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