(Level 1)
  
Significant Other Observable Inputs
(Level 2)
  
Significant Unobservable Inputs
(Level 3)
 
KCP&L (millions)  (millions) 
Assets                              
Derivative instruments (a)
 $0.2  $(0.2) $0.2  $0.2  $-  $-  $(0.1) $0.1  $-  $- 
Nuclear decommissioning trust (b)
                                        
Equity securities  44.5   -   44.5   -   -   85.5   -   85.5   -   - 
Debt securities                                        
U.S. Treasury  11.2   -   11.2   -   -   8.9   -   8.9   -   - 
U.S. Agency  3.5   -   -   3.5   -   4.8   -   -   4.8   - 
State and local obligations  3.1   -   -   2.9   0.2   2.5   -   -   2.5   - 
Corporate bonds  18.9   -   -   18.9   -   23.7   -   -   23.7   - 
Foreign governments  0.7   -   -   0.7   -   0.7   -   -   0.7   - 
Other  1.2   -   -   1.2   -   0.4   -   -   0.4   - 
Total Nuclear Decommissioning Trust 83.1   -   55.7   27.2   0.2 
Total nuclear decommissioning trust  126.5   -   94.4   32.1   - 
Total  83.3   (0.2)  55.9   27.4   0.2   126.5   (0.1)  94.5   32.1   - 
Liabilities                                        
Derivative instruments (a)
  -   (0.2)  -   0.2   -   -   (0.1)  0.1   -   - 
Total $-  $(0.2) $-  $0.2  $-  $-  $(0.1) $0.1  $-  $- 
Other Great Plains Energy                                        
Assets                                        
Derivative instruments (a)
 $9.2  $(0.7) $0.7  $5.1  $4.1  $8.9  $(0.5) $0.5  $5.2  $3.7 
SERP rabbi trust (b)
                    
SERP rabbi trust (c)
                    
Equity securities  0.2   -   0.2   -   -   0.2   -   0.2   -   - 
Debt securities  6.9   -   -   6.9   -   7.0   -   -   7.0   - 
Total SERP rabbi trust  7.1   -   0.2   6.9   -   7.2   -   0.2   7.0   - 
Total  16.3   (0.7)  0.9   12.0   4.1   16.1   (0.5)  0.7   12.2   3.7 
Liabilities                                        
Derivative instruments (a)
  0.8   (1.6)  1.6   0.8   -   20.8   (3.0)  3.0   20.8   - 
Total $0.8  $(1.6) $1.6  $0.8  $-  $20.8  $(3.0) $3.0  $20.8  $- 
Great Plains Energy                                        
Assets                                        
Derivative instruments (a)
 $9.4  $(0.9) $0.9  $5.3  $4.1  $8.9  $(0.6) $0.6  $5.2  $3.7 
Nuclear decommissioning trust (b)
  83.1   -   55.7   27.2   0.2   126.5   -   94.4   32.1   - 
SERP rabbi trust (b)
  7.1   -   0.2   6.9   - 
SERP rabbi trust (c)
  7.2   -   0.2   7.0   - 
Total  99.6   (0.9)  56.8   39.4   4.3   142.6   (0.6)  95.2   44.3   3.7 
Liabilities                                        
Derivative instruments (a)
  0.8   (1.8)  1.6   1.0   -   20.8   (3.1)  3.1   20.8   - 
Total $0.8  $(1.8) $1.6  $1.0  $-  $20.8  $(3.1) $3.1  $20.8  $- 
                                        



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        Fair Value Measurements Using 
Description 
December 31
2009
 
Netting(d)
  
Quoted Prices in Active Markets for Identical Assets
(Level 1)
  
Significant Other Observable Inputs
(Level 2)
  
Significant Unobservable Inputs
(Level 3)
 
KCP&L (millions) 
Assets               
Derivative instruments (a)
 $0.2  $(0.2) $0.2  $0.2  $- 
Nuclear decommissioning trust (b)
                    
Equity securities  44.5   -   44.5   -   - 
Debt securities                    
U.S. Treasury  11.2   -   11.2   -   - 
U.S. Agency  3.5   -   -   3.5   - 
State and local obligations  3.1   -   -   2.9   0.2 
Corporate bonds  18.9   -   -   18.9   - 
Foreign governments  0.7   -   -   0.7   - 
Other  1.2   -   -   1.2   - 
Total nuclear decommissioning trust  83.1   -   55.7   27.2   0.2 
Total  83.3   (0.2)  55.9   27.4   0.2 
Liabilities                    
Derivative instruments (a)
  -   (0.2)  -   0.2   - 
Total $-  $(0.2) $-  $0.2  $- 
Other Great Plains Energy                    
Assets                    
Derivative instruments (a)
 $9.2  $(0.7) $0.7  $5.1  $4.1 
SERP rabbi trust (c)
                    
Equity securities  0.2   -   0.2   -   - 
Debt securities  6.9   -   -   6.9   - 
Total SERP rabbi trust  7.1   -   0.2   6.9   - 
Total  16.3   (0.7)  0.9   12.0   4.1 
Liabilities                    
Derivative instruments (a)
  0.8   (1.6)  1.6   0.8   - 
Total $0.8  $(1.6) $1.6  $0.8  $- 
Great Plains Energy                    
Assets                    
Derivative instruments (a)
 $9.4  $(0.9) $0.9  $5.3  $4.1 
Nuclear decommissioning trust (b)
  83.1   -   55.7   27.2   0.2 
SERP rabbi trust (c)
  7.1   -   0.2   6.9   - 
Total  99.6   (0.9)  56.8   39.4   4.3 
Liabilities                    
Derivative instruments (a)
  0.8   (1.8)  1.6   1.0   - 
Total $0.8  $(1.8) $1.6  $1.0  $- 
                     
(a)  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.
(b)  Fair value is based on quoted market prices of the investments held by the fund and/or valuation models.  The total does not include $2.7 million and $29.4 million at December 31, 2010 and 2009, respectively, of cash and cash equivalents, which are not subject to the fair value requirements.
 
121125
 
 
         Fair Value Measurements Using 
           
Description
 December 31
2008
 
Netting(c)
  
Quoted Prices in Active Markets for Identical Assets
(Level 1)
  
Significant Other Observable Inputs
(Level 2)
  
Significant Unobservable Inputs
(Level 3)
 
KCP&L (millions) 
Assets               
Derivative instruments (a)
 $0.6  $-  $-  $0.6  $- 
Nuclear decommissioning trust (b)
  95.2   -   52.9   35.5   6.8 
Total  95.8   -   52.9   36.1   6.8 
Liabilities                    
Derivative instruments (a)
  80.3   -   -   80.3   - 
Total $80.3  $-  $-  $80.3  $- 
Other Great Plains Energy                    
Assets                    
Derivative instruments (a)
 $17.2  $(0.7) $3.2  $10.9  $3.8 
SERP rabbi trust (b)
  6.7   -   0.2   6.5   - 
Total  23.9   (0.7)  3.4   17.4   3.8 
Liabilities                    
Derivative instruments (a)
  5.9   (11.4)  10.1   7.2   - 
Total $5.9  $(11.4) $10.1  $7.2  $- 
Great Plains Energy                    
Assets                    
Derivative instruments (a)
 $17.8  $(0.7) $3.2  $11.5  $3.8 
Nuclear decommissioning trust (b)
  95.2   -   52.9   35.5   6.8 
SERP rabbi trust (b)
  6.7   -   0.2   6.5   - 
Total  119.7   (0.7)  56.3   53.5   10.6 
Liabilities                    
Derivative instruments (a)
  86.2   (11.4)  10.1   87.5   - 
Total $86.2  $(11.4) $10.1  $87.5  $- 
                      
(a)The fair value of derivative instruments is estimated using market quotes, over-the-counter forward priced and volatility curves and
 correlation among fuel prices, net of estimated credit risk.
(b)Fair value is based on quoted market prices of the investments held by the fund and/or valuation models.  The total does not include
 $29.4 million and $1.7 million at December 31, 2009 and 2008, respectively, of cash and cash equivalents, which are not subject to
 the fair value requirements.
(c)Represents the difference between derivative contracts in an asset or liability position presented on a net basis by counterparty on
 the consolidated balance sheet where a master netting agreement exists between the Company and the counterparty.
 At December 31, 2009 and 2008, Great Plains Energy netted $0.9 million and $10.7 million, respectively, of cash
 collateral posted with counterparties.
(c)  Fair value is based on quoted market prices of the investments held by the fund and/or valuation models.  The total does not include $14.6 million and $16.2 million at December 31, 2010 and 2009, respectively, of cash and cash equivalents, which are not subject to the fair value requirements.
(d)  Represents the difference between derivative contracts in an asset or liability position presented on a net basis by counterparty on the consolidated balance sheet where a master netting agreement exists between the Company and the counterparty.  At December 31, 2010 and 2009, Great Plains Energy netted $2.5 million and $0.9 million, respectively, of cash collateral posted with counterparties.
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The following tables reconcile the beginning and ending balances for all level 3 assets and liabilities, net measured at fair value on a recurring basis for 20092010 and 2008.2009.
                   
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
              Other    
              Great  Great
              Plains  Plains
  KCP&L  Energy  Energy
     Mortgage          
  U.S.  State & Local Backed     Derivative    
Description Agency  Obligations Securities  Total  Instruments  Total
  (millions) 
Balance January 1, 2009 $3.9  $-  $2.9  $6.8  $3.8  $10.6 
Total realized/unrealized gains or (losses)                       
Included in regulatory liability  -   -   1.1   1.1   -   1.1 
Included in non-operating income  -   -   -   -   1.2   1.2 
Purchases, issuances and settlements  (3.9)  -   (4.0)  (7.9)  (0.9)  (8.8)
Transfers in and/or out of Level 3  -   0.2   -   0.2   -   0.2 
Balance December 31, 2009 $-  $0.2  $-  $0.2  $4.1  $4.3 
                         
Total unrealized gains and (losses) included in non-operating                  
income relating to assets and liabilities still on the                    
consolidated balance sheet at December 31, 2009$-  $-  $-  $-  $0.8  $0.8 
                         
          
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)       
     Other  
     Great Great
     Plains Plains
  KCP&L Energy Energy
  State & Local Derivative  
  Obligations Instruments Total
  (millions)
Balance January 1, 2010 $0.2  $4.1  $4.3 
Total realized/unrealized gains or (losses)            
Included in non-operating income  -   (12.5)  (12.5)
Sales  (0.2)  -   (0.2)
Settlements  -   12.1   12.1 
Balance December 31, 2010 $-  $3.7  $3.7 
             
Total unrealized gains and (losses) included in non-operating            
 income relating to assets and liabilities still on the            
consolidated balance sheet at December 31, 2010 $-  $0.1  $0.1 
             



          
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
     Other   
     Great Great
    Plains Plains
  KCP&L Energy Energy
 Nuclear     
 DecommissioningDerivative   
DescriptionTrustInstruments Total
  (millions) 
Balance January 1, 2008 $6.5  $22.4  $28.9 
GMO acquisition July 14, 2008  -   6.6   6.6 
Total realized/unrealized gains or (losses)            
Included in regulatory liability  (1.0)  -   (1.0)
Included in non-operating income  -   (1.8)  (1.8)
Purchase, issuances, and settlements  (2.5)  (1.0)  (3.5)
Transfers in and/or out of Level 3  3.8   (16.4)  (12.6)
Discontinued operations  -   (6.0)  (6.0)
Balance December 31, 2008 $6.8  $3.8  $10.6 
             
Total unrealized gains and (losses) included in non-operating            
income relating to assets and liabilities still on the            
consolidated balance sheet at December 31, 2008 $-  $(2.3) $(2.3)
             
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On January 1, 2009,

 
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
              Other  
              Great Great
              Plains Plains
  KCP&L  Energy Energy
     Mortgage       
  U.S. State & Local Backed    Derivative  
Description Agency Obligations Securities Total  Instruments Total
  (millions)
Balance January 1, 2009 $3.9  $-  $2.9  $6.8  $3.8  $10.6 
Total realized/unrealized gains or (losses)                        
Included in regulatory liability  -   -   1.1   1.1   -   1.1 
Included in non-operating income  -   -   -   -   1.2   1.2 
Purchase, issuances, and settlements  (3.9)  -   (4.0)  (7.9)  (0.9)  (8.8)
Transfers in and/or out of Level 3  -   0.2   -   0.2   -   0.2 
Balance December 31, 2009 $-  $0.2  $-  $0.2  $4.1  $4.3 
                         
Total unrealized gains and (losses) included in non-operating                 
income relating to assets and liabilities still                        
on the consolidated balance sheet at December 31, 2009$-  $-  $-  $-  $0.8  $0.8 
                         
Investments in Affordable Housing Limited Partnerships
Nearly all of Great Plains Energy’s investments in affordable housing limited partnerships were recorded at cost; the equity method was used for the remainder.  Accounting guidance requires entities to evaluate whether an event or change in circumstances has occurred that may have a significant adverse effect on the fair value of the investment (an impairment indicator).  During 2010, an impairment indicator occurred, which required Great Plains Energy to evaluate if its cost method investments in affordable housing limited partnerships were impaired.  The value of these investments is derived from tax credits and KCP&L adoptedpotential cash distributions from the fair value measurementpartnerships upon sales of the underlying properties.  All of the tax credits have been received and disclosure requirements for nonfinancial assetsmanagement does not anticipate receiving any cash distributions from the partnership; therefore, management concluded that the investments were impaired and liabilities measured at fair value on a nonrecurring basis, such as AROs, reporting units and long-lived asset groups measured at fair value forthat the impairment testing, nonfinancial assets and liabilities measured at fair value in a business combination and not measured at fair value in subsequent periods.  
123
Management evaluatedwas other than temporary since the impact of adoption to those nonfinancial assets and liabilities and determined there was no significant impact on Great Plains Energy's and KCP&L's fair value measurement processes.
In April 2009, the Financial Accounting Standards Board (FASB) issued additional guidance for estimating fair value when the volume and level of activity for the asset or liability have significantly decreased and guidance on identifying circumstances that indicate a transaction is not orderly that became effectivepartnerships are in the second quarterprocess of 2009 forliquidating over the next 2 – 3 years.  As a result of the evaluation, management concluded that the cost method investments have no value and accordingly, Great Plains Energy and KCP&L.  Management determined there was no significant impactrecorded an $11.2 million pre-tax impairment loss in non-operating expense on Great Plains Energy's and KCP&L's fair value measurement processes.the consolidated income statement.
 
In August 2009, the FASB issued additional guidance to clarify the principles on fair value measurement of liabilities.  Management determined there was no significant impact on Great Plains Energy's and KCP&L's fair value measurement processes upon adoption in the fourth quarter of 2009.
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22.21.  TAXES
 
Components of income tax expense are detailed in the following tables.
                  
Great Plains Energy 2009  2008  2007  2010 2009 2008
Current income taxes (millions)  (millions)
Federal $(11.1) $(21.0) $44.3  $(7.4) $(11.1) $(21.0)
State  (0.9)  1.1   6.5   (4.3)  (0.9)  1.1 
Foreign  1.3   -   -   0.1   1.3   - 
Total  (10.7)  (19.9)  50.8   (11.6)  (10.7)  (19.9)
Deferred income taxes                        
Federal  (13.6)  3.3   22.5   99.8   (13.6)  3.3 
State  10.0   40.8   1.3   24.0   10.0   40.8 
Total  (3.6)  44.1   23.8   123.8   (3.6)  44.1 
Noncurrent income taxes                        
Federal  8.3   (0.6)  (0.7)  (4.8)  8.3   (0.6)
State  1.1   (1.0)  (0.9)  (1.8)  1.1   (1.0)
Foreign  (1.5)  -   -   0.5   (1.5)  - 
Total  7.9   (1.6)  (1.6)  (6.1)  7.9   (1.6)
Investment tax credit                        
Deferral  37.2   74.2   -   (4.2)  37.2   74.2 
Amortization  (2.2)  (1.8)  (1.5)  (2.9)  (2.2)  (1.8)
Total  35.0   72.4   (1.5)  (7.1)  35.0   72.4 
Total income tax expense  28.6   95.0   71.5   99.0   28.6   95.0 
Less: taxes on discontinued operations                        
Current tax expense  (1.1)  25.8   5.4   -   (1.1)  25.8 
Deferred tax expense  0.2   4.5   21.4   -   0.2   4.5 
Noncurrent income tax expense (benefit)  -   0.9   (0.2)
Noncurrent income tax expense  -   -   0.9 
Income tax expense on continuing operations $29.5  $63.8  $44.9  $99.0  $29.5  $63.8 
                        
          
KCP&L 2010 2009 2008
Current income taxes (millions)
Federal $5.5  $41.2  $(8.0)
State  1.1   4.8   4.5 
Total  6.6   46.0   (3.5)
Deferred income taxes            
Federal  69.8   (41.7)  (38.4)
State  13.4   3.5   30.9 
Total  83.2   (38.2)  (7.5)
Noncurrent income taxes            
Federal  (1.6)  3.4   (1.7)
State  (0.3)  (0.1)  (0.3)
Total  (1.9)  3.3   (2.0)
Investment tax credit            
Deferral  (4.2)  37.2   74.2 
Amortization  (2.1)  (1.4)  (1.4)
Total  (6.3)  35.8   72.8 
Total $81.6  $46.9  $59.8 
             


 
124128
 
          
KCP&L 2009  2008  2007 
Current income taxes (millions) 
Federal $41.2  $(8.0) $38.7 
State  4.8   4.5   4.4 
Total  46.0   (3.5)  43.1 
Deferred income taxes            
Federal  (41.7)  (38.4)  17.7 
State  3.5   30.9   2.0 
Total  (38.2)  (7.5)  19.7 
Noncurrent income taxes            
Federal  3.4   (1.7)  (1.7)
State  (0.1)  (0.3)  (0.3)
Total  3.3   (2.0)  (2.0)
Investment tax credit            
Deferral  37.2   74.2   - 
Amortization  (1.4)  (1.4)  (1.5)
Total  35.8   72.8   (1.5)
Total $46.9  $59.8  $59.3 
             
Income Tax Expense and Effective Income Tax Rates
Income tax expense and the effective income tax rates reflected in continuing operations in the financial statements and the reasons for their differences from the statutory federal rates are detailed in the following tables.
 Income Tax Expense  Income Tax Rate Income Tax Expense Income Tax Rate
Great Plains Energy 2009 2008 2007 2009 2008 2007 2010 2009 2008 2010 2009 2008
 (millions)           (millions)         
Federal statutory income taxFederal statutory income tax$63.4  $64.2  $58.0   35.0%  35.0%  35.0% $108.7  $63.4  $64.2   35.0%  35.0%  35.0%
Differences between book and taxDifferences between book and tax                                               
depreciation not normalizeddepreciation not normalized (9.9)  (5.4)  2.0   (5.5)  (2.9)  1.2   (5.2)  (9.9)  (5.4)  (1.7)  (5.5)  (2.9)
Amortization of investment tax creditsAmortization of investment tax credits (2.2)  (1.8)  (1.5)  (1.2)  (1.0)  (0.9)  (2.9)  (2.2)  (1.8)  (0.9)  (1.2)  (1.0)
Federal income tax creditsFederal income tax credits (8.0)  (10.2)  (7.9)  (4.4)  (5.6)  (4.8)  (12.5)  (8.0)  (10.2)  (4.1)  (4.4)  (5.6)
State income taxesState income taxes 7.9   3.2   (0.1)  4.4   1.8   (0.1)  11.4   7.9   3.2   3.7   4.4   1.8 
Rate change on deferred taxesRate change on deferred taxes -   19.3   -   -   10.5   -   -   -   19.3   -   -   10.5 
Medicare Part D subsidy legislation  2.8   -   -   0.9   -   - 
Changes in uncertain tax positions, netChanges in uncertain tax positions, net (72.1)  0.1   0.6   (39.8)  0.1   0.3   0.3   (72.1)  0.1   0.1   (39.8)  0.1 
GMO transaction costsGMO transaction costs -   (1.9)  (3.7)  -   (1.0)  (2.2)  -   -   (1.9)  -   -   (1.0)
Valuation allowanceValuation allowance 55.8   -   -   30.8   -   -   (2.7)  55.8   -   (0.9)  30.8   - 
OtherOther (5.4)  (3.7)  (2.5)  (3.0)  (2.1)  (1.5)  (0.9)  (5.4)  (3.7)  (0.3)  (3.0)  (2.1)
TotalTotal$29.5  $63.8  $44.9   16.3%  34.8%  27.0% $99.0  $29.5  $63.8   31.8%  16.3%  34.8%
                                                

 
  Income Tax Expense Income Tax Rate
KCP&L 2010 2009 2008 2010 2009 2008
  (millions)          
Federal statutory income tax $85.7  $61.5  $64.7   35.0%  35.0%  35.0%
Differences between book and tax                        
depreciation not normalized  (4.5)  (7.7)  (5.2)  (1.8)  (4.4)  (2.8)
Amortization of investment tax credits  (2.1)  (1.4)  (1.4)  (0.9)  (0.8)  (0.8)
Federal income tax credits  (8.5)  (7.8)  (9.8)  (3.5)  (4.4)  (5.3)
State income taxes  8.9   5.8   3.8   3.6   3.3   2.1 
Medicare Part D subsidy legislation  2.8   -   -   1.1   -   - 
Changes in uncertain tax positions, net  -   (0.5)  (0.6)  -   (0.3)  (0.3)
Parent company tax benefits (a)
  -   -   (6.7)  -   -   (3.6)
Rate change on deferred taxes  -   -   20.3   -   -   11.0 
Other  (0.7)  (3.0)  (5.3)  (0.2)  (1.7)  (3.0)
Total $81.6  $46.9  $59.8   33.3%  26.7%  32.3%
(a) The tax sharing between Great Plains Energy and its subsidiaries was modified on July 14, 2008.  As part of the new
     agreement, parent company tax benefits are no longer allocated to KCP&L or other subsidiaries.
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  Income Tax Expense  Income Tax Rate 
KCP&L 2009  2008  2007  2009  2008  2007 
  (millions)          
Federal statutory income tax$61.5  $64.7  $75.6   35.0%  35.0%  35.0%
Differences between book and tax                       
depreciation not normalized (7.7)  (5.2)  2.0   (4.4)  (2.8)  0.9 
Amortization of investment tax credits (1.4)  (1.4)  (1.5)  (0.8)  (0.8)  (0.7)
Federal income tax credits (7.8)  (9.8)  (6.4)  (4.4)  (5.3)  (2.9)
State income taxes 5.8   3.8   4.7   3.3   2.1   2.2 
Changes in uncertain tax positions, net (0.5)  (0.6)  (0.3)  (0.3)  (0.3)  (0.1)
Parent company tax benefits (a)
 -   (6.7)  (12.0)  -   (3.6)  (5.6)
Rate change on deferred taxes -   20.3   -   -   11.0   - 
Other (3.0)  (5.3)  (2.8)  (1.7)  (3.0)  (1.4)
Total$46.9  $59.8  $59.3   26.7%  32.3%  27.4%
(a) The tax sharing between Great Plains Energy and its subsidiaries was modified on July 14, 2008.  As part of the new
    agreement, parent company tax benefits are no longer allocated to KCP&L or other subsidiaries.

Great Plains Energy and KCP&L are required to adjust deferred tax assets and liabilities to reflect tax rates that are anticipated to be in effect when timing differences reverse.  Due to the 2008 sale of Strategic Energy, L.L.C. (Strategic Energy), the composite tax rate for the companies was expected to increase as a result of the change in composition of states that Great Plains Energy conducts business.  Therefore, deferred tax assets and liabilities were adjusted in 2008 to reflect the expected increase in the composite tax rate.  The impact of the increase in the composite tax rate on deferred tax assets and liabilities resulted in tax expense for Great Plains Energy and KCP&L of $19.3 million and $20.3 million, respectively, at December 31, 2008.
 
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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  Great Plains Energy KCP&L
December 31 2009  2008  2009  2008  2010 2009 2010 2009
Current deferred income taxes (millions)  (millions)
Net operating loss carryforward $30.4  $26.2  $-  $-  $-  $30.4  $-  $- 
Other  7.8   5.9   0.3   4.9   14.7   7.8   5.6   0.3 
Net current deferred income tax asset before                                
valuation allowance  38.2   32.1   0.3   4.9   14.7   38.2   5.6   0.3 
Valuation allowance  (1.4)  (3.5)  -   -   (0.4)  (1.4)  -   - 
Net current deferred income tax asset  36.8   28.6   0.3   4.9   14.3   36.8   5.6   0.3 
Noncurrent deferred income taxes                                
Plant related  (854.7)  (775.2)  (631.0)  (599.3)  (975.5)  (854.7)  (711.5)  (631.0)
Income taxes on future regulatory recoveries  (104.5)  (122.5)  (77.6)  (71.6)  (142.6)  (104.5)  (117.2)  (77.6)
Derivative instruments  39.3   44.1   37.4   40.0   46.0   39.3   34.4   37.4 
Pension and postretirement benefits  (4.5)  (6.9)  6.5   (9.9)  (16.3)  (4.5)  2.0   6.5 
SO2 emission allowance sales
  30.3   32.4   34.5   34.6   30.8   30.3   33.4   34.5 
Fuel clause adjustments  (17.6)  (20.4)  0.2   (0.6)  (16.6)  (17.6)  (3.2)  0.2 
Transition costs  (19.9)  (18.2)  (11.4)  (11.4)  (20.0)  (19.9)  (11.4)  (11.4)
Tax credit carryforwards  202.4   140.3   97.6   36.4   204.3   202.4   101.5   97.6 
Long-term debt fair value adjustment  32.5   45.3   -   -   19.2   32.5   -   - 
Capital loss carryforwards  -   49.7   -   - 
Customer demand programs  (23.3)  (16.5)  (17.3)  (13.8)
Net operating loss carryforward  361.3   315.2   0.6   -   409.2   361.3   1.1   0.6 
Other  (18.1)  1.4   (16.2)  (14.4)  (7.3)  (1.6)  (3.8)  (2.4)
Net noncurrent deferred tax liability before                                
valuation allowance  (353.5)  (314.8)  (559.4)  (596.2)  (492.1)  (353.5)  (692.0)  (559.4)
Valuation allowance  (28.4)  (72.3)  -   -   (26.2)  (28.4)  -   - 
Net noncurrent deferred tax liability  (381.9)  (387.1)  (559.4)  (596.2)  (518.3)  (381.9)  (692.0)  (559.4)
Net deferred income tax liability $(345.1) $(358.5) $(559.1) $(591.3) $(504.0) $(345.1) $(686.4) $(559.1)
                                
 Great Plains Energy  KCP&L  Great Plains Energy KCP&L
December 31 2009  2008  2009  2008  2010 2009 2010 2009
 (millions)  (millions)
Gross deferred income tax assets $1,126.4  $955.9  $597.9  $460.3  $1,140.7  $1,126.4  $602.4  $597.9 
Gross deferred income tax liabilities  (1,471.5)  (1,314.4)  (1,157.0)  (1,051.6)  (1,644.7)  (1,471.5)  (1,288.8)  (1,157.0)
Net deferred income tax liability $(345.1) $(358.5) $(559.1) $(591.3) $(504.0) $(345.1) $(686.4) $(559.1)
                          
Tax Credit Carryforwards
At December 31, 20092010 and 2008,2009, Great Plains Energy had $102.6 million and $98.7 million, respectively, of federal general business income tax credit carryforwards.  At December 31, 2010 and $37.32009, KCP&L had $101.5 million and $97.6 million, respectively, of federal general business income tax credit carryforwards.  The carryforwards relate primarily to Advanced Coal Investment Tax Creditsfor both Great Plains Energy and Wind Production tax credits and expire in years 2021 to 2029.  At December 31, 2009 and 2008, KCP&L had $97.6 million and $36.4 million, respectively, of federal general business income tax credit carryforwards.  The carryforwards relate primarily to Advanced Coal Investment Tax Credits and Wind Production tax credits and expire in years 2028 to 2029.2030.  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 these credits to expire unutilized and has provided a valuation allowance against $0.5$0.4 million of the federal income tax benefit.
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At December 31, 20092010 and 2008,2009, Great Plains Energy had $87.6$90.0 million and $87.4$87.6 million, respectively, of federal alternative minimum tax credit carryforwards.  Of this amount, $87.0$89.8 million was acquired in the GMO acquisition.  These credits do not expire and can be used to reduce taxes paid in the future.
 
At December 31, 20092010 and 2008,2009, Great Plains Energy had $16.2$11.8 million and $15.9$16.2 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 years 20102011 to 2013.2015.  Management expects that a portion of these credits will expire unutilized and has provided a valuation allowance against $0.6 million of the state income tax benefit.
 
Advanced Coal Credit
In April 2008, KCP&L was notified that its application filed in 2007 for $125.0 million in advanced coal investment tax credits (ITC) was approved by the IRS.  The credit is based on the amount of expenses incurred on the construction of Iatan No. 2.  Additionally, in order to meet the advanced clean coal standards and avoid forfeiture and/or the recapture of tax credits in the future, KCP&L must meet or exceed certain environmental performance standards for at least five years once the plant is placed in service.
 
In September 2010, the IRS issued an amended memorandum of understanding to reallocate $17.7 million of the original $125 million of the advanced coal project credits to Empire, meeting the requirements of an arbitration order issued on December 30, 2009.  See Note 16 for the related legal proceeding.  As a result, Great Plains Energy and KCP&L recognized deferred federal tax benefitsreduced the amount of $37.2 million in 2009 and $29.2 million of current and $45.0 millionadvanced coal credit previously recognized.  The amount of deferred federal tax benefitsexpense associated with the reduction in 2008.  However,2010, was $4.2 million.  Since the tax laws require KCP&L to reduce income tax expense for ratemaking and financial statement purposes ratably over the life of the plant.  Therefore,plant, Great Plains Energy and KCP&L concurrently recognized a separate deferred advanced coal ITC expensebenefit to offset the current and deferred federal tax benefit.expense.  Great Plains Energy and KCP&L recognized $0.7 million of ITC in 2010 after the plant was placed in service and will continue to recognize the tax benefits over the life of the plant.  At December 31, 2009,2010, Great Plains Energy and KCP&L had $111.4$106.6 million of deferred advanced coal ITC.  Great Plains Energy and KCP&L will recognize the tax benefits of the ITC over the life of the plant once it is placed in service.  See Note 17 for a related legal proceeding.
Capital Loss Carryforwards
At December 31, 2008, Great Plains Energy had approximately $49.7 million of tax benefits related to capital loss carryforwards that were acquired in the GMO acquisition.  These capital losses were treated as ordinary losses on filed income tax returns.  The tax benefits from the ordinary losses on the returns as filed were included in unrecognized tax benefits for net operating loss carryforwards at December 31, 2008.  In March 2009, the Joint Committee on Taxation approved the settlement of the IRS audit of GMO’s 2003-2004 tax years and the entire amount of unrecognized tax benefits from the net operating loss carryforwards was recognized and the tax benefits from capital loss carryforwards were reduced to zero.
 
Net Operating Loss Carryforwards
At December 31, 20092010 and 2008,2009, Great Plains Energy had $337.5$353.0 million and $295.2$337.5 million, respectively, of tax benefits related to federal net operating loss (NOL) carryforwards.  Approximately $320.5$317.5 million and $295.2$320.5 million, at December 31, 20092010 and 2008,2009, respectively, are tax benefits related to NOLs that were acquired in the GMO acquisition.  The tax benefits for NOLs originating in 2003 are $37.1$34.4 million, $152.4 million originating in 2004, $74.5$74.1 million originating in 2005, $53.1$53.3 million originating in 2006, $1.4$1.3 million originating in 2007, $2.6$2.5 million originating in 2008, and $16.4$26.9 million originating in 2009.2009 and $8.1 million originating in 2010.  The federal NOL carryforwards expire in years 2023 to 2029.  Management expects that a portion of these credits will expire unutilized and has provided a valuation allowance against $2.7 million of these NOL carryforward federal income tax benefits.2030.
 
In addition, Great Plains Energy also had deferred tax benefits of $54.2$56.2 million and $46.2$54.2 million related to state net operating lossesNOLs as of December 31, 20092010 and 2008,2009, respectively.  Approximately $49.9$49.4 million and $44.8$49.9 million at December 31, 20092010 and 2008,2009, respectively, were acquired in the GMO acquisition.  Management does not expect to utilize $26.0$25.7 million of NOLs in state tax jurisdictions where the companyCompany does not expect to operate in the future.  Therefore, a valuation allowance has been provided against $26.0$25.7 million of state tax benefits.
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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 federal and state tax NOL carryforwards, and tax credit carryforwards.
 
During 2010 and 2009, $3.2 million of tax benefit and 2008, $6.5 million and $0.9 million, respectively, of tax expense, respectively, on continuing operations was recorded and primarily relates to a portion of the valuation allowance against federal and state
131
NOL carryforwards.  The remaining valuation allowances against federal and state NOL carryforwards and tax credit carryforwards were acquired in the GMO acquisition and were recorded as a part of the purchase accounting entries impacting goodwill.
 
Uncertain Tax Positions
At December 31, 20092010 and 2008,2009, Great Plains Energy had $51.4$42.0 million and $97.3$51.4 million, respectively, of liabilities related to unrecognized tax benefits.  Of these amounts, $17.3 million at December 31, 2010 and 2009, and $80.2 million at December 31, 2008, areis expected to impact the effective tax rate if recognized.  The $9.4 million decrease in unrecognized tax benefits is primarily due to a decrease of $8.6 million of unrecognized tax benefits related to the sale of certain GMO property during 2010.
At December 31, 2008, Great Plains Energy had $97.3 million of liabilities related to unrecognized tax benefits of which $80.2 million is expected to impact the effective rate if recognized.  The $45.9 million decrease in unrecognized tax benefits isin 2009 was primarily due to a decrease of unrecognized tax benefits of $74.5 million related to the Joint Committee on Taxation approval of the IRS audit for GMO’s 2003-2004 tax years, offset by an increase of $11.3 million of unrecognized tax benefits related to prior year tax positions taken on GMO tax returns, and a $20.5 million increase of unrecognized tax benefits related to Great Plains Energy consolidated 2008 and 2009 tax years.  The tax benefits recognized related to the GMO 2003-2004 IRS audit were also offset by an increase in valuation allowance for federal and state NOLsnet operating losses of $56.0 million and a reduction in deferred income tax assets of $2.5 million, which resulted in an increase to net income of $16.0 million.  At December 31, 2007, Great Plains Energy had $21.9 million of liabilitiesin 2009 related to unrecognized tax benefits of which $3.6 million is expected to impact the effective tax rate if recognized.2003-2004 IRS audit.
 
At December 31, 20092010 and 2008,2009, KCP&L had $20.9 million$19.1 and $17.6$20.9 million, respectively, of liabilities related to unrecognized tax benefits.  Of these amounts, $0.3 million at December 31, 2010, and $0.4 million at December 31, 2009, and $1.2 million at December 31, 2008, are expected to impact the effective tax rate if recognized.  The $3.3$1.8 million increasedecrease in unrecognized tax benefits is primarily due to a $6.9 million increase of unrecognized tax benefits related to the 2008 and 2009 tax years offset by a $2.1$2.6 million decrease as a result of the settlements of the IRS audit for the Great Plains Energy consolidated 20042005 tax year.  At December 31, 2007,2008, KCP&L had $19.6$17.6 million of liabilities related to unrecognized tax benefits of which $1.3$1.1 million is expected to impact the effective tax rate if recognized.
 
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 
  2009  2008  2007  2009  2008  2007 
  (millions) 
Balance at January 1$97.3  $21.9  $23.5  $17.6  $19.6  $21.6 
Additions for current year tax positions 13.2   5.3   4.1   3.9   3.8   2.9 
Additions for prior year tax positions 8.2   2.6   0.1   3.0   2.6   0.1 
Additions for GMO prior year tax positions 11.6   77.0   -   -   -   - 
Reductions for prior year tax positions (1.3)  (0.8)  (5.0)  (0.8)  (0.7)  (4.9)
Settlements (76.7)  (8.5)  -   (2.2)  (7.5)  - 
Statute expirations (0.7)  (0.2)  (0.8)  (0.6)  (0.2)  (0.1)
Foreign currency translation adjustments (0.2)  -   -   -   -   - 
Balance at December 31 $51.4  $97.3  $21.9  $20.9  $17.6  $19.6 
                         
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 Great Plains Energy KCP&L
 2010 2009 2008 2010 2009 2008
 (millions)
Balance at January 1$51.4  $97.3  $21.9  $20.9  $17.6  $19.6 
Additions for current year tax positions 2.7   13.2   5.3   1.3   3.9   3.8 
Additions for prior year tax positions 2.1   8.2   2.6   1.5   3.0   2.6 
Additions for GMO prior year tax positions -   11.6   77.0   -   -   - 
Reductions for prior year tax positions (10.6)  (1.3)  (0.8)  (1.6)  (0.8)  (0.7)
Settlements (3.8)  (76.7)  (8.5)  (2.9)  (2.2)  (7.5)
Statute expirations (0.3)  (0.7)  (0.2)  (0.1)  (0.6)  (0.2)
Foreign currency translation adjustments 0.5   (0.2)  -   -   -   - 
Balance at December 31$42.0  $51.4  $97.3  $19.1  $20.9  $17.6 
 
Great Plains Energy and KCP&L recognize interest accrued related to unrecognized tax benefits in interest expense and penalties in non-operating expenses.  At December 31, 2010, 2009 and 2008, accrued interest related to unrecognized tax benefits for Great Plains Energy was $6.7 million, $5.9 million and $2.6 million, respectively.  Amounts accrued for penalties with respect to unrecognized tax benefits was $1.1 million at December 31, 2010 and 2009.  ForIn 2010 and 2009, Great Plains Energy recognized an increase of $0.5 million and $1.4 million, respectively, of interest expense related to unrecognized tax benefits.  The remaining increase in accrued interest
132
and the penalties of $1.1 million were primarily associated with prior year GMO tax return positions identified and recorded to goodwill.  In 2008, Great Plains Energy recognized a reduction of $6.6 million of interest expense and in 2007 recognized an increase in interest expense of $2.0$6.6 million.
 
KCP&L had accrued interest related to unrecognized tax benefits of $1.4 million at December 31, 2010 and $1.7 million at December 31, 2009 and 2008.  Amounts accrued for penalties with respect to unrecognized tax benefits for KCP&L are insignificant.  In 2010, KCP&L recognized a reduction of $0.3 million of interest expense.  In 2008, KCP&L recognized a reduction of $1.7 million of interest expense and in 2007 recognized an increase in interest expense of $1.0 million.expense.
 
The IRS is currently auditing Great Plains Energy and its subsidiaries for the 2005-20082006-2008 tax years and the Company is protesting an audit assessment by the Canada Revenue Authority (CRA) against a former GMO subsidiary for the 2002 tax year.  The Company estimates that it is reasonably possible that $5.2$18.2 million for Great Plains Energy and $4.9$12.2 million for KCP&L of unrecognized tax benefits may be recognized in the next twelve months due to statute expirations or settlement agreements with tax authorities.
 
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.  The Company also files separate company returns in Canada and certain other states.  
 
23.22.  SEGMENTS AND RELATED INFORMATION
 
Great Plains Energy
Great Plains Energy has one reportable segment based on its method of internal reporting, which generally segregates reportable segments based on products and services, management responsibility and regulation.  The one reportable business segment is electric utility, consisting of KCP&L and GMO’s regulated utility operations.  Other includes GMO activity other than its regulated utility operations, Services, KLT Inc. (including Strategic Energy discontinued operations),operations, unallocated corporate charges, consolidating entries and intercompany eliminations.  Intercompany eliminations include insignificant amounts of intercompany financing-related activities.  The summary of significant accounting policies applies to the reportable segment.  For segment reporting, the segment’s income taxes include the effects of allocating holding company tax benefits prior to July 14, 2008.  GMO is only included for periods subsequent to the July 14, 2008, date of acquisition.  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.
 Electric   Great Plains Electric   Great Plains
2009 Utility Other Energy
2010 Utility Other Energy
 (millions)  (millions)
Operating revenues $1,965.0  $-  $1,965.0   $2,255.5  $-  $2,255.5 
Depreciation and amortization  (302.2)  -   (302.2)   (331.6)  -   (331.6)
Interest charges  (151.0)  (29.9)  (180.9)   (143.1)  (41.7)  (184.8)
Income tax benefit (expense)  (63.6)  34.1   (29.5) 
Income tax (expense) benefit  (123.3)  24.3   (99.0)
Loss from equity investments  -   (0.4)  (0.4)   -   (1.0)  (1.0)
Discontinued operations  -   (1.5)  (1.5) 
Net income attributable to Great Plains Energy  157.8   (7.7)  150.1  
Net income (loss) attributable to Great Plains Energy  235.3   (23.6)  211.7 
            



 
130133
 

 Electric   Great Plains Electric   Great Plains
2008 Utility Other Energy
2009 Utility Other Energy
 (millions)  (millions)
Operating revenues $1,670.1  $-  $1,670.1   $1,965.0  $-  $1,965.0 
Depreciation and amortization  (235.0)  -  (235.0)   (302.2)  -   (302.2)
Interest charges  (96.9)  (14.4) (111.3)   (151.0)  (29.9)  (180.9)
Income tax benefit (expense)  (70.9)  7.1  (63.8) 
Income tax (expense) benefit  (63.6)  34.1   (29.5)
Loss from equity investments  -   (1.3) (1.3)   -   (0.4)  (0.4)
Discontinued operations  -   35.0  35.0    -   (1.5)  (1.5)
Net income attributable to Great Plains Energy  143.1   11.4  154.5  
Net income (loss) attributable to Great Plains Energy  157.8   (7.7)  150.1 
 
 
  Electric   Great Plains
2008 Utility Other Energy
  (millions)
Operating revenues $1,670.1  $-  $1,670.1 
Depreciation and amortization  (235.0)  -   (235.0)
Interest charges  (96.9)  (14.4)  (111.3)
Income tax (expense) benefit  (70.9)  7.1   (63.8)
Loss from equity investments  -   (1.3)  (1.3)
Discontinued operations  -   35.0   35.0 
Net income attributable to Great Plains Energy  143.1   11.4   154.5 
             

             
  
Electric
Utility
      Great Plains
  Other EliminationsEnergy
2010 (millions) 
Assets $9,152.7  $66.3  $(400.8) $8,818.2 
Capital expenditures  618.1   -   -   618.1 
2009                
Assets $8,765.3  $152.5  $(435.0) $8,482.8 
Capital expenditures  841.3   -   -   841.3 
2008                
Assets $8,161.9  $141.7  $(434.3) $7,869.3 
Capital expenditures (a)
  1,023.7   1.2   -   1,024.9 
                 
(a) Includes capital expenditures from discontinued operations of $0.8 million.
 
  Electric   Great Plains
2007 Utility Other Energy
  (millions) 
Operating revenues $1,292.7  $-  $1,292.7  
Depreciation and amortization  (175.6)  -  (175.6) 
Interest charges  (67.2)  (24.7) (91.9) 
Income tax benefit (expense)  (59.3)  14.4  (44.9) 
Loss from equity investments  -   (2.0) (2.0) 
Discontinued operations  -   38.3  38.3  
Net income attributable to Great Plains Energy  156.8   2.4  159.2  
 
             
  
Electric
Utility
      Great Plains
  Other EliminationsEnergy
2009 (millions) 
Assets $8,765.3  $152.5  $(435.0) $8,482.8 
Capital expenditures  841.3   -   -   841.3 
2008                
Assets $8,161.9  $141.7  $(434.3) $7,869.3 
Capital expenditures (a)
  1,023.7   1.2   -   1,024.9 
2007                
Assets (b)
 $4,290.7  $551.2  $(9.8) $4,832.1 
Capital expenditures (a)
  511.5   4.4   -   515.9 
                 
(a) Includes capital expenditures from discontinued operations of $0.8 million and $3.7 million for
    2008 and 2007, respectively.
(b) Other includes assets of discontinued operations.
131
KCP&L
For 2009 and 2008, KCP&L has one reportable segment, KCP&L, which is the same as the KCP&L registrant financial statements for 2009 and 2008.  The following table reflects summarized financial information concerning KCP&L’s reportable segment for 2007.  For the periods prior to the January 2, 2008, transfer of Home Service Solutions Inc., (HSS) to KLT Inc., other included HSS and intercompany eliminations.  Intercompany eliminations include insignificant amounts of intercompany financing-related activities.
 
        Consolidated
2007 KCP&L Other KCP&L
  (millions) 
Operating revenues $1,292.7  $-  $1,292.7 
Depreciation and amortization  (175.6)  -   (175.6)
Interest charges  (67.2)  -   (67.2)
Income taxes  (59.3)  -   (59.3)
Net income (loss)  156.8   (0.1)  156.7 
             
24.23.  DISCONTINUED OPERATIONS
 
On June 2, 2008, Great Plains Energy completed the sale of Strategic Energy to Direct Energy Services, LLC (Direct Energy), a subsidiary of Centrica plc.  Great Plains Energy received gross cash proceeds of $307.7 million, including the base purchase price of $300.0 million, plus a working capital adjustment of $7.7 million.  Strategic Energy is reported as discontinued operations for the periods presented.

Under the terms of the purchase agreement with Direct Energy, Great Plains Energy indemnifiesindemnified Direct Energy for various matters, including: breaches of representations, warranties and covenants; funds advanced by Strategic Energy to certain of its channel partners if such funds became uncollectible before December 2, 2009, (approximately $8 million, excluding commission offsets); and losses associated with litigation and other certain claims to the extent such losses exceed $7.5 million in the aggregate.
 
134
At December 31, 2008, Great Plains Energy had reserved $2.0 million with respect to the indemnification obligations.  In 2009, Great Plains Energy reducedsubsequently reversed this reserve by $1.4 million.reserve.  Additionally, during 2009, Great Plains Energy recorded $3.8 million of gross receipts taxes for periods prior to the sale for which Great Plains Energy indemnified Direct Energy.  The following table summarizes the income (loss) from Strategic Energy’s discontinued operations.
      
 2009  2008  2007  2009 2008
 (millions)  (millions)
Revenues $-  $667.4  $1,974.4  $-  $667.4 
                    
Income from operations before income taxes (a)
 $-  $182.4  $64.9  $-  $182.4 
Loss on disposal before income taxes  (2.4)  (116.2)  -   (2.4)  (116.2)
Total income (loss) on discontinued operations                    
before income taxes  (2.4)  66.2   64.9   (2.4)  66.2 
Income tax benefit (expense)  0.9   (31.2)  (26.6)  0.9   (31.2)
Income (loss) from discontinued operations,                    
net of income taxes $(1.5) $35.0  $38.3  $(1.5) $35.0 
(a) For 2008, amount includes $189.1 millon of unrealized net gains related to derivative instruments. 
(a) For 2008, amount includes $189.1 millon of unrealized net gains related to derivative(a) For 2008, amount includes $189.1 millon of unrealized net gains related to derivative 
instruments.        
132
25.24.  JOINTLY OWNED ELECTRIC UTILITY PLANTS
 
Great Plains Energy’s and KCP&L’s share of jointly owned electric utility plants at December 31, 2009,2010, are detailed in the following tables.
 
Great Plains EnergyGreat Plains Energy            Great Plains Energy
 Wolf Creek LaCygne Iatan No. 1 Iatan No. 2 Iatan Jeffrey Wolf Creek LaCygne Iatan No. 1 Iatan No. 2 Iatan Jeffrey
 Unit Units Unit Unit Common Energy Center Unit Units Unit Unit Common Energy Center
 (millions, except MW amounts)  (millions, except MW amounts)
Great Plains Energy's shareGreat Plains Energy's share47% 50% 88% 73% 79% 8%   47%  50%  88%  73%  79%  8%
                                     
Utility plant in serviceUtility plant in service $    1,412.5  $       407.5  $       637.3  $             -  $       243.5  $       151.6  $1,423.7  $410.5  $638.9  $1,282.4  $326.8  $151.1 
Accumulated depreciationAccumulated depreciation          752.8           285.0           221.2                 -               2.6             73.7   778.2   298.0   239.9   58.9   16.1   74.8 
Nuclear fuel, netNuclear fuel, net            68.2                 -                 -                 -                 -                 -   79.2   -   -   -   -   - 
Construction work in progressConstruction work in progress            44.4             19.1               5.9        1,115.3             83.5               4.4   75.3   48.1   23.4   8.0   23.3   6.4 
2010 accredited capacity-MWs             545              709              621               NA               NA              173 
2011 accredited capacity-MWs  560   709   621   618  NA   173 
                                     

KCP&L
  Wolf Creek LaCygne Iatan No. 1 Iatan No. 2 Iatan
  Unit Units Unit Unit Common
  (millions, except MW amounts)
KCP&L's share  47%  50%  70%  55%  61%
                     
Utility plant in service $1,423.7  $410.5  $514.1  $973.0  $255.0 
Accumulated depreciation  778.2   298.0   196.3   56.4   13.9 
Nuclear fuel, net  79.2   -   -   -   - 
Construction work in progress  75.3   48.1   14.5   7.1   14.4 
2011 accredited capacity-MWs  560   709   494   465  NA 
                     


KCP&L         
  Wolf Creek LaCygne Iatan No. 1 Iatan No. 2 Iatan
  Unit Units Unit Unit Common
  (millions, except MW amounts)
KCP&L's share47% 50% 70% 55% 61%
           
Utility plant in service $    1,412.5  $       407.5  $       513.2  $             -  $       189.0
Accumulated depreciation          752.8           285.0           179.1                 -               1.9
Nuclear fuel, net            68.2                 -                 -                 -                 -
Construction work in progress            44.4             19.1               4.6           835.0             64.9
2010 accredited capacity-MWs             545              709              494              NA               NA
           
135
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 is included in the appropriate operating expense classifications in Great Plains Energy’s and KCP&L’s financial statements.
 
26.  NEW ACCOUNTING STANDARDS
In June 2009, the FASB issued two amendments to existing GAAP, one of which amends previous derecognition guidance and eliminates the concept of a qualifying special-purpose entity (QSPEs).  The second amends previous consolidation guidance applicable to variable interest entities (VIEs) requiring companies to reconsider previous conclusions, including whether an entity is a VIE, whether the Company is the VIE’s primary beneficiary and what type of financial statement disclosures are required.  The provisions of these amendments are effective for Great Plains Energy and KCP&L for financial asset transfers occurring after January 1, 2010, and requires transferors to evaluate all existing QSPEs and all VIEs to determine whether they must be consolidated effective January 1, 2010, in accordance with the amended consolidation guidance.  As a result of the derecognition guidance amendments, beginning January 1, 2010, the sale of an undivided percentage ownership in accounts receivable by Receivables Company to an outside investor under the revolving agreement will no longer meet the criteria for derecognition and will be accounted for as a secured borrowing.  Therefore, beginning January 1, 2010, $95 million of trade receivables will be recorded with a corresponding short-term secured liability on Great Plains Energy’s and KCP&L’s balance sheets.  There will be no impact to results of operations and no impact is expected to any debt covenant agreements as a result of this accounting change.  Management is continuing to evaluate the impact of this new guidance but does not anticipate it will have any other significant impacts to Great Plains Energy’s or KCP&L’s financial position.
133
In June 2009, the FASB issued the FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles (Codification) as the exclusive authoritative reference for U.S. GAAP to be applied by nongovernmental entities.  The Codification changes the referencing of accounting standards and is effective for interim and annual reporting periods ending after September 15, 2009.  There was no impact on Great Plains Energy’s and KCP&L’s consolidated financial statements upon adoption of the Codification other than referencing accounting standards.
27.25.  QUARTERLY OPERATING RESULTS (UNAUDITED)
                        
 Quarter  Quarter
Great Plains Energy 1st 2nd 3rd 4th 1st 2nd 3rd 4th
2010 (millions, except per share amounts)
Operating revenue $506.9  $552.0  $728.8  $467.8 
Operating income  62.0   134.9   243.8   31.6 
Net income (loss)  20.3   64.4   132.0   (4.8)
Net income (loss) attributable to Great Plains Energy  20.3   64.3   132.0   (4.9)
Basic earnings (loss) per common share  0.15   0.47   0.97   (0.04)
Diluted earnings (loss) per common share  0.15   0.47   0.96   (0.04)
2009 (millions, except per share amounts)    
Operating revenue $419.2  $480.5  $587.7  $477.6  $419.2  $480.5  $587.7  $477.6 
Operating income  20.9   90.3   151.2   57.7   20.9   90.3   151.2   57.7 
Income from continuing operations  21.7   36.9   78.4   14.9   21.7   36.9   78.4   14.9 
Net income  21.7   33.8   79.2   15.7   21.7   33.8   79.2   15.7 
Net income attributable to Great Plains Energy  21.7   33.7   79.1   15.6   21.7   33.7   79.1   15.6 
Basic and diluted earnings per common share from                                
continuing operations  0.18   0.28   0.57   0.10   0.18   0.28   0.57   0.10 
Basic and diluted earnings per common share  0.18   0.26   0.58   0.11   0.18   0.26   0.58   0.11 
2008   
Operating revenue $297.6  $335.0  $593.6  $443.9 
Operating income  19.1   51.6   169.6   34.7 
Income (loss) from continuing operations  (5.4)  13.2   104.7   7.2 
Net income (loss)  47.5   (5.0)  105.0   7.2 
Net income (loss) attributable to Great Plains Energy  47.5   (5.0)  105.0   7.0 
Basic and diluted earnings (loss) per common share from                
continuing operations  (0.07)  0.15   0.92   0.06 
Basic and diluted earnings (loss) per common share  0.55   (0.06)  0.92   0.06 
                                

 
  Quarter
KCP&L 1st 2nd 3rd 4th
2010 (millions)
Operating revenue $335.6  $372.6  $486.5  $322.4 
Operating income  40.5   84.7   163.6   22.6 
Net income  19.2   48.2   92.6   3.2 
2009                
Operating revenue $277.5  $324.8  $395.5  $320.4 
Operating income  14.9   68.2   105.9   43.2 
Net income  8.4   34.9   65.6   20.0 
                 
        
  Quarter 
KCP&L 1st 2nd 3rd 4th
2009 (millions) 
Operating revenue $277.5  $324.8  $395.5  $320.4 
Operating income  14.9   68.2   105.9   43.2 
Net income  8.4   34.9   65.6   20.0 
2008                
Operating revenue $297.6  $335.0  $423.7  $286.7 
Operating income  29.4   52.5   127.9   28.3 
Net income  17.0   7.9   83.9   16.4 
                 
Quarterly data is subject to seasonal fluctuations with peak periods occurring in the summer months.  In the third and fourth quarters of 2010, Great Plains Energy recorded a $4.0 million and $12.8 million, respectively, pre-tax loss for KCP&L’s and GMO’s combined share of certain Iatan construction costs.  See Note 6 for additional information.  In the fourth quarter of 2010, Great Plains Energy recorded an $11.2 million pre-tax impairment loss related to its investments in affordable housing limited partnerships.  See Note 20 for additional information.


134136

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders of
Great Plains Energy Incorporated
Kansas City, Missouri
 
We have audited the accompanying consolidated balance sheets of Great Plains Energy Incorporated and subsidiaries (the "Company") as of December 31, 20092010 and 2008,2009, and the related consolidated statements of income, comprehensive income, common shareholders' equity and noncontrolling interest, and cash flows for each of the three years in the period ended December 31, 2009.2010. Our audits also included the financial statement schedules listed in the Index at Item 15. These financial statements and financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion on the financial statements and financial statement schedules based on our audits.
 
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
 
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of the CompanyGreat Plains Energy Incorporated and subsidiaries as of December 31, 20092010 and 2008,2009, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2009,2010, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company's internal control over financial reporting as of December 31, 2009,2010, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 25, 201024, 2011 expressed an unqualified opinion on the Company's internal control over financial reporting.
 
/s/DELOITTE & TOUCHE LLP
 
Kansas City, Missouri
February 25, 201024, 2011

 
135137
 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors of
Kansas City Power & Light Company
Kansas City, Missouri
 
We have audited the accompanying consolidated balance sheets of Kansas City Power & Light Company and subsidiaries (the "Company") as of December 31, 20092010 and 2008,2009, and the related consolidated statements of income, comprehensive income, common shareholder’s equity, and cash flows for each of the three years in the period ended December 31, 2009.2010. Our audits also included the financial statement schedulesschedule listed in the Index at Item 15. These financial statements and financial statement schedulesschedule are the responsibility of the Company's management. Our responsibility is to express an opinion on the financial statements and financial statement schedulesschedule based on our audits.
 
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
 
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of theKansas City Power & Light Company and subsidiaries as of December 31, 20092010 and 2008,2009, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2009,2010, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedules,schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presentpresents fairly, in all material respects, the information set forth therein.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company's internal control over financial reporting as of December 31, 2009,2010, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 25, 201024, 2011 expressed an unqualified opinion on the Company's internal control over financial reporting.
 
/s/DELOITTE & TOUCHE LLP
 
Kansas City, Missouri
February 25, 201024, 2011




 
136138
 
ITEM 9. CHANGES AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
 
None.
 
ITEM 9A.  CONTROLS AND PROCEDURES
 
GREAT PLAINS ENERGY

Disclosure Controls and Procedures
Great Plains Energy carried out evaluationsan evaluation of its disclosure controls and procedures (as defined in Rules 13a-15(e) or 15d-15(e) under the Securities Exchange Act of 1934, as amended)amended (the “Exchange Act”).  These evaluations wereThis evaluation was conducted under the supervision, and with the participation, of Great Plains Energy’s management, including the chief executive officer and chief financial officer, and Great Plains Energy’s disclosure committee.  Based upon these evaluations,this evaluation, the chief executive officer and chief financial officer of Great Plains Energy have concluded as of the end of the period covered by this report that the disclosure controls and procedures of Great Plains Energy were effective at a reasonable assurance level.
 
Changes in Internal Control Over Financial Reporting
There has been no change in Great Plains Energy’s internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) of the Exchange Act) that occurred during the quarterly period ended December 31, 2009,2010, that has materially affected, or is reasonably likely to materially affect, its internal control over financial reporting.
 
Management’s Report on Internal Control Over Financial Reporting
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis.  Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.  Also, projections of any evaluation of the effectiveness of internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
Management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended)Act) for Great Plains Energy.  Under the supervision and with the participation of Great Plains Energy’s chief executive officer and chief financial officer, management evaluated the effectiveness of Great Plains Energy’s internal control over financial reporting as of December 31, 2009.2010.  Management used for this evaluation the framework in Internal Control – Integrated Framework issued by the Committee of Sponsoring Organizations (COSO) of the Treadway Commission.

Management has concluded that, as of December 31, 2009,2010, Great Plains Energy’s internal control over financial reporting is effective based on the criteria set forth in the COSO framework.  Deloitte & Touche LLP, the independent registered public accounting firm that audited the financial statements included in this annual report on Form 10-K, has issued its attestation report on Great Plain’sPlains Energy’s internal control over financial reporting, which is included below.
 

139
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
To the Board of Directors and Shareholders of
Great Plains Energy Incorporated
Kansas City, Missouri
137
We have audited the internal control over financial reporting of Great Plains Energy Incorporated and subsidiaries (the "Company") as of December 31, 2009,2010, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit.
 
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
 
A company's internal control over financial reporting is a process designed by, or under the supervision of, the company's principal executive and principal financial officers, or persons performing similar functions, and effected by the company's board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
 
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2009,2010, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.
 

140

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements and financial statement schedules as of and for the year ended December 31, 2009,2010, of the Company and our report dated February 25, 201024, 2011 expressed an unqualified opinion on those financial statements and financial statement schedules.
 
/s/DELOITTE & TOUCHE LLP
 
Kansas City, Missouri
February 25, 201024, 2011
138
KCP&L
 
Disclosure Controls and Procedures
KCP&L carried out evaluationsan evaluation of its disclosure controls and procedures (as defined in Rules 13a-15(e) or 15d-15(e) under the Securities Exchange Act of 1934, as amended)Act).  These evaluations wereThis evaluation was conducted under the supervision, and with the participation, of KCP&L’s management, including the chief executive officer and chief financial officer, and KCP&L’s disclosure committee.  Based upon these evaluations,this evaluation, the chief executive officer and chief financial officer of KCP&L have concluded as of the end of the period covered by this report that the disclosure controls and procedures of KCP&L were effective at a reasonable assurance level.
 
Changes in Internal Control Over Financial Reporting
There has been no change in KCP&L’s internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) of the Exchange Act) that occurred during the quarterly period ended December 31, 2009,2010, that has materially affected, or is reasonably likely to materially affect, its internal control over financial reporting.
 
Management’s Report on Internal Control Over Financial Reporting
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis.  Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.  Also, projections of any evaluation of the effectiveness of internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
Management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended)Act) for KCP&L.  Under the supervision and with the participation of KCP&L’s chief executive officer and chief financial officer, management evaluated the effectiveness of KCP&L’s internal control over financial reporting as of December 31, 2009.2010.  Management used for this evaluation the framework in Internal Control – Integrated Framework issued by the COSO of the Treadway Commission.
 
Management has concluded that, as of December 31, 2009,2010, KCP&L’s internal control over financial reporting is effective based on the criteria set forth in the COSO framework.  Deloitte & Touche LLP, the independent registered public accounting firm that audited the financial statements included in this annual report on Form 10-K, has issued its attestation report on KCP&L’s internal control over financial reporting, which is included below.
 

141
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
To the Board of Directors of
Kansas City Power & Light Company
Kansas City, Missouri
 
We have audited the internal control over financial reporting of Kansas City Power & Light Company and subsidiaries (the "Company") as of December 31, 2009,2010, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit.
 
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit
139
included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
 
A company's internal control over financial reporting is a process designed by, or under the supervision of, the company's principal executive and principal financial officers, or persons performing similar functions, and effected by the company's board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
 
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2009,2010, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.
 

142

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements and financial statement schedulesschedule as of and for the year ended December 31, 2009,2010, of the Company and our report dated February 25, 201024, 2011 expressed an unqualified opinion on those financial statements and financial statement schedules.schedule.
 
/s/DELOITTE & TOUCHE LLP
 
Kansas City, Missouri
February 25, 201024, 2011
 
ITEM 9B.  OTHER INFORMATION
 
None.Extension of Accounts Receivable Facility
The following information is provided in this Annual Report in lieu of reporting such information under Item 1.01, Entry into a Material Definitive Agreement, of Form 8-K.
 
KCP&L, Receivables Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch (Agent) and Victory Receivables Corporation (Purchaser) are parties to a certain Receivables Sale Agreement, dated as of July 1, 2005, as previously amended (as amended, the “RSA”). Pursuant to the RSA and associated agreements, KCP&L sells all of its retail electric accounts receivable to its wholly owned subsidiary, Receivables Company, which in turn sells an undivided percentage ownership interest in the accounts receivable to the Purchaser.  On February 23, 2011, the parties entered into an amendment to the RSA, extending the termination date of the RSA from May 4, 2011 to October 31, 2011.
The Agent and an affiliate are lenders under revolving credit agreements with Great Plains Energy, KCP&L and GMO aggregating to $1.25 billion.  An affiliate of the Agent is trustee under indentures associated with all of GMO’s long-term debt.  The Agent and certain of its affiliates have provided, and in the future may continue to provide, investment banking, commercial banking and/or other financial services, including the provision of credit facilities, to Great Plains Energy, KCP&L and/or their affiliates in the ordinary course of business for which they have received and may in the future receive customary compensation.
PART III
 
ITEM 10.  DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
 
Great Plains Energy Directors
The information required by this item is incorporated by reference from the Great Plains Energy 20102011 Proxy Statement (Proxy Statement), which will be filed with the SEC no later than April 30, 2010:2011:

·  Information regarding the directors of Great Plains Energy required by this item is contained in the Proxy Statement section titled “Election of Directors.”
140
·  Information regarding compliance with Section 16(a) of the Securities Exchange Act of 1934 required by this item is contained in the Proxy Statement section titled “Security Ownership of Certain Beneficial Owners, Directors and Officers - Section 16(a) Beneficial Ownership Reporting Compliance.”
 
·  Information regarding the Audit Committee of Great Plains Energy required by this item is contained in the Proxy Statement section titled “Corporate Governance – Committees of the Board.”
 
Great Plains Energy and KCP&L Executive Officers
Information required by this item regarding the executive officers of Great Plains Energy and KCP&L is contained in this report in the Part I, Item 1 sectionssection titled “Executive Officers.”
 
143
Great Plains Energy and KCP&L Code of Ethical Business Conduct
The Company has adopted a Code of Ethical Business Conduct (Code), which applies to all directors, officers and employees of Great Plains Energy, KCP&L and their subsidiaries.  The Code is posted on the corporate governance page of the Internet websites at www.greatplainsenergy.com and www.kcpl.com.  A copy of the Code is available, without charge, upon written request to Corporate Secretary, Great Plains Energy Incorporated, 1200 Main St., Kansas City, Missouri 64105.  Great Plains Energy and KCP&L intend to satisfy the disclosure requirements under Item 5.05 of Form 8-K regarding an amendment to, or a waiver from, a provision of the Code that applies to the principal executive officer, principal financial officer, principal accounting officer or controller of those companies by posting such information on the corporate governance page of the Internet websites.
 
Other KCP&L Information
The other information required by this item regarding KCP&L has been omitted in reliance on General Instruction (I).
 
ITEM 11.  EXECUTIVE COMPENSATION
 
Great Plains Energy
The information required by this item contained in the sections titled “Executive Compensation,” “Director Compensation,” “Compensation Discussion and Analysis”, “Compensation Committee Report” and “Director Independence – Compensation Committee Interlocks and Insider Participation” of the Proxy Statement is incorporated by reference.
 
KCP&L
The information required by this item regarding KCP&L has been omitted in reliance on General Instruction (I).
 
ITEM 12.  SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
 
Great Plains Energy
The information required by this item regarding security ownership of the directors and executive officers of Great Plains Energy contained in the section titled “Security Ownership of Certain Beneficial Owners, Directors and Officers” of the Proxy Statement is incorporated by reference.
 
KCP&L
The information required by this item regarding KCP&L has been omitted in reliance on General Instruction (I).
 
Equity Compensation Plans
Great Plains Energy’s Long-Term Incentive Plan is an equity compensation plan approved by its shareholders.  The Long-Term Incentive Plan permits the grant of restricted stock, stock options, 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.
141

Effective with the July 14, 2008 acquisition of GMO, Great Plains Energy assumed GMO’s equity compensation plans.  Stock options outstanding under those plans at the time of acquisition were converted into Great Plains Energy stock options.  Great Plains Energy has not issued, and does not intend to issue, any new grants or awards under the assumed plans.
 
KCP&L does not have an equity compensation plan; however, KCP&L officers and certain employees participate in Great Plains Energy’s Long-Term Incentive Plan.  The GMO incentive plans that were assumed by Great Plains Energy upon the acquisition include stock options held by certain KCP&L employees that were issued prior to the acquisition.
 

144
The following table provides information, as of December 31, 2009,2010, regarding the number of common shares to be issued upon exercise of outstanding options, warrants and rights, their weighted average exercise price, and the number of shares of common stock remaining available for future issuance.  The table excludes shares issued or issuable under Great Plains Energy’s defined contribution savings plans.
                         
          Number of securities          Number of securities
          remaining available          remaining available
 Number of securities    for future issuance Number of securities    for future issuance
 to be issued uponWeighted-average  under equity to be issued uponWeighted-averageunder equity
 exercise ofexercise price of  compensation plans exercise ofexercise price ofcompensation plans
 outstanding options,outstanding options,  (excluding securities outstanding options,outstanding options,(excluding securities
 warrants and rightswarrants and rights  reflected in column (a)) warrants and rightswarrants and rightsreflected in column (a))
Plan CategoryPlan Category (a) (b)  (c)Plan Category (a)(b)(c)
Equity compensation plans approved by security holdersEquity compensation plans approved by security holders         Equity compensation plans approved by security holders          
Great Plains Energy Long-Term Incentive Plan      404,107(1)   $    25.57
 (2)
       2,971,125 Great Plains Energy Long-Term Incentive Plan        531,449(1)   $    25.58 (2)       2,742,120 
GMO incentive plans (stock options)      156,587          43.00           161,376 GMO incentive plans (stock options)        138,179          35.54           142,968 
Equity compensation plans not approved by           
security holders                  -          -                       - 
(1)Total      560,694    $    36.73
 (2)
       3,132,501 
Equity compensation plans not approved by security holdersEquity compensation plans not approved by security holders                  -                -                       - 
Total        669,628    $    32.51 (2)       2,885,088 
(1)Includes 294,641 performance shares at target performance levels, options for 88,023 shares of Great Plains Energy commonIncludes 431,784 performance shares at target performance levels, options for 60,602 shares of Great Plains Energy common
stock and director deferred share units for 21,443 shares of Great Plains Energy common stock outstanding at December 31, 2009.stock and director deferred share units for 39,063 shares of Great Plains Energy common stock outstanding at December 31, 2010.
(2)The 294,641 performance shares and director deferred share units for 21,443 shares of Great Plains Energy common stock haveThe 431,784 performance shares and director deferred share units for 39,063 shares of Great Plains Energy common stock have
no exercise price and therefore are not reflected in the weighted average exercise price.no exercise price and therefore are not reflected in the weighted average exercise price.
 
ITEM 13.  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
 
Great Plains Energy
The information required by this item contained in the section titled “Director Independence” and “Related Party Transactions” of the Proxy Statement is incorporated by reference.
 
KCP&L
The information required by this item regarding KCP&L has been omitted in reliance on General Instruction (I).
 
ITEM 14.  PRINCIPAL ACCOUNTING FEES AND SERVICES
 
GREAT PLAINS ENERGYGreat Plains Energy
The information required by this item regarding the independent auditors of Great Plains Energy and its subsidiaries contained in the section titled “Ratification of Appointment of Independent Auditors” of the Proxy Statement is incorporated by reference.

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KCP&L
The Audit Committee of the Great Plains Energy Board functions as the Audit Committee of KCP&L.  The following table sets forth the aggregate fees billed by Deloitte & Touche LLP for audit services rendered in connection with the consolidated financial statements and reports for 20092010 and 20082009 and for other services rendered during 20092010 and 20082009 on behalf of KCP&L, as well as all out-of-pocket costs incurred in connection with these services:
 
Fee Category 2009  2008  2010 2009
Audit Fees $1,082,677  $1,086,087  $1,098,722  $1,082,677 
Audit-Related Fees  88,744   97,372   104,169   88,744 
Tax Fees  141,472   32,561   112,058   141,472 
All Other Fees  -   -   -   - 
Total Fees $1,312,893  $1,216,020  $1,314,949  $1,312,893 

Audit Fees:  Consists of fees billed for professional services rendered for the audits of the annual consolidated financial statements of KCP&L and reviews of the interim condensed consolidated financial statements included in quarterly reports.  Audit fees also include: services provided by Deloitte & Touche LLP in connection with statutory and regulatory filings or engagements; audit reports on audits of the effectiveness of internal control over financial reporting and on management’s assessment of the effectiveness of internal control over financial reporting and other attest services, except those not required by statute or regulation; services related to filings with the SEC, including comfort letters, consents and assistance with and review of documents filed with the SEC; and accounting research in support of the audit.
 
Audit-Related Fees:  Consists of fees billed for assurance and related services that are reasonably related to the performance of the audit or review of consolidated financial statements of KCP&L and are not reported under “Audit Fees”.  These services include consultation concerning financial accounting and reporting standards.
 
Tax Fees:  Consists of fees billed for tax compliance and related support of tax returns and other tax services, including assistance with tax audits, and tax research and planning.
 
All Other Fees:  Consists of fees for all other services other than those described above.
 
Audit Committee Pre-Approval of Audit and Permissible Non-Audit Services of Independent Auditors
The Audit Committee pre-approves all audit and permissible non-audit services provided by the independent registered public accounting firm to KCP&L.  These services may include audit services, audit-related services, tax services and other services.  The Audit Committee has adopted for KCP&L policies and procedures for the pre-approval of services provided by the independent registered public accounting firm.  Under these policies and procedures, the Audit Committee may pre-approve certain types of services, up to aggregate fee levels established by the Audit Committee.  Any proposed service within a pre-approved type of service that would cause the applicable fee level to be exceeded cannot be provided unless the Audit Committee either amends the applicable fee level or specifically approves the proposed service.  Pre-approval is generally provided for up to one year, unless the Audit Committee specifically provides for a different period.  The Audit Committee receives reports at each regular meeting regarding the pre-approved services performed by the independent auditor.  The Chairman of the Audit Committee may between meetings pre-approve audit and non-audit services provided by the independent auditor, and report such pre-approval at the next Audit Committee meeting.

 
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PART IV
 
ITEM 15.   EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

Financial Statements
 
 
Great Plains Energy
 
Page No.
a.
Consolidated Statements of Income for the years ended December 31, 2010, 2009 2008 and 20072008
53         54
b.
Consolidated Balance Sheets - December 31, 20092010 and 20082009
 
54         55
c.
Consolidated Statements of Cash Flows for the years ended December 31, 2010, 2009 2008 and 20072008
56         57
d.
Consolidated Statements of Common Shareholders’ Equity and Noncontrolling Interest for the years ended December 31, 2010, 2009 2008 and 20072008
57         58
e.
Consolidated Statements of Comprehensive Income for the years ended December 31, 2010, 2009 2008 and 20072008
58         59
f.
Notes to Consolidated Financial Statements
65         66
g.
Report of Independent Registered Public Accounting Firm
135       137
   
KCP&L
 
 
h.
Consolidated Statements of Income for the years ended December 31, 2010, 2009 2008 and 20072008
 
59         60      
i.
Consolidated Balance Sheets - December 31, 20092010 and 20082009
60         61
j.
Consolidated Statements of Cash Flows for the years ended December 31, 2010, 2009 2008 and 20072008
62         63
k.
Consolidated Statements of Common Shareholder’s Equity for the years ended December 31, 2010, 2009 2008 and 20072008
63         64
l.
Consolidated Statements of Comprehensive Income for the years ended December 31, 2010, 2009 2008 and 20072008
64         65
m.
Notes to Consolidated Financial Statements
65         66
n.
Report of Independent Registered Public Accounting Firm
136138
   
Financial Statement Schedules
 
 Great Plains Energy 
a.
Schedule I – Parent Company Financial Statements
156         161
b.
Schedule II – Valuation and Qualifying Accounts and Reserves
159
         164
 KCP&L 
c.Schedule II – Valuation and Qualifying Accounts and Reserves160         165

 
144147
 
Exhibits
 
Great Plains Energy Documents
 
Exhibit
Number
 Description of Document
Registrant
2.1.12.1*
Agreement and Plan of Merger among Aquila, Inc., Great Plains Energy Incorporated, Gregory Acquisition Corp., and Black Hills Corporation dated as of February 6, 2007 (Exhibit 2.1 to Form 8-K filed on February 8, 2007).
 
Great Plains Energy
2.1.22.2*
Mutual Notice of Extension among Aquila, Inc., Great Plains Energy Incorporated, Gregory Acquisition Corp., and Black Hills Corporation dated as of January 31, 2008 (Exhibit 2.1.2 to Form 10-K for the year ended December 31, 2007).
 
Great Plains Energy
2.1.32.3*
Mutual Notice of Extension among Aquila, Inc., Great Plains Energy Incorporated, Gregory Acquisition Corp., and Black Hills Corporation dated as of April 29, 2008 (Exhibit 10.1 to Form 8-K filed on April 30, 2008).
 
Great Plains Energy
3.1.13.1*
Articles of Incorporation of Great Plains Energy Incorporated, as amended effective May 7, 2009 (Exhibit 3.1.1 to Form 10-Q for the quarter ended March 31, 2009).
 
Great Plains Energy
3.1.23.2*
By-laws of Great Plains Energy Incorporated, as amended December 2, 2008May 4, 2010 (Exhibit 3.1 to Form 8-K filed on December 8,May 5, 2010).
Great Plains Energy
3.3
Restated Articles of Incorporation of Kansas City Power & Light Company, restated as of October 26, 2010.
KCP&L
3.4*
By-laws of Kansas City Power & Light Company, as amended April 1, 2008 (Exhibit 3.2 to Form 8-K filed on April 7, 2008).
 
KCP&L
4.1.14.1*
Indenture, dated June 1, 2004, between Great Plains Energy Incorporated and BNY Midwest Trust Company, as Trustee (Exhibit 4.54.4 to Form 8-A/A filed on June 14, 2004).
 
Great Plains Energy
4.1.24.2*
First Supplemental Indenture, dated June 14, 2004, between Great Plains Energy Incorporated and BNY Midwest Trust Company, as Trustee (Exhibit 4.5 to Form 8-A/A filed on June 14, 2004).
 
Great Plains Energy
4.1.34.3*
Second Supplemental Indenture dated as of September 25, 2007, between Great Plains Energy Incorporated and The Bank of New York Trust Company, N.A., as trustee (Exhibit 4.1 to Form 8-K filed on September 26, 2007).
 
Great Plains Energy
4.1.44.4*
Third Supplemental Indenture dated as of August 13, 2010 between Great Plains Energy Incorporated and The Bank of New York Mellon Trust Company, N.A., as trustee (Exhibit 4.1 to Form 8-K filed on August 13, 2010).
Great Plains Energy
4.5*Subordinated Indenture dated as of May 18, 2009 between Great Plains Energy Incorporated and The Bank of New York Mellon Trust Company, N.A., as trustee (Exhibit 4.1 to Form 8-K filed on May 19, 2009).Great Plains Energy
148
4.1.54.6*
Supplemental Indenture No. 1 dated as of May 18, 2009 between Great Plains Energy Incorporated and The Bank of New York Mellon Trust Company, N.A., as trustee (Exhibit 4.2 to Form 8-K filed on May 19, 2009).
 
Great Plains Energy
4.1.64.7*
Purchase Contract and Pledge Agreement dated as of May 18, 2009 among Great Plains Energy Incorporated, The Bank of New York Mellon Trust Company, N.A., as purchase contract agent and The Bank of New York Mellon Trust Company, N.A., as collateral agent, custodial agent and securities intermediary (Exhibit 4.3 to Form 8-K filed on May 19, 2009).
 
Great Plains Energy
4.1.74.8*
Indenture, dated as of August 24, 2001, between Aquila, Inc. and BankOne Trust Company, N.A., as Trustee (Exhibit 4(d) to Registration Statement on Form S-3 (File No. 333-68400) filed by Aquila, Inc. on August 27, 2001).
 
Great Plains Energy
4.1.84.9*
Second Supplemental Indenture, dated as of July 3, 2002, between Aquila, Inc. and BankOne Trust Company, N.A., as Trustee related to 11.875% Senior Notes due July 1, 2012.2012 (Exhibit 4(c) to Form S-4 (File No. 333-100204) filed by Aquila, Inc. on September 30, 2002).
Great Plains Energy
4.10*
General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, n.a. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4-bb to Form 10-K for the year ended December 31, 1986).
Great Plains Energy  
KCP&L
4.11*
Fifth Supplemental Indenture dated as of September 15, 1992, to Indenture dated as of December 1, 1986 (Exhibit 4-a to Form 10-Q for the quarter ended September 30, 1992).
Great Plains Energy  
KCP&L
4.12*
Seventh Supplemental Indenture dated as of October 1, 1993, to Indenture dated as of December 1, 1986 (Exhibit 4-a to Form 10-Q for the quarter ended September 30, 1993).
Great Plains Energy  
KCP&L
4.13*
Eighth Supplemental Indenture dated as of December 1, 1993, to Indenture dated as of December 1, 1986 (Exhibit 4 to Registration Statement, Registration No. 33-51799).
Great Plains Energy  
KCP&L
4.14*
Eleventh Supplemental Indenture dated as of August 15, 2005, to the General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, N.A. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4.2 to Form 10-Q for the quarter ended September 30, 2005).
Great Plains Energy  
KCP&L
4.15*Twelfth Supplemental Indenture, dated as of March 1, 2009, to the General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, N.A. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4.2 to Form 8-K filed on March 24, 2009).
Great Plains Energy  
KCP&L

145149
10.1.14.16*
*Thirteenth Supplemental Indenture, dated as of March 1, 2009, to the General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, N.A. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4.3 to Form 8-K filed on March 24, 2009).
Great Plains Energy  
KCP&L
4.17*
Fourteenth Supplemental Indenture, dated as of March 1, 2009, to the General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, N.A. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4.4 to Form 8-K filed on March 24, 2009).
Great Plains Energy  
KCP&L
4.18*
Indenture dated as of December 1, 2000, between Kansas City Power & Light Company and The Bank of New York (Exhibit 4-a to Form 8-K filed on December 18, 2000).
Great Plains Energy  
KCP&L
4.19*
Term sheet for $150 million aggregate principal amount of 6.50% Senior Notes due November 15, 2011 (Exhibit 4-b to Form 8-K filed on November 19, 2001).
Great Plains Energy  
KCP&L
4.20*
Indenture dated March 1, 2002 between The Bank of New York and Kansas City Power & Light Company (Exhibit 4.1.b. to Form 10-Q for the quarter ended March 31, 2002).
Great Plains Energy  
KCP&L
4.21*
Supplemental Indenture No. 1 dated as of November 15, 2005, to Indenture dated March 1, 2002 between The Bank of New York and Kansas City Power & Light Company (Exhibit 4.2.j to Form 10-K for the year ended December 31, 2005).
Great Plains Energy  
KCP&L
4.22*
Indenture dated as of May 1, 2007, between Kansas City Power & Light Company and The Bank of New York Trust Company, N.A., as trustee (Exhibit 4.1 to Form 8-K filed on June 4, 2007).
Great Plains Energy  
KCP&L
4.23*
Supplemental Indenture No. 1 dated as of June 4, 2007 between Kansas City Power & Light Company and The Bank of New York Trust Company, N.A., as trustee (Exhibit 4.2 to Form 8-K filed on June 4, 2007).
Great Plains Energy  
KCP&L
4.24*
Supplemental Indenture No. 2 dated as of March 11, 2008, between Kansas City Power & Light Company and The Bank of New York Trust Company, N.A., as trustee (Exhibit 4.2 to Form 8-K filed on March 11, 2008).
Great Plains Energy  
KCP&L
10.1*+
Amended Long-Term Incentive Plan, effective as of May 7, 2002 (Exhibit 10.1.a to Form 10-K for the year ended December 31, 2002).
 
Great Plains Energy  
KCP&L
10.1.210.2
*
+
Great Plains Energy Incorporated Long-Term Incentive Plan as amended May 1, 2007 (Exhibit 10.1 to Form 8-K filed on May 4, 2007).
 
Great Plains Energy  
KCP&L
10.1.310.3
*
+
Great Plains Energy Incorporated Long-Term Incentive Plan Awards Standards and Performance Criteria Effective as of May 6, 2008 (Exhibit 10.1.25 to Form 10-Q for the quarter ended June 30, 2008).
Great Plains Energy
KCP&L
150
10.1.410.4
*
+
Great Plains Energy Incorporated Long-Term Incentive Plan awards Standards and Performance Criteria effective as of January 1, 2009 (Exhibit 10.1.6 to Form 10-Q for the quarter ended June 30, 2009).
 
Great Plains Energy
KCP&L
10.1.510.5*+
*Great Plains Energy Incorporated Long-Term Incentive Plan Awards Standards and Performance Criteria Effective as of January 1, 2010 (Exhibit 10.1.3 to Form 10-Q for the quarter ended March 31, 2010).
Great Plains Energy
KCP&L
10.6*+
Form of Restricted Stock Agreement Pursuant to the Great Plains Energy Incorporated Long-Term Incentive Plan Effective May 7, 2002 (Exhibit 10.1.6 to Form 10-K for the year ended December 31, 2006).
 
Great Plains Energy
KCP&L
10.1.610.7
*
+
Form of 2008 Restricted Stock Agreement (Exhibit 10.1.20 to Form 10-Q for the quarter ended June 30, 2008).
 
Great Plains Energy
KCP&L
10.1.710.8
*
+
Form of Restricted Stock Agreement between Great Plains Energy Incorporated and grantee dated May 5, 2009 (Exhibit 10.1.410.1.5 to Form 10-Q for the quarter ended June 30, 2009).
 
Great Plains Energy
KCP&L
10.1.810.9
*
+
Form of 2007 three-year Performance Share Agreement Pursuant to the Great Plains Energy Incorporated Long-Term Incentive Plan Effective May 7, 2002 for Great Plains Energy and KCP&L officers (Exhibit 10.1.10 to Form 10-K for the year ended December 31, 2006).
 
Great Plains Energy
KCP&L
10.1.9
10.10
*
+
Form of Amendment to Performance Share Agreement dated May 5, 2009, between Great Plains Energy Incorporated and grantee, amending Performance Share Agreement dated February 6, 2007 (Exhibit 10.1.2 to Form 10-Q for the quarter ended March 31, 2009).
 
Great Plains Energy
KCP&L
10.1.10
10.11
*
+
Form of 2008 three-year Performance Share Agreement (Exhibit 10.1.21 to Form 10-Q for the quarter ended June 30, 2008).
 
Great Plains Energy
KCP&L
10.1.11
10.12
*
+
Form of Amendment to Performance Share Agreement dated May 5, 2009, between Great Plains Energy Incorporated and grantee, amending Performance Share Agreement dated May 6, 2008 (Exhibit 10.1.3 to Form 10-Q for the quarter ended March 31, 2009).
 
Great Plains Energy
KCP&L
10.1.12
10.13
*
+
Form of Performance Share Agreement between Great Plains Energy Incorporated and grantee dated May 5, 2009 (Exhibit 10.1.4 to Form 10-Q for the quarter ended March 31, 2009).
 
Great Plains Energy
KCP&L
10.1.1310.14*+
Form of 2001 and 2002 Nonqualified Stock Option Agreement.Agreement (Exhibit 10.1.13 to Form 10-K for the year ended December 31, 2009).
 
Great Plains Energy
KCP&L
10.1.1410.15*+
Form of 2003 Nonqualified Stock Option Agreement.Agreement (Exhibit 10.1.14 to Form 10-K for the year ended December 31, 2009).
 
Great Plains Energy
KCP&L
10.1.15
10.16		*+
*
+
Form of Amendment to 2003 Stock OptionOption Grants (Exhibit 10.1.9 to Form 10-Q for the quarter ended September 30, 2007).
 
Great Plains Energy
KCP&L
10.1.1610.17*+Form of 2010 three-year Performance Share Agreement (Exhibit 10.1.1 to Form 10-Q for the quarter ended March 31, 2010).
*Great Plains Energy
KCP&L

151

10.18*+
Form of 2010 Restricted Stock Agreement (Exhibit 10.1.2 to Form 10-Q for the quarter ended March 31, 2010).
Great Plains Energy
KCP&L
10.19*+
Aquila, Inc. 2002 Omnibus Incentive Compensation Plan (Exhibit 10.3 to Form 10-Q for the quarter ended September 30, 2002, filed by Aquila, Inc.).
 
10.1.17
*
+
Great Plains Energy Incorporated Kansas City Power & Light Company Annual Incentive Plan amended effective as of January 1, 2007, and 2008 objectives adopted as of May 6, 2008 (Exhibit 10.1.22 to Form 10-Q for the quarter ended June 30, 2008). 
10.1.1810.20*+
*
+
Great Plains Energy Incorporated and Kansas City Power & Light Company Annual Incentive Plan awardsAward Standards and Performance Criteria amended effective as of January 1, 2009 (Exhibit 10.1.7 to Form 10-Q for the quarter ended March 31, 2009).
146
10.1.19
*Great Plains Energy
KCP&L
10.21*+
Great Plains Energy Incorporated, Kansas City Power & Light Company and KCP&L Greater Missouri Operations Company Annual Incentive Plan amended effective as of January 1, 2010 (Exhibit 10.1.4 to Form 10-Q for the quarter ended March 31, 2010).
Great Plains Energy
KCP&L
10.22*+
Form of Indemnification Agreement with each officer and director (Exhibit 10-f to Form 10-K for year ended December 31, 1995).
 
Great Plains Energy
KCP&L
10.1.2010.23
*
+
Form of Conforming Amendment to Indemnification Agreement with each officer and director (Exhibit 10.1.a to Form 10-Q for the quarter ended March 31, 2003).
 
Great Plains Energy
KCP&L
10.1.2110.24
*
+
Form of Indemnification Agreement with each director and officer (Exhibit 10.1 to Form 8-K filed on December 8, 2008).
 
Great Plains Energy
KCP&L
10.1.2210.25
*
+
Form of Indemnification Agreement with officers and directors (Exhibit 10.1.p to Form 10-K for the year ended December 31, 2005).
 
Great Plains Energy
KCP&L
10.1.2310.26
*
+
Form of Change in Control Severance Agreement with Michael J. Chesser (Exhibit 10.1.a to Form 10-Q for the quarter ended September 30, 2006).
 
Great Plains Energy
KCP&L
10.1.2410.27
*
+
Form of Change in Control Severance Agreement with William H. Downey (Exhibit 10.1.b to Form 10-Q for the quarter ended September 30, 2006).
 
Great Plains Energy
KCP&L
10.1.2510.28
*
+
Form of Change in Control Severance Agreement with John R. Marshall (Exhibit 10.1.c to Form 10-Q for the quarter ended September 30, 2006).
 
Great Plains Energy
KCP&L
10.1.2610.29
*
+
Form of Change in Control Severance Agreement with other executive officers of Great Plains Energy Incorporated and Kansas City Power & Light Company (Exhibit 10.1.e to Form 10-Q for the quarter ended September 30, 2006).
 
Great Plains Energy
KCP&L
10.1.2710.30*+
Great Plains Energy Incorporated Supplemental Executive Retirement Plan (As Amended and Restated for I.R.C. §409A), as amended December 8, 2009. (Exhibit 10.1.10 to Form 10-Q for the quarter ended September 30, 2007).
Great Plains Energy
KCP&L

152

10.1.2810.31
*
+
Great Plains Energy Incorporated Supplemental Executive Retirement Plan (As Amended and Restated for I.R.C. §409A), as amended February 10, 2009 (Exhibit 10.1.29 to Form 10-K for the year ended December 31, 2008).
 
Great Plains Energy
KCP&L
10.1.2910.32*+
*Great Plains Energy Incorporated Supplemental Executive Retirement Plan (As Amended and Restated for I.R.C. §409A), as amended December 8, 2009 (Exhibit 10.1.27 to Form 10-K for the year ended December 31, 2009).
Great Plains Energy
KCP&L
10.33*+
Great Plains Energy Incorporated Nonqualified Deferred Compensation Plan (As Amended and Restated for I.R.C. §409A) (Exhibit 10.1.1010.1.11 to Form 10-Q for the quarter ended September 30, 2007).
 
Great Plains Energy
KCP&L
10.1.3010.34*+
Great Plains Energy Incorporated Nonqualified Deferred Compensation Plan (As Amended and Restated for I.R.C. §409A) , amended effective January 1, 2010 (Exhibit 10.1.5 to Form 10-Q for the quarter ended March 31, 2010).
Great Plains Energy
KCP&L
10.35+
Description of Compensation Arrangements with Directors and Certain Executive Officers.
 
Great Plains Energy
KCP&L
10.1.3110.36
*
+
Letter regarding enhanced supplemental retirement and severance benefit for William H. Downey, dated August 5, 2008 (Exhibit 10.1.23 to Form 10-Q for the quarter ended June 30, 2008).
 
Great Plains Energy
KCP&L
10.1.3210.37
*
+
Employment offer letters to Michael J. Chesser dated September 10 and September 16, 2003 (Exhibit 10.1.35 to Form 10-K for the year ended December 31, 2008).
 
Great Plains Energy
KCP&L
10.1.3310.38
*
+
Bonus Agreement dated as of May 5, 2009 between Great Plains Energy Incorporated and Michael J. Chesser (Exhibit 10.1.10 to Form 10-Q for the quarter ended June 30, 2009).
 
Great Plains Energy
KCP&L
10.1.3410.39
*
+
Discretionary Bonus Agreement dated as of May 5, 2009 between Great Plains Energy Incorporated and Terry Bassham (Exhibit 10.1.11 to Form 10-Q for the quarter ended June 30, 2009).
 
Great Plains Energy
KCP&L
10.1.3510.40*+
Discretionary Bonus Agreement dated as of May 5, 2009 between Great Plains Energy Incorporated and Barbara B. Curry.Curry (Exhibit 10.1.35 to Form 10-K for the year ended December 31, 2009).
 
Great Plains Energy
KCP&L
10.1.3610.41*+
Employment offer letter to John R. Marshall dated April 7, 2005 (Exhibit 10.2.21 to Form 10-K for the year ended December 31, 2008).
Great Plains Energy
KCP&L
10.42*+
Retirement and Consulting Agreement among Great Plains Energy Incorporated, Kansas City Power & Light Company, KCP&L Greater Missouri Operations Company and John R. Marshall (Exhibit 10.1 to Form 8-K filed on May 5, 2010).
Great Plains Energy
KCP&L
10.43*+Consulting Services Assignment and Assumption Agreement between John R. Marshall and Coastal Partners Inc. (Exhibit 10.2 to Form 10-Q for the quarter ended June 30, 2010).
Great Plains Energy
KCP&L
153
10.44*+
Retirement and Consulting Agreement among Great Plains Energy Incorporated, Kansas City Power & Light Company, KCP&L Greater Missouri Operations Company and Barbara B. Curry (Exhibit 10.1 to Form 8-K filed on May 5, 2010).
Great Plains Energy
KCP&L
10.45+
Agreement among Great Plains Energy Incorporated, Kansas City Power & Light Company, KCP&L Greater Missouri Operations Company and William G. Riggins dated as of October 26, 2010.
Great Plains Energy
KCP&L
10.46*+
Agreement between Kansas City Power & Light Company and Stephen T. Easley dated December 2, 2008 (Exhibit 10.2.20 to Form 10-K for the year ended December 31, 2008).
Great Plains Energy
KCP&L
10.47*
Asset Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated, and Gregory Acquisition Corp., dated February 6, 2007 (Exhibit 10.1 to Form 8-K filed on February 8, 2007).
Great Plains Energy
147
10.1.3710.48*
Partnership Interests Purchase Agreement by and among Aquila, Inc., Aquila Colorado, LLC, Black Hills Corporation, Great Plains Energy Incorporated, and Gregory Acquisition Corp., dated February 6, 2007 (Exhibit 10.2 to Form 8-K filed on February 8, 2007).
 
Great Plains Energy
10.1.3810.49*
Letter Agreement dated as of June 29, 2007 to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated, and Gregory Acquisition Corp., dated February 6, 2007 (Exhibit 10.1.1 to Form 10-Q for the quarter ended June 30, 2007). 
 
Great Plains Energy
10.1.3910.50*
Letter Agreement dated as of August 31, 2007, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition CorpCorp. (Exhibit 10.1.4 to Form 10-Q for the quarter ended September 30, 2007). 
 
Great Plains Energy
10.1.4010.51*
Letter Agreement dated as of September 28, 2007, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition CorpCorp. (Exhibit 10.1.5 to Form 10-Q for the quarter ended September 30, 2007).
 
Great Plains Energy
10.1.4110.52*
Letter Agreement dated as of October 3, 2007, to Agreement and Plan of Merger, Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition CorpCorp. (Exhibit 10.1.6 to Form 10-Q for the quarter ended September 30, 2007). 
 
Great Plains Energy
10.1.4210.53*
Letter Agreement dated as of November 30, 2007, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition Corp. (Exhibit 10.1.40 to Form 10-K for the year ended December 31, 2007).
Great Plains Energy
154
10.1.4310.54*
Letter Agreement dated as of January 30, 2008, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition Corp. (Exhibit 10.1.41 to Form 10-K for the year ended December 31, 2007).
 
Great Plains Energy
10.1.4410.55*
Letter Agreement dated as of February 28, 2008, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition Corp. (Exhibit 10.1.3 to Form 10-Q for the quarter ended March 31, 2008).
 
Great Plains Energy
10.1.4510.56*
Letter Agreement dated as of March 28, 2008, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition Corp. (Exhibit 10.1.4 to Form 10-Q for the quarter ended March 31, 2008).
 
Great Plains Energy
10.1.4610.57*
Letter Agreement dated as of April 28, 2008, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition Corp. (Exhibit 10.1.5 to Form 10-Q for the quarter ended March 31, 2008).
 
Great Plains Energy
10.1.4710.58*
Letter Agreement dated as of May 29, 2008, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition Corp. (Exhibit 10.1.5 to Form 10-Q for the quarter ended June 30, 2008).
Great Plains Energy
148
10.1.4810.59*
Letter Agreement dated as of June 19, 2008, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition Corp. (Exhibit 10.1.6 to Form 10-Q for the quarter ended June 30, 2008).
 
Great Plains Energy
10.1.4910.60*
Letter Agreement dated as of June 27, 2008, to Asset Purchase Agreement and Partnership Interests Purchase Agreement by and among Aquila, Inc., Black Hills Corporation, Great Plains Energy Incorporated and Gregory Acquisition Corp. (Exhibit 10.1.7 to Form 10-Q for the quarter ended June 30, 2008).
 
Great Plains Energy
10.1.5010.61*
Joint Motion and Settlement Agreement dated as of February 26, 2008, among Great Plains Energy Incorporated, Kansas City Power & Light Company, the Kansas Corporation Commission Staff, the Citizens’ Utility Ratepayers Board, Aquila, Inc. d/b/a Aquila Networks, Black Hills Corporation, and Black Hills/Kansas Gas Utility Company, LLC (Exhibit 10.1.7 to Form 10-Q for the quarter ended March 31, 2008).
 
Great Plains Energy
KCP&L
10.1.5110.62*
Purchase Agreement, dated as of April 1, 2008, by and among Custom Energy Holdings, L.L.C., Direct Energy Services, LLC and Great Plains Energy Incorporated (Exhibit 10.1 to Form 8-K filed on April 2, 2008).
Great Plains Energy
155
10.1.5210.63*
Credit Agreement dated as of May 11, 2006,August 9, 2010 among Great Plains Energy Incorporated, Bank of America, N.A., JPMorgan Chase Bank, N.A., BNP Paribas, The Bank of Tokyo-Mitsubishi UFJ, Limited, Chicago Branch, Wachovia Bank N.A., The Bank of New York, Keybank National Association, The Bank of Nova Scotia, UMB Bank, N.A., and Commerce Bank, N.A. (Exhibit 10.1.a to Form 10-Q for the quarter ended June 30, 2006).
10.1.53* 
Notice of Election to Transfer Unused Commitment between the Great Plains Energy Incorporated and Kansas City Power & Light Company Credit Agreements dated as of May 11, 2006, withCertain Lenders, Bank of America, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., as Syndication Agent, BNP Paribas, The Bank of Tokyo-Mitsubishi UFJ, Limited, Chicago Branch and Wachovia Bank N.A., as Co-Documentation Agents, The Bank of New York, KeyBank National Association, The Bank of Nova Scotia, UMB Bank, N.A., and Commerce Bank, N.A. (Exhibit 10.1.2 to Form 10-Q for the quarter ended June 30, 2007).
10.1.54*
First Amendment to Credit Agreement dated as of May 16, 2008, among Great Plains Energy Incorporated, the Lenders party thereto and Bank of America, N.A., as Administrative Agent (Exhibit 10.1 to Form 8-K filed on May 22, 2008)
10.1.55*
Second Amendment to Credit Agreement dated as of May 16, 2008, among Great Plains Energy Incorporated, the Lenders party thereto and Bank of America, N.A., as Administrative Agent (Exhibit 10.2 to Form 8-K filed on May 22, 2008).
10.1.56*
Third Amendment to Credit Agreement dated as of June 13, 2008, among Great Plains Energy Incorporated, the Lenders party thereto and Bank of America, N.A., as Administrative Agent (Exhibit 10.1 to Form 8-K filed on June 19, 2008).
10.1.57*
Financing Agreement dated as of April 22, 2005, among Aquila, Inc., the lenders from time to time party thereto, and Union Bank, N.A. and Wells Fargo Bank, National Association, as Syndication Agents, Barclays Bank PLC and U.S. Bank National Association, as Documentation Agents, Banc of California,America Securities LLC, Union Bank, N.A., and Wells Fargo Securities, LLC as agentJoint Lead Arrangers and Joint Book Managers (Exhibit 10.1 to Form 8-K filed by Aquila, Inc. on April 26, 2005).
10.1.58*Amendment No. 2 to Financing Agreement dated December 9, 2006, by and between Aquila, Inc., the lenders from time to time party thereto, and Union Bank of California, N.A., as agent (Exhibit 10.1 to Form 8-K filed by Aquila, Inc. on December 11, 2006).
149
10.1.59*
Amendment to Financing Agreement dated June 10, 2008, by and among Aquila, Inc., the lenders from time to time party thereto, and Union Bank of California, N.A., as agent (Exhibit 10.1.3 to Form 10-Q for the quarter ended September 30, 2008)2010).
 
Great Plains Energy
10.1.6010.64*
Amendment to FinancingCredit Agreement dated October 28, 2008, byas of August 9, 2010 among Kansas City Power & Light Company, Certain Lenders, Bank of America, N.A., as Administrative Agent, and Union Bank, N.A. and Wells Fargo Bank, National Association, as Syndication Agents, The Royal Bank of Scotland PLC and BNP Paribas , as Documentation Agents, Banc of America Securities LLC, Union Bank, N.A. and Wells Fargo Securities, LLC as Joint Lead Arrangers and Joint Book Managers (Exhibit 10.2 to Form 10-Q for the quarter ended September 30, 2010).
Great Plains Energy
KCP&L
10.65*
Credit Agreement dated as of August 9, 2010 among KCP&L Greater Missouri Operations Company, the lenders from time to time party thereto, and UnionCertain Lenders, Bank of California,America, N.A., as agent (Exhibit 10.1.60 to Form 10-K for the year ended December 31, 2008).
10.1.61*
Amendment to Financing Agreement dated April 16, 2009 by and among KCP&L Greater Missouri Operations Company, the lenders from time to time party thereto,Administrative Agent, and Union Bank, N.A. and Wells Fargo Bank, National Association, as agentSyndication Agents, The Royal Bank of Scotland PLC and BNP Paribas , as Documentation Agents, Banc of America Securities LLC, Union Bank, N.A. and Wells Fargo Securities, LLC as Joint Lead Arrangers and Joint Book Managers (Exhibit 10.510.3 to Form 8-K filed on April 22, 2009)10-Q for the quarter ended September 30, 2010).
 
10.1.62*
Guaranty dated as of July 14, 2008, between Great Plains Energy Incorporated and Union Bank of California, N.A., related to Financing Agreement dated as of April 22, 2005, as amended, among Aquila, Inc., the lenders from time to time party thereto, and Union Bank of California, N.A. as Agent. (Exhibit 10.1 to Form 8-K filed on July 18, 2008).
10.1.6310.66*
Guaranty dated as of July 15, 2008, issued by Great Plains Energy Incorporated in favor of Union Bank of California, N.A., as successor trustee, and the holders of the Aquila, Inc., 11.875% Senior Notes due July 1, 2012.2012 (Exhibit 10.3 to Form 8-K filed on July 18, 2008).
 
Great Plains Energy
10.1.6410.67*
Guaranty dated as of July 15, 2008, issued by Great Plains Energy Incorporated in favor of Union Bank of California, N.A., as successor trustee, and the holders of the Aquila, Inc., 7.75% Senior Notes due June 15, 2011.2011 (Exhibit 10.4 to Form 8-K filed on July 18, 2008).
 
Great Plains Energy
10.1.6510.68*
Guaranty dated as of July 15, 2008, issued by Great Plains Energy Incorporated in favor of Union Bank of California, N.A., as successor trustee, and the holders of the Aquila, Inc., 7.95% Senior Notes due February 1, 2011.2011 (Exhibit 10.5 to Form 8-K filed on July 18, 2008).
 
Great Plains Energy
10.1.6610.69*
Guaranty dated as of July 15, 2008, issued by Great Plains Energy Incorporated in favor of Union Bank of California, N.A., as successor trustee, and the holders of the Aquila, Inc., 8.27% Senior Notes due November 15, 2021.2021 (Exhibit 10.6 to Form 8-K filed on July 18, 2008).
10.1.67*
Guaranty dated as of July 15, 2008, issued by Great Plains Energy Incorporated in favor of Union Bank of California, N.A., as successor trustee, and the holders of the Aquila, Inc., 7.625% Senior Notes due November 15, 2009. (Exhibit 10.7 to Form 8-K filed on July 18, 2008).
156
10.1.68*
Credit Agreement dated as of September 23, 2008, among Aquila, Inc., as the Borrower, Great Plains Energy Incorporated, as the Guarantor, certain lenders, Bank of America, N.A., as Administrative Agent, Union Bank of California, N.A., as Syndication Agent and BNP Paribas, JPMorgan Chase Bank, N.A. and The Royal Bank of Scotland plc as Co-Documentation Agents, Banc of America Securities LLC and Union Bank of California, N.A., as Joint Lead Arrangers and Joint Book Managers. (Exhibit 10.1 to Form 8-K filed on September 23, 2008).
10.1.6910.70*
Sales Agency Financing Agreement dated August 14, 2008 between Great Plains Energy Incorporated and BNY Mellon Capital Markets, LLC.LLC (Exhibit 1.1 to Form 8-K filed on August 14, 2008).
 
10.1.70*Non-Unanimous Stipulation and Agreement dated May 22, 2009 among KCP&L Greater Missouri Operations Company, the Staff of the Missouri Public Service Commission, the Office of the Public Counsel, Missouri Department of Natural Resources and Dogwood Energy, LLC. (Exhibit 10.1 to Form 8-K filed on May 27, 2009).
150
12.1
Computation of Ratio of Earnings to Fixed Charges.
21.1
List of Subsidiaries of Great Plains Energy Incorporated.
23.1
Consent of Independent Registered Public Accounting Firm.
24.1
Powers of Attorney.
31.1.a
Rule 13a-14(a)/15d-14(a) Certifications of Michael J. Chesser.
31.1.b
Rule 13a-14(a)/15d-14(a) Certifications of Terry Bassham.
32.1Section 1350 Certifications.

*Filed with the SEC as exhibits to prior SEC filings and are incorporated herein by reference and made a part hereof.  The SEC filing and the exhibit number of the documents so filed, and incorporated herein by reference, are stated in parenthesis in the description of such exhibit.
+ Indicates management contract or compensatory plan or arrangement.
Copies of any of the exhibits filed with the SEC in connection with this document may be obtained from Great Plains Energy upon written request.
Great Plains Energy agrees to furnish to the SEC upon request any instrument with respect to long-term debt as to which the total amount of securities authorized does not exceed 10% of total assets of Great Plains Energy and its subsidiaries on a consolidated basis.
Exhibits 4.2.1 through 4.2.16 and 10.2.1 through 10.2.26 filed by KCP&L are also filed by Great Plains Energy.
KCP&L Documents
Exhibit Number
Description of Document
3.2.1*
Restated Articles of Consolidation of Kansas City Power & Light Company, as amended October 1, 2001 (Exhibit 3-(i) to Form 10-Q for the quarter ended September 30, 2001).
3.2.2*
By-laws of Kansas City Power & Light Company, as amended April 1, 2008 (Exhibit 3.2. to Form 8-K filed on April 7, 2008).
4.2.1*
General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, n.a. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4-bb to Form 10-K for the year ended December 31, 1986).
4.2.2*
Fourth Supplemental Indenture dated as of February 15, 1992, to Indenture dated as of December 1, 1986 (Exhibit 4-y to Form 10-K for the year ended December 31, 1991).
4.2.3*
Fifth Supplemental Indenture dated as of September 15, 1992, to Indenture dated as of December 1, 1986 (Exhibit 4-a to quarterly report on Form 10-Q for the quarter ended September 30, 1992).
4.2.4*
Seventh Supplemental Indenture dated as of October 1, 1993, to Indenture dated as of December 1, 1986 (Exhibit 4-a to quarterly report on Form 10-Q for the quarter ended September 30, 1993).
4.2.5*Eighth Supplemental Indenture dated as of December 1, 1993, to Indenture dated as of December 1, 1986 (Exhibit 4 to Registration Statement, Registration No. 33-51799).
151
4.2.6*
Eleventh Supplemental Indenture dated as of August 15, 2005, to the General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, n.a. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4.2 to Form 10-Q for the quarter ended September 30, 2005).
4.2.7*
Twelfth Supplemental Indenture, dated as of March 1, 2009, to the General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, n.a. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4.2 to Form 8-K filed on March 24, 2009).
4.2.8*
Thirteenth Supplemental Indenture, dated as of March 1, 2009, to the General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, n.a. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4.3 to Form 8-K filed on March 24, 2009).
4.2.9*
Fourteenth Supplemental Indenture, dated as of March 1, 2009, to the General Mortgage and Deed of Trust dated as of December 1, 1986, between Kansas City Power & Light Company and UMB Bank, n.a. (formerly United Missouri Bank of Kansas City, N.A.), Trustee (Exhibit 4.4 to Form 8-K filed on March 24, 2009).
4.2.10*
Indenture for Medium-Term Note Program dated as of February 15, 1992, between Kansas City Power & Light Company and The Bank of New York (Exhibit 4-bb to Registration Statement, Registration No. 33-45736).
4.2.11*
Indenture for $150 million aggregate principal amount of 6.50% Senior Notes due November 15, 2011 and $250 million aggregate principal amount of 7.125% Senior Notes due December 15, 2005 dated as of December 1, 2000, between Kansas City Power & Light Company and The Bank of New York (Exhibit 4-a to Report on Form 8-K filed on December 18, 2000).
4.2.12*
Indenture dated March 1, 2002 between The Bank of New York and Kansas City Power & Light Company (Exhibit 4.1.b. to Form 10-Q for the quarter ended March 31, 2002).
4.2.13*
Supplemental Indenture No. 1 dated as of November 15, 2005, to Indenture dated March 1, 2002 between The Bank of New York and Kansas City Power & Light Company (Exhibit 4.2.j to Form 10-K for the year ended December 31, 2005).
4.2.14*
Indenture dated as of May 1, 2007, between Kansas City Power & Light Company and The Bank of New York Trust Company, N.A., as trustee (Exhibit 4.1 to Form 8-K filed on June 4, 2007).
4.2.15*
Supplemental Indenture No. 1 dated as of June 4, 2007 between Kansas City Power & Light Company and The Bank of New York Trust Company, N.A., as trustee (Exhibit 4.2 to Form 8-K filed on June 4, 2007).
4.2.16*
Supplemental Indenture No. 2 dated as of March 11, 2008, between Kansas City Power & Light Company and The Bank of New York Trust Company, N.A., as trustee (Exhibit 4.2 to Form 8-K filed on March 11, 2008).
10.2.110.71*
Insurance agreement between Kansas City Power & Light Company and XL Capital Assurance Inc., dated December 5, 2002 (Exhibit 10.2.f to Form 10-K for the year ended December 31, 2002).
 
Great Plains Energy
KCP&L
10.2.210.72*
Insurance Agreement dated as of August 1, 2004, between Kansas City Power & Light Company and XL Capital Assurance Inc. (Exhibit 10.2 to Form 10-Q for the quarter ended September 30, 2004).
Great Plains Energy
KCP&L
152
10.2.310.73*
Insurance Agreement dated as of September 1, 2005, between Kansas City Power & Light Company and XL Capital Assurance Inc. (Exhibit 10.2.e to Form 10-K for the year ended December 31, 2005).
 
Great Plains Energy
KCP&L
10.2.410.74*
Insurance Agreement dated as of September 1, 2005, between Kansas City Power & Light Company and XL Capital Assurance Inc. (Exhibit 10.2.e10.2.f to Form 10-K for the year ended December 31, 2005).
 
Great Plains Energy
KCP&L
10.2.510.75*
Insurance Agreement dated as of September 19, 2007, by and between Financial Guaranty Insurance Company and Kansas City Power & Light Company (Exhibit 10.2.2  1 to Form 10-Q for the quarter ended September 30, 2007).
 
Great Plains Energy
KCP&L
10.76*
Purchase and Sale Agreement dated as of July 1, 2005, between Kansas City Power & Light Company, as Originator, and Kansas City Power & Light Receivables Company, as Buyer (Exhibit 10.2.b to Form 10-Q for the quarter ended June 30, 2005).
Great Plains Energy
KCP&L
10.77*
Receivables Sale Agreement dated as of July 1, 2005, among Kansas City Power & Light Receivables Company, as the Seller, Kansas City Power & Light Company, as the Initial Collection Agent, The Bank of Tokyo-Mitsubishi, Ltd., New York Branch, as the Agent, and Victory Receivables Corporation (Exhibit 10.2.c to Form 10-Q for the quarter ended June 30, 2005).
Great Plains Energy
KCP&L
10.78*
Amendment No. 1 dated as of April 2, 2007, among Kansas City Power & Light Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation to the Receivables Sale Agreement dated as of July 1, 2005 (Exhibit 10.2.2 to Form 10-Q for the quarter ended March 31, 2007).
Great Plains Energy
KCP&L
10.79*Amendment No. 2 dated as of July 11, 2008, among Kansas City Power & Light Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation to the Receivables Sale Agreement dated as of July 1, 2005 (Exhibit 10.2.2 to Form 10-Q for the quarter ended June 30, 2008).
Great Plains Energy
KCP&L

157

10.2.610.80*
Amendment dated as of July 9, 2009 to Receivables Sale Agreement dated as of July 1, 2005 among Kansas City Power & Light  Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation (Exhibit 10.4 to Form 8-K filed on July 13, 2009).
Great Plains Energy
KCP&L
10.81*
Amendment and Waiver dated as of September 25, 2009 to the Receivables Sale Agreement dated as of July 1, 2005 among Kansas City Power & Light Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation (Exhibit 10.2.2 to Form 10-Q for the quarter ended September 30, 2009).
Great Plains Energy
KCP&L
10.82*
Amendment dated as of May 5, 2010 to Receivables Sale Agreement dated as of July 1, 2005 among Kansas City Power & Light  Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation (Exhibit 10.2.2 to Form 10-Q for the quarter ended March 31, 2010).
Great Plains Energy
KCP&L
10.83*
Iatan Unit 2 and Common Facilities Ownership Agreement, dated as of May 19, 2006, among Kansas City Power & Light Company, Aquila, Inc., The Empire District Electric Company, Kansas Electric Power Cooperative, Inc., and Missouri Joint Municipal Electric Utility Commission (Exhibit 10.2.a to Form 10-Q for the quarter ended June 30, 2006).
 
Great Plains Energy
10.2.7*
Credit Agreement dated as of May 11, 2006, among Kansas City Power & Light Company, Bank of America, N.A., JPMorgan Chase Bank, N.A., BNP Paribas, The Bank of Tokyo-Mitsubishi UFJ, Limited, Chicago Branch, Wachovia Bank N.A., The Bank of New York, Keybank National Association, The Bank of Nova Scotia, UMB Bank, N.A., and Commerce Bank, N.A. (Exhibit 10.2.b to Form 10-Q for the quarter ended June 30, 2006).
KCP&L
10.2.8*
Notice of Election to Transfer Unused Commitment between the Great Plains Energy Incorporated and Kansas City Power & Light Company Credit Agreements dated as of May 11, 2006, with Bank of America, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., as Syndication Agent, BNP Paribas, The Bank of Tokyo-Mitsubishi UFJ, Limited, Chicago Branch and Wachovia Bank N.A., as Co-Documentation Agents, The Bank of New York, KeyBank National Association, The Bank of Nova Scotia, UMB Bank, N.A., and Commerce Bank, N.A. (Exhibit 10.1.2 to Form 10-Q for the quarter ended June 30, 2007).
10.2.910.84*
Stipulation and Agreement dated March 28, 2005, among Kansas City Power & Light Company, Staff of the Missouri Public Service Commission, Office of the Public Counsel, Missouri Department of Natural Resources, Praxair, Inc., Missouri Independent Energy Consumers, Ford Motor Company, Aquila, Inc., The Empire District Electric Company, and Missouri Joint Municipal Electric Utility Commission (Exhibit 10.2 to Form 10-Q for the quarter ended March 31, 2005).
 
Great Plains Energy
KCP&L
10.2.1010.85*
Stipulation and Agreement filed April 27, 2005, among Kansas City Power & Light Company, the Staff of the State Corporation Commission of the State of Kansas, Sprint, Inc., and the Kansas Hospital Association (Exhibit 10.2.a to Form 10-Q for the quarter ended June 30, 2005).
 
Great Plains Energy
KCP&L
10.2.1110.86*
Joint Motion and Settlement Agreement dated as of February 26, 2008, among Great Plains Energy Incorporated, Kansas City Power & Light Company, the Kansas Corporation Commission Staff, the Citizens’ Utility Ratepayers Board, Aquila, Inc. d/b/a Aquila Networks, Black Hills Corporation, and Black Hills/Kansas Gas Utility Company, LLC (Exhibit 10.1.7 to Form 10-Q for the quarter ended March 31, 2008).
Great Plains Energy
KCP&L
158

10.2.1210.87*
Stipulation and Agreement dated April 24, 2009, among Kansas City Power & Light Company, Staff of the Missouri Public Service Commission, Office of Public Counsel, Praxair, Inc., Midwest Energy Users Association, U.S. Department of Energy and the U.S. Nuclear Security Administration, Ford Motor Company, Missouri Industrial Energy Consumers and Missouri Department of Natural Resources (Exhibit 10.1 to Form 8-K filed April 30, 2009.)2009).
Great Plains Energy
KCP&L
153
10.2.1310.88*
PurchaseNon-Unanimous Stipulation and Sale Agreement dated asMay 22, 2009 among KCP&L Greater Missouri Operations Company, the Staff of July 1, 2005, between Kansas City Power & Light Company, as Originator,the Missouri Public Service Commission, the Office of the Public Counsel, Missouri Department of Natural Resources and Kansas City Power & Light Receivables Company, as BuyerDogwood
Energy, LLC (Exhibit 10.2.b to Form 10-Q for the quarter ended June 30, 2005).
10.2.14*
Receivables Sale Agreement dated as of July 1, 2005, among Kansas City Power & Light Receivables Company, as the Seller, Kansas City Power & Light Company, as the Initial Collection Agent, The Bank of Tokyo-Mitsubishi, Ltd., New York Branch, as the Agent, and Victory Receivables Corporation (Exhibit 10.2.c to Form 10-Q for the quarter ended June 30, 2005).
10.2.15*
Amendment No. 1 dated as of April 2, 2007, among Kansas City Power & Light Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation to the Receivables Sale Agreement dated as of July 1, 2005 (Exhibit 10.2.2 to Form 10-Q for the quarter ended March 31, 2007).
10.2.16*
Amendment No. 2 dated as of July 11, 2008, among Kansas City Power & Light Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation to the Receivables Sale Agreement dated as of July 1, 2005 (Exhibit 10.2.2 to For 10-Q for the quarter ended June 30, 2008).
10.2.17*
Amendment dated as of July 9, 2009 to Receivables Sale Agreement dated as of July 1, 2005, among Kansas City Power & Light Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation (Exhibit 10.410.1 to Form 8-K filed on July 13,May 27, 2009).
 
10.2.18*
Amendment and Waiver dated as of September 25, 2009 to the Receivables Sale Agreement dated as of July 1, 2005 among Kansas City Power & Light Receivables Company, Kansas City Power & Light Company, The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and Victory Receivables Corporation (Exhibit 10.2.2 to Form 10-Q for the quarter ended September 31, 2009).
Great Plains Energy
10.2.1910.89*
Collaboration Agreement dated as of March 19, 2007, among Kansas City Power & Light Company, Sierra Club and Concerned Citizens of Platte County, Inc. (Exhibit 10.1 to Form 8-K filed on March 20, 2007).
 
Great Plains Energy
KCP&L
10.2.2010.90*
Amendment to the Collaboration Agreement datedeffective as of September 5, 2008 among Kansas City Power & Light Company, Sierra Club and Concerned Citizens of Platte County, Inc. (Exhibit 10.2.20 to Form 10-K for the year ended December 31, 2009).
 
Great Plains Energy
KCP&L
10.2.2110.91*
Joint Operating Agreement between Kansas City Power & Light Company and Aquila, Inc., dated as of October 10, 2008 (Exhibit 10.2.110.2.2 to Form 10-Q for the quarter ended September 30, 2008).
 
10.2.22
*
+
Great Plains Energy Incorporated Kansas City Power & Light Company Annual Incentive Plan amended effective as of January 1, 2007, and 2008 objectives adopted as of May 6, 2008 (Exhibit 10.1.22 to Form 10-Q for the quarter ended June 30, 2008). 
KCP&L
10.2.23
*
+
Great Plains Energy Incorporated and Kansas City Power & Light Company Annual Incentive Plan Awards Standards and Performance Criteria amended effective as of January 1, 2009 (Exhibit 10.1.7 to Form 10-Q for the quarter ended March 31, 2009).
10.2.24
*
+
Agreement between Kansas City Power & Light Company and Stephen T. Easley dated December 2, 2008 (Exhibit 10.2.20 to Form 10-K for the year ended December 31, 2008).
10.2.25
*
+
Employment offer letter to John R. Marshall dated April 7, 2005 (Exhibit 10.2.21 to Form 10-K for the year ended December 31, 2008).
12.212.1 
Computation of Ratio of Earnings to Fixed Charges.
Great Plains Energy
154
12.2
Computation of Ratio of Earnings to Fixed Charges.
KCP&L
21.1
List of Subsidiaries of Great Plains Energy Incorporated.
Great Plains Energy
23.1
Consent of Independent Registered Public Accounting Firm.
Great Plains Energy
23.2 
Consent of Independent Registered Public Accounting Firm.
 
KCP&L
24.1
Powers of Attorney.
Great Plains Energy
24.2 
Powers of Attorney.
 
31.2.a
Rule 13a-14(a)/15d-14(a) Certifications of Michael J. Chesser.
KCP&L
31.2.b31.1 
Rule 13a-14(a)/15d-14(a) CertificationsCertification of Terry Bassham.Michael J. Chesser.
 
Great Plains Energy
31.2
Rule 13a-14(a)/15d-14(a) Certification of James C. Shay.
Great Plains Energy
31.3
Rule 13a-14(a)/15d-14(a) Certification of Michael J. Chesser.
KCP&L
31.4Rule 13a-14(a)/15d-14(a) Certification of James C. Shay.KCP&L
159
32.1**
Section 1350 Certifications.
Great Plains Energy
32.2**
Section 1350 Certifications.
KCP&L
101.INS**
XBRL Instance Document.
Great Plains Energy
KCP&L
101.SCH**
XBRL Taxonomy Extension Schema Document.
Great Plains Energy
KCP&L
101.CAL**
XBRL Taxonomy Extension Calculation Linkbase Document.
Great Plains Energy
KCP&L
101.DEF**
XBRL Taxonomy Extension Definition Linkbase Document.
Great Plains Energy
KCP&L
101.LAB**
XBRL Taxonomy Extension Labels Linkbase Document.
Great Plains Energy
KCP&L
101.PRE**XBRL Taxonomy Extension Presentation Linkbase Document.
Great Plains Energy
KCP&L

* Filed with the SEC as exhibits to prior SEC filings and are incorporated herein by reference and made a part hereof.  The SEC filings and the exhibit number of the documents so filed, and incorporated herein by reference, are stated in parenthesis in the description of such exhibit.
** Furnished and shall not be deemed filed for the purpose of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”).  Such document shall not be incorporated by reference into any registration statement or other document pursuant to the Exchange Act or the Securities Act of 1933, as amended, unless otherwise indicated in such registration statement or other document.
 
+ Indicates management contract or compensatory plan or arrangement.
 
Copies of any of the exhibits filed with the SEC in connection with this document may be obtained from KCP&L upon written request.
 
KCP&L agreesThe registrants agree to furnish to the SEC upon request any instrument with respect to long-term debt as to which the total amount of securities authorized does not exceed 10% of total assets of KCP&Lsuch registrant and its subsidiaries on a consolidated basis.
160
Schedule I – Parent Company Financial Statements

GREAT PLAINS ENERGY INCORPORATED
Income Statements of Parent Company
          
          
Year Ended December 31 2010 2009 2008
Operating Expenses (millions, except per share amounts)
Selling, general and administrative $1.2  $8.8  $9.3 
Maintenance  -   0.2   1.0 
General taxes  0.9   1.1   0.8 
Total  2.1   10.1   11.1 
Operating loss  (2.1)  (10.1)  (11.1)
Equity in earnings from subsidiaries  239.3   174.7   144.8 
Non-operating income  3.4   -   0.6 
Interest charges  (44.7)  (28.2)  (19.2)
Income from continuing operations before income taxes  195.9   136.4   115.1 
Income taxes  15.8   15.2   4.4 
Income from continuing operations  211.7   151.6   119.5 
Equity in earnings (loss) from discontinued subsidiary  -   (1.5)  35.0 
Net income  211.7   150.1   154.5 
Preferred stock dividend requirements  1.6   1.6   1.6 
Earnings available for common shareholders $210.1  $148.5  $152.9 
             
Average number of basic common shares outstanding  135.1   129.3   101.1 
Average number of diluted common shares outstanding  136.9   129.8   101.2 
             
Basic earnings (loss) per common share            
Continuing operations $1.55  $1.16  $1.16 
Discontinued operations  -   (0.01)  0.35 
Basic earnings per common share $1.55  $1.15  $1.51 
             
Diluted earnings (loss) per common share            
Continuing operations $1.53  $1.15  $1.16 
Discontinued operations  -   (0.01)  0.35 
Diluted earnings per common share $1.53  $1.14  $1.51 
             
Cash dividends per common share $0.83  $0.83  $1.66 
             
The accompanying Notes to Financial Statements of Parent Company are an integral part of these statements.     

 
155161
 

SCHEDULE I – PARENT COMPANY FINANCIAL STATEMENTS
GREAT PLAINS ENERGY INCORPORATED
Balance Sheets of Parent Company
       
December 31 2010 2009
ASSETS (millions, except share amounts)
Current Assets      
Cash and cash equivalents $0.3  $6.1 
Accounts receivable from subsidiaries  -   0.2 
Notes receivable from subsidiaries  249.4   0.6 
Money pool receivable  2.0   0.9 
Taxes receivable  7.2   7.2 
Other  0.7   0.1 
Total  259.6   15.1 
Investments and Other Assets        
Investment in KCP&L  2,005.0   1,931.7 
Investments in other subsidiaries  1,360.2   1,328.3 
Deferred income taxes  7.2   8.3 
Other  6.2   5.6 
Total  3,378.6   3,273.9 
Total $3,638.2  $3,289.0 
         
LIABILITIES AND CAPITALIZATION        
Current Liabilities        
Notes payable $9.5  $20.0 
Accounts payable to subsidiaries  31.1   28.9 
Accounts payable  -   0.1 
Accrued interest  6.4   3.6 
Derivative instruments  20.8   0.2 
Other  7.1   5.4 
Total  74.9   58.2 
Deferred Credits and Other Liabilities        
Derivative instruments  -   0.5 
Other  1.4   11.7 
Total  1.4   12.2 
Capitalization        
Common shareholders' equity        
Common stock-250,000,000 shares authorized without par value        
136,113,954 and 135,636,538 shares issued, stated value  2,324.4   2,313.7 
Retained earnings  626.5   529.2 
Treasury stock-400,889 and 213,423 shares, at cost  (8.9)  (5.5)
Accumulated other comprehensive loss  (56.1)  (44.9)
Total  2,885.9   2,792.5 
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  637.0   387.1 
Total  3,561.9   3,218.6 
Commitments and Contingencies        
Total $3,638.2  $3,289.0 
         
The accompanying Notes to Financial Statements of Parent Company are an integral part of these statements. 

GREAT PLAINS ENERGY INCORPORATED 
Income Statements of Parent Company 
          
          
Year Ended December 31 2009 2008 2007
Operating Expenses (millions, except per share amounts) 
Selling, general and administrative $8.8  $9.3  $18.5 
Maintenance  0.2   1.0   0.8 
General taxes  1.1   0.8   0.3 
Total  10.1   11.1   19.6 
Operating loss  (10.1)  (11.1)  (19.6)
Equity in earnings from subsidiaries  174.7   144.8   156.8 
Non-operating income  -   0.6   4.2 
Interest charges  (28.2)  (19.2)  (26.8)
Income from continuing operations before income taxes  136.4   115.1   114.6 
Income taxes  15.2   4.4   6.3 
Income from continuing operations  151.6   119.5   120.9 
Equity in earnings (loss) from discontinued subsidiary  (1.5)  35.0   38.3 
Net income  150.1   154.5   159.2 
Preferred stock dividend requirements  1.6   1.6   1.6 
Earnings available for common shareholders $148.5  $152.9  $157.6 
             
Average number of basic common shares outstanding  129.3   101.1   84.9 
Average number of diluted common shares outstanding  129.8   101.2   85.2 
             
Basic earnings (loss) per common share            
Continuing operations $1.16  $1.16  $1.41 
Discontinued operations  (0.01)  0.35   0.45 
Basic earnings per common share $1.15  $1.51  $1.86 
             
Diluted earnings (loss) per common share            
Continuing operations $1.15  $1.16  $1.40 
Discontinued operations  (0.01)  0.35   0.45 
Diluted earnings per common share $1.14  $1.51  $1.85 
             
Cash dividends per common share $0.83  $1.66  $1.66 
             
The accompanying Notes to Financial Statements of Parent Company are an integral part of these statements. 
 
156162
 

GREAT PLAINS ENERGY INCORPORATED
Statements of Cash Flows of Parent Company
          
Year Ended December 31 2010 2009 2008
Cash Flows from Operating Activities (millions)
Net income $211.7  $150.1  $154.5 
Adjustments to reconcile income to net cash from operating activities:            
Amortization  3.9   1.9   0.9 
Deferred income taxes, net  13.9   (6.1)  3.3 
Equity in earnings from subsidiaries  (239.3)  (174.7)  (144.8)
Equity in (earnings) loss from discontinued subsidiary  -   1.5   (35.0)
Cash flows affected by changes in:            
Accounts receivable from subsidiaries  (2.6)  3.7   (26.3)
Taxes receivable  -   4.8   (8.7)
Accounts payable to subsidiaries  2.2   0.2   17.7 
Other accounts payable  (0.1)  0.1   0.2 
Accrued interest  2.7   1.4   - 
Cash dividends from subsidiaries  138.6   94.0   416.7 
Other  (7.8)  8.8   2.7 
Net cash from operating activities  123.2   85.7   381.2 
Cash Flows from Investing Activities            
Equity contributions to subsidiaries  -   (455.0)  (200.0)
Intercompany lending  (248.8)  -   - 
Net money pool lending  (1.1)  (0.9)  - 
GMO acquisition  -   -   (5.0)
Purchases of nonutility property  -   -   (0.3)
Net cash from investing activities  (249.9)  (455.9)  (205.3)
Cash Flows from Financing Activities            
Issuance of common stock  6.2   219.9   15.3 
Issuance of long-term debt  249.9   287.5   - 
Issuance fees  (3.2)  (18.8)  (1.0)
Net change in short-term borrowings  (10.5)  (10.0)  (12.0)
Dividends paid  (114.2)  (110.5)  (172.0)
Other financing activities  (7.3)  (3.8)  (0.8)
Net cash from financing activities  120.9   364.3   (170.5)
Net Change in Cash and Cash Equivalents  (5.8)  (5.9)  5.4 
Cash and Cash Equivalents at Beginning of Year  6.1   12.0   6.6 
Cash and Cash Equivalents at End of Year $0.3  $6.1  $12.0 
             
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 2009 2008
ASSETS (millions, except share amounts)
Current Assets      
Cash and cash equivalents $6.1  $12.0 
Accounts receivable from subsidiaries  0.2   4.8 
Notes receivable from subsidiaries  0.6   0.6 
Money pool receivable  0.9   - 
Taxes receivable  7.2   12.0 
Deferred income taxes  -   0.2 
Other  0.1   0.4 
Total  15.1   30.0 
Investments and Other Assets        
Investment in KCP&L  1,931.7   1,621.9 
Investments in other subsidiaries  1,328.3   1,094.8 
Deferred income taxes  8.3   1.2 
Other  5.6   6.0 
Total  3,273.9   2,723.9 
Total $3,289.0  $2,753.9 
         
LIABILITIES AND CAPITALIZATION   
Current Liabilities        
Notes payable $20.0  $30.0 
Accounts payable to subsidiaries  28.9   28.7 
Accounts payable  0.1   1.3 
Accrued interest  3.6   2.0 
Derivative instruments  0.2   - 
Other  5.4   0.8 
Total  58.2   62.8 
Deferred Credits and Other Liabilities        
Derivative instruments  0.5   - 
Other  11.7   1.9 
Total  12.2   1.9 
Capitalization        
Common shareholders' equity        
Common stock-250,000,000 shares authorized without par value        
135,636,538 and 119,375,923 shares issued, stated value  2,313.7   2,118.4 
Retained earnings  529.2   489.3 
Treasury stock-213,423 and 120,677 shares, at cost  (5.5)  (3.6)
Accumulated other comprehensive loss  (44.9)  (53.5)
Total  2,792.5   2,550.6 
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  387.1   99.6 
Total  3,218.6   2,689.2 
Commitments and Contingencies        
Total $3,289.0  $2,753.9 
         
The accompanying Notes to Financial Statements of Parent Company are an integral part of these statements. 
157
GREAT PLAINS ENERGY INCORPORATED 
Statements of Cash Flows of Parent Company 
          
Year Ended December 31 2009 2008 2007
Cash Flows from Operating Activities (millions)
Net income $150.1  $154.5  $159.2 
Adjustments to reconcile income to net cash from operating activities:            
Amortization  1.9   0.9   1.0 
Deferred income taxes, net  (6.1)  3.3   (6.2)
Equity in earnings from subsidiaries  (174.7)  (144.8)  (156.8)
Equity in (earnings) loss from discontinued operations  1.5   (35.0)  (38.3)
Cash flows affected by changes in:            
Accounts receivable from subsidiaries  3.7   (26.3)  0.6 
Taxes receivable  4.8   (8.7)  (1.8)
Accounts payable to subsidiaries  0.2   17.7   (4.8)
Other accounts payable  0.1   0.2   0.1 
Accrued interest  1.4   -   1.1 
Cash dividends from subsidiaries  94.0   416.7   159.7 
Other  8.8   2.7   1.8 
Net cash from operating activities  85.7   381.2   115.6 
Cash Flows from Investing Activities            
Equity contributions to subsidiaries  (455.0)  (200.0)  (94.0)
Net money pool lending  (0.9)  -   - 
Net change in notes receivable from subsidiaries  -   -   1.7 
GMO acquisition  -   (5.0)  - 
Purchases of nonutility property  -   (0.3)  (0.7)
Net cash from investing activities  (455.9)  (205.3)  (93.0)
Cash Flows from Financing Activities            
Issuance of common stock  219.9   15.3   10.5 
Issuance of long-term debt  287.5   -   99.5 
Issuance fees  (18.8)  (1.0)  (1.4)
Net change in notes payable to subsidiaries  -   -   (13.2)
Net change in short-term borrowings  (10.0)  (12.0)  42.0 
Equity forward settlement  -   -   (12.3)
Dividends paid  (110.5)  (172.0)  (144.5)
Other financing activities  (3.8)  (0.8)  (2.4)
Net cash from financing activities  364.3   (170.5)  (21.8)
Net Change in Cash and Cash Equivalents  (5.9)  5.4   0.8 
Cash and Cash Equivalents at Beginning of Year  12.0   6.6   5.8 
Cash and Cash Equivalents at End of Year $6.1  $12.0  $6.6 
             
The accompanying Notes to Financial Statements of Parent Company are an integral part of these statements. 


GREAT PLAINS ENERGY INCORPORATED
Statements of Common Shareholders’ Equity of Parent Company
Statements of Comprehensive Income of Parent Company

Incorporated by reference is Great Plains Energy Consolidated Statements of Common Shareholders’ Equity and Consolidated Statements of Comprehensive Income.

 
158163
 
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.

Schedule II – Valuation and Qualifying Accounts and Reserves
 
Great Plains Energy Incorporated
Valuation and Qualifying Accounts
Years Ended December 31, 2010, 2009 and 2008
                 
     Additions   
      Charged     
   Balance At To Costs Charged  Balance
   Beginning And To Other  At End
 Description Of Period Expenses Accounts DeductionsOf Period
Year Ended December 31, 2010 (millions)
 Allowance for uncollectible accounts $7.1  $9.7  $6.9(a) $16.7(b) $7.0 
 Legal reserves  5.1   7.0   -   1.9(c)  10.2 
 Environmental reserves  2.4   0.1   -   -   2.5 
 Tax valuation allowance  29.8   0.2   -   3.4(d)  26.6 
Year Ended December 31, 2009                    
 Allowance for uncollectible accounts $6.8  $8.7  $6.0(a) $14.4(b) $7.1 
 Legal reserves  10.2   2.6   -   7.7(c)  5.1 
 Environmental reserves  0.5   2.0   -   0.1   2.4 
 Tax valuation allowance  75.8   57.0   -   103.0(d)  29.8 
Year Ended December 31, 2008                    
 Allowance for uncollectible accounts $4.3  $7.6  $6.8(a) $11.9(b) $6.8 
 Legal reserves  2.2   8.3   9.5(e)  9.8(c)  10.2 
 Environmental reserves  0.3   -   0.2(e)  -   0.5 
 Tax valuation allowance  -   0.9   74.9(e)  -   75.8 
(a)Recoveries.  Charged to other accounts for the year ended December 31, 2008, includes the establishment of an allowance
 of $1.1 million and a $1.4 million increase due to the acquisition of GMO.
(b)Uncollectible accounts charged off.
(c)Payment of claims.
(d)Reversal of tax valuation allowance.
(e)Acquisition of GMO.
Great Plains Energy
Valuation and Qualifying Accounts
Years Ended December 31, 2009, 2008 and 2007
 
    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, 2009 (millions) 
 Allowance for uncollectible accounts  $         6.8  $        8.7  $        6.0(a) $          14.4(b) $         7.1 
 Legal reserves           10.2            2.6               -                7.7(c)            5.1 
 Environmental reserves             0.5            2.0               -                0.1             2.4 
 Tax valuation allowance           75.8          57.0               -            103.0(d)          29.8 
Year Ended December 31, 2008           
 Allowance for uncollectible accounts  $         4.3  $        7.6  $        6.8(a) $          11.9(b) $         6.8 
 Legal reserves             2.2            8.3            9.5(e)               9.8(c)          10.2 
 Environmental reserves             0.3               -            0.2(e)                 -             0.5 
 Tax valuation allowance                -            0.9          74.9(e)                 -           75.8 
Year Ended December 31, 2007           
 Allowance for uncollectible accounts  $         4.2  $        5.4  $        2.9(a) $            8.2(b) $         4.3 
 Legal reserves             3.9            1.9               -                3.6(c)            2.2 
 Environmental reserves             0.3               -               -                  -             0.3 
(a)Recoveries.  Charged to other accounts for the year ended December 31, 2008, includes the establishment of an allowance
 of $1.1 million and a $1.4 million increase due to the acquisition of GMO.
(b)Uncollectible accounts charged off.
(c)Payment of claims.
(d)Reversal of tax valuation allowance.
(e)Acquisition of GMO.
 
159164
 

Kansas City Power & Light Company
Valuation and Qualifying Accounts
Years Ended December 31, 2010, 2009 and 2008
 
     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, 2010 (millions)
 Allowance for uncollectible accounts $1.7  $6.2  $4.3(a) $10.7(b) $1.5 
 Legal reserves  2.3   1.9   -   1.2(c)  3.0 
 Environmental reserves  0.3   -   -   -   0.3 
Year Ended December 31, 2009                    
 Allowance for uncollectible accounts $1.2  $5.5  $3.9(a) $8.9(b) $1.7 
 Legal reserves  2.4   1.2   -   1.3(c)  2.3 
 Environmental reserves  0.3   -   -   -   0.3 
Year Ended December 31, 2008                    
 Allowance for uncollectible accounts $4.3  $5.9  $3.3(a) $12.3(b) $1.2 
 Legal reserves  2.2   3.2   -   3.0(c)  2.4 
 Environmental reserves  0.3   -   -   -   0.3 
(a)Recoveries.
(b)Uncollectible accounts charged off.
(c)Payment of claims.

Kansas City Power & Light Company
Valuation and Qualifying Accounts
Years Ended December 31, 2009, 2008 and 2007
            
     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, 2009  (millions)
 Allowance for uncollectible accounts  $           1.2  $        5.5  $        3.9(a) $            8.9(b) $         1.7
 Legal reserves               2.4            1.2               -                1.3(c)            2.3
 Environmental reserves               0.3               -               -                  -             0.3
Year Ended December 31, 2008          
 Allowance for uncollectible accounts  $           4.3  $        5.9  $        3.3(a) $          12.3(b) $         1.2
 Legal reserves               2.2            3.2               -                3.0(c)            2.4
 Environmental reserves               0.3               -               -                  -             0.3
Year Ended December 31, 2007          
 Allowance for uncollectible accounts  $           4.2  $        5.4  $        2.9(a) $            8.2(b) $         4.3
 Legal reserves               3.9            1.9               -                3.6(c)            2.2
 Environmental reserves               0.3               -               -                  -             0.3
(a)Recoveries.
(b)Uncollectible accounts charged off.
(c)Payment of claims.

 
160165
 
SIGNATURES
 
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
GREAT PLAINS ENERGY INCORPORATED
Date: February 25, 2010
By:  /s/Michael J. Chesser
Michael J. Chesser
Date: February 24, 2011                                                                                            By: /s/Michael J. Chesser
              Michael J. Chesser
Chairman of the Board and
Chief Executive Officer

Pursuant to the requirements of the Securities Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
 
SignatureTitle
Date
/s/Michael J. Chesser
Michael J. Chesser
Chairman of the Board and Chief
Executive Officer
(Principal Executive Officer)
)
)
)
  )
 
/s/Terry BasshamJames C. Shay
Terry BasshamJames C. Shay
ExecutiveSenior Vice President – Finance and
Strategic Development and
Chief Financial Officer
(Principal Financial Officer)
)
)
)
)
  )
/s/Lori A. Wright
Lori A. Wright
Vice President and Controller
(Principal Accounting Officer)
)
)
  )
David L. Bodde*Director)   February 25, 201024, 2011
  )
/s/William H. Downey
William H. Downey
Director
)
)
  )
Randall C. Ferguson, Jr.*Director)
  )
Gary D. Forsee*Director)
  )
James A. Mitchell*Director)
  )
William C. Nelson*Director)
  )
John J. Sherman*Director)
  )
Linda H. Talbott*Director)
  )
Robert H. West*Director)

*By         /s/Michael J. Chesser
Michael J. Chesser
Attorney-in-Fact*
 
161166
 
SIGNATURES
 
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
KANSAS CITY POWER & LIGHT COMPANY
Date: February 25, 2010                                                              24, 2011                                                                                    By: /s/Michael J. Chesser
Michael J. Chesser
             Michael J. Chesser
Chairman of the Board and
Chief Executive Officer

Pursuant to the requirements of the Securities Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
 
SignatureTitle
Date
/s/Michael J. Chesser
Michael J. Chesser
Chairman of the Board and Chief
Executive Officer
(Principal Executive Officer)
)
)
)
  )
/s/James C. Shay
/s/Terry Bassham
Terry BasshamJames C. Shay
ExecutiveSenior Vice President – Finance and
Strategic Development and
Chief Financial Officer
(Principal Financial Officer)
)
)
)
)
  )
/s/Lori A. Wright
Lori A. Wright
Vice President and Controller
(Principal Accounting Officer)
)
)
  )
David L. Bodde*Director)   February 25, 201024, 2011
  )
/s/ William H. Downey
William H. Downey
Director
)
)
  )
Randall C. Ferguson, Jr.*Director)
  )
Gary D. Forsee*Director)
  )
James A. Mitchell*Director)
  )
William C. Nelson*Director)
  )
John J. Sherman*Director)
  )
Linda H. Talbott*Director)
  )
*By         /s/Michael J. Chesser
Michael J. Chesser
Attorney-in-Fact*

 
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