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                                   Form 10-Q
                       SECURITIES AND EXCHANGE COMMISSION

                             Washington, D.C. 20549


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

                  For the quarterly period ended June 30, 2002

                                       or

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

                For the transition period from _______ to _______


Commission       Registrant, State of Incorporation,          I.R.S. Employer
File Number         Address and Telephone Number           Identification Number

  0-33207         GREAT PLAINS ENERGY INCORPORATED               43-1916803
                      (A Missouri Corporation)
                         1201 Walnut Street
                     Kansas City, Missouri 64106
                           (816) 556-2200

   1-707          KANSAS CITY POWER & LIGHT COMPANY              44-0308720
                      (A Missouri Corporation)
                         1201 Walnut Street
                     Kansas City, Missouri 64106
                           (816) 556-2200

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:

Registrant Title of each class Great Plains Energy Incorporated Cumulative Preferred Stock par value $100 per share 3.80% Cumulative Preferred Stock par value $100 per share 4.50% Cumulative Preferred Stock par value $100 per share 4.35% Common Stock without par value
Securities registered pursuant to Section 12(g) of the Act: None. 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. Yes X No The number of shares outstanding of the registrant's Common stock at August 9, 2002, was 61,908,574 shares. Great Plains Energy and KCP&L separately file this combined Quarterly Report on Form 10-Q. Information contained herein relating to an individual registrant and its subsidiaries is filed by such registrant on its own behalf. Each registrant makes representations only as to information relating to itself and its subsidiaries. This report should be read in its entirety. No one section of the report deals with all aspects of the subject matter. GLOSSARY OF TERMS The following is a glossary of frequently used abbreviations or acronyms that are found throughout this report: Abbreviation or Acronym Definition Clean Air Act Clean Air Act Amendments of 1990 CO2 Carbon Dioxide Consolidated KCP&L KCP&L and its subsidiary HSS COLI Corporate Owned Life Insurance DIP Debtor-in-Possession DTI DTI Holdings, Inc. and its subsidiary Digital Teleport Inc. EIRR Environmental Improvement Revenue Refunding EPA Environmental Protection Agency EPS Earnings per share FASB Financial Accounting Standards Board FERC Federal Energy Regulatory Commission GPP Great Plains Power Incorporated, a subsidiary of Great Plains Energy Incorporated HSS Home Service Solutions Inc., a subsidiary of KCP&L KCC The State Corporation Commission of the State of Kansas KCP&L Kansas City Power & Light Company, a regulated, integrated electric utility subsidiary of Great Plains Energy Incorporated MACT Maximum Achievable Control Technology MISO Midwest Independent System Operator MPSC Missouri Public Service Commission NEIL Nuclear Electric Insurance Limited NRC Nuclear Regulatory Commission NOx Nitrogen Oxide PCBs Polychlorinated biphenyls RSAE R.S. Andrews Enterprises, Inc. a consumer services company in which HSS owns a 72% equity interest Receivables Company Kansas City Power & Light Receivables Company RTO Regional Transmission Organization SPP Southwest Power Pool SFAS Statement of Financial Accounting Standards WCNOC Wolf Creek Nuclear Operating Corporation 2 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. In connection with the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, the registrants are providing a number of important factors that could cause actual results to differ materially from provided forward-looking information. These important factors include: o future economic conditions in the regional, national and international markets o state, federal and foreign regulation o weather conditions including weather-related damage o cost of fuel o financial market conditions including, but not limited to, changes in interest rates o inflation rates o increased competition including, but not limited to, the deregulation of the electric utility industry and the entry of new competitors o ability to carry out marketing and sales plans o ability to achieve generation planning goals and the occurrence of unplanned generation outages o nuclear operations o ability to enter new markets successfully and capitalize on growth opportunities in nonregulated businesses o adverse changes in applicable laws, regulations or rules governing environmental regulations (including air quality), tax or accounting matters o delays in the anticipated in-service dates of additional generating capacity o performance of projects undertaken by our non-regulated businesses and the success of efforts to invest in and develop new opportunities o non-performance of counterparties o impact of terrorist acts o availability and cost of capital and o other risks and uncertainties. This list of factors is not all-inclusive because it is not possible to predict all possible factors. 3 PART I - FINANCIAL INFORMATION Item 1. Consolidated Financial Statements GREAT PLAINS ENERGY Consolidated Balance Sheets (Unaudited) June 30 December 31 2002 2001 (thousands) ASSETS Current Assets Cash and cash equivalents $ 30,743 $ 29,034 Receivables 219,317 152,114 Fuel inventories, at average cost 25,514 22,246 Materials and supplies, at average cost 50,815 50,696 Current income taxes 40,548 31,031 Deferred income taxes 743 5,061 Other 18,496 19,167 Total 386,176 309,349 Nonutility Property and Investments Affordable housing limited partnerships 72,251 81,136 Gas property and investments 46,840 43,385 Nuclear decommissioning trust fund 62,834 61,766 Other 70,983 63,616 Total 252,908 249,903 Utility Plant, at Original Cost Electric 4,397,314 4,332,464 Less-accumulated depreciation 1,845,264 1,793,786 Net utility plant in service 2,552,050 2,538,678 Construction work in progress 37,768 51,265 Nuclear fuel, net of amortization of $114,736 and $127,101 28,650 33,771 Total 2,618,468 2,623,714 Deferred Charges Regulatory assets 141,135 124,406 Prepaid pension costs 87,140 88,337 Goodwill 34,066 37,066 Other deferred charges 34,973 30,724 Total 297,314 280,533 Total $ 3,554,866 $ 3,463,499 LIABILITIES AND CAPITALIZATION Current Liabilities Notes payable $ 215,311 $ 144,404 Commercial paper 94,920 62,000 Current maturities of long-term debt 29,487 238,767 EIRR bonds classified as current 177,500 177,500 Accounts payable 178,779 173,956 Accrued taxes 24,034 14,324 Accrued interest 18,230 13,262 Accrued payroll and vacations 24,082 26,422 Accrued refueling outage costs 1,906 12,979 Other 27,674 35,810 Total 791,923 899,424 Deferred Credits and Other Liabilities Deferred income taxes 609,890 594,704 Deferred investment tax credits 43,657 45,748 Accrued nuclear decommissioning costs 64,122 63,040 Other 117,561 114,085 Total 835,230 817,577 Capitalization (see statements) 1,927,713 1,746,498 Commitments and Contingencies (Note 7) Total $ 3,554,866 $ 3,463,499 The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 4 GREAT PLAINS ENERGY Consolidated Statements of Capitalization (Unaudited)
June 30 December 31 2002 2001 (thousands) Long-term Debt (excluding current maturities) General Mortgage Bonds Medium-Term Notes due 2004-08, 7.37%* and 7.28%** weighted-average rate $ 159,000 $ 179,000 2.90%* and 2.71%** EIRR bonds due 2012-23 158,768 158,768 EIRR bonds classified as current liabilities (31,000) (31,000) Senior Notes 7.125% due 2005 250,000 250,000 6.500% due 2011 150,000 150,000 6.000% due 2007 225,000 - Unamortized discount (1,027) (660) EIRR bonds 3.25%*** Series A & B due 2015 106,500 106,500 3.25%*** Series D due 2017 40,000 40,000 EIRR bonds classified as current liabilities (146,500) (146,500) 4.50%*** Series C due 2017 50,000 50,000 Subsidiary Obligations R.S. Andrews Enterprises, Inc. long-term debt 8.03%* and 8.14%** weighted-average rate due 2003-07 2,933 2,832 Affordable Housing Notes 7.83%* and 8.16%** weighted-average rate due 2003-08 11,197 19,746 Total 974,871 778,686 Company-obligated Mandatorily Redeemable Preferred Securities of a trust holding solely KCP&L Subordinated Debentures 150,000 150,000 Cumulative Preferred Stock $100 Par Value 3.80% - 100,000 shares issued 10,000 10,000 4.50% - 100,000 shares issued 10,000 10,000 4.20% - 70,000 shares issued 7,000 7,000 4.35% - 120,000 shares issued 12,000 12,000 Total 39,000 39,000 Common Stock Equity Common stock-150,000,000 shares authorized without par value 61,908,726 shares issued, stated value 449,697 449,697 Capital stock premium and expense (1,632) (1,656) Retained earnings (see statements) 322,693 344,815 Treasury stock (4) (903) Accumulated other comprehensive loss Loss on derivative hedging instruments (5,881) (12,110) Minimum pension liability (1,031) (1,031) Total 763,842 778,812 Total $ 1,927,713 $ 1,746,498
* Weighted-average rate as of June 30, 2002 ** Weighted-average rate as of December 31, 2001 *** Weighted-average rate as of June 30, 2002 and December 31, 2001 The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 5 GREAT PLAINS ENERGY Consolidated Statements of Income (Unaudited)
Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (thousands) Operating Revenues Electric revenues - KCP&L $ 247,229 $ 237,564 $ 446,138 $ 436,386 Electric revenues - Strategic Energy 200,973 80,268 346,987 130,583 Other revenues 17,162 28,738 31,045 59,791 Total 465,364 346,570 824,170 626,760 Operating Expenses Fuel 35,350 39,589 69,357 72,303 Purchased power - KCP&L 12,301 13,875 23,232 38,045 Purchased power - Strategic Energy 175,881 64,644 300,873 109,173 Gas purchased and production expenses 737 4,960 1,589 17,115 Other 81,414 85,059 158,618 164,859 Maintenance 20,774 20,444 55,708 41,753 Depreciation and depletion 37,301 39,991 74,732 76,622 General taxes 23,240 22,562 46,401 45,414 Total 386,998 291,124 730,510 565,284 Gain on property (108) (20,398) (67) (21,706) Total 386,890 270,726 730,443 543,578 Operating income 78,474 75,844 93,727 83,182 Gain (loss) from equity investments (316) 424 (632) (112) Minority interest in subsidiaries (2,918) (1,606) (5,355) 1,179 Non-operating income 2,363 3,943 3,580 7,459 Non-operating expenses (4,293) (1,688) (12,675) (9,169) Interest charges 23,540 25,615 44,338 49,836 Income before income taxes, extraordinary item and cumulative effect of a change in accounting principle 49,770 51,302 34,307 32,703 Income taxes 13,803 15,070 1,237 (557) Income before extraordinary item and cumulative effect of a change in accounting principle 35,967 36,232 33,070 33,260 Early extinguishment of debt, net of income taxes - - - 15,872 Cumulative effect to January 1, 2002, of a change in accounting principle - - (3,000) - Net income 35,967 36,232 30,070 49,132 Preferred stock dividend requirements 411 412 823 824 Earnings available for common stock $ 35,556 $ 35,820 $ 29,247 $ 48,308 Average number of common shares outstanding 61,909 61,855 61,897 61,855 Basic and diluted earnings per common share before extraordinary item and cumulative effect of a change in accounting principle $ 0.57 $ 0.58 $ 0.52 $ 0.52 Early extinguishment of debt - - - 0.26 Cumulative effect to January 1, 2002, of a change in accounting principle - - (0.05) - Basic and diluted earnings per common share $ 0.57 $ 0.58 $ 0.47 $ 0.78 Cash dividends per common share $ 0.415 $ 0.415 $ 0.83 $ 0.83
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 6 GREAT PLAINS ENERGY Consolidated Statements of Cash Flows (Unaudited)
Year to Date June 30 2002 2001 (thousands) Cash Flows from Operating Activities Net income $ 30,070 $ 49,132 Adjustments to reconcile income to net cash from operating activities: Early extinguishment of debt, net of income taxes - (15,872) Cumulative effect of a change in accounting principle 3,000 - Depreciation and depletion 74,732 76,622 Amortization of: Nuclear fuel 5,894 8,428 Other 4,968 8,561 Deferred income taxes (net) 15,167 346 Investment tax credit amortization (2,091) (2,145) Loss from equity investments 632 112 Gain on property (67) (21,706) Allowance for equity funds used during construction 16 (3,646) Deferred storm costs (19,518) - Other operating activities (Note 3) (60,120) (93,223) Net cash from operating activities 52,683 6,609 Cash Flows from Investing Activities Utility capital expenditures (66,603) (120,010) Allowance for borrowed funds used during construction (452) (7,698) Purchases of investments (5,421) (40,653) Purchases of nonutility property (7,185) (37,168) Proceeds from sale of assets 1,621 62,485 Hawthorn No. 5 partial insurance recovery - 30,000 Loan to DTI prior to majority ownership - (94,000) Other investing activities (7,697) 8,124 Net cash from investing activities (85,737) (198,920) Cash Flows from Financing Activities Issuance of long-term debt 224,640 94,000 Repayment of long-term debt (237,829) (63,320) Net change in short-term borrowings 103,827 197,151 Dividends paid (52,192) (52,164) Other financing activities (3,683) (436) Net cash from financing activities 34,763 175,231 Net Change in Cash and Cash Equivalents 1,709 (17,080) Cash and Cash Equivalents at Beginning of Year 29,034 34,877 Cash and Cash Equivalents at End of Period $ 30,743 $ 17,797 The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
7 GREAT PLAINS ENERGY Consolidated Statements of Comprehensive Income (Unaudited)
Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (thousands) Net income $ 35,967 $ 36,232 $ 30,070 $ 49,132 Other comprehensive income: Gain (loss) on derivative hedging instruments (43) (31,578) 5,800 (34,168) Income taxes 13 13,127 (2,378) 14,207 Net gain (loss) on derivative hedging instruments (30) (18,451) 3,422 (19,961) Reclassification to revenues and expenses, net of tax 1,367 (4,333) 2,807 (8,340) Comprehensive income before cumulative effect of a change in accounting principles, net of income taxes 37,304 13,448 36,299 20,831 Cumulative effect to January 1, 2001, of a change in accounting principles, net of income taxes - - - 17,443 Comprehensive income $ 37,304 $ 13,448 $ 36,299 $ 38,274
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. GREAT PLAINS ENERGY Consolidated Statements of Retained Earnings (Unaudited)
Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (thousands) Beginning balance (Note 8) $312,829 $460,139 $344,815 $473,321 Net income 35,967 36,232 30,070 49,132 348,796 496,371 374,885 522,453 Dividends declared Preferred stock - at required rates 411 412 823 824 Common stock 25,692 25,670 51,369 51,340 Ending balance $322,693 $470,289 $322,693 $470,289
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 8 KANSAS CITY POWER & LIGHT COMPANY Consolidated Balance Sheets (Unaudited) June 30 December 31 2002 2001 (thousands) ASSETS Current Assets Cash and cash equivalents $ 1,308 $ 962 Receivables 82,902 62,511 Fuel inventories, at average cost 25,514 22,246 Materials and supplies, at average cost 50,815 50,696 Deferred income taxes 743 5,061 Other 15,685 11,484 Total 176,967 152,960 Nonutility Property and Investments Nuclear decommissioning trust fund 62,834 61,766 Other 45,415 40,797 Total 108,249 102,563 Utility Plant, at Original Cost Electric 4,397,314 4,332,464 Less-accumulated depreciation 1,845,264 1,793,786 Net utility plant in service 2,552,050 2,538,678 Construction work in progress 37,768 51,265 Nuclear fuel, net of amortization of $114,736 and $127,101 28,650 33,771 Total 2,618,468 2,623,714 Deferred Charges Regulatory assets 141,135 124,406 Prepaid pension costs 87,140 88,337 Goodwill 19,952 22,952 Other deferred charges 28,038 30,724 Total 276,265 266,419 Total $ 3,179,949 $ 3,145,656 LIABILITIES AND CAPITALIZATION Current Liabilities Notes payable $ 23,311 $ 20,404 Commercial paper 94,920 62,000 Current maturities of long-term debt 20,351 227,383 EIRR bonds classified as current 177,500 177,500 Accounts payable 79,096 113,029 Accrued taxes 23,673 15,895 Accrued interest 17,779 11,327 Accrued payroll and vacations 22,240 22,581 Accrued refueling outage costs 1,906 12,979 Other 13,595 14,562 Total 474,371 677,660 Deferred Credits and Other Liabilities Deferred income taxes 643,339 630,699 Deferred investment tax credits 43,657 45,748 Accrued nuclear decommissioning costs 64,122 63,040 Other 79,840 75,186 Total 830,958 814,673 Capitalization (see statements) 1,874,620 1,653,323 Commitments and Contingencies (Note 7) Total $ 3,179,949 $ 3,145,656 The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 9 KANSAS CITY POWER & LIGHT COMPANY Consolidated Statements of Capitalization (Unaudited)
June 30 December 31 2002 2001 (thousands) Long-term Debt (excluding current maturities) General Mortgage Bonds Medium-Term Notes due 2004-08, 7.37%* and 7.28%** weighted-average rate $ 159,000 $ 179,000 2.90%* and 2.71%** EIRR bonds due 2012-23 158,768 158,768 EIRR bonds classified as current liabilities (31,000) (31,000) Senior Notes 7.125% due 2005 250,000 250,000 6.500% due 2011 150,000 150,000 6.000% due 2007 225,000 - Unamortized discount (1,027) (660) EIRR bonds 3.25%*** Series A & B due 2015 106,500 106,500 3.25%*** Series D due 2017 40,000 40,000 EIRR bonds classified as current liabilities (146,500) (146,500) 4.50%*** Series C due 2017 50,000 50,000 Subsidiary Obligations R.S. Andrews Enterprises, Inc. long-term debt 8.03%* and 8.14%** weighted-average rate due 2003-07 2,933 2,832 Total 963,674 758,940 Company-obligated Mandatorily Redeemable Preferred Securities of a trust holding solely KCP&L Subordinated Debentures 150,000 150,000 Common Stock Equity Common stock-1,000 shares authorized without par value 1 share issued, stated value 562,041 526,041 Retained earnings (see statements) 199,897 219,524 Accumulated other comprehensive income (loss) Income (loss) on derivative hedging instruments 39 (151) Minimum pension liability (1,031) (1,031) Total 760,946 744,383 Total $ 1,874,620 $ 1,653,323
* Weighted-average rate as of June 30, 2002 ** Weighted-average rate as of December 31, 2001 *** Weighted-average rate as of June 30, 2002 and December 31, 2001 The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 10 KANSAS CITY POWER & LIGHT COMPANY Consolidated Statements of Income (Unaudited)
Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (thousands) Operating Revenues Electric revenues $ 247,229 $ 317,832 $ 446,138 $ 566,969 Other revenues 17,018 28,738 30,294 59,791 Total 264,247 346,570 476,432 626,760 Operating Expenses Fuel 35,350 39,589 69,357 72,303 Purchased power 12,301 78,519 23,232 147,218 Gas purchased and production expenses - 4,960 - 17,115 Other 69,276 85,059 135,345 164,859 Maintenance 20,741 20,444 55,638 41,753 Depreciation and depletion 36,940 39,991 73,819 76,622 General taxes 22,927 22,562 45,750 45,414 Total 197,535 291,124 403,141 565,284 Gain on property (183) (20,398) (305) (21,706) Total 197,352 270,726 402,836 543,578 Operating income 66,895 75,844 73,596 83,182 Income (loss) from equity investments - 424 - (112) Minority interest in subsidiaries - (1,606) - 1,179 Non-operating income 1,889 3,943 2,750 7,459 Non-operating expenses (2,346) (1,688) (5,003) (9,169) Interest charges 21,543 25,615 40,955 49,836 Income before income taxes, extraordinary item and cumulative effect of a change in accounting principle 44,895 51,302 30,388 32,703 Income taxes 17,864 15,070 11,338 (557) Income before extraordinary item and cumulative effect of a change in accounting principle 27,031 36,232 19,050 33,260 Early extinguishment of debt, net of income taxes - - - 15,872 Cumulative effect to January 1, 2002, of a change in accounting principle - - (3,000) - Net income 27,031 36,232 16,050 49,132 Preferred stock dividend requirements - 412 - 824 Earnings available for common stock $ 27,031 $ 35,820 $ 16,050 $ 48,308
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 11 KANSAS CITY POWER & LIGHT COMPANY Consolidated Statements of Cash Flows (Unaudited) Year to date June 30 2002 2001 (thousands) Cash Flows from Operating Activities Net income $ 16,050 $ 49,132 Adjustments to reconcile income to net cash from operating activities: Early extinguishment of debt, net of income taxes - (15,872) Cumulative effect of a change in accounting principle 3,000 - Depreciation and depletion 73,819 76,622 Amortization of: Nuclear fuel 5,894 8,428 Other 3,511 8,561 Deferred income taxes (net) 16,836 346 Investment tax credit amortization (2,091) (2,145) Loss from equity investments - 112 Gain on property (305) (21,706) Allowance for equity funds used during construction 16 (3,646) Deferred storm costs (19,518) - Other operating activities (Note 3) (50,950) (93,223) Net cash from operating activities 46,262 6,609 Cash Flows from Investing Activities Utility capital expenditures (66,603) (120,010) Allowance for borrowed funds used during construction (452) (7,698) Purchases of investments (1,711) (40,653) Purchases of nonutility property (1,613) (37,168) Proceeds from sale of assets - 62,485 Hawthorn No. 5 partial insurance recovery - 30,000 Loan to DTI prior to majority ownership - (94,000) Other investing activities (7,728) 8,124 Net cash from investing activities (78,107) (198,920) Cash Flows from Financing Activities Issuance of long-term debt 224,640 94,000 Repayment of long-term debt (227,032) (63,320) Net change in short-term borrowings 35,827 197,151 Dividends paid - (52,164) Dividends paid to Great Plains Energy (35,677) - Equity contribution from Great Plains Energy 36,000 - Other financing activities (1,567) (436) Net cash from financing activities 32,191 175,231 Net Change in Cash and Cash Equivalents 346 (17,080) Cash and Cash Equivalents at Beginning of Year 962 34,877 Cash and Cash Equivalents at End of Period $ 1,308 $ 17,797 The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 12 KANSAS CITY POWER & LIGHT COMPANY Consolidated Statements of Comprehensive Income (Unaudited)
Three months ended Year to date June 30 June 30 2002 2001 2002 2001 (thousands) Net income $ 27,031 $ 36,232 $ 16,050 $ 49,132 Other comprehensive income: Gain (loss) on derivative hedging instruments (186) (31,578) 422 (34,168) Income taxes 72 13,127 (165) 14,207 Net gain (loss) on derivative hedging instruments (114) (18,451) 257 (19,961) Reclassification to revenues and expenses, net of tax (104) (4,333) (67) (8,340) Comprehensive income before cumulative effect of a change in accounting principles, net of income taxes 26,813 13,448 16,240 20,831 Cumulative effect to January 1, 2001, of a change in accounting principles, net of income taxes - - - 17,443 Comprehensive income $ 26,813 $ 13,448 $ 16,240 $ 38,274
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. KANSAS CITY POWER & LIGHT COMPANY Consolidated Statements of Retained Earnings (Unaudited)
Three months ended Year to date June 30 June 30 2002 2001 2002 2001 (thousands) Beginning balance (Note 8) $182,866 $460,139 $219,524 $473,321 Net income 27,031 36,232 16,050 49,132 209,897 496,371 235,574 522,453 Dividends declared Preferred stock - at required rates - 412 - 824 Common stock - 25,670 - 51,340 Common stock held by Great Plains Energy 10,000 - 35,677 - Ending balance $199,897 $470,289 $199,897 $470,289
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements. 13 GREAT PLAINS ENERGY INCORPORATED KANSAS CITY POWER & LIGHT COMPANY Notes to Consolidated Financial Statements In management's opinion, the consolidated interim financial statements reflect all adjustments (which include only normal recurring adjustments) necessary to present fairly the results of operations for the interim periods presented. These statements and notes should be read in connection with the financial statements and related notes included in our combined 2001 annual report on Form 10-K. The notes to consolidated financial statements that follow are a combined presentation for Great Plains Energy and consolidated KCP&L, both registrants under this filing. 1. ORGANIZATION Great Plains Energy (The Company) Great Plains Energy's consolidated financial statements include consolidated KCP&L, KLT Inc. and GPP. KLT Inc.'s major holdings consist of Strategic Energy, KLT Gas, and investments in affordable housing limited partnerships. GPP's assets and results of operations are insignificant to Great Plains Energy's financial position and results of operations for all periods presented. During the second quarter of 2002, the Company's management revised its corporate business strategy. As a result of this revision, management has decided to limit the operations of GPP until market conditions improve, or the Company makes changes in its business strategy. Effective October 1, 2001, KCP&L distributed, as a dividend, its 100% ownership of KLT Inc. and GPP to Great Plains Energy. As a result, those companies are subsidiaries of Great Plains Energy and are not included in consolidated KCP&L's results of operations and financial position since that date. The presentation of the prior year results of operations for Great Plains Energy is provided for comparative purposes and is identical to the results of operations for consolidated KCP&L, prior to formation of the holding company, presented for that year. Intercompany balances and transactions have been eliminated in consolidation. Consolidated KCP&L KCP&L's consolidated financial statements include its wholly owned subsidiary HSS. HSS has two subsidiaries: Worry Free Service, Inc. and RSAE. In addition, KCP&L's consolidated results of operations include KLT Inc. and GPP for all periods prior to the October 1, 2001, formation of the holding company. 14 Strategic Energy Revenues and Purchased Power Reclassified Great Plains Energy retail electric revenues and purchased power have been reduced by $5.8 million for the three months ended March 31, 2002 to reflect Strategic Energy's policy of reflecting customer credits as a reduction of electricity energy sales when such credits are determined to be payable. Similarly, retail electric revenues and purchased power reported in the second quarter 2002 earnings press release have been reduced by $4.3 million and $10.1 million for the three months ended and year to date June 30, 2002, respectively. The table below details the originally reported amounts and the reclassification.
Three Months Three Months Ended Ended Year to Date March 30 June 30 June 30 2002 (a) 2002 (b) 2002 (b) (millions) Operating revenues- Strategic Energy, as reported $ 152.2 $ 205.5 $ 357.7 Reclassification (5.8) (4.3) (10.1) Operating revenues - Strategic Energy $ 146.4 $ 201.2 $ 347.6 Purchased power - Strategic Energy, as reported $ 130.8 $ 180.2 $ 311.0 Reclassification (5.8) (4.3) (10.1) Purchased power - Strategic Energy $ 125.0 $ 175.9 $ 300.9
(a) As reported in Form 10-Q for the period ended March 30, 2002 and on Form 8-K dated April 24, 2002. (b) As reported in the press release dated July 24, 2002 for the period ended June 30, 2002. 2. RESTRICTED CASH Strategic Energy has entered into performance assurance agreements with selected electricity power suppliers. As part of the agreements, Strategic Energy has directed selected retail customers to remit payment to lockboxes that are held in trust and managed by a Trustee, agreed upon by both the supplier and Strategic Energy. As part of the trust administration, the Trustee remits payment to the supplier for electricity purchased by Strategic Energy during the month according to the supplier payment terms. Any excess remittances into the lockboxes are remitted back to Strategic Energy after the disbursement to the supplier has been made. The assets of the Trust are included in cash and cash equivalents in the Great Plains Energy consolidated balance sheets and totaled $14.1 million at June 30, 2002 and $2.2 million at December 31, 2001. 15 3. SUPPLEMENTAL CASH FLOW INFORMATION Great Plains Energy Other Operating Activities Year to Date June 30 2002 2001 Cash flows affected by changes in: (thousands) Receivables $ (67,203) $ (60,076) Fuel inventories (3,102) (3,107) Materials and supplies (119) (1,326) Accounts payable 4,823 (41,118) Accrued taxes and current income taxes 193 3,568 Accrued interest 4,968 472 Wolf Creek refueling outage accrual (11,073) 5,670 Pension and postretirement benefit obligations (20) (14,051) Other 11,413 16,745 Total other operating activities $ (60,120) $ (93,223) Cash paid during the period: Interest $ 38,295 $ 41,178 Income taxes $ 5,753 $ 8,624 Consolidated KCP&L Other Operating Activities Year to Date June 30 2002 2001 Cash flows affected by changes in: (thousands) Receivables $ (20,391) $ (60,076) Fuel inventories (3,102) (3,107) Materials and supplies (119) (1,326) Accounts payable (33,933) (41,118) Accrued taxes 7,778 3,568 Accrued interest 6,452 472 Wolf Creek refueling outage accrual (11,073) 5,670 Pension and postretirement benefit obligations (20) (14,051) Other 3,458 16,745 Total other operating activities $ (50,950) $ (93,223) Cash paid during the period: Interest $ 33,428 $ 41,178 Income taxes $ 1,800 $ 8,624 During the first quarter of 2001, KLT Telecom, a wholly owned subsidiary of KLT Inc., increased its equity ownership in DTI to a majority ownership and HSS increased its equity ownership in RSAE to a majority ownership. The effect of these transactions is summarized in the tables that follow. The initial consolidation of DTI (February 8, 2001) and RSAE (January 1, 2001) are excluded from both Great 16 Plains Energy and KCP&L's consolidated statement of cash flows year to date June 30, 2001. See Note 11 for discussion of DTI's bankruptcy. DTI RSAE (thousands) Cash paid to obtain majority ownership $ (39,855) $ (560) Subsidiary cash 4,557 1,053 Purchase of DTI and RSAE, net of cash received $ (35,298) $ 493 Initial consolidation of subsidiaries: Assets Cash $ 4,557 $ 1,053 Receivables 1,012 4,078 Other nonutility property and investments 363,825 6,267 Goodwill 62,974 24,496 Other assets 5,143 3,919 Eliminate equity investment (67,660) (7,200) Total assets $ 369,851 $ 32,613 Liabilities Notes payable $ 5,300 $ 10,057 Accounts payable 31,299 6,219 Accrued taxes 2,414 24 Deferred income taxes 7,437 - Other liabilities and deferred credits 46,531 13,418 Loan from KLT Telecom (a) 94,000 - Long-term debt 182,870 2,895 Total liabilities $ 369,851 $ 32,613 (a) KLT Telecom provided a $94 million loan to DTI for the completion of the tender offer of 50.4 percent of DTI's Senior Discount Notes prior to increasing its DTI investment to a majority ownership. 4. CAPITALIZATION KCP&L Financing I (Trust) has previously issued $150.0 million of 8.3% preferred securities. The sole asset of the Trust is the $154.6 million principal amount of 8.3% Junior Subordinated Deferrable Interest Debentures, due 2037, issued by KCP&L. In March 2002, KCP&L issued $225 million of 6.0% unsecured senior notes, maturing in 2007, through a private placement. The proceeds from the issuance were primarily used to refinance maturing unsecured medium-term notes. KCP&L, pursuant to its obligations under a registration rights agreement entered into in connection with the private placement, filed an S-4 registration statement offering to exchange up to $225 million of 6.0% unsecured senior notes registered under the Securities Act for the $225 million privately placed notes. KCP&L expects the registration statement to become effective during the third quarter. During the first quarter of 2002, Great Plains Energy terminated its $129 million bridge revolving credit facility. Great Plains Energy replaced the bridge facility with a $205 million syndicated 364-day, revolving credit facility with a group of banks. During June 2002, Great Plains Energy entered into a separate $20 million 364-day revolving credit facility with a bank. At June 30, 2002, Great Plains Energy had $192.0 million of borrowings, at an average interest rate of 2.725%, outstanding under the facilities. 17 In March 2002, Great Plains Energy made a $36 million capital contribution to KCP&L increasing capital stock premium and expense to $75 million, which is reflected in Common stock in the KCP&L consolidated statement of capitalization. Great Plains Energy filed an S-3 registration statement on April 29, 2002, for the issuance of an aggregate amount up to $300 million of any combination of senior debt securities, subordinated debt securities, trust preferred securities, convertible securities, or common stock. Great Plains Energy has previously announced its plans to issue additional common equity. The timing and amount of this transaction is dependent on a number of factors, including overall and sector-specific equity market conditions. 5. SEGMENT AND RELATED INFORMATION Great Plains Energy Great Plains Energy has three reportable segments based on its method of internal reporting, which generally segregates the reportable segments based on products and services, management responsibility and regulation. During the second quarter of 2002, the Company's management revised its corporate business strategy focusing on the following three primary business segments: (1) KCP&L, an integrated electric utility, generates, transmits and distributes electricity; (2) Strategic Energy earns a management fee on the direct delivery to retail customers under long-term contracts of wholesale power purchased under long-term contracts while operating in several deregulated electricity markets; and (3) KLT Gas acquires and develops early stage coal bed methane properties. "Other" includes the operations of HSS and GPP, all KLT Inc. operations other than Strategic Energy and KLT Gas, unallocated corporate charges and intercompany eliminations. The summary of significant accounting policies applies to all of the reportable segments. Segment performance is evaluated based on net income. The tables below reflect summarized financial information concerning Great Plains Energy's reportable segments. Prior year information has been restated to conform to the current presentation.
For the three months ended Strategic Great Plains June 30, 2002 KCP&L Energy KLT Gas Other Energy (millions) Operating revenues $247.2 $201.2 $ (0.1) $ 17.1 $ 465.4 Depreciation and depletion (36.1) (0.2) (0.1) (0.9) (37.3) Interest charges (21.1) (0.1) - (2.3) (23.5) Loss from equity investments - - - (0.3) (0.3) Income taxes (17.9) (5.8) 2.5 7.4 (13.8) Net income (loss) 27.3 8.2 (0.3) 0.8 36.0
For the three months ended Strategic Great Plains June 30, 2001 KCP&L Energy KLT Gas Other Energy (millions) Operating revenues $237.6 $ 85.1 $ 0.4 $ 23.4 $ 346.5 Depreciation and depletion (33.8) (0.1) (0.4) (5.7) (40.0) Interest charges (18.3) - - (7.3) (25.6) Income (loss) from equity investments - - 0.9 (0.5) 0.4 Income taxes (14.4) (4.4) (5.3) 9.0 (15.1) Net income (loss) 23.4 6.3 11.9 (5.4) 36.2
18
Strategic Great Plains Year to date June 30, 2002 KCP&L Energy KLT Gas Other Energy (millions) Operating revenues $446.1 $347.6 $ 0.1 $ 30.4 $ 824.2 Depreciation and depletion (71.9) (0.4) (0.4) (2.0) (74.7) Interest charges (40.1) (0.2) - (4.0) (44.3) Loss from equity investments - - - (0.6) (0.6) Income taxes (11.3) (10.6) 4.8 15.9 (1.2) Cumulative effect of a change in accounting principle - - - (3.0) (3.0) Net income (loss) 20.4 15.1 (0.4) (5.0) 30.1
Strategic Great Plains Year to date June 30, 2001 KCP&L Energy KLT Gas Other Energy (millions) Operating revenues $436.4 $146.0 $ 1.9 $ 42.4 $ 626.7 Depreciation and depletion (66.5) (0.1) (1.0) (9.0) (76.6) Interest charges (37.7) (0.1) - (12.0) (49.8) Income (loss) from equity investments - - 1.0 (1.1) (0.1) Income taxes (10.1) (5.1) (3.5) 19.2 0.5 Early extinguishment of debt - - - 15.9 15.9 Net income 21.3 7.3 13.3 7.2 49.1
Strategic KLT Great Plains KCP&L Energy Gas Other Energy June 30, 2002 (millions) Assets(a) $ 3,123.9 $ 183.1 $ 54.8 $ 193.1 $ 3,554.9 Capital and investment expenditures (b) 68.3 0.6 4.6 5.7 79.2 December 31, 2001 Assets(a) $ 3,089.4 $ 129.1 $ 57.6 $ 187.4 $ 3,463.5 Capital and investment expenditures (b) 265.8 1.5 25.0 82.0 374.3
(a) KCP&L assets do not match the KCP&L assets in the consolidated KCP&L segment table due to the reclassification of accrued taxes to current income taxes during consolidation with Great Plains Energy. (b) Capital and investment expenditures reflect year to date amounts for the periods presented. Consolidated KCP&L On October 1, 2001, consolidated KCP&L distributed, as a dividend, its ownership interest in KLT Inc. and GPP to Great Plains Energy. As a result, those companies are direct subsidiaries of Great Plains Energy and have not been included in consolidated KCP&L's results of operations and financial position since October 1, 2001. 19 The table below reflects summarized financial information for the three months ended and year to date June 30, 2002, concerning consolidated KCP&L's reportable segment. For the three months ended and year to date June 30, 2001, consolidated KCP&L's segment information is identical to the Great Plains Energy segment information presented above. For the three months ended Consolidated June 30, 2002 KCP&L Other KCP&L (millions) Operating revenues $ 247.2 $ 17.0 $ 264.2 Depreciation and depletion (36.1) (0.8) (36.9) Interest charges (21.1) (0.5) (21.6) Income taxes (17.9) 0.1 (17.8) Net income (loss) 27.3 (0.2) 27.1 Consolidated Year to date June 30, 2002 KCP&L Other KCP&L (millions) Operating revenues $ 446.1 $ 30.3 $ 476.4 Depreciation and depletion (71.9) (1.9) (73.8) Interest charges (40.1) (0.9) (41.0) Income taxes (11.3) - (11.3) Cumulative effect of a change in accounting principle - (3.0) (3.0) Net income (loss) 20.4 (4.3) 16.1 Consolidated KCP&L Other KCP&L June 30, 2002 (millions) Assets $ 3,125.2 $ 54.7 $ 3,179.9 Capital and investment expenditures (a) 68.3 1.6 69.9 December 31, 2001 Assets $ 3,092.5 $ 53.1 $ 3,145.6 Capital and investment expenditures (a) 265.8 87.0 352.8 (a) Capital and investment expenditures reflect year to date amounts for the periods presented. 6. RELATED PARTY TRANSACTIONS AND RELATIONSHIPS In January of 1997, KLT Energy Services, a wholly-owned subsidiary of KLT Inc., acquired approximately 71% of Custom Energy from Environmental Lighting Concepts. In February of 1999, Custom Energy acquired 100% of the outstanding ownership interest in Strategic Energy in exchange for 25% of the ownership interest in Custom Energy. In a December 1999 reorganization, Custom Energy changed its name to Custom Energy Holdings and transferred all of its operations to a new wholly owned subsidiary called Custom Energy. After the reorganization, Custom Energy Holdings' assets consisted of its ownership interests in Strategic Energy and Custom Energy. Through a series of transactions, KLT Energy Services has increased its indirect ownership position in Strategic Energy to approximately 83% as of December 31, 2001. In a July 2002 transaction, Custom Energy was distributed to KLT Energy Services and a third-party investor, resulting in Strategic Energy being the sole subsidiary of Custom Energy Holdings. Environmental Lighting Concepts continues to own a 5.8% indirect ownership interest in Strategic Energy. Gregory Orman, Executive Vice President of Corporate Development and Strategic Planning of Great Plains Energy and President and CEO of KLT Inc., holds a 67% interest in Environmental Lighting Concepts. 20 Custom Energy Holdings' business and affairs are controlled and managed by a three member Management Committee composed of one representative designated by KLT Energy Services, one representative designated by Environmental Lighting Concepts and one representative designated by a third party investor. Certain actions (including amendment of Custom Energy Holdings' operating agreement, approval of actions in contravention of the operating agreement, approval of a dissolution of Custom Energy Holdings, additional capital contributions and assumption of recourse indebtedness) require the unanimous consent of all the members of Custom Energy Holdings. Certain other actions (including mergers with Custom Energy Holdings, acquisitions by Custom Energy Holdings, assumption of non-recourse indebtedness, sales of substantial assets, approval of distributions, filing of registration statements, partition of assets, admission of new members and transfers of interests in Custom Energy Holdings) can be approved by the Management Committee, but to the extent they affect the rights, obligations, assets or business of Strategic Energy, the approval of the Strategic Energy Management Committee is also required. Strategic Energy's business and affairs are controlled and managed exclusively by a four member Management Committee composed of two representatives designated by KLT Energy Services, one representative designated by Environmental Lighting Concepts and one representative designated by a third party investor. Certain actions (including amendment of Strategic Energy's operating agreement, approval of actions in contravention of the operating agreement, approval of transactions between Strategic Energy and affiliates of its members, approval of a dissolution of Strategic Energy, and assumption of recourse indebtedness) require the unanimous consent of all the Management Committee representatives of Strategic Energy. 7. COMMITMENTS AND CONTINGENCIES Nuclear Liability and Insurance Liability Insurance The Price-Anderson Act currently limits the combined public liability of nuclear reactor owners to $9.5 billion for claims that could arise from a single nuclear incident. The owners of Wolf Creek, a nuclear generating station, (the Owners) carry the maximum available commercial insurance of $0.2 billion. Secondary Financial Protection, an assessment plan mandated by the NRC, provides insurance for the $9.3 billion balance. Under Secondary Financial Protection, if there were a catastrophic nuclear incident involving any of the nation's licensed reactors, the Owners would be subject to a maximum retrospective assessment per incident of up to $88 million ($41 million, KCP&L's 47% share). The Owners are jointly and severally liable for these charges, payable at a rate not to exceed $10 million ($5 million, KCP&L's 47% share) per incident per year, excluding applicable premium taxes. The assessment, most recently revised in 1998, is subject to an inflation adjustment every five years based on the Consumer Price Index. Property, Decontamination, Premature Decommissioning and Extra Expense Insurance The Owners also carry $2.8 billion ($1.3 billion, KCP&L's 47% share) of property damage, decontamination and premature decommissioning insurance for loss resulting from damage to the Wolf Creek facilities. NEIL provides this insurance. In the event of an accident, insurance proceeds must first be used for reactor stabilization and NRC mandated site decontamination. 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. 21 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, KCP&L is 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 to KCP&L under the current policies could total about $10.7 million. 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 could have a material, adverse effect on its financial condition, results of operations and cash flows. Low-Level Waste The Low-Level Radioactive Waste Policy Amendments Act of 1985 mandated that the various states, individually or through interstate compacts, develop alternative low-level radioactive waste disposal facilities. The states of Kansas, Nebraska, Arkansas, Louisiana and Oklahoma formed the Central Interstate Low-Level Radioactive Waste Compact and selected a site in northern Nebraska to locate a disposal facility. WCNOC and the owners of the other five nuclear units in the compact provided most of the pre-construction financing for this project. KCP&L's net investment on its books at June 30, 2002 and December 31, 2001, was $7.4 million. Significant opposition to the project has been raised by Nebraska officials and residents in the area of the proposed facility, and attempts have been made through litigation and proposed legislation in Nebraska to slow down or stop development of the facility. On December 18, 1998, the application for a license to construct this project was denied. This issue is being addressed in the courts. The passage of time, as well as developments in pending legal proceedings, has increased the chances for reversal of the license denial. In May 1999, the Nebraska legislature passed a bill withdrawing Nebraska from the Compact. In August 1999, the Nebraska Governor gave official notice of the withdrawal to the other member states. Withdrawal will not be effective for five years and will not, of itself, nullify the site license proceeding. Environmental Matters KCP&L's operations are subject to regulation by federal, state and local authorities with regard to air and other environmental matters. The generation and transmission of electricity produces and requires disposal of certain hazardous products which are subject to these laws and regulations. In addition to imposing continuing compliance obligations, these laws and regulations authorize the imposition of substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. Failure to comply with these laws and regulations could have a material adverse effect on KCP&L. KCP&L operates in an environmentally responsible manner and seeks to use current technology to avoid and treat contamination. KCP&L regularly conducts environmental audits designed to ensure compliance with governmental regulations and to detect contamination. Governmental bodies, however, may impose additional or more rigid environmental regulations that could require substantial changes to operations or facilities at a significant cost. At June 30, 2002, and December 31, 2001, KCP&L had $1.9 million accrued for environmental remediation expenses covering water monitoring at one site and unasserted claims for remediation at a second site. The amounts accrued were established on an undiscounted basis and KCP&L does not currently have an estimated time frame over which the accrued amounts may be paid out. Expenditures to comply with environmental laws 22 and regulations have not been material in amount during the periods presented and are not expected to be material in the upcoming years with the exception of the issues discussed below. Certain Air Toxic Substances In July 2000, the National Research Council published its findings of a study under the Clean Air Act which stated that power plants that burn fossil fuels, particularly coal, generate the greatest amount of mercury emissions. As a result, in December 2000, the EPA announced it would propose Maximum Achievable Control Technology (MACT) requirements by December 2003 to reduce mercury emissions and issue final rules by December 2004. Until the rules are proposed, KCP&L cannot predict the likelihood or compliance costs of such regulations. Air Particulate Matter In July 1997, the EPA revised ozone and particulate matter air quality standards creating a new eight-hour ozone standard and establishing a new standard for particulate matter less than 2.5 microns (PM-2.5) in diameter. These standards were challenged in the U. S. Court of Appeals for the District of Columbia (Appeals Court) that decided against the EPA. Upon further appeal, the U. S. Supreme Court reviewed the standards and remanded the case back to the Appeals Court for further review, including a review of whether the standards were arbitrary and capricious. On March 26, 2002, the Appeals Court issued its 3 to 0 decision on challenges to the 8-hour ozone and PM-2.5 national ambient air quality standards (NAAQS). This ruling denies all state, industry and environmental groups petitions for review and thus upheld as valid the EPA's new 8-hour ozone and PM-2.5 NAAQS. In so doing, the court held that the EPA acted consistently with the Clean Air Act in setting the standards at the levels it chose and the EPA's actions were reasonable and not arbitrary and capricious, and cited the deference given the Agency's decision-making authority. The court stated that the extensive records established for each rule supported the EPA's actions in both rulemakings. This ruling by the Appeals Court removed the last major hurdle to the EPA's implementation of stricter ambient air quality standards for ozone and fine particles. The EPA has not yet issued regulations incorporating the new standards. Until new regulations are issued, KCP&L is unable to estimate the impact of the new standards. However, the impact on KCP&L and all other utilities that use fossil fuels could be substantial. In addition, the EPA is conducting a three-year study of fine particulate ambient air levels. Until this testing and review period has been completed, KCP&L cannot determine additional compliance costs, if any, associated with the new particulate regulations. Nitrogen Oxide The EPA announced in 1998 regulations implementing reductions in NOx emissions. These regulations initially called for 22 states, including Missouri, to submit plans for controlling NOx emissions. The regulations require a significant reduction in NOx emissions from 1990 levels at KCP&L's Missouri coal-fired plants by the year 2003. In December 1998, KCP&L and several other western Missouri utilities filed suit against the EPA over the inclusion of western Missouri in the NOx reduction program based on the 1-hour NOx standard. On March 3, 2000, a three-judge panel of the District of Columbia Circuit of the U.S. Court of Appeals sent the NOx rules related to Missouri back to the EPA, stating the EPA failed to prove that fossil plants in the western part of Missouri significantly contribute to ozone formation in downwind states. On March 5, 2001, the U.S. Supreme Court denied certiorari, making the decision of the Court of Appeals final. In the February 22, 2002, Federal Register, the EPA issued proposed Phase II NOx SIP Call regulation which specifically excludes the fossil plants in the western part of Missouri from the NOx SIP Call. To date, the EPA has not issued its final Phase II NOx SIP Call regulation. 23 If required to be implemented, KCP&L would need to incur significant capital costs, purchase power or purchase NOx emission allowances. Preliminary analysis of the regulations indicates that selective catalytic reduction technology, as well as other changes, may be required for some of the KCP&L units. Currently, KCP&L estimates that additional capital expenditures to comply with these regulations could range from $40 million to $60 million. Operations and maintenance expenses could also increase by more than $2.5 million per year. KCP&L continues to refine these preliminary estimates and explore alternatives. The ultimate cost of these regulations, if any, could be significantly different from the amounts estimated above. Carbon Dioxide At a December 1997 meeting in Kyoto, Japan, delegates from 167 nations, including the United States, agreed to a treaty (Kyoto Protocol) that would require a seven percent reduction in United States carbon dioxide (CO2) emissions below 1990 levels. Although the United States agreed to the Kyoto Protocol, the treaty has not been sent to Congress for ratification. The financial impact on KCP&L of future requirements in the reduction of CO2 emissions cannot be determined until specific regulations are adopted. Proposed Water Use Regulations In February 2002, the EPA issued proposed rules related to certain existing power producing facilities that employ cooling water intake structures that withdraw 50 million gallons or more per day and use 25% or more of that water for cooling purposes. The EPA must take final action by August 2003. KCP&L will continue to monitor the progress of this rulemaking. The impact of these proposed rules has not yet been quantified, however, KCP&L's generating stations would be affected. KCP&L Leases In 2001, KCP&L entered into a synthetic lease arrangement with a Trust (Lessor) to finance the purchase, installation, assembly and construction of five combustion turbines and related property and equipment that will add 385 megawatts of peaking capacity (the "Project). The Trust is a special-purpose entity and has an aggregate financing commitment from third-party equity and debt participants (Investors) of $200 million. KCP&L is in the process of amending the lease arrangement to adjust the amount financed from the previously estimated $200 million to $176 million to reflect a reduction in the estimated cost for the purchase, installation, assembly and construction of the five combustion turbines. In accordance with SFAS No. 13 "Accounting for Leases," and related EITF issues (including EITF Issue No. 90-15, "Impact of Non-substantive Lessors, Residual Value Guarantees, and Other Provisions in Leasing Transactions" and EITF Issue No. 97-10, "The Effect of Lessee Involvement in Asset Construction"), the Project and related lease obligations are not included in KCP&L's consolidated balance sheet. The Lessor has appointed KCP&L as supervisory agent responsible for completing construction of the Project by no later than June 2004. The initial lease term is approximately three and one quarter years, beginning at the date of construction completion, which is expected to be June 2003. At the end of the lease term (October 2006), KCP&L may choose to sell the Project for the Lessor, guaranteeing to the Lessor a residual value for the Project in an amount which may be up to 83.21% of the project cost. If KCP&L does not elect the sale option, KCP&L must either extend the lease, if it can obtain the consent of the Lessor, or purchase the Project for the then outstanding project cost. KCP&L also has contingent obligations to the Lessor upon an event of a default during both the construction period and lease period. Upon a default in the construction period, KCP&L's maximum obligation to the Lessor equals (i) in the circumstances of bankruptcy, fraud, illegal acts, misapplication of funds and willful misconduct, 100% of then-incurred project costs, and (ii) in all other circumstances, an amount which may be up to 89.9% of then-incurred project costs that are capitalizable in accordance with GAAP. At June 30, 2002, cumulative project costs were approximately $86.8 million. Upon a default during the lease period, KCP&L's maximum obligation to the Lessor equals 100% of project costs. KCP&L's rental obligation, which reflects interest payments only, is expected to be approximately $24.6 million in the aggregate. 24 During the second quarter of 2002, the FASB issued an exposure draft related to identifying and accounting for special-purpose entities. The proposed interpretation would require consolidation of special-purpose entities by a business that has a controlling financial interest. The proposed interpretation would explain how to determine if a business has a controlling financial interest through a variable interest such as financial instruments, service contracts, nonvoting ownership interest, or other arrangements. The provisions of the proposed interpretation would apply immediately to special-purpose entities created after the date of the final interpretation and would apply to special-purpose entities already in existence as of the beginning of the first fiscal year or interim period beginning after March 15, 2003. If the exposure draft were to be issued as currently proposed, the Company believes the synthetic lease discussed above would need to be consolidated. Strategic Energy Purchased Power Energy Commitments Strategic Energy has entered into agreements to purchase electricity at various fixed prices to meet estimated supply requirements. Commitments at June 30, 2002, under these agreements total $1,138.8 million through 2010. Commitments for the remainder of 2002 total $262.2 million and for the years 2003 through 2006 total $370.3 million, $242.3 million, $203.6 million, and $45.3 million, respectively. See Note 10 for further discussion. Put Option Held by Minority Interests in Strategic Energy KLT Energy Services indirectly owns approximately 83% of Strategic Energy. Certain employees of Strategic Energy and other investors have a put option to sell all or part of their interests in Strategic Energy (currently 11.45%) to Custom Energy Holdings at any time within the 90 days following January 31, 2004, under certain circumstances, at fair market value. Fair market value would be determined by the mutual agreement of the parties, or if an agreement cannot be reached, by third party appraisal. DTI Holdings, Inc. and Subsidiaries On December 31, 2001, DTI, a subsidiary of KLT Telecom, filed voluntary petitions for bankruptcy. DTI's reorganization under Chapter 11 of the U.S. Bankruptcy Code continues in process. Timing of completion of the bankruptcy process has yet to be determined. During the first quarter of 2002, the bankruptcy court approved $5 million in DIP financing to be provided by KLT Telecom. As of June 30, 2002, none of the DIP financing has been borrowed by DTI. As a result of DTI's filing for bankruptcy protection and KLT Telecom's resultant loss of control, KLT Telecom has not included the ongoing earnings or loss incurred by DTI in its results for the three months ended and year to date June 30, 2002. Consistent with the fiduciary obligation of the creditors' committee to investigate potential sources of recovery for the DTI bankruptcy estate, the creditors' committee served a request for the production of documents by the Company and its affiliates relating to the issue of whether DTI should have been compensated for the use by the Company of its tax losses. The Company believes that it would have meritorious defenses to any such claim that ultimately might be asserted by the creditors' committee. Since the legal and factual basis for any such unasserted claim have not yet been established, the Company is currently unable to estimate the amount of liability or loss, if any, that might arise if a claim is asserted. 8. GOODWILL SFAS No. 142, "Goodwill and Other Intangible Assets" The Company adopted SFAS No. 142 on January 1, 2002. Under the new standard, goodwill is no longer amortized, but rather is tested for impairment upon adoption and at least annually thereafter. The annual test may be performed anytime during the year, but must be performed at the same time 25 each year. The Company will perform its annual goodwill impairment tests before the end of the year. Any future impairment of goodwill would be reflected in continuing operations. Strategic Energy's initial valuation has been completed and there was no impairment of the $14 million of goodwill. In accordance with SFAS No. 142, the Company completed its initial impairment test of RSAE during the second quarter of 2002 and recorded a $3.0 million write-down of goodwill. The goodwill write-down is reflected as a cumulative effect to January 1, 2002, of a change in accounting principle. After the write-down, RSAE had goodwill of $20 million, which was unchanged through June 30, 2002. First quarter 2002 income statement information has been restated to reflect the cumulative effect to January 1, 2002, of a change in accounting principle as follows: For the three months ended March 31, 2002 Great Plains (in thousands, except per share amounts) Energy KCP&L Net loss, as originally reported $ (2,897) $ (7,981) Cumulative effect to January 1, 2002, of a change in accounting principle (3,000) (3,000) Net loss, as restated (5,897) (10,981) Preferred stock dividend requirements 412 - Loss available for common stock, as restated $ (6,309) $ (10,981) Basic and diluted loss per common share, as originally reported $ (0.05) Cumulative effect to January 1, 2002, of a change in accounting principle (0.05) Basic and diluted loss per common share, as restated $ (0.10) Retained earnings at March 31, 2002, as originally reported $ 315,829 $ 185,866 Cumulative effect to January 1, 2002, of a change in accounting principle (3,000) (3,000) Retained earnings at March 31, 2002, as restated $ 312,829 $ 182,866 The following table adjusts the reported 2001 Great Plains Energy and Consolidated KCP&L income statement information to add back goodwill amortization as if the provisions of SFAS No. 142 had been applied during all periods presented. 26 Three Months Year Ended to Date June 30 June 30 (in thousands, except per share amounts) 2001 2001 Income before extraordinary item, as reported $ 36,232 $ 33,260 Add back: Goodwill amortization 703 1,742 Income before extraordinary item 36,935 35,002 Early extinguishment of debt, net of income taxes - 15,872 Income, as adjusted 36,935 50,874 Preferred stock dividend requirments 412 824 Earnings available for common stock, as adjusted $ 36,523 $ 50,050 Basic and diluted earnings per common share before extraordinary item, as reported $ 0.58 $ 0.52 Add back: Goodwill amortization 0.01 0.03 Basic and diluted earnings per common share before extraordinary item, as adjusted 0.59 0.55 Early extinguishment of debt - 0.26 Basic and diluted earnings per common share, as adjusted $ 0.59 $ 0.81 9. RECEIVABLES The Company's accounts receivables are comprised of the following: June 30 December 31 2002 2001 (thousands) Kansas City Power & Light Receivables Company $ 46,774 $ 25,723 KCP&L other receivables 36,128 36,788 Consolidated KCP&L receivables 82,902 62,511 Great Plains Energy other receivables 136,415 89,603 Great Plains Energy receivables $219,317 $152,114 In 1999, KCP&L entered into a revolving agreement to sell all of its right, title and interest in the majority of its customer accounts receivable to Receivables Company, a special purpose entity established to purchase customer accounts receivable from KCP&L. The agreement expires in October 2002, however, KCP&L will seek, and expects to renew the agreement. Receivables Company has sold receivable interests to outside investors. Accounts receivable sold under the revolving agreement between Receivables Company and KCP&L totaled $115.2 million at June 30, 2002 and $95.7 million at December 31, 2001. These sales included unbilled receivables of $46.1 million at June 30, 2002, and $28.9 million at December 31, 2001. In consideration of the sale, KCP&L receives up to $70 million in cash and the remaining balance in the form of a subordinated note from Receivables Company. At June 30, 2002, KCP&L had received $68.4 million in cash from Receivables Company. The agreement is structured as a true 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. 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 and are included in non-operating expenses. KCP&L services the receivables and receives an annual servicing fee of 0.25% of 27 the outstanding principal amount of the receivables sold and retains any late fees charged to customers. As currently proposed, the FASB exposure draft related to identifying and accounting for special-purpose entities would not require consolidation of the Receivables Company. Information regarding KCP&L's sale of accounts receivable is reflected in the following table.
Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (thousands) Gross proceeds on sale of accounts receivable $240,371 $233,047 $432,950 $434,482 Collections 211,785 207,780 419,026 424,577 Loss on sale of accounts receivable 1,251 1,756 2,353 5,659 Late fees 755 1,380 654 1,116
KCP&L other receivables at June 30, 2002 and December 31, 2001, consist primarily of receivables from partners in jointly-owned electric utility plants, bulk power sales receivables and accounts receivable held by RSAE and Worry Free. Great Plains Energy other receivables at June 30, 2002 and December 31, 2001 are primarily the accounts receivable held by Strategic Energy which include unbilled receivables of $65.1 million at June 30, 2002 and $48.5 million at December 31, 2001. 10. DERIVATIVE FINANCIAL INSTRUMENTS On January 1, 2001, the Company adopted SFAS No. 133, "Accounting for Derivative Instruments and Hedging Activities", as amended. SFAS No. 133 requires that every derivative instrument be recorded on the balance sheet as an asset or liability measured at its fair value and that changes in the fair value be recognized currently in earnings unless specific hedge accounting criteria are met. SFAS No. 133 requires that as of the date of initial adoption, the difference between the fair market value of derivative instruments recorded on the balance sheet and the previous carrying amount of those derivatives be reported in net income or other comprehensive income, as appropriate, as a cumulative effect of a change in accounting principle. The adoption of SFAS No. 133 on January 1, 2001, required the Company to record a $0.2 million expense, net of $0.1 million of income tax. The Company did not reflect this immaterial amount as a cumulative effect. This entry increased interest expense by $0.6 million and reduced purchased power expense by $0.3 million. The Company also recorded $17.4 million, net of $12.6 million of income tax, as a cumulative effect of a change in accounting principle applicable to comprehensive income for its cash flow hedges. Cash flow hedges are derivative instruments used to mitigate the exposure to variability in expected future cash flows attributable to a particular risk. Derivative Instruments and Hedging Activities The Company's activities expose it 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 its operating results. The Company's interest rate risk management strategy uses derivative instruments to adjust the Company's liability portfolio to optimize the mix of fixed and floating rate debt within an established range. The Company maintains commodity-price risk management strategies that use derivative instruments to minimize significant, unanticipated earnings fluctuations caused by commodity price volatility. 28 The Company's risk management activities, including the use of derivatives, are subject to the management, direction and control of internal Risk Management Committees. Interest Rate Risk Management KCP&L utilizes interest rate management derivatives to adjust the Company's liability portfolio to optimize the mix of fixed and floating rate debt within an established range. KCP&L has two interest rate swap agreements in place to fix the interest rate on $30 million of floating-rate long-term debt. These swaps do not meet the criteria to qualify for hedge accounting. The swap agreements terminate in 2003 and effectively fix the interest at a weighted-average rate of 3.88%. The fair market values of these agreements are recorded as current assets or liabilities and adjustments to interest expense. Changes in the fair market value of these instruments are recorded in the income statement. Commodity Risk Management KCP&L's risk management policy is to use derivative hedge instruments to mitigate its exposure to market price fluctuations on its projected gas generation requirements for retail and firm wholesale sales. These hedging instruments are designated as cash flow hedges. The fair market value of these instruments is recorded as current assets or current liabilities. When the gas is purchased and to the extent the hedge is effective at mitigating the impact of a change in the purchase price of gas, the amounts in other comprehensive income are reclassified to the consolidated income statement. To the extent that the hedges are not effective, the ineffective portion of the changes in fair market value are recorded directly in fuel expense. Strategic Energy maintains a commodity-price risk management strategy that uses forward physical energy purchases and derivative instruments to minimize significant, unanticipated earnings fluctuations caused by commodity-price volatility. An option that was designated as a cash flow hedge expired on December 31, 2001. The option allowed Strategic Energy to purchase up to 270 megawatts of power at a fixed rate of $21 per mwh. The fair market value of this option and swap agreements designated as cash flow hedges at January 1, 2001, was recorded as a current asset and a cumulative effect of a change in accounting principle in comprehensive income. As a result of supplying electricity to retail customers under fixed rate contracts, Strategic Energy's policy is to match customers' demand with fixed price purchases. In certain markets where Strategic Energy operates, entering into forward fixed price contracts is cost prohibitive. By entering into swap contracts for a portion of its forecasted purchases in these markets, the future purchase price of electricity is effectively fixed under these swap contracts protecting Strategic Energy from price volatility. The swap contracts limit the unfavorable effect that price increases will have on electricity purchases. Under SFAS No. 133, the majority of the swap agreements are designated as cash flow hedges resulting in the difference between the market value of energy and the hedge value being recorded as comprehensive income (loss). To the extent that the hedges are not effective, the ineffective portion of the changes in fair market value will be recorded directly in purchased power. At June 30, 2002, the accumulated comprehensive loss, net of income taxes and minority interest, reflected in Great Plains Energy's consolidated statement of capitalization reflected a $5.9 million loss related to such cash flow hedges. However, substantially all of the energy hedged with the swaps has been sold to customers through contracts at prices different than the fair market value used to value the swaps. Therefore, Strategic Energy does not anticipate incurring any of the losses represented in comprehensive income. The remaining swap agreements do not qualify for hedge accounting. The fair market value of these swaps at January 1, 2001, was recorded as an asset or liability on the consolidated balance sheet and 29 an adjustment to the cost of purchased power. The change in the fair market value and future changes in the fair market values of these swaps will also be recorded in purchased power. KLT Gas' risk management policy is to use firm sales agreements or financial hedge instruments to mitigate its exposure to market price fluctuations on up to 85% of its daily natural gas production. These hedging instruments are designated as cash flow hedges. The fair market value of these instruments at January 1, 2001, was recorded as current assets or current liabilities, as applicable, and the cumulative effect of a change in accounting principle in comprehensive income. When the gas is sold and to the extent the hedge is effective at mitigating the impact of a change in the sales price of gas, the amounts in other comprehensive income are reclassified to the consolidated income statement. To the extent that the hedges are not effective, the ineffective portion of the changes in fair market value are recorded directly in gas revenues. KLT Gas is currently developing gas properties and has no production hedged at June 30, 2002. The amounts recorded related to the cash flow hedges in other comprehensive income (OCI) are summarized below. Great Plains Energy activity for the three months ended June 30, 2002 Increase March 31 (Decrease) June 30 2002 in OCI Reclassified 2002 Assets (millions) Other current assets $ 0.8 $ (0.5) $ (0.2) $ 0.1 Other deferred debits 0.3 0.2 - 0.5 Liabilities and capitalization Other current liabilities (7.4) (3.4) 2.9 (7.9) Accumulated OCI 7.2 - (1.3) 5.9 Deferred income taxes 5.1 - (1.0) 4.1 Other deferred credits (6.0) 3.7 (0.4) (2.7) Consolidated KCP&L activity for the three months ended June 30, 2002 Increase March 31 (Decrease) June 30 2002 in OCI Reclassified 2002 Assets (millions) Other current assets $ 0.4 $ (0.2) $ (0.2) $ - Liabilities and capitalization Accumulated OCI (0.3) 0.2 0.1 - Deferred income taxes (0.1) - 0.1 - Great Plains Energy and Consolidated KCP&L activity for the three months ended June 30, 2001 Increase March 31 (Decrease) June 30 2001 in OCI Reclassified 2001 Assets (millions) Other current assets $ 30.1 $(13.8) $(10.3) $ 6.0 Liabilities and capitalization Other current liabilities (4.4) (24.7) 1.1 (28.0) Accumulated OCI (11.9) 18.4 4.3 10.8 Deferred income taxes (8.7) 13.1 3.1 7.5 Other deferred credits (5.1) 7.0 1.8 3.7 30 Great Plains Energy activity year to date June 30, 2002 Increase December 31 (Decrease) June 30 2001 in OCI Reclassified 2002 Assets (millions) Other current assets $ (0.2) $ 0.4 $ (0.1) $ 0.1 Other deferred debits - 0.5 - 0.5 Liabilities and capitalization Other current liabilities (12.7) (1.0) 5.8 (7.9) Accumulated OCI 12.1 (3.4) (2.8) 5.9 Deferred income taxes 8.5 (2.4) (2.0) 4.1 Other deferred credits (7.7) 5.9 (0.9) (2.7) Consolidated KCP&L activity year to date June 30, 2002 Increase December 31 (Decrease) June 30 2001 in OCI Reclassified 2002 Assets (millions) Other current assets $ (0.2) $ 0.3 $ (0.1) $ - Liabilities and capitalization Other current liabilities (0.1) 0.1 - - Accumulated OCI 0.2 (0.2) - - Deferred income taxes 0.1 (0.2) 0.1 - Great Plains Energy and Consolidated KCP&L activity year to date June 30, 2001 Cumulative Effect to Increase January 1, (Decrease) June 30 2001 in OCI Reclassified 2001 Assets (millions) Other current assets $ 44.5 $(17.3) $(21.2) $ 6.0 Liabilities and capitalization Other current liabilities (6.8) (24.4) 3.2 (28.0) Accumulated OCI (17.4) 19.9 8.3 10.8 Deferred income taxes (12.7) 14.2 6.0 7.5 Other deferred credits (7.6) 7.6 3.7 3.7 Reclassified to earnings for the three months ended June 30, Great Plains Energy Consolidated KCP&L 2002 2001 2002 2001 (millions) Gas revenues $ (0.2) $ (1.0) $ - $ (1.0) Fuel expense 0.2 - 0.2 - Purchased power expense (2.7) 10.2 - 10.2 Minority interest 0.4 (1.8) - (1.8) Income taxes 1.0 (3.1) (0.1) (3.1) OCI $ (1.3) $ 4.3 $ 0.1 $ 4.3 31 Reclassified to earnings year to date June 30, Great Plains Energy Consolidated KCP&L 2002 2001 2002 2001 (millions) Gas revenues $ (0.2) $ (3.1) $ - $ (3.1) Fuel expense 0.1 - 0.1 - Purchased power expense (5.6) 21.1 - 21.1 Minority interest 0.9 (3.7) - (3.7) Income taxes 2.0 (6.0) (0.1) (6.0) OCI $ (2.8) $ 8.3 $ - $ 8.3 11. KCP&L JANUARY ICE STORM At the end of January 2002, the most damaging ice storm in Kansas City history caused roughly 285,000 customer outages throughout the KCP&L territory. Incremental costs incurred through June 30, 2002, related to the January ice storm were approximately $50.2 million of which $14.7 million were capital expenditures and therefore recorded to utility plant. KCP&L expensed $16.0 million ($0.16 per share) for the Kansas jurisdictional portion of the storm costs and deferred as a regulatory asset $19.5 million of the storm costs applicable to Missouri. In the second quarter of 2002, the KCC approved the stipulation and agreement that KCP&L had reached with the Commission staff and the Citizens Utility Ratepayers Board with regard to treatment of the Kansas portion of the ice storm costs. Under this stipulation and agreement, KCP&L received a rate moratorium until 2006 in exchange for KCP&L's agreement to not seek recovery of the $16.0 million expense for the Kansas jurisdictional portion of the storm costs, and reduce rates by $12.0 - $13.0 million annually beginning in 2003. Additionally, KCP&L agreed to determine depreciation expense of the Wolf Creek nuclear generating station using a 60 year life instead of a 40 year life effective January 2003, which results in a reduction of expense by approximately $7.0 - $8.0 million annually. KCP&L also agreed to file a rate case by May 15, 2006. Effective August 2002, the MPSC approved KCP&L's application for an accounting authority order related to the Missouri jurisdictional portion of the storm costs. The order allows KCP&L to defer and amortize $19.5 million, representing the Missouri impact of the storm, through January 2007. The amortization will begin in September 2002 and is expected to be approximately $1.5 million in 2002 and approximately $4.6 million annually for the remainder of the amortization period. 32 ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS The Management's Discussion and Analysis of Financial Condition and Results of Operations that follow are a combined presentation for Great Plains Energy and KCP&L, both registrants under this filing. The discussion and analysis by management focuses on those factors that had a material effect on the financial condition and results of operations of the registrants during the periods presented. It should be read in conjunction with the accompanying Financial Statements and Notes and with the management's discussion and analysis included in the Company's 2001 annual report on Form 10-K. Great Plains Energy Incorporated Effective October 1, 2001, Great Plains Energy became the holding company of KCP&L, GPP and KLT Inc. and subsidiaries. As a diversified energy company, its primary segments of business include: o KCP&L, an integrated electric utility in the states of Missouri and Kansas, provides reliable, low-cost electricity to retail customers; o Strategic Energy provides power supply coordination services in several deregulated electricity markets, including Pennsylvania, southern California, Ohio, New York, Massachusetts and Texas. o KLT Gas acquires and develops early stage coalbed methane natural gas properties. Effective October 1, 2001, all outstanding KCP&L shares were exchanged one for one for shares of Great Plains Energy. The Great Plains Energy trading symbol "GXP" replaced the KCP&L trading symbol "KLT" on the New York Stock Exchange. During the second quarter of 2002, the Company's management revised its corporate business strategy. The goal is to become a premier diversified energy company that achieves annual growth in earnings per share in a financially disciplined manner. To achieve this goal, Great Plains Energy intends to focus on its three primary segments of business and identify synergistic energy investments by: o Developing KCP&L into an operationally excellent electric utility, o Continuing to grow Strategic Energy's business model into new markets, o Developing KLT Gas into a premier brand in the unconventional natural gas exploration market, and o Identifying synergistic energy investments that drive earnings growth while supporting the Company's core strategies. 33 Great Plains Energy Results of Operations Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (millions) Operating revenues $ 465.4 $ 346.5 $ 824.2 $ 626.7 Fuel (35.4) (39.6) (69.4) (72.3) Purchased power (188.2) (78.4) (324.1) (147.1) Revenues, net of fuel and purchased power 241.8 228.5 430.7 407.3 Other operating expenses (126.2) (133.1) (262.4) (269.2) Depreciation and depletion (37.3) (40.0) (74.7) (76.6) Gain on property 0.1 20.4 0.1 21.7 Operating income 78.4 75.8 93.7 83.2 Loss from equity investments (0.3) 0.4 (0.6) (0.1) Non-operating income (expenses) (4.8) 0.7 (14.5) (0.6) Interest charges (23.5) (25.6) (44.3) (49.8) Income taxes (13.8) (15.1) (1.2) 0.5 Early extinguishment of debt - - - 15.9 Cumulative effect of a change in accounting principle - - (3.0) - Net income 36.0 36.2 30.1 49.1 Preferred dividends (0.5) (0.4) (0.9) (0.8) Earnings applicable to common $ 35.5 $ 35.8 $ 29.2 $ 48.3 Three months ended June 30, 2002, compared to June 30, 2001 - ----------------------------------------------------------- Great Plains Energy's earnings for the three months ended, as detailed in the table below, decreased slightly compared to the same period of 2001. Three Months Ended June 30 2002 2001 2002 2001 Earnings Earnings EPS EPS (millions) KCP&L $ 27.3 $ 23.0 $ 0.44 $ 0.37 Subsidiary operations (0.2) (1.6) - (0.02) Consolidated KCP&L 27.1 21.4 0.44 0.35 Strategic Energy 8.2 6.3 0.13 0.10 KLT Gas (0.3) 11.9 - 0.19 Other non-regulated operations 0.5 (3.8) - (0.06) Total $ 35.5 $ 35.8 $ 0.57 $ 0.58 KCP&L's increase in earnings for the three months ended June 30, 2002, compared to the same period of 2001, is primarily the result of warmer June 2002 weather, continued load growth, lower average cost per mmbtu of fuel, and a significantly lower price per mwh of purchased power. These factors combined to more than offset increased pension costs of $4.0 million. Strategic Energy's continued growth in the retail markets (including increases in customer accounts) and mwh's served increased earnings $6.6 million excluding earnings during the three months ended June 30, 2001, of $4.7 million resulting from the sale of power purchased from one supplier under wholesale contracts that expired at the end of 2001. KLT Gas is currently developing production properties following its most recent sale of property during the second quarter of 2001 which resulted in an after tax gain of $11.6 million. Other 34 non-regulated operations includes, among other things, earnings from affordable housing of $2.7 million and $3.7 million for the three months ended June 30, 2002 and 2001, respectively. Additionally, the three months ended June 30, 2001, reflects DTI losses of $9.5 million. Year to date June 30, 2002, compared to June 30, 2001 - ----------------------------------------------------- Great Plains Energy's earnings year to date June 30, 2002, compared to 2001 remained unchanged, excluding the cumulative effect of a change in accounting principle in 2002 and the early extinguishment of debt in 2001. Year to Date June 30 2002 2001 2002 2001 Earnings Earnings EPS EPS (millions) KCP&L $ 20.4 $ 20.5 $ 0.33 $ 0.33 Subsidiary operations (1.3) (3.4) (0.02) (0.05) Cumulative effect to January 1, 2002 of a change in accounting principle (3.0) - (0.05) - Consolidated KCP&L 16.1 17.1 0.26 0.28 Strategic Energy 15.1 7.3 0.24 0.12 KLT Gas (0.4) 13.3 (0.01) 0.21 Other non-regulated operations (1.6) (5.3) (0.02) (0.09) Earnings excluding extraordinary item 29.2 32.4 0.47 0.52 Early extinguishment of debt - 15.9 - 0.26 Total $ 29.2 $ 48.3 $ 0.47 $ 0.78 KCP&L earnings were unchanged year to date June 30, 2002, compared to the same period of 2001. The positive impact of the return to service of Hawthorn No. 5 in June 2001 and significantly lower cost per mwh of purchased power were offset by increased pension expense and the impact of expensing the Kansas jurisdictional portion of the January 2002 ice storm costs. Strategic Energy's continued growth in the retail markets increased earnings $13.0 million excluding earnings during year to date June 30, 2001, of $5.2 million resulting from the sale of power purchased from one supplier under wholesale contracts that expired at the end of 2001. KLT Gas is currently developing production properties following its most recent sale of property during the second quarter of 2001 which resulted in an after tax gain of $11.6 million. Other non-regulated operations includes earnings from affordable housing of $3.2 million and $7.0 million year to date June 30, 2002 and 2001, respectively. Additionally, year to date June 30, 2001, reflects DTI losses of $13.9 million, excluding the early extinguishment of debt. On December 31, 2001, DTI filed voluntary petitions for bankruptcy. As a result of DTI's filing for bankruptcy protection, and KLT Telecom's resultant loss of control, KLT Telecom has not included in its results for the three months ended and year to date June 30, 2002, the ongoing earnings or loss incurred by DTI. The Company adopted SFAS No. 142, "Goodwill and Other Intangible Assets" effective January 1, 2002. In accordance with SFAS No. 142, the Company completed its initial impairment test of RSAE during the second quarter of 2002 and determined that a $3.0 million write-down of goodwill was required. As a result, Great Plains Energy's year to date June 30, 2002, net income was reduced by the $3.0 million which is reflected as a cumulative effect to January 1, 2002, of a change in accounting principle. 35 On February 1, 2001, DTI, an equity investment of KLT Telecom on that date, completed a tender offer for 50.4% of its outstanding senior discount notes. This transaction resulted in a $15.9 million ($0.26 per share) extraordinary gain on the early extinguishment of debt. For further discussion regarding each segment's results of operations, see its respective section below. Consolidated KCP&L The following discussion of consolidated KCP&L results of operations includes KCP&L, an integrated electric utility and HSS, an unregulated subsidiary of KCP&L. References to KCP&L, in the discussion that follows, reflect only the operations of the integrated electric utility. The discussion excludes the results of operations for KLT Inc. and subsidiaries and GPP, which were transferred to Great Plains Energy on October 1, 2001. Consolidated KCP&L Business Overview KCP&L consists of two business units - power and delivery. The power business unit has over 3,700 megawatts of generating capacity. During 2001, KCP&L entered into a $200 million, five-year construction and synthetic operating lease transaction for five combustion turbines that will add 385 megawatts of peaking capacity. The lease is currently in the process of being amended to reduce the amount financed from the previously estimated $200 million to $176 million to reflect changes in the estimated cost for the purchase, installation, assembly and construction of the five combustion turbines. Construction will begin in 2002 with the expected commercial operation of the five combustion turbines in the spring and summer 2003. The delivery business unit consists of transmission and distribution facilities that serve over 480,000 customers as of June 30, 2002. Historically, load growth has increased approximately 2.0% to 2.5% annually through increased customer usage and additional customers. Rates charged for electricity are below the national average. KCP&L has an obligation, under FERC Order 2000, to join a FERC approved RTO. RTOs combine regional transmission operations of utility businesses into an organization that schedules transmission services and monitors the energy market to ensure regional transmission reliability and non-discriminatory access. KCP&L is a member of the SPP. During the first quarter of 2002, the SPP and the MISO voted to consolidate the two organizations to create a larger Midwestern RTO, a non-profit organization that will operate in twenty states and one Canadian province. The consolidation is expected to be completed during the third quarter of 2002 and has received FERC approval. FERC has already approved an RTO proposal submitted by the MISO. KCP&L also has a wholly-owned unregulated subsidiary, HSS, that holds investments in businesses primarily in residential services. HSS is comprised of two subsidiaries, RSAE and Worry Free Services, Inc. 36 Consolidated KCP&L Results of Operations The following table summarizes consolidated KCP&L's comparative results of operations. For comparative purposes only, the 2001 periods presented below have been restated to exclude the results of operations for KLT Inc. and subsidiaries and GPP, which were transferred to Great Plains Energy on October 1, 2001. Therefore, the 2001 periods presented below do not agree with the 2001 periods presented in KCP&L's consolidated statements of income and should only be used in the context of the discussion and analysis that follows. Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (millions) Operating revenues $ 264.2 $ 256.3 $ 476.4 $ 471.8 Fuel (35.4) (39.6) (69.4) (72.3) Purchased power (12.3) (13.8) (23.2) (38.0) Revenues, net of fuel and purchased power 216.5 202.9 383.8 361.5 Other operating expenses (112.9) (112.6) (236.7) (226.2) Depreciation and depletion (36.9) (34.5) (73.8) (67.8) Gain on property 0.2 (1.4) 0.3 (1.4) Operating income 66.9 54.4 73.6 66.1 Loss from equity investments - - - (0.1) Non-operating income (expenses) (0.4) 0.4 (2.2) (0.5) Interest charges (21.6) (18.6) (41.0) (38.4) Income taxes (17.8) (14.5) (11.3) (9.2) Cumulative effect of a change in accounting principle - - (3.0) - Net income 27.1 21.7 16.1 17.9 Preferred dividends - (0.4) - (0.8) Earnings applicable to common $ 27.1 $ 21.3 $ 16.1 $ 17.1 Consolidated KCP&L's earnings increased $5.8 million for the three months ended June 30, 2002, and decreased $1.0 million year to date June 30, 2002, compared to the same periods of 2001. For the three months ended June 30, 2002, KCP&L earnings increased $4.3 million, compared to the same period of 2001. Warmer June 2002 weather, continued load growth, lower average cost per mmbtu of fuel, and a lower price per mwh of purchased power combined to more than offset increased pension costs of $4.0 million. HSS improved its results of operations $1.4 million despite a 9% decline in revenues due to the closure of some locations and the implementation of cost saving strategies. Year to date June 30, 2002, KCP&L earnings were unchanged. The positive impact of the return to service of Hawthorn No. 5 in June 2001 and significantly lower prices per mwh of purchased power were offset by increased pension expense and the impact of expensing the Kansas jurisdictional portion of the January 2002 ice storm costs. HSS, excluding the cumulative effect of a change in accounting principle, improved operating results $2.1 million due to the closure of some locations and the implementation of cost saving strategies. The Company adopted SFAS No. 142, "Goodwill and Other Intangible Assets" effective January 1, 2002. In accordance with SFAS No. 142, the Company completed its initial impairment test of RSAE during the second quarter of 2002 and determined that a $3.0 million write-down of goodwill was required. As a result, year to date June 30, 2002, Great Plains Energy net income was reduced by the 37 $3.0 million which is reflected as a cumulative effect to January 1, 2002, of a change in accounting principle. Consolidated KCP&L Sales Revenues and Megawatt-hour (mwh) Sales
Three Months Ended Year to Date June 30 % June 30 % 2002 2001 Change 2002 2001 Change Retail revenues (millions) (millions) Residential $ 84.2 $ 78.3 8 % $154.0 $149.1 3 % Commercial 110.2 107.8 2 % 196.7 191.9 2 % Industrial 26.4 25.8 2 % 46.2 53.0 (13)% Other retail revenues 2.1 2.1 4 % 4.3 4.1 4 % Total retail 222.9 214.0 4 % 401.2 398.1 1 % Sales for resale revenues Bulk power sales 20.3 18.7 8 % 36.9 28.9 28 % Other sales for resale revenues 0.8 0.8 (5)% 1.7 2.0 (14)% Other revenues 3.2 4.1 (20)% 6.3 7.4 (14)% KCP&L electric revenues 247.2 237.6 4 % 446.1 436.4 2 % Subsidiary revenues 17.0 18.7 (9)% 30.3 35.4 (14)% Consolidated KCP&L revenues $264.2 $256.3 3 % $476.4 $471.8 1 %
Three Months Ended Year to Date June 30 % June 30 % 2002 2001 Change 2002 2001 Change Retail mwh sales (thousands) (thousands) Residential 1,080 1,012 7 % 2,149 2,126 1 % Commercial 1,726 1,721 - % 3,282 3,265 1 % Industrial 522 515 1 % 948 1,082 (12)% Other retail mwh sales 19 19 8 % 41 39 7 % Total retail 3,347 3,267 2 % 6,420 6,512 (1)% Sales for resale mwh Bulk power sales 968 732 32 % 1,793 1,127 59 % Other sales for resale 30 29 2 % 60 60 (1)% KCP&L electric mwh sales 4,345 4,028 8 % 8,273 7,699 7 %
Total revenues increased for the three months ended and year to date June 30, 2002, compared to the same periods of 2001. Warmer June 2002 weather and continued load growth increased retail revenues for the three months ended June 30, 2002. The increase was mostly offset by the mild weather in the first quarter of 2002 and the bankruptcy of one major industrial customer in early 2001 ($4.4 million of revenues year to date June 30, 2001) to net a slight increase in retail revenue year to date, compared to the same period of 2001. Load growth resulting from higher usage-per-customer and the addition of new customers partially offset the decreases. Less than 1% of revenues include an automatic fuel adjustment provision. Bulk power sales vary with system requirements, generating unit and purchased power availability, fuel costs and requirements of other electric systems. The significant increases in bulk power mwh sales were partially offset by a decline of approximately 20% in prices per bulk power mwh sold for the three months ended and year to date June 30, 2002, compared to the same periods in 2001. 38 In the second quarter 2002, the KCC approved the stipulation and agreement that KCP&L had reached with the Commission staff and the Citizens Utility Ratepayers Board with regard to treatment of the Kansas portion of the ice storm costs. Under this stipulation and agreement, KCP&L received a rate moratorium until 2006 in exchange for KCP&L's agreement to not seek recovery of the $16 million expense for the Kansas jurisdictional portion of the storm costs, and reduce rates by $12 - $13 million in 2003. Additionally, KCP&L agreed to determine depreciation expense of the Wolf Creek nuclear generating station using a 60 year life instead of a 40 year life effective January 2003, which results in a reduction of expense by approximately $7 - $8 million in 2003. KCP&L also agreed to file a rate case by May 15, 2006. KCP&L Fuel and Purchased Power KCP&L fuel costs decreased $4.2 million for the three months ended and $2.9 million year to date June 30, 2002, compared to the same periods of 2001, even though generation increased 10% and 11%, respectively. Lower fuel cost per mmBtu due to a change in the generation fuel mix (additional coal and less natural gas and oil) following the return to service of Hawthorn No. 5, a coal-fired unit, in June 2001 was the primary reason for the decline in fuel costs. Significantly lower natural gas prices in the 2002 periods also contributed to the lower cost. Purchased power expenses decreased $1.5 million for the three months ended and $14.8 million year to date June 30, 2002, compared to the same period of 2001. Cost per mwh purchased decreased approximately 40% in 2002 compared to 2001 due to regional energy availability and a less volatile energy market. The significantly lower cost per mwh purchased more than offset the effect on purchased power expense of a 36% increase in the quantity of power purchased during the three months ended. Also contributing to the year to date decrease was a 17% decrease in the quantity of power purchased due to the availability of KCP&L generating units. The cost per mmBtu of fuel and the cost per mwh of purchased power have a significant impact on the results of operations for KCP&L. Generation fuel mix can change the cost per mmBtu of fuel substantially. Nuclear fuel costs per mmBtu remain substantially less than the mmBtu price of coal. Replacement power costs for planned Wolf Creek outages are accrued evenly over the unit's operating cycle, as discussed below. KCP&L expects its cost of nuclear fuel to remain fairly constant through the year 2003. Coal has a significantly lower cost per mmBtu than natural gas and oil. KCP&L's procurement strategies continue to provide delivered coal costs below the regional average. The cost per mwh for purchased power is still significantly higher than the fuel cost per mwh of coal and nuclear generation. KCP&L continually evaluates its system requirements, the availability of generating units, availability and cost of fuel supply, availability and cost of purchased power and the requirements of other electric systems to provide reliable power economically. In June 2002, Montrose Unit No. 3, a 176-mw unit, began a forced outage due to damage to the turbine blades in the combined high and intermediate pressure section of the turbine. The unit is expected to be back on-line in the first half of September 2002. This unanticipated outage is expected to cost approximately $4.0 million of capital, $0.6 million in additional operations and maintenance expense and $3.0 million in net fuel and purchased power expense in 2002. To date, favorable wholesale market energy prices and near capacity operation of KCP&L's base load units have combined to mitigate some of KCP&L's exposure to higher purchased power costs to replace the lost generation at Montrose Unit No. 3. However, the expected costs could be significantly influenced by the price of energy, both purchases and sales for the remainder of the outage. Consolidated KCP&L Other Operating Expenses KCP&L's other operating expenses increased $2.5 million for the three months ended June 30, 2002, compared to the same period of 2001 primarily due to a $4.0 million increase in pension expense. KCP&L's other operating expenses increased $20.5 million year to date June 30, 2002, compared to 39 the same period of 2001 primarily due to an increase in pension expense of $8.0 million and expensing $16.0 million for the Kansas jurisdictional portion of the January ice storm. The increased pension expense for both periods is mostly due to a significant decline in the market value of plan assets at the end of the plan's year, September 30, 2001. HSS's other expenses decreased $2.2 million for the three months ended and $10.0 million year to date June 30, 2002, compared to the same periods of 2001 due to the closure of some locations and the implementation of cost saving strategies. Consolidated KCP&L Depreciation Consolidated KCP&L's depreciation expense increased $2.4 million for the three months ended and $6.0 million year to date June 30, 2002, compared to the same periods of 2001, primarily due to increased capital additions relating to Hawthorn No. 5, which was returned to service in 2001, and the purchase of the previously leased Hawthorn No. 6 turbine at the end of the third quarter of 2001. Consolidated KCP&L Interest Charges Consolidated KCP&L's interest charges increased $3.0 million for the three months ended and $2.6 million year to date June 30, 2002, compared to the same periods of 2001, primarily due to a significant decrease in capitalized interest. The decrease in capitalized interest was partially offset by significantly lower rates on variable rate debt year to date June 30, 2002, compared to 2001. A portion of proceeds from long-term debt issuances have been used to refinance short-term debt. Long-term debt interest expense KCP&L's long-term debt interest expense increased $1.9 million for the three months ended June 30, 2002, and decreased $0.7 million year to date June 30, 2002, compared to the same periods of 2001. Higher average levels of long-term debt were partially offset by lower average interest rates in the three months ended. Lower average interest rates more than offset the higher average levels of long-term debt year to date. The higher average levels of long-term debt primarily reflect the issuances of $375.0 million of unsecured, fixed-rate senior notes partially offset by $257.0 million of scheduled debt repayments since June 30, 2001. Short-term debt interest expense KCP&L's short-term debt interest expense decreased $2.6 million for the three months ended and $4.5 million year to date June 30, 2002, compared to the same periods of 2001. Average interest rates and average levels of outstanding commercial paper for the 2002 periods are both down more than 50% compared to the same periods of 2001. KCP&L had $94.9 million of commercial paper outstanding at June 30, 2002 and $245.8 million of commercial paper outstanding at June 30, 2001. Capitalized interest Allowance for borrowed funds used during construction decreased $3.4 million for the three months ended and $7.2 million year to date June 30, 2002, compared to the same periods of 2001 because of decreased construction work in progress primarily due to the return to service of Hawthorn No. 5 in 2001. Wolf Creek Wolf Creek, a nuclear generating station, represents about 15% of KCP&L's generating capacity. The plant's operating performance has remained strong over the last three years, contributing an average of 28% of KCP&L's annual mwh generation while operating at an average capacity of 92%. Wolf Creek has the lowest fuel cost per mmBtu of any of KCP&L's generating units. KCP&L accrues the incremental operating, maintenance and replacement power costs for planned outages evenly over the unit's operating cycle, normally 18 months. As actual outage expenses are 40 incurred, the refueling liability and related deferred tax asset are reduced. Wolf Creek returned to service on April 27, 2002, following a 35-day refueling and maintenance outage that began on March 23, 2002. During the outage, a complete inspection of the reactor vessel head indicated no corrosion or other problems of the type experienced at the Davis-Besse nuclear plant in Ohio. The next outage is scheduled for the fall of 2003. Ownership and operation of a nuclear generating unit exposes KCP&L to risks regarding decommissioning costs at the end of the unit's life and to potential retrospective assessments and property losses in excess of insurance coverage. Strategic Energy Strategic Energy Business Overview Strategic Energy provides power supply coordination services by purchasing electricity and reselling it to retail customers in several deregulated electricity markets, including Pennsylvania, California, Ohio, New York, Massachusetts and Texas. As part of its process of managing electricity portfolios for retail customers, Strategic Energy occasionally sells unsold power back into the wholesale market. Strategic Energy also provides strategic planning and consulting services in the natural gas and electricity markets. In the first half of 2002, power supply coordination services provided to retail customers accounted for substantially all of Strategic Energy's operating income. In the first quarter of 2001, KLT Energy Services exchanged its ownership of $4.7 million of preferred stock in another energy service company for additional ownership in Strategic Energy. This transaction increased KLT Energy Services ownership of Strategic Energy from 72% to 83%. As of June 30, 2002, KLT Energy Services has invested $17.0 million in cash and securities to acquire its 83% ownership position. In 2000, Strategic Energy also provided retail gas services to commercial, institutional and small manufacturing customers. Strategic Energy elected to exit this business in the first quarter of 2001 to focus on power supply coordination services and had phased out of retail gas services at the end of 2001. Strategic Energy made this decision after evaluating the organizational demands, growth prospects and relative levels of profitability of both businesses. As the marketplace and Strategic Energy's business evolves, Strategic Energy may elect to re-enter the market for retail gas services. Strategic Energy currently provides power supply coordination services on behalf of approximately 27,500 commercial, institutional and small manufacturing accounts. Strategic Energy's customer base is very diverse. Customers include numerous Fortune 500 companies, school districts, and governmental entities. Based on current signed contracts and expected usage, Strategic Energy forecasts a peak load of 2,527 megawatts in 2002. The largest concentration of the forecasted load, 682 megawatts, is in Texas. The largest customer of the forecasted peak load, 181 megawatts, is a government agency. Strategic Energy enters into full-requirements contracts (usually one to five years in duration) with customers to supply electricity and manage their energy needs. In return, Strategic Energy receives an ongoing management fee which is included in the contracted price for the electricity. The average term remaining on Strategic Energy's current contracts is 2.7 years. To supply its retail contracts, Strategic Energy purchases blocks of electricity under forward contracts to purchase fixed quantities at fixed prices from power suppliers based on projected peak demand under one to five year contracts. When Strategic Energy has excess supply in the on-peak period, the excess is sold in the wholesale market. The savings generated by the sale of excess supply of on-peak electricity is used to reduce the cost of providing energy to Strategic Energy's retail customers and is recorded as a reduction of purchased power. 41 At June 30, 2002, Strategic Energy had entered into forward contracts with multiple suppliers. Should the supplier default and not deliver, Strategic Energy would be exposed to market fluctuations, and possible losses to the extent that the then current market price was higher than the fixed forward contract price. Strategic Energy monitors this risk by evaluating the credit quality of its suppliers on a routine basis as part of its risk management policy and practices. At June 30, 2002, Strategic Energy's five largest suppliers under forward supply contracts represented 77% of the total future committed purchases. Based on current wholesale electricity market prices, management believes that replacement power could be obtained without a significant impact on Strategic Energy's results of operations in the event of a default by a major supplier. Strategic Energy maintains a commodity-price risk management strategy that uses forward physical energy purchases and derivative instruments to minimize significant, unanticipated earnings fluctuations caused by commodity-price volatility. As a result of supplying electricity to retail customers under fixed rate contracts, Strategic Energy's policy is to match customers' demand with fixed price purchases. In certain markets where Strategic Energy operates, entering into forward fixed price contracts is cost prohibitive. By entering into swap contracts for a portion of its forecasted purchases in these markets, the future purchase price of electricity is effectively fixed under these swap contracts. The swap contracts limit the unfavorable effect that price increases will have on electricity purchases. Under SFAS No. 133, the majority of the swap agreements are designated as cash flow hedges resulting in the difference between the market value of energy and the hedge value being recorded as comprehensive income (loss). At June 30, 2002, the accumulated comprehensive loss, net of income taxes and minority interest, reflected in Great Plains Energy's consolidated statement of capitalization included a $5.9 million loss related to such cash flow hedges. However, substantially all of the energy hedged with the swaps has been sold to customers through contracts at prices different than the fair market value used to value the swaps. Therefore, Strategic Energy does not anticipate incurring the losses represented in comprehensive income. Strategic Energy Results of Operations The following table summarizes Strategic Energy's comparative results of operations. Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (millions) Operating revenues $ 201.2 $ 85.1 $ 347.6 $ 146.0 Purchased power (175.9) (64.6) (300.9) (109.1) Revenues, net of purchased power 25.3 20.5 46.7 36.9 Other operating expenses (8.2) (8.8) (15.2) (23.1) Depreciation (0.2) (0.1) (0.4) (0.1) Operating income 16.9 11.6 31.1 13.7 Non-operating expenses (2.8) (0.9) (5.2) (1.2) Interest charges (0.1) - (0.2) (0.1) Income taxes (5.8) (4.4) (10.6) (5.1) Net income $ 8.2 $ 6.3 $ 15.1 $ 7.3 Strategic Energy continued its trend of strong revenue and earnings growth in the second quarter of 2002, compared to the same period of 2001. Net income from Strategic Energy increased $1.9 million for the three months ended and $7.8 million year to date June 30, 2002, compared to the same periods of 2001. Operating income increased $5.3 million (46%) for the three months ended and $17.4 million (127%) year to date June 30, 2002, compared to the same periods of 2001, primarily due to growth in 42 retail electric sales from the expansion into new markets and continued sales efforts, partially offset by decreases in wholesale electric and commercial gas sales and increases in other operating expenses. Strategic Energy Operating Revenues Operating revenues from Strategic Energy increased $116.1 million (136%) for the three months ended and $201.6 million (138%) year to date June 30, 2002, compared to the same periods of 2001. The following table reflects the operating revenues of Strategic Energy for the three months ended and year to date June 30, 2002 and 2001. Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (millions) Electric - Retail $ 194.3 $ 56.6 $ 333.1 $ 93.2 Electric - Wholesale 6.7 23.6 13.9 37.3 Gas and other 0.2 4.9 0.6 15.5 Total Operating Revenues $ 201.2 $ 85.1 $ 347.6 $ 146.0 Strategic Energy currently serves approximately 27,500 commercial and small manufacturing accounts, compared to about 12,600 accounts at June 30, 2001. Strategic Energy added approximately 6,000 commercial and small manufacturing accounts during the second quarter of 2002, and approximately 8,000 commercial and small manufacturing accounts since the beginning of 2002. Based on current signed contracts and expected usage, Strategic Energy forecasts a peak load of 2,527 megawatts compared to a previously forecasted peak load of 2,268 megawatts disclosed in the 2001 Report on Form 10-K. Retail electric revenues increased $137.7 million (243%) for the three months ended June 30, 2002, compared to the same period of 2001, primarily due to an increase in retail mwh sales. Retail mwh's sold totaled 2,939,904 for the three months ended June 30, 2002, an increase of approximately 244% compared to the same period in 2001. Retail electric revenues increased $239.9 million (257%) year to date June 30, 2002, compared to the same period of 2001, primarily due to a 227% increase in retail mwh sales to 5,180,225 mwh. Wholesale electric revenues decreased $16.9 million (72%) for the three months ended and $23.4 million (63%) year to date June 30, 2002, compared to the same periods of 2001. The decline in wholesale electric revenues was primarily due to large block sales of power during the first and second quarters of 2001 purchased under a specific wholesale contract that expired at the end of 2001. Strategic Energy provides periodic billing credits to its customers resulting from favorable experience in its power supply coordination efforts. The amounts credited back to the customer are treated as a reduction of electricity energy sales when it is determined to be payable. During the fourth quarter of 2001, Strategic Energy phased out its natural gas retail supply service. This is the primary reason for the decrease in gas and other sales revenues for the three months ended and year to date June 30, 2002, compared to the same periods of 2001. Strategic Energy Purchased Power Purchased power increased $111.3 million (172%) for the three months ended and $191.8 million (176%) year to date June 30, 2002, compared to the same periods of 2001 primarily due to the increases in electric sales, as discussed above. Purchase power as a percentage of electric sales increased for both the three months ended and year to date June 30, 2002, compared to the same 43 periods of 2001, primarily due to purchases of power from one supplier during the first and second quarters of 2001 under very favorable wholesale contracts that expired at the end of 2001. Strategic Energy Other Operating Expenses Other operating expenses decreased $0.6 million for the three months ended and $7.9 million year to date June 30, 2002, compared to the same periods of 2001. However, the cost of commercial gas sales is included in other operating expenses for 2001. As previously mentioned, Strategic Energy phased out its natural gas retail supply service during the fourth quarter of 2001. Other operating expenses (excluding the cost of commercial gas sales) increased $3.4 million for the three months ended and $7.1 million year to date June 30, 2002, compared to the same periods of 2001, primarily due to higher general and administrative expenses associated with the growth in retail electric sales, expansion into new markets and increased fuel management and consulting activities. Strategic Energy Non-operating Expenses Non-operating expenses increased $1.9 million for the three months ended June 30, 2002, compared to the same period of 2001, primarily due to a gain of $1.4 million recognized on the sale of gas contracts during the second quarter of 2001. Non-operating expenses increased $4.0 million year to date June 30, 2002, compared to the same period of 2001, primarily due to an increase of $2.7 million in minority interest expense, which represents the share of Strategic Energy's net income not owned by KLT Energy Services, and the gain of $1.4 million recognized on the sale of gas contracts during the second quarter of 2001. KLT Gas KLT Gas Business Overview KLT Gas' business strategy is to acquire and develop early stage coalbed methane properties. KLT Gas believes that coalbed methane production provides an economically attractive alternative source of supply to meet the growing demand for natural gas in North America. KLT Gas has built a knowledge base in coalbed methane production and reserves evaluation. Therefore, KLT Gas focuses on coalbed methane - a niche in the natural gas industry where it believes its expertise provides a competitive advantage. Because it has a longer, predictable reserve life and lower development cost, management believes coalbed methane is inherently lower risk than conventional gas exploration. Although gas prices have been volatile recently, KLT Gas continues to believe that the long-term future price scenarios for natural gas appear strong. Environmental concerns and the increased demand for natural gas for new electric generating capacity are contributing to this projected growth in demand. KLT Gas' properties are located in Colorado, Texas, Wyoming, Kansas, and Nebraska. These leased properties cover approximately 250,000 undeveloped acres. The development of this acreage is in accordance with KLT Gas' exploration plan and capital budget. KLT Gas has revised its capital expenditure estimates, based on changes in market conditions and the anticipated development of recently acquired acreage in Colorado, to approximately $8 million, $33 million, $46 million and $31 million for the years 2002 through 2005, respectively. The timing of the development may vary from current plans based upon obtaining the required environmental and regulatory approvals and permits and future changes in market conditions. During the second quarter of 2002, KLT Gas completed pilot drilling at a Powder River Basin project and continued pilot development and testing of two additional coalbed methane projects in the Rocky Mountain region. 44 KLT Gas Results of Operations The following table summarizes KLT Gas' comparative results of operations. Three Months Ended Year to Date June 30 June 30 2002 2001 2002 2001 (millions) Operating revenues $ (0.1) $ 0.4 $ 0.1 $ 1.9 Other operating expenses (2.5) (3.3) (5.0) (6.0) Depreciation and depletion (0.1) (0.4) (0.4) (1.0) Gain (loss) on property (0.1) 19.6 (0.2) 20.9 Operating income (2.8) 16.3 (5.5) 15.8 Income from equity investments - 0.9 - 1.0 Non-operating income - - 0.3 - Income taxes 2.5 (5.3) 4.8 (3.5) Net income (loss) $ (0.3) $ 11.9 $ (0.4) $ 13.3 KLT Gas incurred losses for the three months ended and year to date June 30, 2002, compared to the same periods of 2001, when KLT Gas realized a gain on the Patrick KLT Gas, LLC sale. Net income for the three months ended and year to date June 30, 2001 included KLT Gas' second quarter 2001 Patrick KLT Gas, LLC, sale which resulted in a $19.5 million before tax gain ($11.6 million after tax). KLT Gas Operating Revenues Operating revenues decreased for the three months ended and year to date June 30, 2002, compared to the same periods of 2001, primarily due to declining production at KLT Gas' South Texas property and the effect of gas hedging activities. KLT Gas Income Taxes KLT Gas recorded tax credits related to its investment in natural gas properties of $1.5 million and $2.8 million for the three months ended and year to date June 30, 2002, respectively, as compared to $1.6 million and $3.4 million for the three months ended and year to date June 30, 2001, respectively. The law that allows these credits will expire at the end of 2002 unless extended by legislation. Other Non Regulated Activities Investments in Affordable Housing Limited Partnerships - KLT Investments At June 30, 2002, KLT Investments had $72.3 million in affordable housing limited partnerships. About 66% of these investments were recorded at cost; the equity method was used for the remainder. Tax expense is reduced in the year tax credits are generated. 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. 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, $45.8 million exceed this 5% level but were made before May 19, 1995. On a quarterly basis, KLT Investments compares the cost of those properties accounted for by the cost method to the total of projected residual value of the properties and remaining tax credits to be received. Estimated residual values are based on studies performed by an independent firm. Based on the latest comparison, KLT Investments reduced its investments in affordable housing limited partnerships by $5.3 million during the first quarter of 2002 and $1.8 million during the second quarter of 2002. KLT Investments estimates that additional reductions in affordable housing investments, 45 primarily as a result of ongoing utilization of tax credits, will approximate $2 million in the remainder of 2002. Projected annual reductions of the carrying value for the years 2003 through 2006 total $14 million, $6 million, $7 million and $6 million, respectively. Even after these reductions, earnings from affordable housing are expected to be positive for the next five years. These projections are based on the latest information available but the ultimate amount and timing of actual reductions made could be significantly different from the above estimates. KLT Investments accrued tax credits related to its investments in affordable housing limited partnerships of $4.8 million and $9.6 million for the three months ended and year to date June 30, 2002, respectively, as compared to $4.8 million and $9.6 million for the three months ended and year to date June 30, 2001, respectively. DTI Bankruptcy Update On December 31, 2001, a subsidiary of KLT Telecom, DTI filed voluntary petitions for bankruptcy. DTI's reorganization under Chapter 11 of the U.S. Bankruptcy Code continues in process. Timing of completion of the bankruptcy process has yet to be determined. During the first quarter of 2002, the bankruptcy court approved $5 million DIP financing to be provided by KLT Telecom. As of June 30, 2002, none of the DIP financing has been borrowed by DTI. As a result of DTI's filing for bankruptcy protection and KLT Telecom's resultant loss of control, KLT Telecom has not included in its results for the three months ended and year to date June 30, 2002, the ongoing earnings or loss incurred by DTI. KLT Telecom's results for the three months ended June 30, 2001, reflected DTI losses of $9.5 million and its results year to date June 30, 2001, reflected DTI losses of $13.9 million, excluding the early extinguishment of debt. Other Consolidated Discussion Significant Balance Sheet Changes (June 30, 2002 compared to December 31, 2001) o Great Plains Energy's receivables increased $67.2 million primarily due to a $51.8 million increase in Strategic Energy's receivables as a result of the strong growth in its power supply coordination services and a $20.4 million increase in consolidated KCP&L's receivables. Consolidated KCP&L's receivables increased primarily due to a $21.1 million increase in KCP&L's receivables due to the seasonal nature of the utility business. o Great Plains Energy's affordable housing limited partnerships decreased $8.9 million primarily due to a reduction in the valuation of the properties held by KLT Investments, Inc. o Great Plains Energy's other nonutility property and investments increased $7.4 million primarily due to a $2.1 million increase in KLT Energy Services' investment in preferred stock in Custom Energy and a $4.6 million increase in consolidated KCP&L's other investments. Consolidated KCP&L's other nonutility property and investments increased primarily due to a $3.2 million increase in property at RSAE to record vehicles under a capital lease. o Great Plains Energy's and consolidated KCP&L's regulatory assets increased $16.7 million primarily due to deferral of $19.5 million of the January ice storm costs applicable to KCP&L's Missouri customers partially offset by scheduled amortization of the assets. o Great Plains Energy's notes payable increased $70.9 million due to increased borrowings by Great Plains Energy of $68.0 million on its short-term credit facility for general corporate purposes and a $2.9 million increase in consolidated KCP&L's notes payable. Consolidated KCP&L's notes payable increased due to additional borrowing by RSAE on its short-term credit facility for general corporate purposes. o Great Plains Energy's and consolidated KCP&L's commercial paper increased $32.9 million primarily due to a $27.0 million repayment of medium-term notes and additional borrowings as expenditures exceeded cash receipts. 46 o Great Plains Energy's current maturities of long-term debt decreased $209.3 million primarily due to a $207.0 million decrease in consolidated KCP&L's current maturities of long-term debt. Consolidated KCP&L's decrease is primarily due to refinancing $200.0 million of maturing KCP&L medium-term notes with the issuance of KCP&L unsecured senior notes and a $27.0 million decrease due to KCP&L retiring medium-term notes partially offset by a $20.0 million increase in the current portion of KCP&L's medium-term notes. o Great Plains Energy's accounts payable increased $4.8 million primarily due to a $45.4 million increase in Strategic Energy's accounts payable as a result of the strong growth in its power supply coordination services, mostly offset by a $33.9 million decrease in consolidated KCP&L's accounts payable and a $6.5 million decrease in KLT Gas' accounts payable. Consolidated KCP&L's accounts payable decreased primarily due to the timing of cash payments. o Great Plains Energy's accrued taxes increased $9.7 million primarily due to a $7.8 million increase in consolidated KCP&L's accrued taxes. Consolidated KCP&L's increase is primarily due to an increase in KCP&L's accrued property taxes because of the timing of property tax payments. o Great Plains Energy's accrued interest increased $5.0 million primarily due to a $6.5 million increase in consolidated KCP&L's accrued interest. Consolidated KCP&L's increase is primarily due to additional debt and the timing of interest payments on KCP&L's long-term debt. o Great Plains Energy's other current liabilities decreased primarily due to the fluctuation in the fair value of Strategic Energy's derivatives. 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 from its subsidiaries or proceeds from the sale of its securities. Great Plains Energy's liquid resources at June 30, 2002, included cash flows from operations of subsidiaries and $99.5 million of unused bank lines of credit. The unused lines consisted of $56.1 million from KCP&L's short-term bank lines of credit, $0.4 million from RSAE's bank credit agreement, $10.0 million from Strategic Energy's bank line of credit, and $33.0 million from Great Plains Energy's revolving credit facilities. During the first quarter of 2002, Great Plains Energy terminated its $129 million bridge revolving credit facility and replaced it with a $205 million 364-day revolving credit facility syndicated with a group of banks. The revolving credit facility contains a Material Adverse Change (MAC) clause that requires Great Plains Energy to represent, prior to receiving any funding, that no MAC has occurred. Great Plains Energy's available liquidity under this facility is not impacted by a decline in credit ratings unless the downgrade occurs in the context of a merger, consolidation or sale. During the second quarter of 2002, Great Plains Energy entered into a $20 million 364-day revolving credit facility with a bank. The revolving credit facility does not contain a MAC clause. Great Plains Energy's available liquidity under this facility is not impacted by a decline in credit ratings unless the downgrade occurs in the context of a merger, consolidation or sale. During August 2002, Strategic Energy increased its bank line of credit to $30 million from $10 million. The line of credit contains a MAC clause. This agreement requires Strategic Energy to represent, prior to receiving any funding, that no MAC has occurred. KCP&L's primary sources of liquidity are cash flows from operations and bilateral credit lines totaling $151.0 million with seven banks (as of June 30, 2002). KCP&L uses these lines to provide support for its issuance of commercial paper, $94.9 million of which was outstanding at June 30, 2002. During July 47 2002, KCP&L repaid $39.3 million of commercial paper. These bank facilities are each for a 364-day term and mature at various times throughout the year. KCP&L has MAC clauses in two agreements covering $50.0 million of available bilateral credit lines. These two agreements require KCP&L to represent, prior to receiving any funding, that no MAC has occurred. KCP&L's available liquidity under these facilities is not impacted by a decline in credit ratings unless the downgrade occurs in the context of a merger, consolidation or sale. Great Plains Energy has agreements with KLT Investments Inc., a wholly owned subsidiary of KLT Inc., associated with notes KLT Investments Inc. issued to acquire its affordable housing investments. Prior to forming Great Plains Energy, KCP&L had these agreements. Great Plains Energy agreed not to take certain actions including, but not limited to, merging, dissolving or causing the dissolution of KLT Investments Inc., or withdrawing amounts from KLT Investments Inc. if the withdrawals would result in KLT Investments Inc. to not be in compliance with minimum net worth and cash balance requirements. The amendment also gives KLT Investments Inc.'s lenders the right to have KLT Investments Inc. repurchase the notes if Great Plains Energy's senior debt rating falls below investment grade, or if Great Plains Energy ceases to own at least 80% of KCP&L's stock. At June 30, 2002, KLT Investments Inc. had $20.3 million in outstanding notes, including current maturities. Pursuant to agreements with the MPSC and the KCC, KCP&L has maintained its common equity at not less than 35 percent of total capitalization. Additionally, Great Plains Energy has maintained its consolidated common equity at no less than 30 percent of total consolidated capitalization. For the purposes of this calculation, capitalization is defined as common equity, preferred stock, long-term debt and short-term debt in excess of construction work in progress. Great Plains Energy's consolidated statements of cash flows include consolidated KCP&L, KLT Inc. and GPP. KCP&L's consolidated statements of cash flows include its wholly owned subsidiary HSS. In addition, KCP&L's consolidated statements of cash flows include KLT Inc. and GPP for all the periods prior to the October 1, 2001 formation of the holding company. The presentation of the prior year statement of cash flows for Great Plains Energy is provided for comparative purposes and is identical to the statement of cash flows for consolidated KCP&L, prior to the formation of the holding company. Great Plains Energy and consolidated KCP&L generated positive cash flows from operating activities year to date June 30, 2002. The increase for Great Plains Energy and consolidated KCP&L over the same period of 2001 is attributable to changes in working capital detailed in Note 3 to the consolidated financial statements. The individual components of working capital vary with normal business cycles and operations. Also, the timing of the Wolf Creek outage affects the refueling outage accrual, deferred income taxes and amortization of nuclear fuel. 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. Year to date June 30, 2002, utility capital expenditures decreased $53.4 million and allowance for borrowed funds used during construction decreased $7.2 million, compared to 2001, primarily due to the 2001 completion of the rebuild of Hawthorn No. 5. The decrease was partially offset by $14.7 million of capital expenditures as a result of the January 2002 ice storm. Cash used for purchases of investments and nonutility property year to date June 30, 2002, compared to the same period of 2001, decreased primarily reflecting KLT Telecom's 2001 investments in DTI and DTI's 2001 purchases of telecommunications property. Cash from Great Plains Energy and consolidated KCP&L financing activities decreased year to date June 30, 2002 compared to the same period of 2001, primarily because of the net changes in short-term borrowings. Additionally, long-term debt issuances, net of repayments decreased $43.9 million for 48 Great Plains Energy and $33.1 million for consolidated KCP&L. These decreases reflect decreased investing activities in utility capital expenditures, nonutility property and investments discussed above. KCP&L expects to meet day-to-day operating requirements including interest payments, construction requirements (excluding new generating capacity) and dividends with internally-generated funds. However, it might not be able to meet these requirements with internally-generated funds because of the effect of inflation on operating expenses, the level of mwh sales, regulatory actions, compliance with future environmental regulations and the availability of generating units. The funds Great Plains Energy and consolidated KCP&L need to retire $396.3 million and $376.9 million, respectively, of maturing debt through the year 2006 are expected to be provided from operations, the issuance of long and short-term debt and/or the issuance of equity or equity-linked instruments. In addition, the Company may issue debt, equity and/or equity-linked instruments to finance growth or take advantage of new opportunities. In March 2002, KCP&L issued $225 million of 6.0% unsecured senior notes, maturing in 2007, through a private placement. The proceeds from the issuance were primarily used to refinance maturing unsecured medium-term notes. KCP&L, pursuant to its obligations under a registration rights agreement entered into in connection with the private placement, filed an S-4 registration statement offering to exchange up to $225 million of 6.0% unsecured senior notes registered under the Securities Act for the $225 million privately placed notes. KCP&L expects the registration statement to become effective during the third quarter. Great Plains Energy filed an S-3 registration statement on April 29, 2002, for the issuance of an aggregate amount up to $300 million of any combination of senior debt securities, subordinated debt securities, trust preferred securities, convertible securities, or common stock. Great Plains Energy has previously announced its plans to issue additional common equity. The timing and amount of this transaction is dependent on a number of factors, including overall and sector-specific equity market conditions. Supplemental Capital Requirements and Liquidity Information Update Great Plains Energy's other long-term contractual cash obligations, net, have increased approximately 28% since December 31, 2001. The increase is primarily for new Strategic Energy purchased power contracts in the years 2003 through 2006 supporting the growth in their power supply coordination services. The Company's guarantees in total are relatively unchanged from December 31, 2001. However, year to date 2002, approximately $126.5 million of KLT Inc.'s guarantees related to Strategic Energy have been replaced by Great Plains Energy guarantees. There was also an increase to $25 million from $22 million at December 31, 2001, in RSAE's line of credit with a commercial bank, which Great Plains Energy supports through an agreement that ensures adequate capital to operate. Environmental Matters The Company's operations comply with federal, state and local environmental laws and regulations. The generation and transmission of electricity produces and requires disposal of certain products and by-products, including PCBs, asbestos and other hazardous materials. The Superfund law imposes strict joint and several liability for those who generate, transport or deposit hazardous waste. In addition, the current owner of contaminated property, as well as prior owners since the time of contamination, may be liable for cleanup costs. Environmental audits are conducted to detect contamination and ensure compliance with governmental regulations. However, compliance programs need to meet new and future environmental laws, as well as regulations governing water and air quality, including carbon dioxide emissions, nitrogen oxide 49 emissions, hazardous waste handling and disposal, toxic substances and the effects of electromagnetic fields. Therefore, compliance programs could require substantial changes to operations or facilities (see Note 7 to the consolidated financial statements). Critical Accounting Policies Update KCP&L is regulated and follows SFAS No. 71, "Accounting for Certain Types of Regulation", which applies to regulated entities with rates that are designed to recover the costs of providing service. Accordingly, KCP&L defers on the balance sheet items when allowed by a commission's rate order or when it is probable, based on regulatory past practices, that future rates will recover the amortization of the deferred costs. If SFAS No. 71 were not applicable, regulatory assets would be written off. At June 30, 2002, KCP&L had $141.1 million of unamortized regulatory assets including storm costs discussed below. Effective August 2002, the MPSC approved KCP&L's application for an accounting authority order related to the Missouri jurisdictional portion of the storm costs. The order allows KCP&L to defer and amortize $19.5 million, representing the Missouri impact of the storm, through January 2007. The amortization begins in September 2002 and is expected to be approximately $1.5 million in 2002 and approximately $4.6 million annually for the remainder of the amortization period. The Company adopted SFAS No. 142 on January 1, 2002. Under the new standard, goodwill is no longer amortized, but rather is tested for impairment upon adoption and at least annually thereafter. The annual test may be performed anytime during the year, but must be performed at the same time each year. The Company will perform its annual goodwill impairment tests before the end of the year. Any future impairment of goodwill would be reflected in continuing operations. Strategic Energy's initial valuation has been completed and there was no impairment of the $14 million of goodwill. In accordance with SFAS No. 142, the Company completed its initial impairment test of RSAE during the second quarter of 2002 and recorded a $3.0 million write-down of goodwill. The goodwill write-down is reflected as a cumulative effect to January 1, 2002 of a change in accounting principle. After the write-down, RSAE had goodwill of $20 million, which was unchanged through June 30, 2002. 50 ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK Great Plains Energy and consolidated KCP&L are exposed to market risks associated with commodity price and supply, interest rates and equity prices. Market risks are handled in accordance with established policies, which may include entering into various derivative transactions. In the normal course of business, Great Plains Energy and consolidated KCP&L also face risks that are either non-financial or non-quantifiable. Such risks principally include business, legal, operational and credit risks and are not represented in the following analysis. Great Plains Energy and consolidated KCP&L interim period disclosures about market risk included in quarterly reports on Form 10-Q address material changes, if any from the most recently filed annual report on Form 10-K. Therefore, interim period disclosures should be read in connection with the quantitative and qualitative disclosures about market risk included in our 2001 annual report on Form 10-K. There have been no material changes in Great Plains Energy's or consolidated KCP&L's market risk since December 31, 2001. 51 PART II - OTHER INFORMATION ITEM 3. OTHER LEGAL PROCEEDINGS Patricia S. Lang, et al. on behalf of herself and all others similarly situated v. Kansas City Power & Light Company. On October 8, 1999, A First Amended Class Action Complaint was filed against KCP&L in the United Sates District Court, Western District of Missouri (the Court) by Patricia Lang (the Plaintiff). The complaint, filed as a class action on behalf of Plaintiff and all other current and former African American employees, alleged that Plaintiff and the members of the proposed class were subjected to a hostile and offensive working environment, denied promotional opportunities, compensated less than similarly or less qualified Caucasian employees, and were disciplined and/or terminated for complaining about allegedly racially discriminatory practices by KCP&L. The complaint sought a monetary award for alleged lost wages and fringe benefits, alleged wage differentials, as well as punitive damages, attorneys fees and costs of the action together with an injunction to prohibit KCP&L from retaliating against the litigants and to continue court monitoring of KCP&L's compliance with anti-discrimination laws. On March 1, 2001, the Court denied Plaintiff's motion to certify a class action of African-American employees in the race discrimination case. The plaintiff appealed this decision and on April 10, 2001, the United States Court of Appeals for the 8th Circuit (the 8th Circuit Court of Appeals) denied the appeal. On January 11, 2002, the Court dismissed Plaintiff's individual case on summary judgment. On February 8, 2002, Plaintiff appealed both the decision dismissing her individual case on summary judgment and the order denying her motion for class certification to the 8th Circuit Court of Appeals. On April 5, 2002, the Eighth Circuit dismissed the appeal. On June 4, 2002, the case was dismissed with prejudice by stipulation. DTI Chapter 11 Reorganization Proceedings. - ----------------------------------------- Pending in the United States Bankruptcy Court for the Eastern District of Missouri (Bankruptcy Court) is the bankruptcy reorganization proceedings filed on December 31, 2001, by DTI and its Virginia subsidiary in Case Nos. 01-54369-399, 01-54370-399 and 01-54371-399. These proceedings have been consolidated for joint procedural administration. DTI is continuing to conduct its business operations while it restructures its financial obligations. KLT Telecom Inc. is a creditor in the proceedings. Timing of completion of the bankruptcy process has yet to be determined. During the first quarter of 2002, the bankruptcy court approved $5 million in DIP financing to be provided by KLT Telecom. As of June 30, 2002, none of the DIP financing has been borrowed by DTI. Consistent with the fiduciary obligation of the creditors' committee to investigate potential sources of recovery for the DTI bankruptcy estate, the creditors' committee served a request for the production of documents by the Company and its affiliates relating to the issue of whether DTI should have been compensated for the use by the Company of its tax losses. The Company believes that it would have meritorious defenses to any such claim that ultimately might be asserted by the creditors' committee. Since the legal and factual basis for any such unasserted claim have not yet been established, the Company is currently unable to estimate the amount of liability or loss, if any, that might arise if a claim is asserted. ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS. Great Plains Energy Incorporated held its annual meeting of shareholders on May 7, 2002. Three matters were submitted to a vote of the Company's shareholders: 1. The following directors were elected by cumulative voting to hold office until the next Annual Meeting of Shareholders in 2003: 52 Abstentions (Withheld Authority) Director Votes Cast to Vote for All Nominee For Directors B. J. Beaudoin 51,929,013 941,887 D. L. Bodde 51,636,604 941,887 M. A. Ernst 51,575,382 941,887 R. C. Ferguson, Jr. 51,650,612 941,887 W. K. Hall 51,838,536 941,887 L. A. Jimenez 51,669,726 941,887 J. A. Mitchell 51,748,748 941,887 W. C. Nelson 51,494,683 941,887 L. H. Talbott 51,807,385 941,887 R. H. West 51,575,681 941,887 2. The term of the Company's Long-Term Incentive Plan was extended by the following vote: For 46,090,000 Against 5,356,904 Abstentions 1,187,620 3. The appointment of Deloitte & Touche LLP as independent auditors was ratified by the following vote: For 50,763,333 Against 1,283,604 Abstentions 587,587 53 ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K. EXHIBITS Great Plains Energy Incorporated Exhibit No. Description 10.1.a. General Agreement of Indemnity issued by Great Plains Energy Incorporated and Strategic Energy, L.L.C., in favor of Federal Insurance Company and subsidiary or affiliated insurers, dated May 23, 2002. 10.1.b. Agreement of Indemnity issued by Great Plains Energy Incorporated and Strategic Energy, L.L.C., in favor of Federal Insurance Company and subsidiary or affiliated insurers, dated May 23, 2002. 10.1.c. Guaranty issued by Great Plains Energy Incorporated in favor of El Paso Merchant Energy, L.P. dated June 14, 2002. 10.1.d. Line of Credit Agreement between Great Plains Energy Incorporated and LaSalle Bank National Association, dated as of June 14, 2002 99.1.a Certification of CEO and CFO Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 Kansas City Power & Light Company Exhibit No. Description 99.2.a Certification of CEO and CFO Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 REPORTS ON FORM 8-K Great Plains Energy Incorporated Great Plains Energy Incorporated filed on April 25, 2002, a report on Form 8-K dated April 24, 2002, including a press release regarding first quarter results and accompanying financials. Kansas City Power & Light Company Kansas City Power & Light Company did not file any reports on Form 8-K during the second quarter 2002. 54 SIGNATURES Pursuant to the requirements of the Securities Exchange Act of 1934, Great Plains Energy Incorporated and Kansas City Power & Light Company have duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. GREAT PLAINS ENERGY INCORPORATED Dated: August 12, 2002 By: /s/Bernard J. Beaudoin (Bernard J. Beaudoin) (Chief Executive Officer) Dated: August 12, 2002 By: /s/Neil Roadman (Neil Roadman) (Principal Accounting Officer) KANSAS CITY POWER & LIGHT COMPANY Dated: August 12, 2002 By: /s/Bernard J. Beaudoin (Bernard J. Beaudoin) (Chief Executive Officer) Dated: August 12, 2002 By: /s/Neil Roadman (Neil Roadman) (Principal Accounting Officer) 55
                                                  Exhibit 10.1.a.

               CHUBB GROUP OF INSURANCE COMPANIES

 15 Mountain View Road, P.O. Box 1615, Warren, New Jersey 07061-
                              1615
 ______________________________________________________________

                 GENERAL AGREEMENT OF INDEMNITY

    WHEREAS,   the  undersigned  (hereinafter  individually   and
collectively  called  "Indemnitor")  desires  FEDERAL   INSURANCE
COMPANY   or  any  of  its  subsidiary  or  affiliated   insurers
(hereinafter   called  "Company")  to  execute  bonds   including
undertakings and other like obligations (hereinafter referred  to
as  bond  or  bonds) on its behalf or on behalf  of  any  of  its
subsidiaries  or on behalf of any subsidiary or a  subsidiary  or
successive  subsidiaries,  direct or indirect,  now  existing  or
hereafter  created  (hereinafter  called  "Subsidiaries")  or  on
behalf  of any one or more of them and also desires the execution
of  bonds on behalf of individuals, partnerships or corporations,
limited liability companies or any other similarly unincorporated
associations of members (hereinafter called "Affiliates").

  WHEREAS, from time to time either the Indemnitor or one of more
of  its  Subsidiaries may be participant in joint  ventures  with
others, and bonds will be required on behalf of the Indemnitor or
one or more of its Subsidiaries along with the other participants
in such joint ventures.

   NOW, THEREFORE, in consideration of the Company executing said
bond or bonds, and the undersigned Indemnitor hereby requests the
execution thereof, and in consideration of the sum of One  Dollar
paid  to  the Indemnitor by said Company, the receipt whereof  is
hereby  acknowledged,  the  Indemnitor  being  benefited  by  the
execution and delivery of said bond or bonds, hereby agrees  that
it  will  at all times jointly and severally indemnify  and  save
harmless  said Company from and against any and all loss,  damage
or  expense, including court costs and attorneys' fees, which  it
shall  at  any  time  incur  by reason of  its  execution  and/or
delivery  of  said bond or bonds or its payment of any  claim  or
liability thereunder and will place the said Company in funds  to
meet  all  its  liability under said bond or  bonds  promptly  on
request  and  before  it  may be required  to  make  any  payment
thereunder  and that the voucher or other evidence of payment  by
said  Company  of  any  such  loss, damage,  expense,  claim,  or
liability shall be prima facie evidence of the fact and amount of
said Indemnitor's liability to said Company under this Agreement.

   IT  IS  UNDERSTOOD AND AGREED that Indemnitor will,  upon  the
written  request of the Company, promptly procure  the  full  and
complete  discharge  of the Company from any bonds  specified  in
such  request and all liability by reason thereof.  If such  full
and  complete discharge is unattainable, the Indemnitor will,  if
requested  by  the  Company,  promptly  provide  the  Company  an
irrevocable  letter  of  credit acceptable  to  the  Company,  as
collateral,  in  an amount sufficient to cover  all  undischarged
liability  under such specified bond or bonds, or  promptly  make
other provisions acceptable to the Company to fully collateralize
the  aforesaid undischarged liability.  Indemnitor further agrees
that,   in  the  event  of  its  breach  of  its  obligation   to
collateralize  the  undischarged liability  under  all  specified
bonds, the Company will have no adequate remedy at law and  shall
therefore be entitled to specific performance of the Indemnitor's
obligation  to  collateralize such undischarged  liability.   The
Company's  failure  to  act  to enforce  its  right  to  specific
performance hereunder shall not be construed as a waiver of  that
right,  which  may be enforced at any time at the Company's  sole
discretion.

   IT IS UNDERSTOOD AND AGREED that with respect to any bonds  on
behalf of Indemnitor, or any Subsidiary participating in a  joint
venture  that if specific application is filed with  the  Company
for  such  bonds the liability of the Indemnitor to  the  Company
with respect to such joint venture bonds shall be limited to  the
amount expressly set forth in said application.

   IT IS UNDERSTOOD AND AGREED that all of the terms, provisions,
and conditions of this Agreement shall be extended to and for the
benefit  not  only  of  the Company either as  a  direct  writing
company  or as a co-surety or reinsurer but also for the  benefit
of  any  surety or insurance company or companies with which  the
Company may participate as a co-surety or reinsurer and also  for
the  benefit of any other company which may execute any  bond  or
bonds  at  the request of the Company on behalf of Indemnitor  or
any of its Subsidiaries or Affiliates.

   IT  IS FURTHER UNDERSTOOD AND AGREED that said Indemnitor, its
heirs, successors and assigns are jointly and severally bound  by
the foregoing conditions of this Agreement.

   IN  WITNESS WHEREOF said Indemnitor has signed this instrument
under seal this 23rd day of May, 2002.

STRATEGIC ENERGY, L.L.C. (Seal)    GREAT PLAINS ENERGY INC.(Seal)

By:  /s/ Richard M. Zomnir         By:  /s/ Andrea F. Bielsker

_______________________________

By: ___________________________    ____________________________
                                                  Individually
_______________________________

By: ___________________________    ____________________________
                                                  Individually
_______________________________



                 CERTIFICATE OF ACKNOWLEDGEMENT

State of Pennsylvania    )
County of Allegheny      )

     On May 23, 2002 before me Eileen L. Parson personally
appeared Richard M. Zomnir personally known to me (or proved to
me on the basis of satisfactory evidence) to be the person(s)
whose name(s) is/are subscribed to the within instrument and
acknowledged to me that he/she/they executed the same in
his/her/their authorized capacity(ies), and that by his/her/their
signature(s) on the instrument the person(s), or the entity upon
behalf of which the person(s) acted, executed the instrument.

     WITNESS my hand and official seal.

Signature  /s/ Eileen L. Parson    (Seal)

                 CERTIFICATE OF ACKNOWLEDGEMENT

State of Pennsylvania    )
County of Allegheny      )

     On May 23, 2002 before me Eileen L. Parson personally
appeared Andrea F. Bielsker, Senior Vice President Finance, Chief
Financial Officer & Treasurer personally known to me (or proved
to me on the basis of satisfactory evidence) to be the person(s)
whose name(s) is/are subscribed to the within instrument and
acknowledged to me that he/she/they executed the same in
his/her/their authorized capacity(ies), and that by his/her/their
signature(s) on the instrument the person(s), or the entity upon
behalf of which the person(s) acted, executed the instrument.

     WITNESS my hand and official seal.

Signature  /s/ Eileen L. Parson    (Seal)

                 CERTIFICATE OF ACKNOWLEDGEMENT

State of Pennsylvania    )
County of Allegheny      )

     On              before me
personally appeared
personally known to me (or proved to me on the basis of
satisfactory evidence) to be the person(s) whose name(s) is/are
subscribed to the within instrument and acknowledged to me that
he/she/they executed the same in his/her/their authorized
capacity(ies), and that by his/her/their signature(s) on the
instrument the person(s), or the entity upon behalf of which the
person(s) acted, executed the instrument.

     WITNESS my hand and official seal.

Signature                          (Seal)

                 CERTIFICATE OF ACKNOWLEDGEMENT

State of Pennsylvania    )
County of Allegheny      )

     On              before me
personally appeared
personally known to me (or proved to me on the basis of
satisfactory evidence) to be the person(s) whose name(s) is/are
subscribed to the within instrument and acknowledged to me that
he/she/they executed the same in his/her/their authorized
capacity(ies), and that by his/her/their signature(s) on the
instrument the person(s), or the entity upon behalf of which the
person(s) acted, executed the instrument.

     WITNESS my hand and official seal.

Signature                          (Seal)



                                                  Exhibit 10.1.b.

               CHUBB GROUP OF INSURANCE COMPANIES

Surety Department, 15 Mountain View Road, P.O. Box 1615, Warren,
                          NJ 07061-1615
       Phone:  (908) 903-3485 * Facsimile:  (908) 903-3656

- -----------------------------------------------------------------

                                        FEDERAL INSURANCE COMPANY

                     AGREEMENT OF INDEMNITY

WHEREAS,  application has been made to FEDERAL INSURANCE COMPANY,
or  any  of its subsidiary or affiliated insurers, of 15 Mountain
View Road, Warren, New Jersey (hereinafter called "Company"),  to
continue  as surety upon specific bonds described on the attached
Schedule A.

NOW,  THEREFORE, in consideration of the Company  having  written
said  bonds  on  behalf  of  Strategic  Energy  L.L.C.,  and  the
undersigned  (hereinafter individually  and  collectively  called
"Indemnitor") acknowledges the release of KLT Inc. as indemnitor,
for  all past, present and future liability, and in consideration
of  the sum of One Dollar paid to the Indemnitor by said Company,
the receipt whereof is hereby acknowledged, the Indemnitor, being
substantially benefited by the continued existence of said bonds,
(and  having  either a direct or indirect financial  interest  in
said applicant), hereby agrees:

  1. That  the  Indemnitor  will at all times indemnify  and  save
     harmless  said  Company from and against any and  all  loss,
     cost,   damage  or  expense,  including  court   costs   and
     attorneys'  fees, which it shall at any time incur,  sustain
     or incur

       i.   by  reason  of having executed or procured  the
            execution of said bonds,
       ii.  by  reason  of  failure of the  undersigned  to
            perform  or  comply with the covenants and conditions
            of this agreement, or
       iii. in   enforcing  any  of  the   covenants   and
            conditions of this agreement,

     and  will  place the said Company in funds to meet  all  its
     liability under said bonds promptly on request and before it
     may  be  required to make any payment thereunder.  That  the
     voucher or other evidence of payment by said Company of  any
     such  loss, cost, damage, expense, claim or liability  shall
     be  prima  facie  evidence of the fact  and  amount  of  the
     Indemnitor's liability to said Company under this Agreement;

  2. That  the  Company  may  make or consent  to  any  change  or
     alteration in said bonds and may execute renewals thereof or
     other  obligations in lieu thereof, or may consent or assent
     to  any change or alteration in any instrument, contract  or
     agreement  concerned  therewith,  without  notice   to   the
     Indemnitor  (notice  being expressly waived)  and,  in  such
     case,  the  Indemnitor shall be liable to the Company  fully
     and  to  the  same extent that the Company shall  be  liable
     under such changed or altered bonds or such renewals thereof
     or other obligations in lieu thereof;

  3. That  the  Company shall have the exclusive right for  itself
     and for the Indemnitor to take charge of all matters arising
     under  said  bonds and decide whether or not  it  is  liable
     thereunder  and shall determine the amount of its  liability
     in  case  it  decides that it is liable.  It may  settle  or
     compromise  any claims and defend, settle or compromise  any
     suits  and  take  such other action in connection  with  any
     claim  matter  arising  under said  bonds  as  it  may  deem
     advisable.   Any  such decision, determination,  settlement,
     defense,  compromise  or  other action  of  the  Company  in
     connection  with any claim matter arising under  said  bonds
     shall  be  final and conclusive and unconditionally  binding
     upon the Indemnitor;

  4. That  the  Indemnitor  and the heirs, legal  representatives,
     successors and assigns of the Indemnitor shall be and hereby
     are  jointly and severally bound by the foregoing provisions
     of  this Agreement, and that the liability of the Indemnitor
     hereunder   and   of   the  heirs,  legal   representatives,
     successors and assigns of the Indemnitor hereunder shall not
     be  dependent upon the proper execution of this Agreement or
     any instrument herein referred to by any other Indemnitor or
     by  said applicant, and that if the Company procures any co-
     surety on said bonds, and it is hereby authorized to do  so,
     this  Agreement  shall be deemed extended  to  and  for  the
     benefit of said co-surety.



IT  IS  UNDERSTOOD  AND  AGREED that Indemnitor  will,  upon  the
written  request of the Company, promptly procure  the  full  and
complete  discharge  of  the Company  from  said  bonds  and  all
liability by reason thereof.  If such full and complete discharge
is  unattainable,  the  Indemnitor  will,  if  requested  by  the
Company,  promptly provide the Company an irrevocable  letter  of
credit  acceptable to the Company, as collateral,  in  an  amount
sufficient to cover all undischarged liability under said  bonds,
or  promptly make other provisions acceptable to the  Company  to
fully   collateralize   the  aforesaid  undischarged   liability.
Indemnitor further agrees that, in the event of its breach of its
obligation to collateralize the undischarged liability under said
bond,  the Company will have no adequate remedy at law and  shall
therefore be entitled to specific performance of the Indemnitor's
obligation  to  collateralize such undischarged  liability.   The
Company's  failure  to  act  to enforce  its  right  to  specific
performance hereunder shall not be construed as a waiver of  that
right,  which  may be enforced at any time at the Company's  sole
discretion.

IT  IS  FURTHER  UNDERSTOOD AND AGREED that  all  of  the  terms,
provisions, and conditions of this Agreement shall be extended to
and  for  the benefit not only of the company either as a  direct
writing  company or as a co-surety or reinsurer but also for  the
benefit  of  any  surety or insurance company or  companies  with
which the Company may participate as a co-surety or reinsurer and
also  for the benefit of any other company which may execute said
bond at the request of the Company.

IN  WITNESS WHEREOF the Indemnitor has signed this Agreement this
23rd day of May, 2002.

STRATEGIC ENERGY, L.L.C.           GREAT PLAINS ENERGY INC.
                    (seal)                             (seal)

By:  /s/ Richard M. Zomnir         By:  /s/ Andrea F. Bielsker

Name and Title:                    Name and Title:
Richard M. Zomnir                  Andrea F. Bielsker
President & CEO                    Senior Vice President,
                                   Finance Chief Financial
                                   Officer & Treasurer



                 CERTIFICATE OF ACKNOWLEDGEMENT

State of Pennsylvania    )
County of Allegheny      )

     On May 23, 2002 before me Eileen L. Parson personally
appeared Richard M. Zomnir personally known to me (or proved to
me on the basis of satisfactory evidence) to be the person(s)
whose name(s) is/are subscribed to the within instrument and
acknowledged to me that he/she/they executed the same in
his/her/their authorized capacity(ies), and that by his/her/their
signature(s) on the instrument the person(s), or the entity upon
behalf of which the person(s) acted, executed the instrument.

     WITNESS my hand and official seal.

Signature:  /s/ Eileen L. Parson        (Seal)

                 CERTIFICATE OF ACKNOWLEDGEMENT

State of Pennsylvania    )
County of Allegheny      )

     On May 23, 2002 before me Eileen L. Parson personally
appeared Andrea F. Bielsker, Senior Vice President Finance, Chief
Financial Officer and Treasurer personally known to me (or proved
to me on the basis of satisfactory evidence) to be the person(s)
whose name(s) is/are subscribed to the within instrument and
acknowledged to me that he/she/they executed the same in
his/her/their authorized capacity(ies), and that by his/her/their
signature(s) on the instrument the person(s), or the entity upon
behalf of which the person(s) acted, executed the instrument.

     WITNESS my hand and official seal.

Signature:  /s/ Eileen L. Parson        (Seal)

                 CERTIFICATE OF ACKNOWLEDGEMENT

State of ___________     )
County of___________     )

     On             before me                personally appeared
personally known to me (or proved to me on the basis of
satisfactory evidence) to be the person(s) whose name(s) is/are
subscribed to the within instrument and acknowledged to me that
he/she/they executed the same in his/her/their authorized
capacity(ies), and that by his/her/their signature(s) on the
instrument the person(s), or the entity upon behalf of which the
person(s) acted, executed the instrument.

     WITNESS my hand and official seal.

Signature:                              (Seal)

                 CERTIFICATE OF ACKNOWLEDGEMENT

State of ___________     )
County of __________     )

     On             before me                personally appeared
personally known to me (or proved to me on the basis of
satisfactory evidence) to be the person(s) whose name(s) is/are
subscribed to the within instrument and acknowledged to me that
he/she/they executed the same in his/her/their authorized
capacity(ies), and that by his/her/their signature(s) on the
instrument the person(s), or the entity upon behalf of which the
person(s) acted, executed the instrument.

     WITNESS my hand and official seal.

Signature:                              (Seal)



                             Page 1
                                                   Exhibit 10.1.c

                            GUARANTY

     This Guaranty, dated as of June 14, 2002, is made by Great
Plains Energy Incorporated (herein called "Guarantor"), a
Missouri corporation with its principal place of business located
at 1201 Walnut, Kansas City, Missouri 64106, in favor of El Paso
Merchant Energy, L.P. (herein called "Creditor") with its
principal place of business located at 1001 Louisiana, Houston,
Tx 77002.

     Creditor and Strategic Energy, L.L.C., a Delaware limited
liability company and a related company of Guarantor (Guarantor
has an indirect ownership interest in Strategic Energy, L.L.C.),
with its principal place of business located at Two Gateway
Center, Pittsburgh, PA 15222,  (herein called "Debtor") have
entered into or hereafter may enter into contracts, agreements or
commitments (i) for the sale, purchase, exchange, transmission or
transportation of electricity or (ii) which constitute or cover
swaps, options or other derivative transactions relative to
electricity or the price thereof (herein collectively called the
"Agreements").  In order to induce Creditor to extend or to
continue to extend credit to Debtor pursuant to the Agreements,
Guarantor has agreed to provide to Creditor this Guaranty and
acknowledges adequate consideration, including the fact that it
will benefit directly and/or indirectly from the Agreement, and
hereby further agrees as follows:

     Section 1.  Guaranty.  Guarantor hereby unconditionally
guarantees the punctual and complete payment when due (whether at
stated maturity, by acceleration or otherwise), of any and all
indebtedness, liabilities, and obligations under the Agreements
of Debtor to Creditor now or hereafter existing, whether absolute
or contingent, joint and/or several, secured or unsecured, direct
or indirect (all such indebtedness, liabilities and obligations
are being herein collectively called the "Obligations").  This
Guaranty is a guarantee of payment and not of collection.
Guarantor acknowledges that it is jointly and severally liable
for payment of the Obligations.

     Section 2.  Demands.  If Debtor fails or refuses to pay any
Obligations when due, and Creditor elects to exercise its rights
under this Guaranty, Creditor shall make a demand upon Guarantor
(hereinafter referred to as a "Payment Demand").  A Payment
Demand shall be in writing and shall reasonably and briefly
specify in what manner and what amount Debtor has failed to pay
and an explanation of why such payment is due, with a specific
statement that Creditor is calling upon Guarantor to pay under
this Guaranty.  A Payment Demand satisfying the foregoing
requirements when delivered to Guarantor pursuant to Section 9 of
this Guaranty shall be the only requirement with respect to
Obligations before Guarantor is required to pay such Obligations
hereunder and shall be deemed sufficient notice to Guarantor that
it must pay the Obligations within ten (10) days after its
receipt of the Payment Demand.  A single written Payment Demand
that complies with the terms of this Section 2 shall be effective
as to any specific failure to pay during the continuance of such
failure to pay, until Debtor or Guarantor has cured such failure
to pay, and additional written demands concerning such failure to
pay shall not be required until such failure to pay is cured.

     Section 3.  Guaranty Absolute.  Creditor may, at any time
and from time to time, without the consent of or notice to
Guarantor, and without impairing,  reducing, affecting or
releasing the Obligations of Guarantor hereunder:

          (a)  change the manner, place or terms of payment of,
     or renew, extend or alter, any or all of the Obligations;

          (b)  amend, waive, terminate or otherwise modify,
     alter, extend or supplement, any document or agreement
     relating to any of  the Obligations;

          (c)  release the Debtor or any other person liable in
     any manner for payment of any or all of the Obligations;

          (d)   take, substitute, surrender, exchange or  release
     any collateral for any or all of the Obligations; or

          (e)   except  as to applicable statutes of  limitation,
     exercise  or  refrain  from exercising  any  rights  against
     Debtor or any other person or otherwise act or refrain  from
     acting or otherwise fail to be diligent.

     Section 4.  Waiver.  Except with respect to the limited
terms and conditions otherwise provided in Sections 2, 7 or 10
hereof, Guarantor hereby waives:

          (a)  notice of acceptance of this Guaranty, of the
     creation and/or existence of any of the Agreements or
     Obligations, and of any action by Creditor in reliance
     hereon or in connection herewith;

          (b)  promptness, diligence, presentment, demand for
     payment, notice of dishonor or nonpayment, protest and
     notice of protest with respect to the Obligations;

          (c)  any requirement that suit be brought against, or
     any other action by Creditor be taken against, or any notice
     of default or other notice be given to, or any demand be
     made on, the Debtor or any other person, or that any other
     action be taken or not taken as a condition to Guarantor's
     obligations under this Guaranty or as a condition to
     enforcement of this Guaranty against Guarantor, and

               (d)  all other notices.

     Section 5.  Effect of Certain Events.  Guarantor agrees that
Guarantor's liability hereunder will not be released, reduced,
affected or impaired by the occurrence of any one or more of the
following events:

          (a)  The liquidation, dissolution, assignment for the
     benefit of creditors, insolvency, bankruptcy,
     reorganization, release, merger, receivership or discharge
     of Debtor, or the arrangement, composition or readjustment
     or other similar proceeding affecting the status,
     composition, identity, existence, assets or obligations of
     Debtor, or the disaffirmance or termination of any of the
     Obligations or Agreements in or as a result of any such
     proceeding;

          (b)  The renewal, consolidation, extension,
     modification, supplementation, termination or amendment from
     time to time of any of the Agreements that might otherwise
     affect the Obligations;

          (c)  Except as to applicable statutes of limitation,
     the failure, delay, lack of diligence, waiver or refusal by
     Creditor to exercise, in whole or part, any right or remedy
     held by Creditor with respect to the Agreements or the
     Obligations;

          (d)  The sale, encumbrance, transfer or other
     modification of the ownership of Debtor or the change in the
     financial condition or management of Debtor;

          (e)  Lack of consideration or any other deficiency in
     the formation of the Agreement and any and all amendments
     and modifications thereof;

           (f)   Lack  of  organizational power or  authority  of
Guarantor or Debtor; or

          (g)  Any changes to the ownership of the Debtor or its
     asset structure, including but not limited to sale, merger,
     acquisition, encumbrance, lien, hypothecation or otherwise.

     Section 6.  Representations and Warranties.  Guarantor
hereby represents and warrants to Creditor as follows:

          (a)  Guarantor is a corporation, duly organized,
     validly existing and in good standing under the laws of the
     state of its organization, and is duly qualified and in good
     standing in each jurisdiction where the nature of its
     business or the character of the assets and properties owned
     or held under lease by it requires such qualification,
     except where the failure to so quality could not reasonably
     be expected to have a material adverse effect on Guarantor.
     Guarantor has all requisite power and authority,
     organizational or otherwise, to conduct in all material
     respects its business and to own, or hold under lease, its
     material assets or properties and to execute and deliver,
     and perform all of its obligations under this Guaranty;

          (b)  The execution, delivery and performance by
     Guarantor of this Guaranty are within the Guarantor's
     organizational powers, have been duly authorized by all
     necessary corporate action and do not contravene the
     organizing documents of Guarantor or any law or material
     contractual restriction binding on or affecting Guarantor;

          (c)  This Guaranty is the legal, valid and binding
     obligation of Guarantor enforceable against the Guarantor in
     accordance with its terms except as the enforceability of
     this Guaranty may be limited by the effect of any applicable
     bankruptcy, insolvency, reorganization, moratorium or
     similar laws affecting creditors rights generally and by
     general principles of equity; and

          (d)  Debtor is a majority-owned indirect subsidiary of
     Guarantor and Guarantor will benefit, directly or
     indirectly, from the Guaranty granted hereby.

     Section 7.  Setoffs and Counterclaims.  Without limiting
Guarantor's own defenses and rights hereunder, Guarantor reserves
to itself all rights, setoffs, counterclaims and other defenses
to which Debtor or any other affiliate of Guarantor is or may be
entitled to, relating to or arising from or out of the Agreements
or otherwise, except for defenses relating to, arising from or
out of the bankruptcy, insolvency, dissolution or liquidation of
Debtor.

     Section 8.  Amendments, etc.  No amendment or waiver of  any
provision  of  this  Guaranty nor consent  to  any  departure  by
Guarantor  therefrom shall in any event be effective  unless  the
same  shall be in writing and signed by Creditor, and  then  such
waiver  or  consent  shall  be effective  only  in  the  specific
instance and for the specific purpose for which given.

     Section 9.  Addresses for Notices.  All notices and other
communications provided for hereunder shall (i) be in writing and
shall be addressed to the parties at their respective addresses
set forth above or at such other addresses as shall be designated
in a written notice to the other party and (ii) except as
otherwise provided herein, when mailed, be effective five days
after being deposited in the U.S. mail, registered or certified
mail, return receipt requested, postage prepaid, and, in the case
of personal delivery, when delivered at the aforesaid address.
Notwithstanding anything herein to the contrary, any notice of
termination provided by Guarantor to Creditor  shall be
transmitted to Creditor only by certified mail, return receipt
requested.

     Section 10.  No Waiver; Remedies.  Except as to applicable
statutes of limitation or repose, no failure on the part of
Creditor to exercise, and no delay in exercising, any right
hereunder shall operate as a waiver thereof; nor shall any single
or partial exercise thereof or the exercise of any other right.
The remedies herein provided are cumulative and not exclusive of
any remedies provided by law.

     Section 11.  Continuing Guaranty; Termination.  This
Guaranty is an absolute and continuing guaranty, except as
specifically set forth herein.  This Guaranty shall terminate on
the first to occur of (a) thirty (30) days after Creditor
receives written notice from Guarantor of such termination, and
(b) June 30, 2003 (the "Termination Date").  From and after the
Termination Date, Guarantor shall have no liability whatsoever
for any Obligations created or incurred after the Termination
Date, but no such termination of this Guaranty shall affect
Guarantor's obligations hereunder for any Obligations created or
incurred on or before the Termination Date.  Notwithstanding
anything to the contrary herein, this Guaranty shall continue to
be effective or reinstated, as the case may be, if at any time
payment, or any part thereof, for any of the Obligations created,
incurred or otherwise contracted for on or before the Termination
Date, is rescinded or must otherwise be returned by Creditor upon
the insolvency, bankruptcy or reorganization of Debtor, or
otherwise under applicable law or at equity, all as though such
payment had not been made.  Guarantor's obligations hereunder may
not be assigned without Creditor's written consent.  This
Guaranty shall be binding upon Guarantor, its successors and
assigns, and shall inure to the benefit of and be enforceable by
Creditor and its successors and assigns.

     Section 12.  Governing Law.  This Guaranty and the rights
and obligations of the parties hereunder shall be governed by and
construed in accordance with the laws of the State of Texas,
without reference to conflict of laws principles of said state.

     Section 13.  Additional Events of Default.  Notwithstanding
anything to the contrary in any document or agreement now or
hereafter existing between Creditor and Debtor, Guarantor agrees
that, solely for the purposes of this Guaranty, the Obligations
of Debtor shall, whether or not then due under any such document
or agreement, automatically be deemed and become immediately due
and payable without presentment, demand, protest or other notice
of any kind, all of which are hereby waived by Guarantor, upon
the occurrence of any of the following events: (i) Guarantor or
Debtor shall commence a voluntary case concerning itself under
Title 11 of the United States Code entitled "Bankruptcy" as now
or hereafter in effect, or any successor thereto (the "Bankruptcy
Code"); (ii) an involuntary case is commenced against Guarantor
or Debtor, and the petition is not controverted within ten days,
or is not dismissed within sixty days, after commencement of the
case; (iii) a custodian (as defined in the Bankruptcy Code) is
appointed for, or takes charge of, all or substantially all of
the property of Guarantor or Debtor; (iv) Guarantor or Debtor
commences any other proceeding under any reorganization,
arrangement, adjustment of debt, relief of debtors, dissolution,
insolvency or liquidation or similar law of any jurisdiction
whether now or hereafter in effect relating to it or there is
commenced against Guarantor or Debtor any such proceeding which
remains undismissed for a period of sixty days or any order of
relief or other order approving any such case or proceeding is
entered; (v) Guarantor or Debtor is adjudicated insolvent or
bankrupt; (vi) Guarantor or Debtor suffers any appointment of any
custodian or the like for it or any substantial part of its
property to continue undischarged or unstayed for a period of
sixty days; (vii) Guarantor or Debtor makes a general assignment
for the benefit of creditors; (viii) any organizational action is
taken by Guarantor or Debtor for the purpose of effecting any of
the foregoing; or (ix) any representation or warranty made by
Guarantor herein shall prove to be untrue in any material respect
on the date as of which made.

     Section  14.   Severability.   If  any  provision  of   this
Guaranty  or the application thereof to any party or circumstance
shall  be invalid or unenforceable, then the remaining provisions
or  the application of such provision to parties or circumstances
other  than  those  as to which it is invalid  or  unenforceable,
shall continue to be valid and enforceable.

     Section 15.  Limitation on Guarantor's Liability.
Notwithstanding anything herein to the contrary, the liability of
Guarantor under this Guaranty shall be limited to the following:

          (a)  Guarantor's liability hereunder shall be and is
     specifically limited to payments expressly required to be
     made by Debtor under the Agreements, and to the extent that
     they have been expressly disclaimed under such Agreements
     Guarantor shall not be liable or otherwise subject hereunder
     to any indirect, special, incidental, consequential,
     exemplary, punitive or tort damages; and

          (b)  Guarantor's aggregate liability to Creditor under
     this Guaranty is limited to and shall not exceed Twenty
     Million Five Hundred Thousand Dollars ($20,500,000.00).

     Section 16.  Entire Agreement.  This Guaranty embodies the
entire agreement and understanding between Guarantor and Creditor
and supersedes all prior and contemporaneous agreements and
understandings relating to the subject matter hereof.  The
headings in this Guaranty are for purposes of reference only, and
shall not affect the meaning hereof.

     IN WITNESS WHEREOF, Guarantor has caused this Guaranty to be
duly executed and delivered by its duly authorized officer as of
the date first above written.


                         GREAT PLAINS ENERGY INCORPORATED


                         By: /s/ Andrea F. Bielsker
                         Name: Andrea F. Bielsker
                         Title: Senior VP Finance, Chief
                         Financial Officer & Treasurer


                                             Exhibit 10.1.d

                    LINE OF CREDIT AGREEMENT


THIS  LINE  OF CREDIT AGREEMENT (this "Agreement"), dated  as  of
June  14,  2002,  is between GREAT PLAINS ENERGY INCORPORATED,  a
Missouri  corporation (herein called the "Company"), and  LASALLE
BANK NATIONAL ASSOCIATION (herein called the "Bank").

On  the  terms  and subject to the conditions set forth  in  this
Agreement,  the  Bank  hereby agrees  to  make  Advances  to  the
Company, from time to time on any Business Day falling during the
period  from  the date hereof to June 13, 2003, (the  "Commitment
Termination Date"), in such amounts as the Company may from  time
to  time  request  but  not  exceeding $20,000,000  in  aggregate
principal  amount  (the  "Commitment Amount")  at  any  one  time
outstanding.  Subject to the terms hereof, the Company  may  from
time   to   time  borrow,  prepay  and  (before  the   Commitment
Termination  Date)  reborrow  Advances  made  pursuant  to   this
Agreement.

In addition to the terms defined elsewhere in this Agreement, the
following terms shall have the meanings indicated for purposes of
this  Agreement  and  the  Note  (such  meanings  to  be  equally
applicable  to both the singular and plural forms  of  the  terms
defined):

      "Advance"  means  a borrowing hereunder (or  conversion  or
continuation thereof) consisting of the aggregate amount  of  the
several  loans  made  on  the same Borrowing  Date  (or  date  of
conversion  or continuation) by the Bank to the Borrower  of  the
same  Type and, in the case of Eurodollar Advances, for the  same
Interest Period.

     "Alternate Base Rate" means, for any day, a rate of interest
per  annum equal to the higher of (i) the Prime Rate for such day
and (ii) the sum of the Federal Funds Effective Rate for such day
plus 1/2% per annum.

      "Applicable Margin" means, with respect to Advances of  any
Type  at  any  time,  the  percentage rate  per  annum  which  is
applicable at such time with respect to Advances of such Type  as
set forth in the Pricing Schedule.

      "Attributable  Indebtedness" means, on  any  date,  (a)  in
respect  of  any Capitalized Lease Obligation of any Person,  the
capitalized  amount thereof that would appear on a balance  sheet
of  such Person prepared as of such date in accordance with GAAP,
and  (b)  in  respect  of  any Synthetic  Lease  Obligation,  the
capitalized  amount  of the remaining lease  payments  under  the
relevant  lease  that  would appear on a balance  sheet  of  such
Person  prepared as of such date in accordance with GAAP is  such
lease were accounted for as a Capitalized Lease.

       "Authorized  Officer"  means  any  officer   or   employee
designated  by  the Company from time to time  in  an  incumbency
certificate,  which  certificate  shall  become  effective   when
received by the Bank.

       "Borrower"  means  Great  Plains  Energy  Incorporated,  a
Missouri corporation, and it's permitted successors and assigns.

      "Borrowing Date" means a date on which an Advance  is  made
hereunder.

      "Business  Day"  means (i) with respect to  any  borrowing,
payment  or  rate selection of Eurodollar Advances, a day  (other
than  a Saturday or Sunday) on which banks generally are open  in
Chicago  and  New  York for the conduct of substantially  all  of
their  commercial  lending activities and on  which  dealings  in
United  States  dollars are carried on in  the  London  interbank
market  and  (ii)  for all other purposes, a day  (other  than  a
Saturday or Sunday) on which banks generally are open in  Chicago
for  the conduct of substantially all of their commercial lending
activities.

      "Capitalized Lease" of a Person means any lease of Property
by  such Person as lessee which would be capitalized on a balance
sheet of such Person prepared in accordance with GAAP.

     "Capitalized Lease Obligations" of a Person means the amount
of  the obligations of such Person under Capitalized Leases which
would  be shown as a liability on a balance sheet of such  Person
prepared in accordance with GAAP.

     "Consolidated  EBITDA"  means,  for  any  period,  for   the
Borrower  and its Consolidated Subsidiaries, an amount  equal  to
the  result of (i) Consolidated Net Income plus (ii) Consolidated
Interest  Charges  plus (iii) the amount of taxes,  based  on  or
measured by income, used or included in the determination of such
Consolidated Net Income plus (iv) the amount of depreciation  and
amortization  expense deducted in determining  such  Consolidated
Net  Income  plus  (v)  all  other  non-cash  items  that  reduce
Consolidated  Net Income for such period minus (vi) all  non-cash
items that increase Consolidated Net Income for such period.

     "Consolidated Interest Charges" means, for the Borrower  and
its  Consolidated Subsidiaries for any period, the sum of (i) all
interest, premium payments, fees, charges and related expenses of
the Borrower and its Consolidated Subsidiaries in connection with
borrowed  money (including capitalized interest) or in connection
with  the deferred purchase price of assets, in each case to  the
extent treated as interest in accordance with GAAP, and (ii)  the
portion  of  rent  expense of the Borrower and  its  Consolidated
Subsidiaries  with  respect to such period under  capital  leases
that  is  treated  as interest in accordance with  GAAP.   It  is
understood  and agreed that Consolidated Interest  Charges  shall
not  include  any obligations of the Borrower or any Consolidated
Subsidiary with respect to subordinated, deferrable interest debt
securities, and any related securities issued by a trust or other
special  purpose entity in connection therewith, as long  as  the
maturity  date  of  such debt securities  is  subsequent  to  the
scheduled Commitment Termination Date.

     "Consolidated  Net Income" means, for any  period,  for  the
Borrower and its Consolidated Subsidiaries, the net income of the
Borrower   and  its  Consolidated  Subsidiaries  from  continuing
operations, excluding extraordinary items for that period.

     "Consolidated  Subsidiaries" means, as to any  Person,  each
Subsidiary  of  such  Person (whether now existing  or  hereafter
created  or acquired) the financial statements of which shall  be
(or  should have been) consolidated with the financial statements
of such Person in accordance with GAAP.

      "Contingent  Obligation" of a Person means  any  agreement,
undertaking   or  arrangement  by  which  such  Person   assumes,
guarantees, endorses, contingently agrees to purchase or  provide
funds for the payment of, or otherwise becomes or is contingently
liable upon, the obligation or liability of any other Person,  or
agrees  to  maintain the net worth or working  capital  or  other
financial condition of any other Person, or otherwise assures any
creditor of such other Person against loss.

     "DTI Company" means any of DTI Holdings, Inc. and any of its
Subsidiaries.

      "Eurodollar Advance" means an Advance which bears  interest
at the applicable Eurodollar Rate.

      "Eurodollar Base Rate" means, with respect to a  Eurodollar
Advance  for the relevant Interest Period, the applicable British
Bankers'  Association Interest Settlement Rate  for  deposits  in
U.S.  dollars appearing on Reuters Screen FRBD as of  11:00  a.m.
(London  time) two Business Days prior to the first day  of  such
Interest  Period,  and having a maturity equal to  such  Interest
Period;  provided  that,  (i)  if  Reuters  Screen  FRBD  is  not
available  to the Bank for any reason, the applicable  Eurodollar
Base  Rate for the relevant Interest Period shall instead be  the
applicable British Bankers' Association Interest Settlement  Rate
for  deposits in U.S. dollars as reported by any other  generally
recognized financial information service as of 11:00 a.m. (London
time)  two Business Days prior to the first day of such  Interest
Period, and having a maturity equal to such Interest Period,  and
(ii)  if no such British Bankers' Association Interest Settlement
Rate  is  available to the Bank, the applicable  Eurodollar  Base
Rate  for the relevant Interest Period shall instead be the  rate
determined by the Bank to be the rate at which the Bank offers to
place  deposits  in U.S. dollars with first-class  banks  in  the
London interbank market at approximately 11:00 a.m. (London time)
two Business Days prior to the first day of such Interest Period,
in  the approximate amount of the Bank's relevant Eurodollar Loan
and having a maturity equal to such Interest Period.

      "Eurodollar Loan" means a loan which bears interest at  the
applicable Eurodollar Rate.

      "Eurodollar  Rate"  means, with  respect  to  a  Eurodollar
Advance or Eurodollar Loan for the relevant Interest Period,  the
sum  of  (i)  the  quotient  of  (a)  the  Eurodollar  Base  Rate
applicable to such Interest Period, divided by (b) one minus  the
Reserve  Requirement (expressed as a decimal) applicable to  such
Interest Period, plus (ii) the Applicable Margin.  The Eurodollar
Rate  shall be rounded to the next higher multiple of 1/16 of  1%
if the rate is not such a multiple.

      "Facility Fee Rate" means, at any time, the percentage rate
per annum at which facility fees are accruing at such time as set
forth in the Pricing Schedule.

      "Federal  Funds  Effective Rate" means, for  any  date,  an
interest  rate  per annum equal to the weighted  average  of  the
rates on overnight Federal funds transactions with members of the
Federal Reserve System arranged by Federal funds brokers on  such
day, as published for such day (or, if such day is not a Business
Day,  for the immediately preceding Business Day) by the  Federal
Reserve  Bank  of New York, or, if such rate is not so  published
for  any  day  which  is  a  Business Day,  the  average  of  the
quotations at approximately 10:00 a.m. (Chicago time) on such day
on  such  transactions received by the Bank  from  three  Federal
funds brokers of recognized standing selected by the Bank in  its
sole discretion.

      "Floating Rate" means, for any day, a rate per annum  equal
to  the sum of (i) the Alternate Base Rate for such day plus (ii)
the  Applicable  Margin, in each case changing when  and  as  the
Alternate Base Rate changes.

      "Floating  Rate  Advance"  means  an  Advance  which  bears
interest at the Floating Rate.

      "Floating  Rate Loan" means a loan which bears interest  at
the Floating Rate.

     "GAAP"  means  generally accepted accounting principles  set
forth from time to time in the opinions and pronouncements of the
Accounting  Principles  Board  and  the  American  Institute   of
Certified  Public  Accountants and statements  of  the  Financial
Accounting Standards Board.

     "Indebtedness" means, as to any Person at a particular time,
all of the following, without duplication, to the extent recourse
may  be had to the assets or properties of such Person in respect
thereof:   (i) all obligations of such Person for borrowed  money
and   all   obligations  of  such  Person  evidenced  by   bonds,
debentures,  notes, loan agreements or other similar instruments;
(ii)  any direct or contingent obligations of such Person in  the
aggregate in excess of $2,000,000 arising under letters of credit
(including  standby and commercial), banker's  acceptances,  bank
guaranties,  surety  bonds  and similar  instruments;  (iii)  net
obligations  of  such  Person  under  Swap  Contracts;  (iv)  all
obligations of such Person to pay the deferred purchase price  of
property  or services except trade accounts payable arising,  and
accrued  expenses incurred, in the ordinary course of  business),
and indebtedness (excluding prepaid interest thereon) secured  by
a  Lien  on  property  owned or being purchased  by  such  Person
(including indebtedness arising under conditional sales or  other
title  retention  agreements), whether or not  such  indebtedness
shall have been assumed by such Person or is limited in recourse;
(v) Capitalized Lease Obligations and Synthetic Lease Obligations
of  such  Person;  and  (vi) all Contingent Obligations  of  such
Person in respect of any of the foregoing.

      For  all  purposes hereof, the Indebtedness of  any  Person
shall  include  the  Indebtedness of  any  partnership  or  joint
venture  in  which such Person is a general partner  or  a  joint
venturer,  unless  such  Indebtedness  is  non-recourse  to  such
Person.  It is understood and agreed that Indebtedness (including
Contingent Obligations) shall not include any obligations of  the
Borrower  with respect to subordinated, deferrable interest  debt
securities, and any related securities issued by a trust or other
special  purpose entity in connection therewith, as long  as  the
maturity  date  of  such  debt  is subsequent  to  the  scheduled
Commitment  Termination  Date;  provided  that  the   amount   of
mandatory principal amortization or defeasance of such debt prior
to the scheduled Commitment Termination Date shall be included in
this  definition of Indebtedness.  The amount of any  Capitalized
Lease  Obligation or Synthetic Lease Obligation as  of  any  date
shall be deemed to be the amount of Attributable Indebtedness  in
respect thereof as of such date.

      "Interest  Period"  means, with  respect  to  a  Eurodollar
Advance, a period of one, two, three or six months commencing  on
a  Business  Day  selected  by  the  Borrower  pursuant  to  this
Agreement.   Such  Interest Period shall end  on  the  day  which
corresponds  numerically to such date  one,  two,  three  or  six
months  thereafter; provided, however, that if there is  no  such
numerically  corresponding day in such  next,  second,  third  or
sixth  succeeding month, such Interest Period shall  end  on  the
last   Business  Day  of  such  next,  second,  third,  or  sixth
succeeding month.  If an Interest Period would otherwise end on a
day  which is not a Business Day, such Interest Period shall  end
on  the next succeeding Business Day; provided, however, that  if
said  next succeeding Business Day falls in a new calendar month,
such  Interest  Period  shall end on  the  immediately  preceding
Business Day.

      "Lien"  means  any  lien (statutory  or  other),  mortgage,
pledge,    hypothecation,   assignment,   deposit    arrangement,
encumbrance  or preference, priority or other security  agreement
or  preferential  arrangement of any kind  or  nature  whatsoever
(including,  without  limitation, the interest  of  a  vendor  or
lessor  under  any conditional sale, Capitalized Lease  or  other
title retention agreement).

     "Moody's" means Moody's Investors Service, Inc.

     "Person" means any natural person, corporation, firm,  joint
venture,  partnership,  limited liability  company,  association,
enterprise,  trust  or  other  entity  or  organization,  or  any
government or political subdivision or any agency, department  or
instrumentality thereof.

      "Pricing  Schedule"  means  the  schedule  attached  hereto
identified as such.

      "Prime Rate" means a rate per annum equal to the prime rate
of interest announced by the Bank from time to time (which is not
necessarily  the  lowest rate charged to any customer),  changing
when and as said prime rate changes.

     "Project Finance Subsidiary" means any Subsidiary that meets
the following requirements: (i) it is primarily engaged, directly
or  indirectly, in the ownership, operation and/or  financing  of
independent  power production and related facilities and  assets;
and  (ii)  neither  the Borrower nor any other Subsidiary  (other
than  another  Project  Finance Subsidiary)  has  any  liability,
contingent   or   otherwise,  for  the  Indebtedness   or   other
obligations of such Subsidiary (other than non-recourse liability
resulting from the pledge of stock of such Subsidiary).

      "Property" of a Person means any and all property,  whether
real,  personal, tangible, intangible, or mixed, of such  Person,
or other assets owned, leased or operated by such Person.

     "Regulatory Change" means the introduction of, or any change
in  any applicable law, treaty, rule, regulation or guideline  or
in   the   interpretation  or  administration  thereof   by   any
governmental  authority  or any central  bank  or  other  fiscal,
monetary or other authority having jurisdiction over the Bank  or
its lending office.

      "Reserve  Requirement" means, with respect to  an  Interest
Period, the maximum aggregate reserve requirement (including  all
basic,  supplemental,  marginal  and  other  reserves)  which  is
imposed under Regulation D on Eurocurrency liabilities.

     "S&P" means Standard and Poor's Ratings Services, a division
of The McGraw Hill Companies, Inc.

       "Shareholders'  Equity"  means,  as   of   any   date   of
determination for the Borrower and its Consolidated  Subsidiaries
on  a  consolidated basis, shareholders equity as  of  that  date
determined in accordance with GAAP.

     "Subsidiary" of a Person means (i) any corporation more than
50% of the outstanding securities having ordinary voting power of
which  shall  at  the  time be owned or controlled,  directly  or
indirectly,  by such Person or by one or more of its Subsidiaries
or  by  such Person and one or more of its Subsidiaries, or  (ii)
any  partnership,  limited liability company,  association,  join
venture  or  similar business organization more than 50%  of  the
ownership  interests having ordinary voting power of which  shall
at  the  time  be so owned or controlled; provided  that  no  DTI
Company  will  be  considered a Subsidiary of  the  Borrower  for
purposes of this Agreement.  Unless otherwise expressly provided,
all  references herein to a "Subsidiary" shall mean a  Subsidiary
of the Borrower.

       "Swap   Contract"  means  (i)  any  and  all   rate   swap
transactions,   basis  swaps,  credit  derivative   transactions,
forward  rate  transactions, commodity swaps, commodity  options,
forward  commodity  contracts, equity or equity  index  swaps  or
options,  bond  or bond price or bond index swaps or  options  or
forward  bond  or  forward  bond  price  or  forward  bond  index
transactions,  interest  rate options, forward  foreign  exchange
transactions,   cap   transaction,  floor  transactions,   collar
transactions,  currency  swap transactions,  cross-currency  rate
swap transactions, currency options, spot contracts, or any other
similar  transactions or any combination of any of the  foregoing
(including  any  options  to enter into any  of  the  foregoing),
whether  or not any such transaction is governed by a subject  to
any  master agreement, and (ii) any and all transactions  of  any
kind,  and  the related confirmations, which are subject  to  the
terms  and  conditions of, or governed by,  any  form  of  master
agreement  published by the International Swaps  and  Derivatives
Association,  Inc.  any  International  Foreign  Exchange  Master
Agreement,  or any other master agreement (any master  agreement,
together  with  any  related schedules,  a  "Master  Agreement"),
including  any such obligations or liabilities under  any  Master
Agreement.

      "Synthetic Lease Obligation" means the monetary  obligation
of  a Person under (a) a so-called synthetic or off-balance sheet
or  tax  retention  lease, or (b) an agreement  for  the  use  or
possession of property creating obligations that do not appear on
the  balance sheet of such Person but which, upon the  insolvency
or  bankruptcy  of  such Person, would be  characterized  as  the
indebtedness  of  such  Person  (without  regard  to   accounting
treatment).

      "Total  Capitalization"  means Total  Indebtedness  of  the
Borrower  and its Consolidated Subsidiaries plus the sum  of  (i)
Shareholder's  Equity  and  (ii)  to  the  extent  not  otherwise
included  in Indebtedness or Shareholder's Equity, preferred  and
preference  stock  and  securities  of  the  Borrower   and   its
Subsidiaries  included in a consolidated  balance  sheet  of  the
Borrower  and  its Consolidated Subsidiaries in  accordance  with
GAAP.

      "Total Indebtedness" means all Indebtedness of the Borrower
and  its  Consolidated  Subsidiaries  on  a  consolidated  basis,
excluding  (i) Indebtedness arising under Swap Contracts  entered
into  in  the  ordinary course of business  to  hedge  bona  fide
transactions  and  business risks and not for  speculation,  (ii)
Indebtedness  of  Project Finance Subsidiaries, (iii)  Contingent
Obligations  incurred  after  May  15,  1996  with   respect   to
Indebtedness  of Strategic Energy, L.L.C. in an aggregate  amount
not   exceeding  $275,000,000  and  (iv)  Indebtedness   of   KLT
Investments Inc. incurred in connection with the acquisition  and
maintenance of its interests (whether direct or indirect) in  low
income housing projects.

      "Type" means, with respect to any Advance, its nature as  a
Floating Rate Advance or a Eurodollar Advance.

      "Utilization  Fee Rate" means, at any time, the  percentage
rate  per  annum at which utilization fees are accruing  at  such
time as set forth in the Pricing Schedule.

All  Advances shall be evidenced by a single promissory  note  of
the  Company (herein called the "Note") in substantially the form
of  Exhibit  A hereto.  The Company hereby irrevocably authorizes
the  Bank to make (or cause to be made) appropriate notations  on
the  grid  attached to the Note (or on any continuation  of  such
grid)  which  notations,  if made, shall  evidence  (among  other
things)  the  date  of,  the outstanding principal  of,  and  the
interest  rate  applicable  to, the Advances  evidenced  thereby.
Such  notations  shall be conclusive and binding on  the  Company
absent  manifest error; provided, however, that failure to record
any  such  notations  shall not limit  or  otherwise  affect  the
Company's  obligations  hereunder  or  under  the  Note  to  make
payments of principal of or interest on the Advances when due.

A  Floating Rate Advance may be made on any Business Day  falling
before  the  Commitment Termination Date upon  prior  written  or
telephonic  request (promptly confirmed in writing) from  any  of
the  Company's Authorized Officers received by the Bank prior  to
2:00  pm, Chicago time, on such Business Day.  Each such  request
shall  specify (i) the Borrowing Date (which shall be a  Business
Day),  (ii) the amount of such Floating Rate Advance and (iii)the
interest  rate  applicable to such Advance.  Each  Floating  Rate
Advance  shall  mature and shall become due and  payable  on  the
Commitment Termination Date.

Any  of  the  Company's Authorized Officers may, on any  Business
Day,  request  and  receive, by telephone,  a  quotation  of  the
Eurodollar  Rate  that would be applicable to a  Eurodollar  Rate
Advance;  provided, however, that the Bank shall be obligated  to
make  a Eurodollar Rate Advance at such Eurodollar Rate only upon
prior  written  or  telephonic  request  (promptly  confirmed  in
writing) from an Authorized Officer received no later than  11:00
a.m., Chicago time, on such Business Day.  Each such request  for
a  Eurodollar  Rate Advance shall specify (i) the Borrowing  Date
(which  shall be at least three Business Days after the  Business
Day on which the quotation of the Eurodollar Rate was made), (ii)
the  principal  amount of such Advance, (iii) the  interest  rate
applicable  to such Advance and (iv) the period of  such  Advance
(which  shall be the period specified when the Company  sought  a
quotation of the Eurodollar Rate).  Each Eurodollar Rate  Advance
shall mature and shall become due and payable on the last day  of
its applicable Interest Period.

Interest  on  (i) Eurodollar Rate Advances and all fees  will  be
calculated  on the basis of a 360 day year for actual  number  of
days  elapsed and (ii) Floating Rate Advances will be  calculated
on  the  basis of a 365 or 366 day year for the actual number  of
days  elapsed.   Interest accrued on each Floating  Rate  Advance
shall  be  payable  quarterly,  in  arrears,  on  the  Commitment
Termination  Date  and  on the date of  any  prepayment  of  such
Advance  (on the principal amount prepaid).  Interest accrued  on
each Eurodollar Advance shall be payable on the maturity date for
such  Advance, on the date of any prepayment of such Advance and,
for  any Eurodollar Advance having an Interest Period longer than
three  months on the last day of each three-month interval during
such Interest Period.  The Company shall have the right to prepay
any Floating Rate Advance in whole or in part at any time without
premium  or  penalty.  No Eurodollar Rate Advance may  be  repaid
prior  to  its  maturity date without the  Bank's  prior  written
consent.

If  the Bank determines in good faith (which determination  shall
be  conclusive, absent manifest error) prior to the  commencement
of  any Interest Period that (i) United States dollar deposits of
sufficient   amount  and  maturity  for  funding  any  Eurodollar
Advances  are  not available to the Bank in the London  Interbank
Eurodollar market in the ordinary course of business, or (ii)  by
reason of circumstances affecting the London Interbank Eurodollar
market, adequate and fair means do not exist for ascertaining the
rate  of  interest  to  be applicable to the relevant  Eurodollar
Advance, the Bank shall promptly notify the Company thereof  and,
so long as the foregoing conditions continue, Advances may not be
advanced as a Eurodollar Advance thereafter.  In addition, at the
Company's  option,  each  existing Eurodollar  Advance  shall  be
immediately (i) converted to a Floating Rate Advance on the  last
Business  Day of the then existing Interest Period, or  (ii)  due
and  payable  on  the  last Business Day  of  the  then  existing
Interest Period, without further demand, presentment, protest  or
notice  of  any  kind,  all of which are  hereby  waived  by  the
Company.

In  addition,  if,  after the date hereof,  a  Regulatory  Change
shall,  in  the  reasonable determination of the  Bank,  make  it
unlawful  for  the  Bank  to  make  or  maintain  the  Eurodollar
Advances,  then  the Bank shall promptly notify the  Company  and
Advances  may not be advanced as a Eurodollar Advance thereafter.
In  addition,  at the Company's option, each existing  Eurodollar
Advance  shall  be immediately (i) converted to a  Floating  Rate
Advance  on  the last Business Day of the then existing  Interest
Period  or on such earlier date as required by law, or  (ii)  due
and  payable  on  the  last Business Day  of  the  then  existing
Interest  Period or on such earlier date as required by law,  all
without  further demand, presentment, protest or  notice  of  any
kind, all of which are hereby waived by the Company.

If any Regulatory Change (whether or not having the force of law)
shall  (a)  impose,  modify  or deem applicable  any  assessment,
reserve,  special deposit or similar requirement  against  assets
held by, or deposits in or for the account of or loans by, or any
other  acquisition of funds or disbursements by,  the  Bank;  (b)
subject  the  Bank or any Eurodollar Advance to  any  tax,  duty,
charge,  stamp  tax  or fee or change the basis  of  taxation  of
payments  to  the  Bank  of principal or interest  due  from  the
Company  to  the  Bank  hereunder (other than  a  change  in  the
taxation  of the overall net income of the  Bank); or (c)  impose
on the Bank any other condition regarding such Eurodollar Advance
or  the  Bank's  funding thereof, and the  Bank  shall  determine
(which  determination shall be conclusive, absent manifest error)
that  the result of the foregoing is to increase the cost to  the
Bank  of  making  or maintaining such Eurodollar  Advance  or  to
reduce  the amount of principal or interest received by the  Bank
hereunder,  then  the Company shall pay to the Bank,  on  demand,
such  additional amounts as the Bank shall, from  time  to  time,
determine are sufficient to compensate and indemnify the Bank for
such increased cost or reduced amount.

Advances,  renewals,  or  payments hereunder  shall  be  made  in
immediately  available funds at the principal banking  office  of
the Bank.

The Company hereby authorizes the Bank to rely upon the telephone
or  written  instructions of any person  identifying  himself  or
herself as an Authorized Officer and upon any signature which the
Bank reasonably believes to be genuine, and the Company shall  be
bound  thereby  in  the  same  manner  as  if  such  person  were
authorized or such signature were genuine.

In  consideration of the Bank's commitment to lend hereunder, the
Company agrees to pay (i) on or as of the date hereof, an upfront
fee equal to 0.150% of the Commitment Amount; (ii) a facility fee
at a per annum rate equal to the Facility Fee Rate (regardless of
usage)  on the Commitment Amount and (iii) for any date on  which
the  Advances outstanding exceed 33% of the Commitment Amount,  a
utilization fee at a per annum rate equal to the Utilization  Fee
Rate  on  outstanding Advances.  The facility fee and utilization
fee  shall accrue during the period commencing with and including
the  date  hereof and ending on and including the last  day  this
Agreement  is  in  effect.  The facility fee and utilization  fee
shall  be  payable in arrears on the last Business  Day  of  each
calendar quarter, commencing June 30, 2002, and on the Commitment
Termination Date.

The  obligation of the Bank to make Advances hereunder is subject
to the satisfaction of the following conditions precedent:

          1.    At  or  before the making of the initial  Advance
          hereunder, the Company shall furnish the Bank with  (i)
          certified  copies  of  resolutions  of  the  Board   of
          Directors  of the Company authorizing or ratifying  and
          approving  the execution and delivery of this Agreement
          and  future borrowings hereunder and the execution  and
          delivery  of  the  Note;  (ii)  a  certificate  of  its
          secretary  or assistant secretary as to the  incumbency
          and  signatures of those of its officers authorized  to
          act  with respect to this Agreement and the Note; (iii)
          an  opinion of counsel for the Company, satisfactory in
          form  and  substance to the Bank, to the effect  (among
          other things specified by the Bank) that the Company is
          a  corporation  duly organized and existing  under  the
          laws  of Missouri and in good standing, that the making
          and  performance of this Agreement and  the  Note  have
          been duly authorized by all necessary corporate action,
          that   all   necessary  governmental   and   regulatory
          approvals  have  been  obtained,  and  that,  upon  the
          execution and delivery of the Note, this Agreement  and
          the  Note  will  constitute legal,  valid  and  binding
          obligations  of the Company, enforceable in  accordance
          with their respective terms under the laws of the State
          of  Missouri;  and  (iv) such additional  documents  or
          information as the Bank may reasonably request.

          2.    At the time of the making of the initial Advance,
          and  each  subsequent  Advance hereunder,  the  Company
          shall,   upon   request,  furnish  the  Bank   with   a
          certificate signed by a Vice President of the  Company,
          together  with the Treasurer or an Assistant  Treasurer
          of  the  Company, it being agreed by the  Company  that
          each such signatory shall be an Authorized Officer,  to
          the  effect that: such Advance will not contravene  any
          provision   of   law,   the   Company's   Articles   of
          Consolidation or By-Laws, or any indenture,  agreement,
          or  instrument to which the Company is a  party  or  by
          which  the  Company or its property  may  be  bound  or
          affected; and no event of default, or event which  with
          notice  or lapse of time or both would become an  event
          of  default,  shall have occurred and be continuing  or
          shall result from the making of such Advance.

Each  of the following shall constitute an event of default under
this Agreement:

     A.   The Company shall fail (i) to pay when due any principal of
          or interest on any
          Advance  or (ii) to comply with any other term of  this
          Agreement, and such failure shall have continued for  a
          period  of 30 days or more after notice thereof by  the
          Bank to the Company;

     B.   An event of default shall occur with respect to any other
          indebtedness of the
          Company for borrowed money and shall have continued for
          a  period  of time sufficient to entitle the holder  of
          such   indebtedness  to  accelerate  the  maturity   or
          otherwise  enforce the payment thereof and such  holder
          has asserted this right to accelerate payment;

     C.   The  Company becomes insolvent or admits in writing its
          inability to pay its
          debts  as  they mature or is adjudicated a bankrupt  or
          insolvent; or the Company applies for, consents to,  or
          acquiesces in the appointment of, a trustee or receiver
          for  the  Company or any property thereof, or  makes  a
          general assignment for the benefit of creditors; or  in
          the   absence   of   such   application,   consent   or
          acquiescence,  a trustee or receiver is  appointed  for
          the  Company or for a substantial part of the  property
          thereof, and is not discharged within 30 days;  or  any
          bankruptcy, reorganization, debt arrangement, or  other
          proceeding under any bankruptcy or insolvency  law,  or
          any   dissolution   or   liquidation   proceeding,   is
          instituted  by or against the Company and if instituted
          against the Company is consented to or acquiesced in by
          the Company or remains for 30 days undismissed;

     D.   Any representation, warranty, or certificate made by or on
          behalf of the
          Company  to the Bank shall prove to have been incorrect
          or misleading in any material respect when made;

     E.   As of the end of each of its fiscal quarters, Borrower fails
          to maintain a
          ratio of (a) Consolidated EBITDA for the period of  the
          four  prior fiscal quarters ending on such date to  (b)
          Consolidated Interest Charges during such period of not
          less than 2.0 to 1.0;

     F.   As of the end of each of its fiscal quarters, the Borrower
          fails to cause the
          ratio   of   (i)  Total  Indebtedness  to  (ii)   Total
          Capitalization  to be less than or  equal  to  0.65  to
          1.00.

If any event of default described in clause A, B, D, E or F above
shall  occur  and  be  continuing,  the  Bank  may  declare   its
commitment  to  make Advances to be terminated  and  declare  the
principal  of, and all interest then accrued on, the Note  to  be
forthwith  due  and  payable,  whereupon  such  commitment  shall
terminate and all Advances and all interest then accrued  thereon
shall  immediately  become due and payable, all  without  notice,
protest,  or demand of any kind.  The Bank shall promptly  advise
the  Company of any such declaration, but failure to do so  shall
not  impair  the  effect of such declaration.   If  an  event  of
default  described  in  clause C above shall  occur,  the  Bank's
commitment to make Advances shall immediately terminate and  each
Advance and all accrued interest thereon shall become immediately
due  and payable, all without notice, protest, or demand  of  any
kind.

This  Agreement shall be governed by and construed in  accordance
with  the internal law of the State of Missouri, shall be  deemed
to  have  been executed in the State of Missouri, shall bind  the
Company  and its successors and assigns, and shall inure  to  the
benefit  of the Bank and its successors and assigns.  The Company
agrees to pay upon demand all expenses (including attorneys' fees
and legal costs and expenses) incurred or paid by the Bank or any
holder  hereof in connection with the enforcement or preservation
of   its   rights  hereunder.   The  Company  irrevocably  waives
presentment, protest, demand and notice of any kind in connection
herewith.
      IN  WITNESS WHEREOF, the Company and the Bank have executed
this Agreement as of the date first above written.


               GREAT PLAINS ENERGY INCORPORATED




               By:     /s/ Andrea F. Bielsker

               Title:   Senior Vice President - Finance,
                    Chief Financial Officer  & Treasurer



               LASALLE BANK NATIONAL ASSOCIATION



               By:    /s/ Denis Campbell IV


               Title:  Senior Vice President

                                                 Exhibit 99.1.a

           Certification of CEO and CFO Pursuant to
                    18 U.S.C. Section 1350,
                    As Adopted Pursuant to
         Section 906 of the Sarbanes-Oxley Act of 2002

     In connection with the Quarterly Report on Form 10-Q of
Great Plains Energy Incorporated (the "Company") for the
quarterly period ended June 30, 2002, as filed with the
Securities and Exchange Commission on the date hereof (the
"Report"), Bernard J. Beaudoin, as Chairman of the Board,
President and Chief Executive Officer of the Company, and
Andrea F. Bielsker, as Senior Vice President - Finance, Chief
Financial Officer and Treasurer of the Company, each hereby
certifies, pursuant to 18 U.S.C. (Section symbol) 1350, as
adopted pursuant to 906 of the Sarbanes-Oxley Act of 2002,
that, to the best of his or her knowledge:

     (1)  The Report fully complies with the requirements of
Section 13(a) or 15(d) of the Securities Exchange Act of 1934;
and

     (2)  The information contained in the Report fairly
presents, in all material respects, the financial condition and
results of operations of the Company.


/s/Bernard J. Beaudoin
Bernard J. Beaudoin
Chairman of the Board, President
    and Chief Executive Officer
Date:  August 12, 2002


/s/Andrea F. Bielsker
Andrea F. Bielsker
Senior Vice President - Finance,
    Chief Financial Officer and
    Treasurer
Date:  August 12, 2002

     This certification accompanies the Report pursuant to
(Section symbol) 906 of the Sarbanes-Oxley Act of 2002 and
shall not, except to the extent required by the Sarbanes-Oxley
Act of 2002, be deemed filed by the Company for purposes of
(Section symbol) 18 of the Securities Exchange Act of 1934,
as amended.


                                                 Exhibit 99.2.a

           Certification of CEO and CFO Pursuant to
                    18 U.S.C. Section 1350,
                    As Adopted Pursuant to
         Section 906 of the Sarbanes-Oxley Act of 2002

     In connection with the Quarterly Report on Form 10-Q of
Kansas City Power & Light Company (the "Company") for the
quarterly period ended June 30, 2002, as filed with the
Securities and Exchange Commission on the date hereof (the
"Report"), Bernard J. Beaudoin, as Chairman of the Board and
Chief Executive Officer of the Company, and Andrea F. Bielsker,
as Senior Vice President - Finance, Chief Financial Officer and
Treasurer of the Company, each hereby certifies, pursuant to 18
U.S.C. (Section symbol) 1350, as adopted pursuant to (Section symbol)
906 of the Sarbanes-Oxley Act of 2002, that, to the best of his
or her knowledge:

     (1)  The Report fully complies with the requirements of
Section 13(a) or 15(d) of the Securities Exchange Act of 1934;
and

     (2)  The information contained in the Report fairly
presents, in all material respects, the financial condition and
results of operations of the Company.


/s/Bernard J. Beaudoin
Bernard J. Beaudoin
Chairman of the Board, President
    and Chief Executive Officer
Date:  August 12, 2002


/s/Andrea F. Bielsker
Andrea F. Bielsker
Senior Vice President - Finance,
    Chief Financial Officer and
    Treasurer
Date:  August 12, 2002

     This certification accompanies the Report pursuant to
(Section symbol) 906 of the Sarbanes-Oxley Act of 2002 and
shall not, except to the extent required by the Sarbanes-Oxley
Act of 2002, be deemed filed by the Company for purposes of
(Section symbol) 18 of the Securities Exchange Act of 1934,
as amended.