<PAGE>

                                   
                               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 September 30, 1997
                                   
                                  OR
                                   
        [  ]  TRANSITION REPORT PURSUANT TO SECTION 13 or 15(d)
                OF THE SECURITIES EXCHANGE ACT OF 1934
                                   
                For the transition period from      to
                                   
                     Commission file number 1-707
                                   
                   KANSAS CITY POWER & LIGHT COMPANY
        (Exact name of registrant as specified in its charter)
                                   
                                   
            Missouri                              44-0308720
 (State or other jurisdiction of               (I.R.S. Employer
 incorporation or organization)              Identification No.)
                                   
                                   
            1201 Walnut, Kansas City, Missouri   64106-2124
         (Address of principal executive offices)   (Zip Code)
                                   
  Registrant's telephone number, including area code: (816) 556-2200


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
October 30, 1997, was 61,892,915 shares.

<PAGE>

PART I - FINANCIAL INFORMATION
ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

KANSAS CITY POWER & LIGHT COMPANY
CONSOLIDATED BALANCE SHEETS
(thousands of dollars)
                                                    September 30   December 31
                                                        1997          1996
ASSETS

UTILITY PLANT, at original cost
 Electric                                             $3,490,314    $3,472,607
 Less-accumulated depreciation                         1,291,399     1,238,187
    Net utility plant in service                       2,198,915     2,234,420
 Construction work in progress                            82,104        69,577
 Nuclear fuel, net of amortization of
   $99,751 and $84,540                                    40,137        39,497
    Total                                              2,321,156     2,343,494

REGULATORY ASSET - RECOVERABLE TAXES                     126,000       126,000

INVESTMENTS AND NONUTILITY PROPERTY                      342,096       231,874

CURRENT ASSETS
 Cash and cash equivalents                               112,038        23,571
 Customer accounts receivable, net of allowance
  for doubtful accounts of $1,943 and $1,644              47,672        27,093
 Other receivables                                        32,012        36,113
 Fuel inventories, at average cost                        15,956        19,077
 Materials and supplies, at average cost                  46,994        47,334
 Deferred income taxes                                     4,852         2,737
 Other                                                     4,082         5,055
    Total                                                263,606       160,980

DEFERRED CHARGES
 Regulatory assets
   Settlement of fuel contracts                            8,544         9,764
   KCC Wolf Creek carrying costs                               0         1,368
   Other                                                  22,397        26,615
 Other deferred charges                                   39,702        14,417
    Total                                                 70,643        52,164

    Total                                             $3,123,501    $2,914,512

CAPITALIZATION AND LIABILITIES
CAPITALIZATION
 Common stock-authorized 150,000,000 shares
   without par value-61,908,726 shares issued-
   stated value                                         $449,697      $449,697
 Retained earnings                                       444,984       455,934
 Unrealized gain on securities available for sale          5,169         6,484
 Capital stock premium and expense                        (1,664)       (1,666)
         Common stock equity                             898,186       910,449
Cumulative preferred stock                                89,062        89,062
Company-obligated mandatorily redeemable Preferred
   Securities of subsidiary trust holding solely
   KCPL Subordinated Debentures *                        150,000             0
Long-term debt                                           936,480       944,136
     Total                                            $2,073,728    $1,943,647
CURRENT LIABILITIES
 Notes payable to banks                                      935             0
 Current maturities of long-term debt                     73,752        26,591
 Accounts payable                                         45,807        55,618
 Accrued taxes                                            62,812        18,443
 Accrued interest                                         17,862        21,054
 Accrued payroll and vacations                            21,855        25,558
 Accrued refueling outage costs                           12,278         7,181
 Other                                                    13,704        11,980
     Total                                               249,005       166,425

DEFERRED CREDITS AND OTHER LIABILITIES
 Deferred income taxes                                   631,859       643,189
 Deferred investment tax credits                          63,937        67,107
 Other                                                   104,972        94,144
    Total                                                800,768       804,440

COMMITMENTS AND CONTINGENCIES

   Total                                              $3,123,501    $2,914,512

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

* The sole asset of the KCPL Financing I Trust is the $154,640,000 principal
  amount of 8.3% Junior Subordinated Deferrable Interest Debentures due 2037

<PAGE>  

<TABLE>
KANSAS CITY POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF INCOME
<CAPTION>
                                     Three Months Ended              Year to Date              Twelve Months Ended
                                          September 30                 September 30                 September 30
                                     1997         1996            1997         1996            1997         1996
                                                               (thousands of dollars)

<S>                               <C>          <C>             <C>          <C>             <C>          <C>
ELECTRIC OPERATING REVENUES        $ 290,218    $ 270,202       $ 700,382    $ 703,031       $ 901,270    $ 907,105

OPERATING EXPENSES
 Operation
   Fuel                               39,832       37,266         104,045      104,135         140,415      139,629
   Purchased power                    17,219       14,261          46,141       40,786          57,810       48,864
   Other                              49,897       44,216         141,358      133,234         188,843      175,526
 Maintenance                          15,973       16,601          52,553       54,039          70,009       73,424
 Depreciation                         27,464       26,992          83,037       76,569         110,380      101,115
 Taxes
   Income                             38,762       33,429          61,128       65,769          63,514       79,252
   General                            27,648       27,457          72,366       75,269          94,345       98,043
 Deferred Wolf Creek costs
   amortization                            0        2,904           1,368        8,712           4,273       11,616
    Total                            216,795      203,126         561,996      558,513         729,589      727,469

OPERATING INCOME                      73,423       67,076         138,386      144,518         171,681      179,636

OTHER INCOME AND (DEDUCTIONS)
 Allowance for equity funds
  used during construction               779          418           1,772        1,535           2,605        2,317
 Miscellaneous income                 11,263        2,154          23,724        4,843          23,724        5,660
 Miscellaneous deductions            (16,896)     (33,865)        (92,560)     (48,578)        (99,154)     (50,271)
 Income taxes                          8,596       14,678          48,691       29,144          55,949       31,882
    Total                              3,742      (16,615)        (18,373)     (13,056)        (16,876)     (10,412)


INCOME BEFORE INTEREST CHARGES        77,165       50,461         120,013      131,462         154,805      169,224

INTEREST CHARGES
 Long-term debt                       15,261       13,097          44,777       39,726          58,990       53,372
 Short-term debt                         103          527           1,273        1,141           1,383        1,272
 Miscellaneous                         4,172        1,128           8,710        3,620           9,930        4,731
 Allowance for borrowed funds
  used during construction              (518)        (500)         (1,891)      (1,431)         (2,407)      (1,904)
    Total                             19,018       14,252          52,869       43,056          67,896       57,471

PERIOD RESULTS
 Net income                           58,147       36,209          67,144       88,406          86,909      111,753
 Preferred stock
  dividend requirements                  952          948           2,866        2,840           3,816        3,812
 Earnings available for
  common stock                        57,195       35,261          64,278       85,566          83,093      107,941

Average number of common
 shares outstanding                   61,896       61,902          61,896       61,902          61,897       61,902
Earnings per common share              $0.92        $0.57           $1.04        $1.38           $1.34        $1.74
Cash dividends per
 common share                         $0.405       $0.405          $1.215       $1.185          $1.620       $1.575
<F1>
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
</TABLE>


<PAGE>

KANSAS CITY POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(thousands of dollars)
                                          Year to Date     Twelve Months Ended
                                            September 30         September 30
                                         1997      1996       1997      1996

CASH FLOWS FROM OPERATING ACTIVITIES
 Net income                            $ 67,144  $ 88,406   $ 86,909  $111,753
 Adjustments to reconcile net income
  to net cash from operating
    activities:
 Depreciation                            83,037    76,569    110,380   101,115
 Amortization of:
  Nuclear fuel                           15,211    10,884     20,421    14,675
  Deferred Wolf Creek costs               1,368     8,712      4,273    11,616
  Other                                   6,049     4,104      7,452     6,106
 Deferred income taxes (net)            (10,168)      608    (19,438)   12,479
 Deferred investment tax credit
   amortization                          (3,170)   (3,106)    (4,227)   (4,152)
 Deferred storm costs                         0         0     (8,885)        0
 Deferred merger costs                   (5,712)        0     (5,712)        0
 Allowance for equity funds used
   during construction                   (1,772)   (1,535)    (2,605)   (2,317)
 Cash flows affected by changes in:
  Receivables                           (16,478)   (5,488)    (9,528)      869
  Fuel inventories                        3,121     2,563      3,584       519
  Materials and supplies                    340       686       (505)   (1,711)
  Accounts payable                       (9,811)   (6,524)      (175)   (1,276)
  Accrued taxes                          44,369    27,336     (4,250)  (38,223)
  Accrued interest                       (3,192)   (3,623)     4,579     4,088
  Wolf Creek refueling outage
    accrual                               5,097    (9,016)     7,731    (6,493)
 Pension and postretirement benefit
     obligations                         (4,335)   (2,399)    (2,020)     (740)
 Other operating activities               6,770     9,452      9,164    13,151
  Net cash from operating
   activites                            177,868   197,629    197,148   221,459

CASH FLOWS FROM INVESTING ACTIVITIES
 Utility capital expenditures           (92,782)  (76,624)  (117,105) (121,304)
 Allowance for borrowed funds used
   during construction                   (1,891)   (1,431)    (2,407)   (1,904)
 Purchases of investments               (98,500)  (15,557)  (118,305)  (34,505)
 Purchases of nonutility property       (12,271)  (15,380)   (17,286)  (15,380)
 Sale of streetlights                    21,500         0     21,500         0
 Other investing activities              (8,390)   (4,445)    (4,876)      838
  Net cash from investing
   activities                          (192,334) (113,437)  (238,479) (172,255)

CASH FLOWS FROM FINANCING ACTIVITIES
 Issuance of mandatorily redeemable
   Preferred Securities of
   subsidiary trust                     150,000         0    150,000         0
 Issuance of long-term debt              66,292    25,441    176,292    45,662
 Repayment of long-term debt            (26,787)  (54,230)   (46,787)  (54,230)
 Net change in short-term borrowings        935    16,000    (34,065)   35,000
 Dividends paid                         (78,094)  (76,201)  (104,096) (101,316)
 Other financing activities              (9,413)     (363)   (11,204)    2,646
  Net cash from financing
   activities                           102,933   (89,353)   130,140   (72,238)
NET CHANGE IN CASH AND CASH
    EQUIVALENTS                          88,468    (5,161)    88,810   (23,034)

CASH AND CASH EQUIVALENTS AT BEGINNING
    OF PERIOD                            23,571    28,390     23,229    46,263

CASH AND CASH EQUIVALENTS AT END
    OF PERIOD                          $112,039   $23,229   $112,039   $23,229

CASH PAID DURING THE PERIOD FOR:
Interest (net of amount capitalized)    $56,562   $45,560    $63,459   $51,893
Income taxes                                 $0   $40,739    $17,605   $84,718

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

<PAGE>

KANSAS CITY POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS
(thousands of dollars)
                                          Year to Date     Twelve Months Ended
                                            September 30         September 30
                                         1997      1996       1997      1996


Beginning balance                      $455,934  $449,966   $462,171  $451,734

Net income                               67,144    88,406     86,909   111,753
                                        523,078   538,372    549,080   563,487
Dividends declared
   Preferred stock - at required rates    2,892     2,847      3,827     3,820
   Common stock                          75,202    73,354    100,269    97,496

Ending balance                         $444,984  $462,171   $444,984  $462,171

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

<PAGE>  

KANSAS CITY POWER & LIGHT COMPANY

      Statements made in this report which are not based on historical
facts   are  forward-looking  and,  accordingly,  involve  risks   and
uncertainties  that  could cause actual results to  differ  materially
from those discussed.  Any forward-looking statements are intended  to
be  as  of  the date on which such a statement is made.  In connection
with  the  safe harbor provisions of the Private Securities Litigation
Reform  Act of 1995, we are providing the following important  factors
that  could  cause actual results to differ materially  from  provided
forward-looking information.  These important factors include: (a) the
outcome  of  the  pending Western Resources Inc.  (Western  Resources)
Merger;  (b) future economic conditions in the regional, national  and
international  markets; (c) state, federal and foreign regulation  and
possible  additional  reductions  in  regulated  electric  rates;  (d)
weather  conditions; (e) financial market conditions,  including,  but
not  limited  to changes in interest rates; (f) inflation  rates;  (g)
changing  competition, including, but not limited to, the deregulation
of  the United States electric utility industry, and the entry of  new
competitors;  (h) the ability to carry out marketing and sales  plans;
(i)   the  ability  to  achieve  generation  planning  goals  and  the
occurrence  of  unplanned generation outages; (j) nuclear  operations;
(k)  the  ability to enter new markets successfully and capitalize  on
growth  opportunities  in  nonregulated businesses,  and  (l)  adverse
changes   in   applicable  laws,  regulations   or   rules   governing
environmental,  tax or accounting matters.  This list of  factors  may
not  be  all inclusive since it is not possible for us to predict  all
possible factors.

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 1996 annual report on Form 10-K.

1.  AGREEMENT AND PLAN OF MERGER WITH WESTERN RESOURCES

     On February 7, 1997, Kansas City Power & Light Company (KCPL) and
Western  Resources, Inc. (Western Resources) entered into an Agreement
and Plan of Merger (the Merger Agreement) to form a strategic business
combination.  The effective time of the merger is dependent  upon  all
conditions  of  the  Merger Agreement being met  or  waived.   At  the
effective time, KCPL will merge with and into Western Resources,  with
Western Resources being the surviving corporation.

      Western Resources first delivered an unsolicited exchange  offer
to  KCPL's Board of Directors during the second quarter of 1996.  This
initial  offer, subject to numerous conditions, proposed the  exchange
of  $28 (later increased to $31) worth of Western Resources stock  for
each  share  of KCPL stock.  After careful consideration, both  offers
were  rejected  by  KCPL's Board of Directors.  In July  1996  Western
Resources commenced an exchange offer for KCPL common stock.  In  late
1996  KCPL  began discussing a possible merger with Western  Resources
leading to the Merger Agreement.

      Under the terms of the Merger Agreement, KCPL common stock  will
be  exchanged  for  Western Resources common stock valued  at  $32.00,
subject to a conversion ratio limiting the amount of Western Resources
common stock that holders of KCPL common stock would receive per share
of KCPL common stock to no more than 1.1 shares (if Western Resources'
stock  is priced at or below $29.09 per share), and no less than 0.917
shares  (if Western Resources' stock is priced at or above $34.90  per
share).   However, there is a provision in the Merger  Agreement  that
allows KCPL to terminate the merger if Western Resources' stock  price
drops  below  $27.64  and  either the  Standard  and  Poor's  Electric
Companies  Index  increases or the decline in Western Resources  stock
price  exceeds by approximately 5% any decline in this index.  Western
Resources  could  avoid this termination by improving  the  conversion
ratio.

<PAGE>

       The  transaction  is  subject  to  several  closing  conditions
including  approval  by  each company's shareholders,  approval  by  a
number  of regulatory authorities (statutory approvals) and dissenting
shares  equaling less than 5.5% of KCPL's outstanding shares.  If  the
effective  time  has  not occurred by June 30, 1998  (the  termination
date),  either party may terminate the agreement as long as  they  did
not   contribute  to  the  delay.   This  termination  date  will   be
automatically  extended  to  June 30,  1999,  if  all  of  the  Merger
Agreement  closing  conditions  have  been  met  except  for   certain
conditions relating to statutory approvals.

      The  Merger Agreement does not allow KCPL to increase its common
stock  dividend prior to the effective time or termination.   It  also
requires  KCPL  to  redeem all outstanding shares of  preferred  stock
prior to completion of the merger.

       If   the   Merger   Agreement  is  terminated   under   certain
circumstances, a payment of $50 million will be due Western  Resources
if,  within two and one-half years following termination, KCPL  agrees
to  consummate a business combination with a third party that  made  a
proposal to combine prior to termination.  Western Resources will  pay
KCPL  $5  million to $35 million if the Merger Agreement is terminated
and  all  closing  conditions  are  satisfied  other  than  conditions
relating  to  Western Resources receiving a favorable tax  opinion,  a
favorable  letter  from its accountants regarding pooling  accounting,
favorable statutory approvals, or an exemption from the Public Utility
Holding Company Act of 1935.

      In February 1997 KCPL paid UtiliCorp United Inc. (UtiliCorp) $53
million for agreeing to combine with Western Resources within two  and
one-half years from the termination of KCPL's agreement to merge  with
UtiliCorp.   This  agreement was terminated due  to  failure  of  KCPL
shareholders to approve the transaction with UtiliCorp.

      During  the first nine months of 1997, $5.7 million  of  merger-
related costs were deferred by KCPL and are included in Other deferred
charges.   These costs will be expensed in the first reporting  period
subsequent to closing of the merger.

2.  SECURITIES AVAILABLE FOR SALE

      Certain  investments in equity securities are accounted  for  as
securities  available  for  sale and adjusted  to  market  value  with
unrealized  gains (or losses), net of deferred income taxes,  reported
as a separate component of shareholders' equity.

     The cost of securities available for sale held by KLT Inc. (KLT),
a  wholly-owned subsidiary of KCPL, was $5 million as of September 30,
1997  and December 31, 1996.  Unrealized gains, net of deferred income
taxes,  decreased  to $5.2 million at September 30,  1997,  from  $6.5
million at December 31, 1996.

3.  CAPITALIZATION

      From  January 1, 1997 to September 30, 1997, KCPL  repaid  $16.5
million of secured medium-term notes.  KCPL is authorized to issue  up
to  $300  million  in unsecured medium-term notes under  an  indenture
dated December 1, 1996.  As of September 30, 1997, no unsecured medium-
term notes had been issued.

     In April 1997 KCPL Financing I (Trust), a wholly-owned subsidiary
of  Kansas  City  Power & Light Company, issued $150,000,000  of  8.3%
preferred securities.  The sole asset of the Trust is the $154,640,000
principal  amount  of  8.3%  Junior Subordinated  Deferrable  Interest
Debentures, due 2037, issued by KCPL.  The terms and interest payments
on  these debentures correspond to the terms and dividend payments  on
the   preferred   securities.   These  payments   are   reflected   as

<PAGE>  

Miscellaneous Interest Charges in the Consolidated Statement of Income
and  are  tax  deductible  by KCPL.  We may elect  to  defer  interest
payments on the debentures for a period up to 20 consecutive quarters,
causing  dividend payments on the preferred securities to be  deferred
as  well.  In case of a deferral, interest and dividends will continue
to  accrue, along with quarterly compounding interest on the  deferred
amounts.  We may redeem all or a portion of the debentures after March
31,  2002,  requiring an equal amount of preferred  securities  to  be
redeemed  at  face  value plus accrued and unpaid distributions.   The
back-up undertakings in the aggregate provide a full and unconditional
guarantee of amounts due on the preferred securities.

4.  COSTANERA INVESTMENT

      In  1997  KLT  invested $46 million for a 12  percent  ownership
position  in the largest fossil-fueled generator in Argentina.   While
the  cost  method  is  used to account for this investment,  Financial
Accounting Standards Board (FASB) Statement No. 115 -- Accounting  for
Certain  Investments in Debt and Equity Securities is  not  applicable
because  the  fair value of Class A stock is not readily determinable.
Because  of  a  legally  binding Consortium and Stockholders  Contract
requiring  the Class A shareholders to authorize the maximum  dividend
distribution,   KLT   accrues  estimated   dividends   before   actual
declaration.

5.  INTANGIBLE ASSETS

       The   application  of  purchase  accounting  for  certain   KLT
investments   during  1997  resulted  in  $12  million   of   goodwill
recognition.  These amounts are included in Other deferred charges  on
the balance sheet and are being amortized over 10 to 15 years.

6.  KANSAS RETAIL REVENUE REQUIREMENT

      On  June  19,  1997, the Kansas Corporation Commission  formally
opened  a  case  for  the purpose of reviewing  KCPL's  Kansas  retail
revenue  requirement.  We filed direct testimony and exhibits  in  the
case in August 1997.  The Company and the KCC staff are in the process
of  negotiating a stipulation and agreement which if approved  by  the
KCC  would result in a $14 million revenue reduction and a $3  million
increase in depreciation beginning January 1998.  About 39 percent  of
KCPL's  retail  sales  revenue, net of gross receipts  tax,  currently
comes from Kansas.

7.  COMMITMENTS AND CONTINGENCIES

     ENVIRONMENTAL MATTERS

      A new proposed rule requiring reduction of nitrogen oxide at our
Missouri   plants  and  new  air  quality  standards  for  ozone   and
particulate matter control for all plants could eventually  result  in
additional  compliance  costs or installation  of  additional  control
equipment.   No estimate of these costs or when they will be  incurred
is available at this time.
                                                                  
<PAGE>  

ITEM 2.  MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS


REGULATION AND COMPETITION

     As competition develops throughout the electric utility industry,
we  are positioning Kansas City Power & Light Company (KCPL) to  excel
in an open market.  We are improving the efficiency of KCPL's electric
utility operations, lowering prices and offering new services.  We now
offer  customized  energy  packages  to  larger  customers,  including
options  offering natural gas contracts.  We have entered an Agreement
and  Plan  of Merger with Western Resources, Inc. (Western Resources).
This agreement was reached after nine months of activities related  to
Western  Resources'  exchange offer (see Note 1  to  the  Consolidated
Financial Statements).

      In December 1996 the Federal Energy Regulatory Commission (FERC)
issued  a  statement concerning electric utility mergers.   Under  the
statement,  companies  must demonstrate that  their  merger  does  not
adversely  affect competition or wholesale rates.  As  remedies,  FERC
may  consider  a range of conditions including transmission  upgrades,
divestitures  of generating assets or formation of independent  system
operators.

     Competition in the electric utility industry was accelerated with
the  National Energy Policy Act of 1992.  This gave FERC the authority
to  require electric utilities to provide transmission line access  to
independent  power  producers (IPPs) and  other  utilities  (wholesale
wheeling).  KCPL, already active in the wholesale wheeling market, was
one  of  the  first utilities to receive FERC's approval of  an  open-
access tariff for wholesale wheeling transactions.  In April 1996 FERC
issued  an  order requiring all owners of transmission  facilities  to
adopt  open-access tariffs and participate in wholesale wheeling.   We
have made the necessary filings to comply with that order.

      FERC's  April  1996  order has encouraged more  movement  toward
retail competition at the state level.  An increasing number of states
have  already  adopted open access requirements for utilities'  retail
electric service, allowing competing suppliers access to their  retail
customers   (retail  wheeling).   Many  other  states   are   actively
considering  retail wheeling.  Kansas has created  a  retail  wheeling
task  force  to  study and report on related issues.  In  Missouri,  a
legislative  committee has been formed to study the  issue  while  the
Missouri Public Service Commission (MPSC) has established a task force
to plan for implementation of retail wheeling if authorized by law.

      Competition through retail wheeling could result in market-based
rates  below  current  cost-based rates.  This  would  provide  growth
opportunities  for  low-cost  producers  and  risks  for   higher-cost
producers,  especially those with large industrial  customers.   Lower
rates  and  the loss of major customers could result in under-utilized
assets  (stranded  investment)  and place  an  unfair  burden  on  the
remaining  customer  base or shareholders.   Testimony  filed  in  our
merger  case  in  Kansas  for KCPL indicates  that  stranded  cost  is
approximately  $1  billion.   An independent  study  prepared  at  the
request  of  the  Kansas Corporation Commission (KCC)  concluded  that
there  are  no  stranded  costs.  We cannot predict  the  extent  that
stranded  costs will be recoverable in future rates.  If  an  adequate
and  fair  provision  for  recovery of  these  lost  revenues  is  not
provided,  certain  generating assets may have  to  be  evaluated  for
impairment  and  appropriate charges recorded  against  earnings.   In
addition  to  lower  profit  margins, market-based  rates  could  also
require generating assets to be depreciated over shorter useful lives,
increasing operating expenses.

<PAGE>  

      Although  Missouri  and Kansas have not  yet  authorized  retail
wheeling,  we believe KCPL is positioned well to compete  in  an  open
market  with  its diverse customer mix and pricing strategies.   About
20% of KCPL's retail mwh sales are to industrial customers compared to
the  utility industry average of about 35%.  KCPL has a flexible  rate
structure  with industrial rates that are competitively priced  within
our  region.  In addition, long-term contracts are in place  or  under
negotiation for a large portion of KCPL's industrial sales.  There has
not been direct competition for retail electric service in our service
territory although there has been competition in the bulk power market
and between alternative fuels.

      Increased  competition  could also  force  utilities  to  change
accounting  methods.   Financial  Accounting  Standards  Board  (FASB)
Statement No. 71 - Accounting for Certain Types of Regulation, applies
to regulated entities whose rates are designed to recover the costs of
providing  service.   An entity's operations could  stop  meeting  the
requirements  of FASB 71 for various reasons, including  a  change  in
regulation or a change in the competitive environment for a  company's
regulated  services.   For  those operations  no  longer  meeting  the
requirements  of  regulatory accounting, regulatory  assets  would  be
written  off.   KCPL's  regulatory assets, totaling  $157  million  at
September 30, 1997, will be maintained as long as FASB 71 requirements
are met.

       It  is  possible  that  competition  could  eventually  have  a
materially  adverse  affect  on  KCPL's  results  of  operations   and
financial  position.   Should  competition  eventually  result  in   a
significant  charge  to equity, capital costs and  requirements  could
increase significantly.

NONREGULATED

     KLT Inc. (KLT) is a wholly-owned subsidiary pursuing nonregulated
business  ventures.  Existing ventures include investments in domestic
and  international nonregulated power production, energy services, oil
and   gas  reserves,  telecommunications,  telemetry  technology,  and
affordable housing limited partnerships.

      KCPL had a total equity investment in KLT of $109 million as  of
September 30, 1997.  KLT's consolidated assets at September 30,  1997,
totaled  $341  million.  The growth of KLT accounts for  most  of  the
increase  in  KCPL's consolidated investments and nonutility  property
(see  Capital Requirements and Liquidity section).  The Agreement  and
Plan  of  Merger  with  Western Resources includes  a  provision  that
requires  Western Resources' approval if annual investments  exceed  a
certain  limit.  Such investments do not include the cost  of  routine
regulated  utility  capital expenditures.  Because annual  investments
are  restricted under this limit, KLT will reallocate its funds  among
its investment plans.

RESULTS OF OPERATIONS

Three-month         three   months  ended  September   30,   1997,
period:             compared  with  three months  ended  September
                    30, 1996
                    
Nine-month          nine   months   ended  September   30,   1997,
period:             compared with nine months ended September  30,
                    1996

Twelve-month        twelve   months  ended  September  30,   1997,
period:             compared  with  twelve months ended  September
                    30, 1996

<PAGE>  

EARNINGS OVERVIEW

                        Earnings Per Share (EPS)
                         For the Periods Ended
                              September 30
                                          Increase
                        1997      1996    (Decrease)                 
Three months ended     $0.92     $0.57    $  .35
Nine months ended      $1.04     $1.38    $(0.34)
Twelve months ended    $1.34     $1.74    $(0.40)

      EPS  for  the three-month period increased mainly  due  to  more
favorable weather and continued load growth.  In addition, EPS for the
three-months ended September 30, 1996, was reduced by $0.26 for merger
costs.  The net effect of the rate reductions approved by the MPSC  in
July 1996 lowered EPS for the three-month period by an estimated $0.02
per share.

     KCPL's pursuit of its strategic options resulted in the September
1996  termination  of  a merger agreement with UtiliCorp  United  Inc.
(UtiliCorp)  and  the February 1997 announcement of our  agreement  to
combine  with  Western  Resources.   These  actions  triggered  KCPL's
payment  of $53 million to UtiliCorp under provisions of the UtiliCorp
merger  agreement, lowering EPS for the nine-month  period  by  $0.52.
The net effect of the rate reductions approved by the MPSC lowered EPS
for   the   nine-month  period  by  an  estimated  $0.15.    Increased
depreciation  expense also negatively affected EPS for the  nine-month
period.   Partially  offsetting  these decreases  are  continued  load
growth  and lower deferred Wolf Creek amortization.  In addition,  EPS
for the nine-months ended 1996 was reduced by $0.31 for merger costs.

     The  decrease  in EPS for the twelve-month period  reflects  the
decrease of EPS by $0.52 because of the payment to UtiliCorp  and  the
net  effect of the rate reductions approved by the MPSC which  lowered
EPS for the twelve-month period by an estimated $0.25.  An increase in
depreciation expense also had a negative effect on EPS for the twelve-
month  period.  Factors contributing positively to EPS for the twelve-
month period included continued load growth, lower deferred Wolf Creek
amortization  and an increase in subsidiary income.  In addition,  EPS
for  the  twelve-months ended 1996 was reduced  by  $0.31  for  merger
costs.

<PAGE>  

MEGAWATT-HOUR (MWH) SALES AND OPERATING REVENUES

Sales and revenue data:
(revenue change in millions)

                       Periods ended September 30, 1997 vs. September 30, 1996
                       Three Months     Six Months       Twelve Months
                        Mwh  Revenues    Mwh  Revenues    Mwh  Revenues
                                        Increase (decrease)
Retail Sales:
  Residential           13 %       12     3 %        5     3 %        2
  Commercial             9 %        7     4 %       (3)    4 %       (5)
  Industrial             2 %        1    (4)%       (3)   (2)%       (3)
  Other                 13 %       (1)    3 %       (1)    2 %       (1)
     Total Retail        9 %       19     2 %       (2)    2 %       (7)
Sales for Resale:
  Bulk Power Sales     (17)%        1    (6)%       (2)   (1)%        4
  Other                  4 %        -    17 %        -    23 %       -
    Total                          20               (4)              (3)
  Other revenues                    -                1               (3)
    Total Operating Revenues       20              $(3)             $(6)

      During  1996  the MPSC approved a new stipulation and  agreement
authorizing  a  $20  million revenue reduction in two  phases  and  an
increase  in  depreciation and amortization expense by $9 million  per
year.   In July 1996 we implemented phase one of the revenue reduction
designed  to reduce revenues from commercial and industrial  customers
by  an estimated $9 million per year.  This decrease is achieved  with
an  increase in summer revenues offset by a larger decrease in  winter
revenues.   This  design more closely follows our increased  costs  of
generating  electricity  in the summer.   The  second  phase  of  this
stipulation,  implemented  January 1, 1997, further  reduces  Missouri
residential,  commercial and industrial revenues by an  estimated  $11
million per year.  The effect of the stipulation changed revenues  and
EPS as follows:

                       For the periods ended September 30
                       Three Months  Six Months    Twelve Months
                       1997  1996    1997  1996    1997  1996
                                     Increase (decrease)
Revenues(in millions)      3     5     (10)    5     (20)    5
EPS                     0.03  0.05   (0.10) 0.05   (0.20) 0.05

      In  June 1997 the KCC formally opened a case for the purpose  of
reviewing  KCPL's Kansas retail revenue requirement.  Rates in  Kansas
have  not  been  adjusted since 1988.  See Note 6 to the  Consolidated
Financial   Statements  regarding  a  proposed  $14  million   revenue
reduction and a $3 million increase in depreciation beginning  January
1998.

      The  higher  mwh sales in September 1997 versus  December  1996,
resulted in a higher customer accounts receivable balance at September
30, 1997, compared with December 31, 1996.

     Three-month retail revenues increased from the prior year because
of  increased mwh sales.  Continued load growth and favorable weather,
as  compared  to  the prior year, contributed to the increase  in  mwh
sales  for the period.  The Missouri rate reductions partially  offset
the  revenue  increase for the three-month period.  Nine- and  twelve-
month  retail revenues decreased primarily 

<PAGE>  

due to the rate reductions and reduced sales to a major industrial customer
because of a strike by its employees.  Revenues from increased mwh sales 
partially offset these decreases for the nine- and twelve-month periods.

      KCPL has long-term sales contracts with certain major industrial
customers.  These contracts are tailored to meet customers'  needs  in
exchange for their long-term commitment to purchase energy.  Long-term
contracts are in place for a large portion of KCPL's industrial  sales
and more contracts are under negotiation.

      Bulk power sales vary with system requirements, generating  unit
and  purchased power availability, fuel costs and the requirements  of
other  electric systems.  Outages at the LaCygne I and  II  generating
units  in  the second quarter of 1997 contributed to lower bulk  power
mwh  sales in the current nine- and twelve-month periods (see Fuel and
Purchased  Power section).  Wolf Creek's spring 1996 refueling  outage
(see Wolf Creek section) contributed to lower bulk power mwh sales  in
the  prior  twelve-month period.  Lower bulk power sales in  September
1997 compared to December 1996 and the conversion of a Note receivable
to  an  investment  (see Capital Requirements and  Liquidity  section)
contributed  to the lower Other receivables balance at  September  30,
1997, compared to December 31, 1996.

      Total  revenue per mwh sold varies with changes in rate tariffs,
the mix of mwh sales among customer classifications and the effect  of
declining  price  per  mwh  as  usage increases.   An  automatic  fuel
adjustment  provision is included in only sales  for  resale  tariffs,
which apply to less than 1% of revenues.

      Future  mwh sales and revenues per mwh will also be affected  by
national  and  local  economies,  weather  and  customer  conservation
efforts.  Competition, including alternative sources of energy such as
natural  gas,  co-generation, IPPs and other electric  utilities,  may
also affect future sales and revenue.

FUEL AND PURCHASED POWER

      Combined  fuel and purchased power expenses for the  three-month
period increased 11% while total mwh sales (total of retail and  sales
for  resale)  increased  5%.   The difference  is  due  mainly  to  an
increased  cost  per  kwh for purchased power in the  current  period.
Also  combined  fuel and purchased power expenses for  the  nine-month
period  increased 4% on approximately equal total mwh sales  with  the
prior  period.  Additional replacement power expense incurred  due  to
LaCygne generating units outages is the main reason for the nine-month
period difference.

      Combined  fuel and purchased power expenses for the twelve-month
period  increased  5%  while  total  mwh  sales  increased  2%.    The
additional increase in expense is due mainly to a $2 million  increase
in  capacity  purchases  and the replacement  power  expense  incurred
during  the  LaCygne  generating units outages.  Partially  offsetting
this,  the  prior  twelve-month period includes the  additional  costs
incurred during Wolf Creek's 1996 refueling outage.

      The  MMBTU price of nuclear fuel remains substantially less than
the  MMBTU  price of coal, despite increasing 9% for the  twelve-month
period.   Nuclear fuel costs averaged 60% of the price of coal  during
the  current twelve months compared with 55% during the prior  twelve-
month  period.  We expect this relationship and the price  of  nuclear
fuel to remain fairly constant through the year 2001.  For the current
twelve-month  period, coal represented about 70% of  fuel  burned  and
nuclear fuel about 29%.  In the prior twelve-month period, coal represented 
about 76% of fuel burned and nuclear fuel about 23%. The increase in 
nuclear fuel as a percentage of fuel burned is due mainly to outages

<PAGE>  

during  1997 at LaCygne I and II, coal-fired  generating units, and the
refueling outage at Wolf Creek in the prior period.

     The MMBTU price of coal decreased 1% for the twelve month period.
Our  coal  procurement strategies continue to provide coal costs  well
below  the  regional average.  We expect coal costs to  remain  fairly
consistent with current levels through 2001.

OTHER OPERATION AND MAINTENANCE EXPENSES

     Combined other operation and maintenance expenses for all periods
increased  due  largely to increases in station  non-fuel  operations,
system  dispatch,  transmission, distribution  and  customer  accounts
expenses.

       We  continue  to  emphasize  new  technologies,  improved  work
methodologies  and  cost control.  We are continuously  improving  our
work   processes  to  provide  increased  efficiencies  and   improved
operations.   Through the use of cellular technology,  a  majority  of
customer meters are read automatically.

DEPRECIATION AND AMORTIZATION

     The increase in depreciation expense for all periods reflects the
implementation of the MPSC stipulation and agreement discussed in  the
revenue  section  as  well as normal increases  in  depreciation  from
capital  additions.  The stipulation and agreement, effective July  1,
1996,  authorized a $9 million annual increase in depreciation expense
at  about  the same time the Missouri portion of Deferred  Wolf  Creek
costs  became  fully  amortized in December 1996.   This  amortization
totaled about $9 million per year.

      The  Kansas  portion of Deferred Wolf Creek costs  became  fully
amortized  in the second quarter of 1997.  Amortization of the  Kansas
portion of this asset totaled about $3 million per year.

INCOME TAXES

     The increase in operating income taxes for the three-month period
reflects higher taxable operating income in the current period.

      The decrease in operating income taxes for the nine-month period
reflects lower taxable operating income.  The decrease for the twelve-
month  period  reflects  lower taxable operating  income,  adjustments
necessary  to  reflect  the filing of the 1995  tax  returns  and  the
settlement  with  the  Internal Revenue Service regarding  tax  issues
included in the 1985 through 1990 tax returns.

      General  taxes decreased for the nine- and twelve-month  periods
reflecting  changes  in  Kansas tax law which reduced  the  mill  levy
rates.

OTHER INCOME AND (DEDUCTIONS)

     Miscellaneous Income
     Miscellaneous  income for all current periods includes  increased
     revenues  from non-utility and subsidiary operations.   Dividends
     on  the  investment in a fossil-fuel generator in Argentina  (see
     Capital Requirements and Liquidity section) and revenues  from  a
     subsidiary  in  which KLT obtained a controlling interest  during
     1997  contributed  to the increase in miscellaneous  income  from
     subsidiary operations.

<PAGE>  

     Miscellaneous Deductions
     Miscellaneous  deductions for the nine- and twelve-month  periods
     increased  due to a $53 million payment to UtiliCorp in  February
     1997.   The  September 1996 termination of the  UtiliCorp  merger
     agreement and the February 1997 announcement of our agreement  to
     combine   with  Western  Resources,  triggered  the  payment   to
     UtiliCorp  under  provisions of the UtiliCorp  merger  agreement.
     Miscellaneous  deductions  for the  prior  periods  included  $26
     million  in the three-month period and $31 million in  the  nine-
     and twelve-month periods in merger related costs.
     
     All periods reflect increased non-utility expenses and subsidiary
     operating and investing activities.  Subsidiary expenses included
     in Miscellaneous deductions increased by $9 million for the three-
     month  period,  $18  million for the nine-month  period  and  $20
     million  for  the  twelve-month period.  The  primary  subsidiary
     expenses  that  increased are cost of sales,  administrative  and
     general  labor  and  benefits,  incentives  for  gas  production,
     provision   for  uncollectible  notes  receivable   and   outside
     consulting services.  Development of independent power producers,
     increased  gas operations and inclusion of three small  companies
     in  which KLT obtained controlling interests during 1997 are  the
     primary activities that contributed to the increased expenses.
     
     Income Taxes
     Income   taxes   reflect  the  tax  impact  of  the   excess   of
     miscellaneous     deductions    over    miscellaneous     income.
     Additionally, during the first nine months of 1997 we accrued tax
     credits  of  $16 million, or three-fourths of the total  expected
     1997   credits,   related  to  affordable   housing   partnership
     investments and oil and gas investments.  This is an increase  of
     $8 million compared with the tax credits accrued during the first
     three  quarters  of  1996.  Tax credits from the  investments  in
     affordable  housing  more than offset the  increase  in  interest
     expense incurred from these investments.  Non-taxable increase in
     the  cash  surrender  value  of  corporate-owned  life  insurance
     contracts  also  affected the relationship between  miscellaneous
     deductions and income taxes.

INTEREST CHARGES

      The  increase  in  long-term interest expense  for  all  periods
reflects  higher  average levels of long-term debt  outstanding.   The
higher  levels  of debt resulted mainly from additional financing  for
new  investments  in unregulated ventures, funding of other  corporate
capital  requirements  and  financing  by  KLT  to  support  expanding
subsidiary operations.

     The increase in miscellaneous interest charges for all periods is
primarily  due  to  interest charges incurred on the  $150,000,000  of
preferred securities.

      We  use  interest  rate  swap and cap agreements  to  limit  the
interest expense on a portion of KCPL's variable-rate long-term  debt.
We  do  not use derivative financial instruments for trading or  other
speculative purposes.  Although these agreements are an integral  part
of  our interest rate management, their incremental effect on interest
expense and cash flows is not significant.

<PAGE>  

WOLF CREEK

       Wolf   Creek  is  one  of  KCPL's  principal  generating  units
representing about 17% of accredited generating capacity.  The plant's
operating performance has remained strong, contributing about  27%  of
annual  mwh generation while operating at an average capacity  of  90%
over  the last three years.  It has the lowest fuel cost per MMBTU  of
any of KCPL's generating units.

      Wolf  Creek's  ninth refueling and maintenance outage  began  in
early October 1997.  Currently, it is forecasted to be approximately a
45  to  50  day  outage.  The incremental operating,  maintenance  and
replacement  power costs are accrued evenly over the unit's  operating
cycle,  normally 18 months.  As actual outage expenses  are  incurred,
the  refueling liability and related deferred tax asset  are  reduced.
Wolf  Creek's eighth scheduled refueling and maintenance outage  began
in early February 1996 and was completed in April 1996 (64 days).  The
eighth  outage  started one month early when the plant was  shut  down
after  water flow from the cooling lake was restricted by ice  buildup
on  an intake screen.  This extended the length of the outage and  was
the  primary reason for the increase in Wolf Creek related replacement
power and maintenance expenses in 1996.

      Currently, no major equipment replacements are expected, but  an
extended  shut-down  of  Wolf Creek could have a  substantial  adverse
effect  on  KCPL's  business,  financial  condition  and  results   of
operations.   Higher  replacement  power  and  other  costs  would  be
incurred  as  a  result.  Although not expected, an unscheduled  plant
shut-down  could  be  caused  by actions  of  the  Nuclear  Regulatory
Commission  reacting to safety concerns at the plant or other  similar
nuclear   units.   If  a  long-term  shut-down  occurred,  the   state
regulatory commissions could consider reducing rates by excluding  the
Wolf Creek investment from rate base.

     Ownership and operation of a nuclear generating unit exposes KCPL
to  risks regarding the cost of decommissioning the unit at the end of
its  life  and  to  potential retrospective assessments  and  property
losses in excess of insurance coverage.

CAPITAL REQUIREMENTS AND LIQUIDITY

      See  Note  3 to the Consolidated Financial Statements  regarding
$150  million  in  financing obtained by KCPL in  April  1997.   Other
liquid  resources of KCPL at September 30, 1997, included  cash  flows
from  operations,  $300 million of registered but  unissued  unsecured
medium-term  notes and $343 million of unused bank  lines  of  credit.
The  unused lines consisted of KCPL's short-term bank lines of  credit
of  $300 million and KLT's long-term revolving line of credit  of  $43
million.   Cash  and cash equivalents increased by  $88  million  from
December  1996  to  September 1997 primarily due to $21.5  million  of
proceeds  from  the sale of streetlights to the City of  Kansas  City,
Missouri; increased seasonal revenues and the issuance of $150 million
of preferred securities.

      KCPL  continues to generate positive cash flows  from  operating
activities,  although  individual components of working  capital  will
vary  with normal business cycles and operations including the  timing
of receipts and payments.  The timing of the Wolf Creek outage affects
the  refueling outage accrual, deferred income taxes and  amortization
of nuclear fuel.

      The  increase  in  accrued  taxes from  December  31,  1996,  to
September  30,  1997, mainly reflects the timing  of  income  tax  and
property  tax payments.  Accelerated depreciation lowers tax  payments
in  the earlier years of an asset's life while increasing deferred tax
liabilities;  this  relationship reverses in the  later  years  of  an
asset's life.  Our last significant generating plant addition was  the
completion  of Wolf Creek in 1985.  Accelerated depreciation  on  Wolf
Creek ended in 1995.

<PAGE>  

      The $8.9 million incurred to repair damages from an October 1996
snow  storm, recorded as a regulatory asset, lowered cash  flows  from
operating  activities  for the twelve-month period.   Amortization  of
these costs over five years began in 1997.

      Subsidiary  goodwill  resulting from KLT  investments,  deferred
merger  costs  and  unamortized debt expense all  contributed  to  the
increase  in Other deferred charges on the Consolidated Balance  Sheet
from December 31, 1996, to September 30, 1997.  Other deferred credits
increased   due   to   an  increase  in  Wolf  Creek   decommissioning
liabilities.   Also, subsidiary minority interests included  in  Other
deferred  credits increased as KLT obtained controlling  interests  in
new companies in 1997.

      Cash  used  in  investing activities varies with the  timing  of
utility  capital  expenditures and KLT's purchases of investments  and
nonutility  properties.   KLT closed several  investments  during  the
first  nine  months  of  1997, increasing Investments  and  Nonutility
Property  on  the  Consolidated Balance Sheet  by  approximately  $100
million.  These include a 12% ownership interest in the largest fossil-
fuel  generator  in  Argentina and an ownership  interest  in  Digital
Teleport,  Inc. (DTI).  DTI is constructing a state of the art,  fiber
optic network throughout the region in anticipation of increased local
and   long  distance  telephone  competition.   As  part  of  the  DTI
transaction,  KLT  converted  a  $9 million  note  receivable  to  the
investment in DTI.

      Construction  work  in progress increased by  $13  million  from
December 1996 to September 1997 due to normal seasonal fluctuations in
the  construction schedule, continued construction on major production
projects and system software upgrades.

     Cash provided by financing activities increased for the nine- and
twelve-month  periods due to additional long-term  borrowings.   Long-
term  debt,  including current maturities, increased by $39.5  million
from  December  1996  to September 1997 primarily  due  to  additional
borrowings  by  KLT  on its long-term revolving line  of  credit.   As
discussed  in  Note 3 to the Consolidated Financial  Statements,  KCPL
Financing I, a wholly-owned subsidiary of KCPL, issued $150,000,000 of
preferred  securities  in  April 1997.  The  $53  million  payment  to
UtiliCorp,  recorded as an expense, and KLT's purchases of investments
and  nonutility properties were financed mostly by this financing  and
additional  long-term  borrowings.   Cash  used  in  Other   financing
activities  increased  for  the  nine- and  twelve-month  periods  due
primarily  to an increase in unamortized debt expense related  to  the
$150,000,000 financing.

      KCPL's  common  dividend payout ratio was 121% for  the  current
twelve-month period and 91% for the prior twelve-month period compared
to  82% for the same period in 1995.  The increase in the payout ratio
for both periods is due mainly to the significant merger related costs
expensed in both periods.

      Day-to-day  operations,  utility construction  requirements  and
dividends  are  expected  to  be met with internally-generated  funds.
Uncertainties  affecting our ability to meet these  requirements  with
internally-generated  funds  include  the  effect  of   inflation   on
operating  expenses, the level of mwh sales, regulatory  actions,  the
availability   of   generating  units  and  compliance   with   future
environmental regulations.  A new proposed rule requiring reduction of
nitrogen  oxide  at our Missouri plants and new air quality  standards
for  ozone  and  particulate  matter  control  for  all  plants  could
eventually  result in additional compliance costs or  installation  of
additional control equipment.  No estimate of these costs or when they
will be incurred is available at this time.  The funds needed for  the
retirement of $425 million of maturing debt through the year 2001 will
be  provided  from  operations, refinancings or short-term  debt.   We
might  incur additional debt and/or issue additional equity to finance
growth or take advantage of new opportunities.

<PAGE>  

PART II - OTHER INFORMATION

Item 1.  Legal Proceedings.

     On July 18, 1997, in Kansas City Power & Light Company vs.
Western Resources, Inc. (previously discussed in the Company's
Form 10-K for the year ended December 31, 1996), the United
States District Court for the Western District of Missouri issued
an Order dismissing Intervenor Jack R. Manson's derivative
amended counterclaim alleging breach of directors' fiduciary
duties in connection with the proposed merger with UtiliCorp
United Inc.  In early August 1997, Manson filed a motion to amend
the Order requesting the Court award his attorneys' fees in this
matter, and the Court, in an Order dated August 25, 1997, agreed
to consider the issue of attorneys' fees.  Manson and his counsel
then filed an Application for an Award of Attorneys' Fees and
Related Disbursements seeking an award of over $6 million.  On
September 23, 1997, Manson appealed the Order as amended, to the
United States Court of Appeals for the Eighth Circuit.  It is our
opinion that any potential net liability to the Company resulting
from these proceedings would be nominal in amount.

Item 6.  Exhibits and Reports on Form 8-K.

Exhibits

Exhibit 27.    Financial Data Schedule (for the nine months ended
               September 30, 1997).

Reports on Form 8-K.

     No reports on Form 8-K were filed during the quarter ended
September 30, 1997.

<PAGE>  

                         SIGNATURES




     Pursuant to the requirements of the Securities Exchange
Act of 1934, the registrant has duly caused this report to
be signed on its behalf by the undersigned thereunto duly
authorized.


                         KANSAS CITY POWER & LIGHT COMPANY

Dated:  November 4, 1997      By:  /s/Drue Jennings
                                     (Drue Jennings)
                                 (Chief Executive Officer)


Dated:  November 4, 1997      By:  /s/Neil Roadman
                                     (Neil Roadman)
                                 (Principal Accounting Officer)

<PAGE>