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 March 31, 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
May 7, 1997, was 61,895,819 shares.




<PAGE>

PART I - FINANCIAL INFORMATION
ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

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

UTILITY PLANT, at original cost
 Electric                                             $3,479,539    $3,472,607
 Less-accumulated depreciation                         1,261,837     1,238,187
    Net utility plant in service                       2,217,702     2,234,420
 Construction work in progress                            84,863        69,577
 Nuclear fuel, net of amortization of
   $89,655 and $84,540                                    36,797        39,497
    Total                                              2,339,362     2,343,494

REGULATORY ASSET - RECOVERABLE TAXES                     126,000       126,000

INVESTMENTS AND NONUTILITY PROPERTY                      306,419       231,874

CURRENT ASSETS
 Cash and cash equivalents                                25,112        23,571
 Customer accounts receivable, net of allowance
  for doubtful accounts of $1,360 and $1,644              15,679        27,093
 Other receivables                                        21,632        36,113
 Fuel inventories, at average cost                        17,717        19,077
 Materials and supplies, at average cost                  47,297        47,334
 Deferred income taxes                                     3,672         2,737
 Other                                                     6,778         5,055
    Total                                                137,887       160,980

DEFERRED CHARGES
 Regulatory assets
   Settlement of fuel contracts                            9,358         9,764
   KCC Wolf Creek carrying costs                             684         1,368
   Other                                                  25,114        26,615
 Other deferred charges                                   28,762        14,417
    Total                                                 63,918        52,164

    Total                                             $2,973,586    $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                                       414,774       455,934
 Unrealized gain on securities available for sale          1,681         6,484
 Capital stock premium and expense                        (1,666)       (1,666)
         Common stock equity                             864,486       910,449
Cumulative preferred stock                                89,000        89,000
Cumulative redeemable preferred stock                         62            62
Refinanced short-term borrowings                          93,000             0
Long-term debt                                           925,136       944,136
     Total                                            $1,971,684    $1,943,647
CURRENT LIABILITIES
 Notes payable to banks                                    1,361             0
 Commercial paper                                          8,000             0
 Current maturities of long-term debt                     71,091        26,591
 Accounts payable                                         36,745        55,618
 Accrued taxes                                            11,087        18,443
 Accrued interest                                         19,863        21,054
 Accrued payroll and vacations                            21,395        25,558
 Accrued refueling outage costs                            9,280         7,181
 Other                                                    12,031        11,980
     Total                                               190,853       166,425

DEFERRED CREDITS AND OTHER LIABILITIES
 Deferred income taxes                                   638,508       643,189
 Deferred investment tax credits                          66,051        67,107
 Other                                                   106,490        94,144
    Total                                                811,049       804,440

COMMITMENTS AND CONTINGENCIES (note 4)

   Total                                              $2,973,586    $2,914,512

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


<TABLE>
KANSAS CITY POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF INCOME
(thousands of dollars)
<CAPTION>

                                        Year to Date              Twelve Months Ended
                                          March 31                     March 31
                                     1997         1996            1997         1996
                                 
<S>                               <C>          <C>             <C>          <C>
ELECTRIC OPERATING REVENUES        $ 194,744    $ 206,624       $ 892,039    $ 893,673

OPERATING EXPENSES
 Operation
   Fuel                               34,922       30,773         144,654      135,425
   Purchased power                    11,246       13,985          49,716       46,036
   Other                              43,923       43,499         181,143      177,653
 Maintenance                          16,816       18,029          70,282       75,790
 Depreciation                         27,842       24,716         107,038       97,802
 Taxes
   Income                              8,530       13,413          63,272       78,858
   General                            22,692       24,361          95,579       97,325
 Deferred Wolf Creek costs
   amortization                          684        2,904           9,397       12,235
    Total                            166,655      171,680         721,081      721,124

OPERATING INCOME                      28,089       34,944         170,958      172,549

OTHER INCOME
 Allowance for equity funds
  used during construction               260          660           1,968        2,704
 Miscellaneous income                  3,893          741           7,995        1,123
 Miscellaneous deductions            (62,161)      (3,785)       (113,548)     (13,213)
 Income taxes                         30,233        6,221          60,414       16,816
    Total                            (27,775)       3,837         (43,171)       7,430


INCOME BEFORE INTEREST CHARGES           314       38,781         127,787      179,979

INTEREST CHARGES
 Long-term debt                       14,516       13,424          55,031       53,275
 Short-term debt                         839          118           1,972          687
 Miscellaneous                           875        1,106           4,609        3,600
 Allowance for borrowed funds
  used during construction              (784)        (390)         (2,341)      (1,805)
    Total                             15,446       14,258          59,271       55,757

PERIOD RESULTS
 Net income (loss)                   (15,132)      24,523          68,516      124,222
 Preferred stock
  dividend requirements                  955          957           3,788        3,942
 Earnings (Loss) applicable to
  common stock                       (16,087)      23,566          64,728      120,280

Average number of common
 shares outstanding                   61,896       61,902          61,900       61,902
Earnings (Loss) per common share      ($0.26)       $0.38           $1.05        $1.94
Cash dividends per
 common share                         $0.405       $0.390          $1.605       $1.550
<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
                                            March 31             March 31
                                         1997      1996       1997      1996

CASH FLOWS FROM OPERATING ACTIVITIES
 Net income (loss)                     $(15,132) $ 24,523   $ 68,516  $124,222
 Adjustments to reconcile net income
  (loss)to net cash from operating
    activities:
 Depreciation                            27,842    24,716    107,038    97,802
 Amortization of:
  Nuclear fuel                            5,115     1,197     20,012    12,464
  Deferred Wolf Creek costs                 684     2,904      9,397    12,235
  Other                                   1,362     1,409      5,460     7,533
 Deferred income taxes (net)             (2,885)    5,731    (17,278)    7,278
 Deferred investment tax credit
   amortization and reversals            (1,056)   (1,024)    (4,195)   (4,242)
 Deferred storm costs                         0         0     (8,885)        0
 Deferred merger costs                   (4,787)   (5,383)       596    (5,383)
 Allowance for equity funds used
   during construction                     (260)     (660)    (1,968)   (2,704)
 Cash flows affected by changes in:
  Receivables                            25,895    17,810      9,547    (9,863)
  Fuel inventories                        1,360     5,083       (697)    4,047
  Materials and supplies                     37     1,503     (1,625)     (805)
  Accounts payable                      (18,873)     (465)   (15,296)   10,211
  Accrued taxes                          (7,356)    1,543    (30,182)  (17,084)
  Accrued interest                       (1,191)    4,885     (1,928)   11,765
  Wolf Creek refueling outage
    accrual                               2,099   (13,006)     8,723    (4,743)
 Pension and postretirement benefit
     obligations                           (532)     (519)       (97)   (2,290)
 Other operating activities              (2,238)    1,878      7,730    12,864
  Net cash from operating
   activites                             10,084    72,125    154,868   253,307

CASH FLOWS FROM INVESTING ACTIVITIES
 Utility capital expenditures           (27,402)  (29,549)   (98,800) (136,962)
 Allowance for borrowed funds used
   during construction                     (784)     (390)    (2,341)   (1,805)
 Purchases of investments               (77,241)  (17,589)   (95,014)  (67,893)
 Purchases of nonutility property        (1,611)        0    (22,006)        0
 Other investing activities              (4,397)   (1,804)    (3,524)    3,936
  Net cash from investing
   activities                          (111,435)  (49,332)  (221,685) (202,724)

CASH FLOWS FROM FINANCING ACTIVITIES
 Issuance of long-term debt              32,000    11,827    155,614   118,719
 Repayment of long-term debt             (6,500)        0    (80,730)  (33,428)
 Net change in short-term borrowings    102,361    (9,000)    92,361   (31,500)
 Dividends paid                         (26,028)  (25,112)  (103,119)  (99,925)
 Other financing activities               1,059      (149)      (946)    2,834
  Net cash from financing
   activities                           102,892   (22,434)    63,180   (43,300)
NET CHANGE IN CASH AND CASH
    EQUIVALENTS                           1,541       359     (3,637)    7,283

CASH AND CASH EQUIVALENTS AT BEGINNING
    OF PERIOD                            23,571    28,390     28,749    21,466

CASH AND CASH EQUIVALENTS AT END
    OF PERIOD                           $25,112   $28,749    $25,112   $28,749

CASH PAID DURING THE PERIOD FOR:
Interest (net of amount capitalized)    $17,019    $8,962    $60,514   $42,354
Income taxes                                 $0    $5,072    $53,272   $68,150

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
                                            March 31             March 31
                                         1997      1996       1997      1996


Beginning balance                      $455,934  $449,966   $449,377  $425,080

Net income (loss)                       (15,132)   24,523     68,516   124,222
                                        440,802   474,489    517,893   549,302
Dividends declared
   Preferred stock - at required rates      960       970      3,772     3,977
   Common stock                          25,068    24,142     99,347    95,948

Ending balance                         $414,774  $449,377   $414,774  $449,377

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


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 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
exceeds  by  approximately  5% any decline  in  this  index.   Western
Resources  could  avoid this termination by improving  the  conversion
ratio.

       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 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 quarter of 1997, $4.8 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 March 31, 1997
and  December  31,  1996.  Unrealized gains, net  of  deferred  income
taxes,  decreased to $1.7 million at March 31, 1997, from $6.5 million
at December 31, 1996.

3.  CAPITALIZATION

      From  January 1 to March 31, 1997, KCPL repaid $6.5  million  of
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 March 31, 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  subordinated
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.    KCPL  guarantees   the   payment   of
distributions on the preferred securities to the extent that KCPL  has
made  payments  of  interest or principal on  the  debentures.   These
payments  will be reflected as Miscellaneous Interest Charges  in  the
Consolidated Statement of Income and will be tax deductible  by  KCPL.
KCPL  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.  KCPL 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.  KCPL  used  $93,000,000  of  the
proceeds  from  this issuance to repay short-term  obligations.   This
amount  is  reflected in the consolidated balance sheet at  March  31,
1997, as "Refinanced short-term borrowings".

     From April 1 through May 7, 1997, KLT's long-term debt, including
current maturities, increased $6.6 million.

4.  LEGAL PROCEEDINGS

       Jack   R.  Manson  (Manson),  as  a  representative  of  KCPL's
shareholders,  alleged in a District Court proceeding, that  KCPL  and
its  directors breached their fiduciary duties in adopting the Amended
Merger  Agreement  with UtiliCorp (Agreement).   Manson  also  alleged
their   actions   1)   were  illegal,   2)  illegally  deprived   KCPL
shareholders of voting and appraisal rights under Missouri law, and 3)
were  a  disproportionate response to Western  Resources'  acquisition
offer.   Also, on June 7, 1996, Western Resources and Robert L.  Rives
each  alleged  against  KCPL in the same court  proceeding,  that  the
Agreement  was  illegal  under Missouri  law  and  the  directors  had
breached their fiduciary duties by adopting the Agreement.

      By  order  dated November 25, 1996, the District  Court  allowed
Manson  to amend his allegation to allege that the directors  breached
their  fiduciary duties by refusing to negotiate a merger with Western
Resources  and  committed  reckless, grossly negligent,  or  negligent
waste  of  corporate  assets by pursuing the  merger  with  UtiliCorp.
Manson  seeks monetary damages in an unspecified amount for the  waste
of  corporate  assets.  KCPL filed a motion on December  9,  1996,  to
dismiss  Manson's  amendment;  it  is  currently  pending  before  the
District  Court.  The  Company cannot predict  the  outcome  of  these
proceedings at this time.


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  core
utility  operations, lowering prices and offering new services.   KCPL
now  offers customized energy packages to larger customers,  including
options  offering natural gas contracts.  We are also creating  growth
through  our  unregulated  subsidiary (see Nonregulated  Opportunities
below).   As competition presents new opportunities, we will  consider
various strategies including partnerships, acquisitions, combinations,
additions  to  or dispositions of service territory, and restructuring
wholesale  and  retail businesses.  We have entered an  Agreement  and
Plan of Merger with Western Resources, Inc. (Western Resources).  This
agreement  was  reached  after nine months  of  defending  against  an
unsolicited  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  or
divestitures of generating assets.

     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.  KCPL
has made the necessary filings to comply with that order.

      FERC's  April  1996 order is likely to encourage  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,
legislative committees are being 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.  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.

      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
22% 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 $161 million at March
31, 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 OPPORTUNITIES

       KLT   Inc.   (KLT)   is  a  wholly-owned  subsidiary   pursuing
nonregulated, mainly energy-related business ventures.  KLT's strategy
capitalizes on new market opportunities by combining our expertise  in
energy-related  fields  with  the  knowledge  of  our  joint   venture
partners.   Existing  ventures  include investments  in  domestic  and
international nonregulated power production, energy services, oil  and
gas  reserves,  telecommunications,  and  affordable  housing  limited
partnerships.

      We  had  a total equity investment in KLT of $99 million  as  of
March  31,  1997,  and expect that investment to grow  to  about  $210
million  within  the  next five years.  KLT's consolidated  assets  at
March  31, 1997, totaled $293 million.  Within the next five years  we
expect  KLT  consolidated  assets of  about  $800  million,  generated
through  the  $210  million of equity investment, subsidiary  retained
earnings  and borrowings.  The growth of KLT accounts for the majority
of  the  increase  in KCPL's consolidated investments  and  nonutility
property.


RESULTS OF OPERATIONS

Three-month         three  months  ended March 31, 1997,  compared
period:             with three months ended March 31, 1996
                    
Twelve-month        twelve  months ended March 31, 1997,  compared
period:             with twelve months ended March 31, 1996


EARNINGS OVERVIEW

                        Earnings Per Share (EPS)
                      For the Periods Ended March
                                   31
                                              
                        1997      1996    Decrease
Three months ended    $(0.26)    $0.38    $(0.64)
Twelve months ended    $1.05     $1.94    $(0.89)

     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   that
agreement,  lowering  EPS  for  the  three-month  period   by   $0.52.
Continued  implementation of rate reductions approved by the  MPSC  in
July  1996 also lowered EPS for the three-month period by an estimated
$0.11.

      The  decrease  in EPS for the twelve-month period  reflects  the
payment to UtiliCorp ($0.52), the estimated twelve-month impact of the
Missouri  rate  reduction ($0.14), and merger costs  expensed  in  the
second  and  third quarters of 1996 ($0.31).  Mild summer temperatures
and an increase in depreciation expense also had a negative impact  on
EPS  for the twelve-month period.  Factors contributing positively  to
EPS for the twelve-month period included continued load growth and  an
increase in bulk power sales.

MEGAWATT-HOUR (MWH) SALES AND OPERATING REVENUES

Sales and revenue data:

                                 Increase (Decrease) from Prior Year
                                 Three-Month        Twelve-Month
                                 Period             Period
                                   Mwh  Revenues      Mwh  Revenues
                                        (millions)         (millions)

Retail sales:
  Residential                        0%    $   (3)     (2%)   $   (9)
  Commercial                         1%        (8)      3%        (3)
  Industrial                        (1%)       (3)      5%         -
  Other                             (1%)        -      (3%)        -
    Total retail                     0%       (14)      2%       (12)
Sales for resale:
  Bulk power sales                  19%         2      14%        13
  Other                             32%         -      35%         -
    Total                                     (12)                 1
Other revenues                                  -                 (3)
    Total electric operating revenues      $  (12)             $  (2)
                                   

      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 lowered revenues  for
the  three-month  period by about $11 million,  and  the  twelve-month
period by about $14 million.

      These  rate reductions, combined with seasonally lower sales  in
March  1997  versus  December  1996,  resulted  in  a  lower  accounts
receivable balance at March 31, 1997, compared with December 31, 1996.

      These  rate  reductions  are  the main  reason  retail  revenues
decreased 7% for the three-month period on relatively flat mwh  sales,
and decreased 1% for the twelve-month period despite a 2% increase  in
mwh sales.  Milder weather also decreased retail sales revenue for the
three-  and twelve-month periods, but this decrease was largely offset
by continued load growth.

      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.  For the  current  twelve-
month  period  additional contracts reduced the average mwh  price  of
industrial sales.

      Bulk power sales vary with system requirements, generating  unit
and  purchased power availability, fuel costs and the requirements  of
other  electric  systems.  Wolf Creek's spring 1996  refueling  outage
(see Wolf Creek section) contributed to lower bulk power sales in  the
prior three- and twelve-month periods.

      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, cogeneration, 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 only 3% while total mwh sales (total of  retail  and
sales  for  resale) increased 5%.  The difference  is  due  mainly  to
additional replacement power expense incurred in the prior three-month
period  during Wolf Creek's spring 1996 refueling outage.  That outage
began one month early and lasted 19 days longer than planned (see Wolf
Creek section).

      Combined  fuel and purchased power expenses for the twelve-month
period  increased  7% while total mwh sales increased  only  5%.   The
additional increase in expense is due mainly to a $6 million  increase
in  capacity  purchases.  Capacity purchases provide a cost  effective
alternative to constructing new capacity.  This increase is  partially
offset  by  a  $2  million  decrease in expense  from  coal  inventory
adjustments.  In addition, the prior twelve-month period includes  the
additional  costs  incurred  for Wolf Creek's  1996  refueling  outage
(discussed above) and a 1995 forced generating station outage.  During
July 1995 a fire forced an outage at LaCygne I, a low-cost, coal-fired
generating  unit.  We replaced the power by increasing  the  usage  of
higher-cost,  coal-fired units and purchasing power on  the  wholesale
market.   Damage to the unit was covered by insurance, but  uninsured,
incremental fuel and purchased power costs were about $4 million.

      The  MMBTU price of nuclear fuel remains substantially less than
the  MMBTU  price of coal, despite increasing 27% for the twelve-month
period.   Nuclear fuel costs averaged 61% of the price of coal  during
the  current twelve months compared with 46% during the prior  twelve-
month  period.  We expect this relationship and the price  of  nuclear
fuel  to  remain fairly constant through the year 2001.   During  both
twelve-month  periods, coal represented about 75%  of  generation  and
nuclear fuel about 25%.

     The MMBTU price of coal decreased 4% 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 the three-
and twelve-month periods varied slightly, due largely to the timing of
scheduled maintenance programs.

      We  continue to emphasize new technologies, improved methods and
cost   control.   We  are  changing  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 the three- and twelve-
month  periods reflects the implementation of the Missouri stipulation
and  agreement  discussed in the revenue section  as  well  as  normal
increases  in  depreciation  from  capital  additions.   The  Missouri
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 will  be  fully
amortized  in  the  second  quarter of 1997, removing  all  regulatory
assets created from the completion of Wolf Creek construction in 1985.
Amortization  of  the Kansas portion of this asset  totaled  about  $3
million per year.

INCOME TAXES

     The decrease in operating income taxes for the three-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.


OTHER INCOME

     Miscellaneous Income
     Miscellaneous  income for the prior twelve-month period  included
     an  adjustment  to  reduce a 1995 gain from  the  sale  of  steel
     railcars  by  $3  million.  The adjustment was  based  on  a  re-
     calculation of the cars' net cost.  Miscellaneous income for  the
     current   three-  and  twelve-month  periods  includes  increased
     revenues from subsidiary operations.

     Miscellaneous Deductions
     Miscellaneous deductions for the three- 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.
     The  twelve-month  period also reflects  $31  million  in  merger
     related costs incurred in the second and third quarters of  1996;
     these  costs consist of $13 million in previously deferred merger
     costs  expensed  as a result of terminating the merger  agreement
     with   UtiliCorp,  a  $5  million  termination  fee   paid   upon
     termination,  and $13 million in costs to defend against  Western
     Resources' unsolicited exchange offer.
     
     Both periods reflect increased subsidiary operating and investing
     activities.    Total  subsidiary  expenses,  including   interest
     charges discussed below, are substantially offset by related  tax
     benefits.
     
     Income Taxes
     Income  tax  reductions for the three- and  twelve-month  periods
     increased   primarily  due  to  the  increases  in  miscellaneous
     deductions  discussed  above.   Additionally,  during  the  first
     quarter  of  1997 we accrued tax credits of $6 million,  or  one-
     fourth  of the total expected 1997 credits, related to affordable
     housing  partnership  investments and oil  and  gas  investments.
     This  is  an increase of $3 million compared with the tax credits
     accrued  during the first quarter of 1996.  Tax credits from  the
     investments  in affordable housing more than offset the  increase
     in interest expense incurred from these investments.  Non-taxable
     increases  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 the  three-  and
twelve-month  periods reflect higher average levels of long-term  debt
outstanding.   The  higher  levels  of  debt  resulted   mainly   from
additional financing by KLT to support expanding subsidiary operations
and new investments in unregulated ventures.

      We  use  interest  rate  swap and cap agreements  to  limit  the
interest expense on a portion of our 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.


WOLF CREEK

       Wolf   Creek  is  one  of  KCPL's  principal  generating  units
representing about 18% of accredited generating capacity.  The plant's
operating performance has remained strong, contributing about  25%  of
annual  mwh generation while operating at an average capacity  of  88%
over  the last three years.  It has the lowest fuel cost per MMBTU  of
any of KCPL's generating units.

      Wolf  Creek's eighth scheduled refueling and maintenance  outage
began  in  early  February 1996 and was completed in  April  1996  (64
days).   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.   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.  Wolf Creek's ninth refueling
and maintenance outage is scheduled for the fall of 1997.

      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 March 31, 1997, included cash flows  from
operations; $300 million of registered but unissued, unsecured medium-
term  notes  and  $359 million of unused bank lines  of  credit.   The
unused  lines consisted of KCPL's short-term bank lines of  credit  of
$296  million  and  KLT's long-term revolving line of  credit  of  $63
million.

      KCPL  continued to generate positive cash flows  from  operating
activities  despite the significant decreases in net  income  for  the
three- and twelve-month periods.  Cash flow variances from changes  in
working  capital items 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  decrease in accrued taxes from December 31, 1996, to  March
31,  1997,  mainly reflects the decrease in taxable income during  the
first three months of 1997.  This decrease is partially offset by  the
loss   of   accelerated  depreciation  on  significant  plant  assets.
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.   We expect property tax requirements to decrease  about  $3
million in 1997 based on changes in Kansas laws.

      The $8.9 million incurred to repair damages from an October 1996
snow storm lowered cash flows from operating activities for the twelve-
month  period.  Amortization of these costs over five years  began  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  three  months  of 1997, increasing Investments  and  Nonutility
Property  on  the  Consolidated Balance  Sheet  by  approximately  $76
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,  lowering Other Receivables on  the  Consolidated
Balance  Sheet.  The increase in nonutility properties in the  twelve-
month  period resulted mainly from KLT's purchase of certain  oil  and
gas projects during 1996.

      As discussed in Note 2 to the Consolidated Financial Statements,
the  market value of KLT's investment in securities available for sale
decreased  during  the first three months of 1997.  This  decrease  is
reflected in the Unrealized Gain on Securities Available for  Sale  in
the Consolidated Balance Sheet.

      The  $53  million  payment to UtiliCorp and KLT's  purchases  of
investments  and  nonutility properties were financed  mostly  through
additional long-term and short-term borrowings.  As discussed in  Note
3  to  the Consolidated Financial Statements, a majority of the short-
term  borrowings during the first three months of 1997 were refinanced
with long-term obligations during April 1997.

      KCPL's  common  dividend payout ratio was 153% for  the  current
twelve-month  period and 80% for the prior twelve-month  period.   The
increase  in the payout ratio is due mainly to the significant  merger
related expenses in the current twelve-month period.

      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,
compliance with future environmental regulations, the availability  of
generating  units, and the outcome of pending legal  proceedings  (see
Note  4  to the Consolidated Financial Statements).  The funds  needed
for  the retirement of $386 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.






PART II - OTHER INFORMATION

Item 6.  Exhibits and Reports on Form 8-K

     (a)  Exhibits

     4-a  Amended and Restated Declaration of Trust of KCPL
Financing I dated
          April 15, 1997

     4-b  Indenture dated as of April 1, 1997 between the Company
and The First
          National Bank of Chicago, Trustee

     4-c  First Supplemental Indenture dated as of April 1, 1997
to the Indenture
          dated as of April 1, 1997 between the Company and The
First National
          Bank of Chicago, Trustee

     4-d  Preferred Securities Guarantee Agreement dated April
15, 1997

     27   Financial Data Schedule (for the three months ended
March 31, 1997)

     (b)  Reports on Form 8-K

          A report on Form 8-K was filed with the Securities and
Exchange Commission
     on February 11, 1997, with attached copy of the Agreement
and Plan of Merger dated
     as of February 7, 1997, between the Company and Western
Resources, Inc.

          A report on Form 8-K was filed with the Securities and
Exchange Commission
     on April 3, 1997, with attached copies of the following: 1)
Statement re Computation
     of Ratios of Earnings to Fixed Charges and Ratios of
Earnings to Fixed Changes
     and Preferred Dividend Requirements; 2) Western Resources
Annual Report on
     Form 10-K for the year ended December 31, 1996; 3) Western
Resources Current
     Report on Form 8-K dated April 1, 1997; 4) Western Resources
Proxy Statement
     dated March 27, 1996 for the 1996 Annual Meeting of
Shareholders held on
     May 7, 1996.
















                                
                           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:   May 9, 1997               /s/ Drue Jennings
                              (Drue Jennings)
                             (Chief Executive Officer)




Dated:   May 9, 1997               /s/ Neil Roadman
                                 (Neil Roadman)
                              (Principal Accounting Officer)