<SUBMISSION>
<ACCESSION-NUMBER>0000074145-01-500003
<TYPE>10-Q
<PUBLIC-DOCUMENT-COUNT>2
<PERIOD>20010331
<FILING-DATE>20010515
<FILER>
<COMPANY-DATA>
<CONFORMED-NAME>OGE ENERGY CORP
<CIK>0001021635
<ASSIGNED-SIC>4911
<IRS-NUMBER>731481638
<STATE-OF-INCORPORATION>OK
<FISCAL-YEAR-END>1231
</COMPANY-DATA>
<FILING-VALUES>
<FORM-TYPE>10-Q
<ACT>34
<FILE-NUMBER>001-12579
<FILM-NUMBER>1638586
</FILING-VALUES>
<BUSINESS-ADDRESS>
<STREET1>321 N HARVEY
<STREET2>P O BOX 321
<CITY>OKLAHOMA CITY
<STATE>OK
<ZIP>73101-0321
<PHONE>4055533000
</BUSINESS-ADDRESS>
<MAIL-ADDRESS>
<STREET1>321 N HARVEY
<STREET2>P O BOX 321
<CITY>OKLAHOMA CITY
<STATE>OK
<ZIP>73101-0321
</MAIL-ADDRESS>
</FILER>
<DOCUMENT>
<TYPE>10-Q
<SEQUENCE>1
<FILENAME>oge10q0301.html
<TEXT>

<HTML>
<HEAD>
<TITLE>Form 10-Q</TITLE>
</HEAD>

<BODY>

<BR><BR>
<HR SIZE=3 WIDTH=100% NOSHADE>


<P ALIGN=CENTER><B><FONT SIZE=5>FORM 10-Q</FONT></B><BR>
<FONT SIZE=4>SECURITIES AND EXCHANGE COMMISSION</FONT><BR>
<FONT SIZE=2>Washington, D.C. 20549</FONT></P>

<P ALIGN=CENTER><FONT SIZE=4>(Mark One)<BR><B>|X| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)<BR>
OF THE SECURITIES EXCHANGE ACT OF 1934</B></FONT>
<P ALIGN=CENTER><FONT SIZE=2>For the quarterly period ended March 31, 2001</FONT></P>

<P ALIGN=CENTER><B><FONT SIZE=3>OR</FONT></B></P>

<P ALIGN=CENTER><FONT SIZE=4><B>|&nbsp;&nbsp;&nbsp;| TRANSITION REPORT PURSUANT TO SECTION 13 or 15(d) OF<BR>
THE SECURITIES EXCHANGE ACT OF 1934</B></FONT></P>

<P ALIGN=CENTER><FONT SIZE=2>Commission file number 1-12579</FONT></P>

<P ALIGN=CENTER><B><FONT SIZE=5>OGE ENERGY CORP.</FONT></B><BR>
<FONT SIZE=2>(Exact name of registrant as specified in its charter)</FONT></P>

<P ALIGN=LEFT><FONT SIZE=2>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;Oklahoma&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;73-1481638<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(State or other jurisdiction of&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;(I.R.S.  Employer<BR>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;incorporation or
organization)&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Identification No.)</FONT></P>

<P ALIGN=CENTER><FONT SIZE=2>321 North Harvey<BR>
P. O. Box 321<BR>
Oklahoma City, Oklahoma 73101-0321<BR>
(Address of principal executive offices)<BR>
(Zip Code)</FONT></P>

<P ALIGN=CENTER><FONT SIZE=2>405-553-3000<BR>
(Registrant's telephone number, including area code)</FONT></P>


<P><FONT  SIZE=2>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
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.</FONT></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;<FONT
SIZE=2>Yes<U>&nbsp;&nbsp;&nbsp;&nbsp;X&nbsp;&nbsp;&nbsp;&nbsp;</U>No<U>&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;</U></FONT></P>

<P><FONT  SIZE=2>There  were 77,921,997  Shares of
Common  Stock,  par  value  $0.01  per  share,  outstanding  as of April 30,
2001.</FONT></P>


<HR SIZE=3 NOSHADE>

<PAGE>
<P ALIGN=CENTER><B>OGE Energy Corp.</B></P>

<P ALIGN=CENTER><B>PART I. FINANCIAL INFORMATION</B></P>

<P ALIGN=LEFT><B>Item 1  FINANCIAL STATEMENTS</B></P>

<P ALIGN=CENTER><B>CONSOLIDATED STATEMENTS OF OPERATIONS<BR>
<FONT SIZE=2>(Unaudited)</FONT></B></P>
<PRE>
                                                                     <B>Three Months Ended
                                                                           March 31
                                                              --------------------------------
                                                                   2001             2000</B>
                                                              --------------    --------------
                                                              <I>(thousands except per share data)</I>
OPERATING REVENUES.........................................   $   1,063,587     $     581,581

COST OF GOODS SOLD.........................................         896,923           400,006
                                                              --------------    --------------
  Gross margin on revenues.................................         116,664           181,575
                                                              --------------    --------------
  Other operation and maintenance..........................          98,090            88,352
  Depreciation and amortization............................          45,324            44,919
  Taxes other than income..................................          16,650            16,108
                                                              --------------    --------------
OPERATING INCOME...........................................           6,600            32,196
                                                              --------------    --------------
OTHER EXPENSES, NET........................................            (250)             (201)
                                                              --------------    --------------
EARNINGS BEFORE INTEREST AND TAXES.........................           6,350            31,995

INTEREST INCOME (EXPENSES):
  Interest income..........................................             869             1,609
  Interest on long-term debt...............................         (26,441)          (25,387)
  Interest on trust preferred securities...................          (4,317)           (4,317)
  Allowance for borrowed funds used during construction....             183               148
  Other interest charges...................................          (3,706)           (5,614)
                                                              --------------    --------------
    Net interest income (expenses).........................         (33,412)          (33,561)
                                                              --------------    --------------
LOSS BEFORE TAXES..........................................         (27,062)           (1,566)

INCOME TAX BENEFIT.........................................         (12,093)           (2,342)
                                                              --------------    --------------
NET INCOME (LOSS)..........................................   $     (14,969)    $         776
                                                              ==============    ==============
AVERAGE COMMON SHARES OUTSTANDING (thousands)..............          77,922            77,863
EARNINGS (LOSS) PER AVERAGE COMMON SHARE...................   $       (0.19)    $        0.01
                                                              ==============    ==============
AVERAGE COMMON SHARES OUTSTANDING
  ASSUMING DILUTION (thousands)............................          77,922            77,863
EARNINGS (LOSS) PER AVERAGE COMMON SHARE
  ASSUMING DILUTION........................................   $       (0.19)    $        0.01
                                                              ==============    ==============
DIVIDENDS DECLARED PER SHARE...............................   $      0.3325     $      0.3325
<I>The accompanying Notes to Consolidated Financial Statements are an integral part hereof.</I>
</PRE>
<P ALIGN=CENTER>1</P><BR>
<PAGE>

<P ALIGN=CENTER><B>CONSOLIDATED BALANCE SHEETS<BR>
<FONT SIZE=2>(Unaudited)</FONT></B></P>
<PRE>
                                                                        <B>March 31         December 31
                                                                          2001              2000</B>
                                                                     -------------      --------------
                                                                          <I>(dollars in thousands)</I>

<B>ASSETS</B>
CURRENT ASSETS:
  Cash and cash equivalents.....................................     $        332       $         454
  Accounts receivable - customers, less reserve of $3,483 and
    $4,135, respectively........................................          316,402             446,185
  Accrued unbilled revenues.....................................           42,300              49,000
  Accounts receivable - other...................................           14,282              24,713
  Fuel inventories..............................................           90,867             200,316
  Materials and supplies, at average cost.......................           41,505              41,517
  Prepayments and other.........................................           36,125              45,715
  Price risk management.........................................           11,226              45,727
  Accumulated deferred tax assets...............................           10,776              10,669
                                                                     -------------      --------------
    Total current assets........................................          563,815             864,296
                                                                     -------------      --------------
OTHER PROPERTY AND INVESTMENTS, at cost.........................           37,872              36,980
                                                                     -------------      --------------
PROPERTY, PLANT AND EQUIPMENT:
  In service....................................................        5,350,814           5,323,541
  Construction work in progress.................................           71,953              47,016
                                                                     -------------      --------------
    Total property, plant and equipment.........................        5,422,767           5,370,557
      Less accumulated depreciation.............................        2,189,561           2,151,093
                                                                     -------------      --------------
  Net property, plant and equipment.............................        3,233,206           3,219,464
                                                                     -------------      --------------
DEFERRED CHARGES:
  Advance payments for gas......................................           12,500              12,500
  Income taxes recoverable through future rates.................           38,394              38,654
  Other.........................................................          117,117             147,736
                                                                     -------------      --------------
    Total deferred charges......................................          168,011             198,890
                                                                     -------------      --------------
TOTAL ASSETS....................................................     $  4,002,904       $   4,319,630
                                                                     =============      ==============
<B>LIABILITIES AND STOCKHOLDERS' EQUITY</B>
CURRENT LIABILITIES:
  Short-term debt...............................................     $    164,300       $     284,500
  Accounts payable..............................................          286,370             330,445
  Dividends payable.............................................           25,909              25,890
  Customers' deposits...........................................           23,395              22,647
  Accrued taxes.................................................            3,717              33,067
  Accrued interest..............................................           29,884              40,699
  Long-term debt due within one year............................            2,000               2,000
  Price risk management.........................................            4,895              33,709
  Other.........................................................           36,005              36,975
                                                                     -------------      --------------
    Total current liabilities...................................          576,475             809,932
                                                                     -------------      --------------
LONG-TERM DEBT..................................................        1,643,693           1,648,523
                                                                     -------------      --------------
DEFERRED CREDITS AND OTHER LIABILITIES:
  Accrued pension and benefit obligation........................           14,535              14,256
  Accumulated deferred income taxes.............................          621,936             618,360
  Accumulated deferred investment tax credits...................           56,141              57,429
  Other.........................................................           68,900             106,822
                                                                     -------------      --------------
    Total deferred credits and other liabilities................          761,512             796,867
                                                                     -------------      --------------
STOCKHOLDERS' EQUITY:
  Common stockholders' equity...................................          443,172             443,298
  Retained earnings.............................................          580,114             621,010
  Accumulated other comprehensive income........................           (2,062)                ---
                                                                     -------------      --------------
    Total stockholders' equity..................................        1,021,224           1,064,308
                                                                     -------------      --------------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY......................     $  4,002,904       $   4,319,630
                                                                     =============      ==============

<I>The accompanying Notes to Consolidated Financial Statements are an integral part hereof.</I>
</PRE>

<P ALIGN=CENTER>2</P><BR>
<PAGE>
<PRE>
                             <B>CONSOLIDATED STATEMENTS OF
                                   CASH FLOWS
                                   (Unaudited)</B>
                                                                              <B>Three Months Ended
                                                                                   March 31
                                                                             2001               2000</B>
                                                                        --------------     --------------
                                                                             <I>(dollars in thousands)</I>
CASH FLOWS FROM OPERATING ACTIVITIES:
  Net Income (Loss)..................................................   $     (14,969)     $         776
  Adjustments to Reconcile Net Income (Loss) to Net Cash
   Provided from Operating Activities:
    Depreciation and amortization....................................          45,324             44,919
    Deferred income taxes and investment tax credits, net............           3,947              8,197
    Gain on sale of assets...........................................             (53)               ---
    Change in Certain Assets and Liabilities:
      Accounts receivable - customers................................         129,783             57,714
      Accrued unbilled revenues......................................           6,700              2,600
      Fuel, materials and supplies inventories.......................         109,461            (13,959)
      Other current assets...........................................          19,916            (25 640)
      Accounts payable...............................................         (44,075)            26,604
      Accrued taxes..................................................         (29,350)           (25,677)
      Accrued interest...............................................         (10,815              2,852
      Other current liabilities......................................            (203)            16,502
    Other operating activities.......................................          (4,575)             5,860
                                                                        --------------     --------------
        Net cash provided from operating activities..................         211,091            100,748
                                                                        --------------     --------------
CASH FLOWS FROM INVESTING ACTIVITIES:
  Capital expenditures...............................................         (59,540)           (43,422)
  Proceeds from sale of assets.......................................              72                ---
  Other investing activities.........................................            (425)               166
                                                                        --------------     --------------
        Net cash used in investing activities........................         (59,893)           (43,256)
                                                                        --------------     --------------
CASH FLOWS FROM FINANCING ACTIVITIES:
  Retirement of long-term debt.......................................          (4,883)               ---
  Proceeds from long-term debt.......................................             ---            400,000
  Decrease in short-term debt, net...................................        (120,200)          (435,400)
  Retirement of common stock.........................................            (125)               ---
  Payment of obligation under capital lease..........................            (184)               ---
  Cash dividends declared on common stock............................         (25,928)           (25,889)
                                                                        --------------     --------------
        Net cash used in financing activities........................        (151,320)           (61,289)
                                                                        --------------     --------------
NET DECREASE IN CASH AND CASH EQUIVALENTS............................            (122)            (3,797)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD.....................             454              7,271
                                                                        --------------     --------------
CASH AND CASH EQUIVALENTS AT END OF PERIOD...........................   $         332      $       3,474
                                                                        ==============     ==============
--------------------------------------------------------------------------------------------------------------
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
  CASH PAID DURING THE PERIOD FOR:
    Interest (net of amount capitalized).............................   $      41,578      $      29,904
    Income taxes.....................................................   $       1,800      $       4,900
--------------------------------------------------------------------------------------------------------------
DISCLOSURE OF ACCOUNTING POLICY:
For purposes of these  statements,  the Company considers all highly liquid debt
instruments  purchased  with a  maturity  of  three  months  or  less to be cash
equivalents. These investments are carried at cost, which approximates market.
<I>The accompanying Notes to Consolidated Financial Statements are an integral part hereof.</I>
                                     3</PRE>
<PAGE>

<P ALIGN=CENTER><B><FONT SIZE=4>NOTES TO CONSOLIDATED FINANCIAL STATEMENTS</FONT></B></P>
<P ALIGN=CENTER>(Unaudited)</P>

<OL>
<LI> The condensed  consolidated financial  statements included herein have been
     prepared by OGE Energy  Corp.  (the  &#147;Company&#148;),  without  audit,
     pursuant  to the rules  and  regulations  of the  Securities  and  Exchange
     Commission.  Certain information and footnote disclosures normally included
     in financial  statements  prepared in accordance  with  generally  accepted
     accounting principles have been condensed or omitted pursuant to such rules
     and  regulations;  however,  the Company  believes that the disclosures are
     adequate to make the information presented not misleading.<BR><BR>

     In the opinion of management,  all adjustments  necessary to present fairly
     the  financial   position  of  the  Company  and  its  subsidiaries  as  of
     March&#160;31,  2001, and  December&#160;31,&#160;2000,  and the results of
     operations  and  the  changes  in cash  flows  for  the&#160;periods  ended
     March&#160;31,&#160;2001, and March 31, 2000, have been included and are of
     a normal recurring  nature.  Certain amounts have been  reclassified on the
     financial statements to conform with the 2001 presentation.<BR><BR>

     The results of  operations  for such  interim  periods are not  necessarily
     indicative  of the results for the full year.  It is  suggested  that these
     condensed consolidated financial statements be read in conjunction with the
     consolidated  financial  statements  and the notes thereto  included in the
     Company&#146;s Form 10-K for the year ended December 31, 2000.<BR><BR>

<LI> The Company is a holding company,  which was incorporated in August 1995 in
     the  State  of  Oklahoma.  The  Company  is not  engaged  in  any  business
     independent  of  that  conducted  through  its  two  primary  subsidiaries,
     Oklahoma Gas and Electric Company ("OG&amp;E") and Enogex Inc. ("Enogex").
     <BR><BR>

     OG&amp;E  is  a  regulated   public  utility  that  owns  and  operates  an
     interconnected   electric   production,   transmission   and   distribution
     system.<BR><BR>

     Enogex is an Oklahoma  intrastate  natural gas  pipeline  company that also
     conducts related  operations,  through its subsidiaries,  in interstate and
     intrastate gas transmission, natural gas gathering, natural gas processing,
     natural gas and  electricity  marketing,  and oil and gas  development  and
     production.<BR><BR>

<LI> Effective  January 1, 2001,  the Company  adopted  Statement  of  Financial
     Accounting   Standards   ("SFAS")  No.  133,   "Accounting  for  Derivative
     Instruments and Hedging  Activities",  as amended by SFAS Nos. 137 and 138.
     SFAS No. 133 requires the Company to record all  derivatives on the balance
     sheet at fair value.  Change in the fair value of derivatives  that are not
     designated  as  hedges,  as  well  as  the  ineffective  portion  of  hedge
     derivatives,  must be recognized as a derivative fair value gain or loss in
     the income  statement.  Changes in fair value of effective cash flow hedges
     are  recorded as a component of  Accumulated  Other  Comprehensive  Income,
     which is later transferred to earnings  when the hedged transaction occurs.
     Physical delivery  contracts which cannot be net cash settled are deemed to
     be  normal  sales  and  therefore  are not  accounted  for as  derivatives.
     However,
</OL>
<P ALIGN=CENTER>4</P><BR>
<PAGE>
<OL START=4>
<P>  physical  delivery  contracts  that have a price not  clearly  and  closely
     associated  with the asset sold are not a normal sale and must be accounted
     for as a non-hedge derivative.<P>

<P>  The Company  accounted  for adoption of SFAS No. 133 on January 1, 2001, by
     recording a cumulative effect  transition  adjustment debit to  Accumulated
     Other Comprehensive Income of approximately $16.5 million.</P>

<P>  The  Company  recorded  a  derivative  fair  value  loss,  related  to  the
     ineffective portion of  hedge derivatives, of $2.9 million during the three
     months ended March 31, 2001.</P>

<P>  As of March 31,  2001,  an  unrealized  derivative  fair value loss of $2.1
     million,  related to cash flow hedges of commodity risk associated with the
     value of  future  natural gas  production  for the  remainder  of 2001  was
     recorded in Accumulated Other  Comprehensive  Income. This loss is expected
     to be  reclassified  into earnings over the last three quarters of 2001, as
     the hedged natural gas production is sold.</P>

<LI> In  accordance  with SFAS No.  130,  Reporting  Comprehensive  Income,  the
     following are components of Other Comprehensive Income:<BR><BR>
</OL>
<PRE>
                                                             Three Months Ended
                                                                  March 31
                                                             <B>2001</B>          2000
                                                          ----------    ----------
                                                           <I>(dollars in thousands)</I>

Net income (loss)......................................   <B>$ (14,969)</B>    $     776
                                                          ----------    ----------
Other comprehensive income (loss), net of tax:
  Transition adjustment................................   <B>  (16,492)</B>          ---
  Change in derivative fair value......................   <B>   15,733</B>           ---
  Reclassification adjustments - contract settlements..   <B>   (1,303)</B>          ---
                                                          ----------    ----------
Total other comprehensive income (loss), net of tax....   <B>   (2,062)</B>          ---
                                                          ----------    ----------
Total comprehensive income (loss)......................   <B>$ (17,031)</B>    $     776
                                                          ==========    ==========
</PRE>
<OL START=5>

<LI> Enogex, in the normal course of business, enters into fixed price contracts
     for either the  purchase or sale of natural gas and  electricity  at future
     dates. Due to fluctuations in the natural gas and electricity  markets, the
     Company buys or sells natural gas and electricity futures contracts,  swaps
     or  options  to  hedge  the  price  and  basis  risk  associated  with  the
     specifically  identified  purchase or sales  contracts.  Additionally,  the
     Company may use these  contracts as an enhancement  or  speculative  trade,
     subject to the Company&#146;s policies on risk management. As market values
     change,  the  Company  recognizes  the  gain  or  loss  on  enhancement  or
     speculative contracts in the results of operations.
</OL>

<P ALIGN=CENTER>5</P><BR>
<PAGE>

<P ALIGN=LEFT><B><FONT SIZE=4>Item 2  MANAGEMENT'S  DISCUSSION AND ANALYSIS OF<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;FINANCIAL
CONDITION AND RESULTS OF OPERATIONS</FONT></B></P>

<P ALIGN=LEFT><B><FONT SIZE=4>RESULTS OF OPERATIONS</FONT></B></P>

<P ALIGN=LEFT><B>OVERVIEW</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The following
discussion  and  analysis   presents  factors  which  affected  the  results  of
operations for the three months ended March 31, 2001 (the "current period"), and
the  financial   position  as  of  March  31,  2001,  of  the  Company  and  its
subsidiaries:  OG&amp;E and Enogex. Unless indicated otherwise,  all comparisons
are with the corresponding  period of the prior year. For the three months ended
March 31, 2001,  approximately 69 percent of the Company's revenues consisted of
the  non-utility  operations  of Enogex,  while the  remaining  31  percent  was
provided by the regulated  sales of electricity by OG&amp;E,  a public  utility.
The Company's earnings, however, have been predominantly from OG&amp;E. Revenues
from  sales of  electricity  are  somewhat  seasonal,  with a large  portion  of
OG&amp;E's annual electric revenues  occurring during the summer months when the
electricity  needs  of  its  customers  increase.   Actions  of  the  regulatory
commissions  that set  OG&amp;E's  electric  rates will  continue  to affect the
Company's financial results.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Some    of    the
matters discussed in this Form 10-Q, including the discussion in "2001 Outlook",
may  contain  forward-looking  statements  that are  subject to  certain  risks,
uncertainties and assumptions.  Such forward-looking  statements are intended to
be  identified  in  this  document  by  the  words   "anticipate",   "estimate",
"objective", "possible", "potential" and similar expressions. Actual results may
vary  materially.  Factors that could cause actual results to differ  materially
include,  but are not limited to: general economic  conditions,  including their
impact on capital  expenditures;  business  conditions  in the energy  industry;
competitive  factors  including the extent and timing of the entry of additional
competition in the markets  served by the Company;  unusual  weather;  state and
federal  legislative and regulatory  decisions and initiatives  that affect cost
and investment recovery,  have an impact on rate structures and affect the speed
and degree to which  competition  enters the Company's  markets;  and other risk
factors  listed in the Company's Form 10-K for the year ended December 31, 2000,
including Exhibit 99.01 thereto and other factors described from time to time in
the Company's reports to the Securities and Exchange Commission.</P>

<P ALIGN=LEFT><B>EARNINGS</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The       current
period  net  loss of $14.9  million  represents  a  decrease  of $15.7  million.
OG&amp;E's earnings increased approximately $2.2 million while Enogex's earnings
decreased   approximately   $17.6  million.  A  decrease  of  $0.3  million  was
attributable to increased  expenses at the corporate  level. As explained below,
OG&amp;E's increase in earnings was primarily attributable to increased revenues
due to increased customer demand.  Enogex's decrease in earnings was due in part
to the depressed  operating  environment  for the processing and sale of natural
gas liquids due to lower fractionation  spreads (the value of liquids after they
are  processed  out of natural  gas,  compared to the price of the gas  itself).
Unprecedented high natural gas prices,  without corresponding price increases in
natural gas liquids resulted in negative</P>

<P ALIGN=CENTER>6</P><BR>
<PAGE>

<P> fractionation spreads in the current period. Other significant factors that
reduced  earnings  at Enogex  were  higher  fuel  expenses  in the  natural  gas
gathering and transmission segment and reduced margins in energy marketing. </P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Also    in    the
current  period,  Enogex  continued  to resolve the  under-recovery  of pipeline
system fuel expenses,  reported with fourth-quarter  2000 results.  Enogex filed
for fuel-recovery rate adjustments with the Federal Energy Regulatory Commission
("FERC") and the new rates became effective on March 1, 2001, subject to refund.
The impact of this filing was minimal in the current period.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Loss  per average
common  share was $0.19 in the current  period  compared to earnings per average
common share of $0.01 in the prior period.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Reference is made
to "Report of Business  Segments" below  for a detailed  breakdown of OG&amp;E's
and Enogex's results of operations for the reported periods.

<P ALIGN=LEFT><B>2001 OUTLOOK</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The Company
previously  projected  2001  earnings at $2 to $2.10 per share.  Due to narrower
fractionation  spreads in natural gas liquids and  expectations  that this trend
will  continue,  the Company has revised its 2001 earnings  estimate to $1.70 to
$1.80 per share.</P>

<P ALIGN=LEFT><B>REVENUES</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total   operating
revenues  increased $482 million or 82.9 percent.  The increase was attributable
to significantly increased revenues at both Enogex and OG&amp;E. Enogex revenues
increased  $400.5  million or 119.1 percent  primarily due to higher natural gas
prices.  Although  revenues  increased across all of Enogex's lines of business,
the largest  increase  was  recorded  in the energy  marketing  business,  where
revenues increased $377.1 million in the current period. As explained above, the
increase in revenue  from  natural gas liquids was more than offset by increases
in prices in natural gas used to produce the liquids, which resulted in negative
fractionation spreads and contributed to the loss for the current period.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&amp;E's
revenues  increased $81.5 million or 33.2 percent  primarily due to the recovery
of higher fuel costs and increased  customer demand.  OG&amp;E  recovered higher
fuel  costs  due to  variances  in the  actual  cost  of fuel  used in  electric
generation and certain  purchased  power costs, as compared to that component in
the  cost-of-service  for  ratemaking,  which are passed  through to  OG&amp;E's
customers  through  automatic  fuel  adjustment  clauses.   The  automatic  fuel
adjustment  clauses are subject to periodic  review by the Oklahoma  Corporation
Commission  ("OCC"),  the Arkansas  Public Service  Commission  ("APSC") and the
Federal Energy  Regulatory  Commission  ("FERC").  See  "Regulation  and Rates".
Partially  offsetting the increased revenues under the fuel adjustment  clauses,
modifications to the Generation  Efficiency  Performance Rider ("GEP Rider") and
lower  recoveries  under the  Acquisition  Premium  Credit  Rider ("APC  Rider")
unfavorably  affected  revenue by  approximately  $1.4 million and $2.9 million,
respectively,  in the  current  period.  See  "Regulation  and  Rates" - "Recent
Regulatory  Matters" for a related  discussion.  Kilowatt-hour sales to OG&amp;E
customers  ("system  sales")  increased 1.3 percent in the current period due to
favorable  weather.  Kilowatt-hour  sales to other utilities and power marketers
("off-</P>

<P ALIGN=CENTER>7</P><BR>
<PAGE>

<P>system  sales")  decreased  15.9  percent;  however,   off-system  sales  are
generally  at lower prices per  kilowatt-hour  and have less impact on operating
revenues and earnings than system sales.</P>

<P ALIGN=LEFT><B>EXPENSES</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Cost   of   goods
sold, which consists of fuel expense for electric  generation,  purchased power,
gas and  electricity  purchased  for resale and natural  gas  purchases - other,
increased  $496.9 million or 124.2 percent in the current  period.  The specific
components of cost of goods sold for the reported periods are as follows:</P>

<PRE>
                                                          Three Months Ended
                                                              March 31
                                                          <B>2001</B>        2000
                                                       ----------  ----------
                                                       <I>(dollars in thousands)</I>

         Fuel.......................................   <B>$ 117,883</B>    $  62,000
         Purchased power............................   <B>   76,969</B>       60,542
         Gas and electricity purchased for resale...   <B>  651,529</B>      249,541
         Natural gas purchases - other..............   <B>   50,542</B>       27,923
                                                       ----------   ----------
           Total cost of goods sold.................   <B>$ 896,923</B>    $ 400,006
                                                       ==========   ==========
</PRE>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Enogex's  natural
gas and  electricity  purchased  for resale  increased  $402.0  million or 161.1
percent in the current period due to increased  volume and prices of natural gas
purchased for resale to third parties.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Enogex's  natural
gas  purchases - other,  which  consists  primarily  of natural  gas  processing
shrinkage, pipeline system fuel expenses and pipeline compressor fuel, increased
$22.6 million or 81.0 percent in the current  period due to the increased  price
of natural gas and the  increases in pipeline  system fuel volume.  As indicated
above,  Enogex  filed with FERC to increase its fuel  recoveries.  The impact of
this filing was minimal during the current period.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The  higher  cost
of goods sold at Enogex more than offset the  increase in Enogex's  revenues for
the current period.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&amp;E
increased  its  purchased  power by $16.4 million or 27.1 percent in the current
period primarily due to the  availability of wholesale  electricity at favorable
prices.  Kilowatt hours of energy purchased increased 40.9 percent, but the cost
of  purchased  energy  per kwh  decreased  9.0  percent  in the  current  period
resulting in the 27.1 percent overall increase in purchased power costs.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&amp;E's   fuel
expense  increased $55.9 million or 90.1 percent in the current period primarily
due to a significant increase in the average cost of fuel (particularly  natural
gas).</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other   operation
and  maintenance  increased  $9.7  million  or 11.0  percent,  primarily  due to
increased  bad debt expense  ($4.3  million),  employee  labor and benefit costs
($2.5  million),  contract  labor ($1.0  million)  and  miscellaneous  corporate
expenses ($1.9 million).</P>

<P ALIGN=CENTER>8</P><BR>
<PAGE>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The increases in
these expenses reduced  operating income by $25.6 million or 79.5 percent in the
current period.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Interest  charges
decreased $0.9 million or 2.4 percent in the current  period  primarily due to a
decrease in short-term debt.</P><BR>

<P ALIGN=LEFT><B>LIQUIDITY AND CAPITAL REQUIREMENTS</B></P><BR>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The     Company's
primary needs for capital are related to  construction of new facilities to meet
anticipated demand for OG&amp;E's utility service, to replace or expand existing
facilities  in  OG&amp;E's  electric  utility  business,  to  replace  or expand
existing  facilities in its non-utility  businesses,  to acquire new non-utility
facilities or businesses and to some extent,  for satisfying  maturing debt. The
Company's  capital  expenditures  for the current  period of $59.5  million were
financed with internally generated funds and short-term borrowings.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The Company meets
its cash needs through a combination of internally  generated funds,  short-term
borrowings  and  permanent  financing.   The  Company  expects  that  internally
generated  funds will be adequate during 2001 to meet  anticipated  construction
expenditures  and  maturities  of long-term  debt.  Short-term  borrowings  will
continue  to be used to meet  temporary  cash  requirements.  The Company has in
place a line of credit for up to $300  million,  with $200  million to expire on
January  15,  2002,  and the  remaining  $100  million to expire on January  15,
2004.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The     Company's
capital  structure and cash flow remained strong  throughout the current period.
The  Company's  combined  cash  and  cash  equivalents  decreased  approximately
$122,000 during the three months ended March 31, 2001. The decrease reflects the
Company's cash flow from operations,  net of cash used in investing  activities,
retirement of long-term  debt,  payments of short-term  debt,  capital lease and
cash dividends.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;On   January  10,
2001,  Enogex  retired $5.0 million of 7.750 percent  senior notes due April 24,
2023. This debt had been assumed as part of the Tejas Transok  Holding,  L.L.C.
acquisition in 1999.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Like          any
business,  the Company is subject to numerous  contingencies,  many of which are
beyond its control.  For a discussion of  significant  contingencies  that could
affect the Company,  reference is made to Part II, Item 1 - "Legal  Proceedings"
of this Form 10-Q and to "Management's Discussion and Analysis" and Notes 10 and
11 of Notes to the Consolidated  Financial Statements in the Company's 2000 Form
10-K.</P>

<P ALIGN=CENTER>9</P><BR>
<PAGE>

<P ALIGN=LEFT><B><FONT SIZE=4>MARKET RISK</FONT></B></P>

<P ALIGN=LEFT><B>RISK MANAGEMENT</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The          risk
management  process  established  by the  Company is  designed  to measure  both
quantitative and qualitative  risks in its businesses.  A senior risk management
committee has been  established  to review these risks on a regular  basis.  The
Company is exposed to market risk, including changes in certain commodity prices
and interest rates.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;To   manage   the
volatility  relating  to  these  exposures,  the  Company  enters  into  various
derivative transactions pursuant to the Company's policies on hedging practices.
Derivative  positions  are monitored  using  techniques  such as  mark-to-market
valuation, value-at-risk and sensitivity analysis.</P>

<P ALIGN=LEFT><B>INTEREST RATE RISK</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The     Company's
exposure  to changes in interest  rates  relates  primarily  to  long-term  debt
obligations and commercial paper. The Company manages its interest rate exposure
by  limiting  its   variable-rate   debt  to  a  certain   percentage  of  total
capitalization  and by  monitoring  the  effects of market  changes in  interest
rates.  The Company may utilize interest rate derivatives to alter interest rate
exposure in an attempt to reduce  interest rate expense related to existing debt
issues.  Interest  rate  derivatives  are used  solely to modify  interest  rate
exposure and not to modify the overall leverage of the debt portfolio.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;   During   March
2001, the Company entered into two separate  interest rate swap agreements;  (i)
OG&amp;E entered into an interest rate swap agreement to convert $110 million of
7.30 percent fixed rate debt,  due October 15, 2025, to a variable rate based on
the three month London InterBank Offering Rate ("LIBOR") and (ii) effective July
15, 2001,  Enogex  entered into an interest rate swap  agreement to convert $200
million of 8.125  percent  fixed rate debt due,  January 15, 2010, to a variable
rate based on LIBOR. Subsequently,  on April 6, 2001, the Company entered into a
one-year  interest rate swap  agreement to convert $140 million of variable rate
short-term debt, to a fixed rate of 4.41 percent effective April 10, 2001.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The fair value of
long-term  debt is  estimated  based on quoted  market  prices and  management's
estimate of current rates  available  for similar  issues.  The following  table
itemizes  the  Company's  long-term  debt  maturities  and the  weighted-average
interest rates by maturity date.</P>

<PRE>
=========================================================================================================
                                                                                              Fair Value
<I>(dollars in millions)</I>        2001     2002     2003     2004     2005   Thereafter   Total    at 3-31-01
---------------------------------------------------------------------------------------------------------
Fixed rate debt:
  Principal amount.......  $   2.0  $ 115.0  $  14.3  $  57.8  $ 152.9  $ 1,170.9  $ 1,512.9  $  1,563.6
  Weighted-average
    interest rate........    7.15%    7.34%    7.70%    7.20%    7.09%      7.57%      7.34%         ---
Variable-rate debt:
  Principal amount.......      ---      ---      ---      ---      ---  $   135.4  $   135.4  $    135.4
  Weighted-average
    interest rate........      ---      ---      ---      ---      ---      4.25%      4.25%         ---
=========================================================================================================
</PRE>

<P ALIGN=CENTER>10</P><BR>
<PAGE>

<P ALIGN=LEFT><B>COMMODITY PRICE EXPOSURE</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The  market  risk
inherent in the Company's  market risk sensitive  instruments  and positions are
the  potential  loss in value  arising  from  adverse  changes in the  Company's
commodity prices.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The   prices   of
natural gas,  natural gas liquids and  electricity  are subject to  fluctuations
resulting  from  changes in supply and demand.  To  partially  reduce price risk
caused  by these  market  fluctuations,  the  Company  may  hedge  (through  the
utilization  of  derivatives)  a portion of the  Company's  supply  and  related
purchase and sale contracts, as well as any anticipated  transactions (purchases
and  sales).   Because  the  commodities   covered  by  these   derivatives  are
substantially  the same  commodities  that  the  Company  buys and  sells in the
physical  market,  no  special  studies  other  than  monitoring  the  degree of
correlation between the derivative and cash markets are deemed necessary.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;A     sensitivity
analysis has been prepared to estimate the price  exposure to the market risk of
the  Company's  natural  gas,  natural  gas liquids  and  electricity  commodity
positions.  The Company's daily net commodity  position  consists of natural gas
inventories,   purchased  electric   capacity,   commodity  purchase  and  sales
contracts, and derivative financial and commodity instruments. The fair value of
such position is a summation of the fair values calculated for each commodity by
valuing each net position at quoted market  prices.  Market risk is estimated as
the  potential  loss in fair  value  resulting  from a  hypothetical  10 percent
adverse  change in such  prices  over the next 12  months.  The  results of this
analysis,  which may differ  from  actual  results,  are as  follows at March 31,
2001:</P>

<PRE>
                                      Wholesale            Non-Trading
=======================================================================

Commodity market risk, net........    $ 656,000            $        0
=======================================================================
</PRE>

<P ALIGN=LEFT><B>ACCOUNTING CHANGES</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The  adoption  of
SFAS No. 133 on January  1, 2001  resulted  in a  cumulative  effect  transition
adjustment  debit to Accumulated  Other  Comprehensive  Income of  approximately
$26.9 million.  For further  discussion  regarding the adoption of SFAS No. 133,
see Note 3 of Notes to Consolidated Financial Statements.</P><BR>

<P ALIGN=LEFT><B><FONT SIZE=4>REGULATION AND RATES</FONT></B></P><BR>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&amp;E's retail
electric  tariffs in Oklahoma  are  regulated by the OCC, and in Arkansas by the
APSC.  The issuance of certain  securities by OG&amp;E is also  regulated by the
OCC and the APSC.  OG&amp;E's  wholesale electric tariffs,  short-term borrowing
authorization  and accounting  practices are subject to the  jurisdiction of the
FERC.  The Secretary of the Department of Energy has  jurisdiction  over some of
OG&amp;E's facilities and operations.</P>

<P ALIGN=CENTER>11</P>
<PAGE>

<P ALIGN=LEFT><B>Recent Regulatory Matters</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;On   January  12,
2000, the OCC Staff (the "Staff") filed three  applications  to address  various
aspects of  OG&amp;E's  electric  rates.  The first  application  related to the
completion on March 1, 2000, of the recovery of the amortization premium paid by
OG&amp;E when it acquired Enogex in 1986 and the resulting removal,  pursuant to
the  Acquisition  Premium  Credit Rider ("APC  Rider"),  of $12.8 million ($10.7
million  in the  Oklahoma  Jurisdiction)  from the  amount  being  recovered  by
OG&amp;E  from  its  customers  through  currently  authorized  electric  rates.
OG&amp;E  consented  to this action and in March 2000,  the OCC approved the APC
Rider for $10.7 million annually.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The        second
application related to a review of the Generation  Efficiency  Performance Rider
("GEP  Rider"),  which,  as part of the OCC's order issued in 1997 in connection
with OG&amp;E's  last general rate review (the "1997 Order"),  was scheduled for
review in March 2000. OG&amp;E collected  approximately $9.9 million pursuant to
the GEP Rider during  2000.  The GEP Rider  initially  was designed so that when
OG&amp;E's  average  annual cost of fuel per kwh was less than 96.261 percent of
the  average  non-nuclear  fuel  cost per kwh of  certain  other  investor-owned
utilities in the region, OG&amp;E was allowed to collect, through the GEP Rider,
one-third  of the amount by which  OG&amp;E's  average  annual  cost of fuel was
below  96.261  percent  of the  average  of the other  specified  utilities.  If
OG&amp;E's fuel cost exceeded  103.739  percent of the stated average,  OG&amp;E
was not allowed to recover  one-third  of the fuel costs above that average from
Oklahoma  customers.  In April  2000  testimony,  the  Staff  stated  that  they
continued to support incentive programs that reward superior performance, but in
their view the existing  GEP Rider was not  functioning  as they had  originally
envisioned it.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;In June 2000, the
OCC approved the  collection of $6.6 million  through the GEP Rider for the time
period  July 1, 2000  through  June 30, 2001 and  approved  the  following  four
modifications  to the GEP Rider:  (i) changing  OG&amp;E's peer group to include
utilities with a higher coal-to-gas  generation mix; (ii) reducing the amount of
fuel costs that can be recovered if  OG&amp;E's  costs exceed the new peer group
by changing the  percentage  above which OG&amp;E will not be allowed to recover
one-third of the fuel costs from  Oklahoma  customers  from  103.739  percent to
101.0 percent;  (iii) reducing  OG&amp;E's  share of cost savings as compared to
its new peer group from 33 percent to 30  percent;  and (iv)  limiting  to $10.0
million  the amount of any  awards  paid to  OG&amp;E  or  penalties  charged to
OG&amp;E.  The GEP Rider is to  terminate  in June  2002.  However,  the OCC may
establish  a  similar  reward  mechanism  in a  subsequent  action  upon  proper
showing.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The         final
application,  relating to fuel cost recoveries, was used by the Staff to address
the  competitive  bid process of OG&amp;E's gas  transportation  needs following
which Enogex  contracted to provide gas  transportation  service to all OG&amp;E
generating  plants.  For a discussion of the background of the  competitive  bid
process,  see Note 11 of  Notes  to  Consolidated  Financial  Statements  in the
Company's 2000 Form 10-K.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;In   July   2000,
OG&amp;E  entered into a stipulation  (the  "Stipulation")  with the Staff,  the
Office of the Attorney General and a coalition of industrial customers regarding
the  competitive  bid process of  OG&amp;E's  gas  transportation  service.  The
Stipulation  (which,  with one  exception,  was  signed  by all  parties  to the
proceeding)  would permit  OG&amp;E to recover  $25.2  million  annually for gas
transportation  services to be provided  by Enogex  pursuant to the  competitive
bid</P>

<P ALIGN=CENTER>12</P>
<PAGE>

<P>process.  The Stipulation was presented for approval to an Administrative Law
Judge ("ALJ") in September 2000, and the ALJ recommended its approval.  However,
at a  hearing  on  September  28,  2000,  the OCC  chose to delay  the  decision
concerning the Stipulation and two of the three commissioners  expressed concern
over the  competitive  bid process.  OG&amp;E cannot predict what further action
the OCC may take. OG&amp;E continues to believe that the competitive bid process
was  appropriate  and is currently  collecting  $28.5 million on an annual basis
through its base rates and APC Rider for gas transportation services from Enogex
for the power plant requirements covered by the competitive bid.</P>

<P ALIGN=LEFT><B>State Restructuring Initiatives</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;<B>Oklahoma:</B>
&nbsp;&nbsp; As previously reported, Oklahoma enacted in April 1997 the Electric
Restructuring  Act of 1997 (the "Act"),  which is designed to provide for choice
by retail  customers  of their  electric  supplier  by July 1, 2002.  Additional
implementing  legislation  needs to be adopted by the  Oklahoma  Legislature  to
address many specific issues associated with the Act and with  deregulation.  In
May 2000, a bill addressing the specific  issues of  deregulation  was passed in
the  Oklahoma  State  Senate  and then was  defeated  in the  Oklahoma  House of
Representatives.  The Company cannot predict what, if any,  legislation  will be
adopted  during the current  legislative  session,  which ends May 25, 2001. The
Company is participating  actively in the legislative process and, at a minimum,
expects  the  scheduled  start  date for  customer  choice of July 1, 2002 to be
postponed.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;<B>Arkansas:</B>
&nbsp;&nbsp;  In April 1999,  Arkansas became the 18th state to pass a law ("the
Restructuring  Law") calling for  restructuring of the electric utility industry
at the retail  level.  The  Restructuring  Law,  like the  Oklahoma  law,  would
significantly  affect OG&amp;E's future operations.  OG&amp;E's electric service
area  includes   parts  of  western   Arkansas,   including   Fort  Smith,   the
second-largest metropolitan market in the state. The Restructuring Law initially
targeted  customer  choice of  electricity  providers  by January  1,  2002.  In
February 2001, the law was amended to delay the start date of customer choice of
electric  providers  in  Arkansas  until  October 1, 2003,  with the APSC having
discretion to further delay implementation to October 1, 2005. The Restructuring
Law also provides that utilities owning or controlling  transmission assets must
transfer control of such transmission  assets to an independent system operator,
independent  transmission  company or regional  transmission  group, if any such
organization   has  been  approved  by  the  FERC.   Other   provisions  of  the
Restructuring  Law permit  municipal  electric  systems to opt in or out, permit
recovery of stranded costs and transition  costs and require filing of unbundled
rates for generation, transmission,  distribution and customer service. OG&amp;E
filed preliminary business separation plans with the APSC on August 8, 2000. The
APSC has  established a timetable to establish rules  implementing  the Arkansas
restructuring statutes.</P>

<P ALIGN=LEFT><B>National Energy Legislation</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The          Bush
Administration is currently  considering  proposing National Energy Legislation,
which among other things may reform or repeal the Public Utility Holding Company
Act of 1935.  At this  time we  cannot  predict  whether  or in what  form  this
legislation may take place.  Except as set forth above,  there are no changes in
the discussion of National Energy Legislation as contained in the Company's 2000
Form 10-K.</P>

<P ALIGN=CENTER>13</P><BR>
<PAGE>

<P ALIGN=LEFT><B><FONT SIZE=4>REPORT OF BUSINESS SEGMENTS</FONT></B></P><BR>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The     Company's
electric utility operations are conducted through OG&amp;E,  an operating public
utility  engaged  in the  generation,  transmission,  distribution  and  sale of
electric energy. The non-utility operations are conducted through Enogex. Enogex
is engaged in  gathering  and  processing  natural  gas,  producing  natural gas
liquids, transporting natural gas through its pipelines in Oklahoma and Arkansas
for various customers (including OG&amp;E),  marketing electricity,  natural gas
and natural gas liquids and  investing  in the drilling  for and  production  of
crude oil and natural  gas.  The  following is the  Company's  business  segment
results.</P>

<PRE>
========================================================================================================
          Three Months Ended               Electric
            March 31, 2001                  Utility     Non-utility    Intersegment            Total
--------------------------------------------------------------------------------------------------------
<I>(dollars in thousands)</I>

 Operating revenues...................<B>   $   326,835    $   750,537    $   (13,785)   (A)   $ 1,063,587</B>
 Fuel.................................<B>       126,962            ---         (9,079)             117,883</B>
 Purchased power......................<B>        76,969            ---            ---               76,969</B>
 Gas and electricity purchased
   for resale.........................<B>           ---        656,235         (4,706)             651,529</B>
 Natural gas purchases - other........<B>           ---         50,542            ---               50,542</B>
--------------------------------------------------------------------------------------------------------
 Cost of goods sold...................<B>       203,931        706,777        (13,785)             896,923</B>
--------------------------------------------------------------------------------------------------------
 Gross margin on sales................<B>       122,904         43,760            ---              166,664</B>
--------------------------------------------------------------------------------------------------------
 Other operation and maintenance......<B>        71,721         26,369            ---               98,090</B>
 Depreciation and amortization........<B>        30,296         15,028            ---               45,324</B>
 Taxes other than income..............<B>        11,685          4,965            ---               16,650</B>
--------------------------------------------------------------------------------------------------------
 Operating income (expenses)..........<B>         9,202         (2,602)           ---                6,600</B>
--------------------------------------------------------------------------------------------------------
 Other income (expenses)..............<B>          (791)           541            ---                 (250)</B>
--------------------------------------------------------------------------------------------------------
 Earnings before interest and taxes...<B>   $     8,411    $    (2,061)   $       ---          $     6,350</B>
 Net loss.............................<B>   $      (997)   $   (13,972)   $       ---          $   (14,969)</B>
========================================================================================================

(A)  Intersegment  revenues  are  recorded at prices  comparable  to those of
unaffiliated customers and are affected by regulatory considerations.
</PRE>

<P ALIGN=CENTER>14</P><BR>
<PAGE>
<PRE>
========================================================================================================
          Three Months Ended               Electric
            March 31, 2000                  Utility     Non-utility    Intersegment            Total
--------------------------------------------------------------------------------------------------------
<I>(dollars in thousands)</I>

 Operating revenues...................   $   245,332    $   365,114    $   (28,865)   (A)   $   581,581
 Fuel.................................        72,249            ---        (10,249)              62,000
 Purchased power......................        60,542            ---            ---               60,542
 Gas and electricity purchased
   for resale.........................           ---        268,157        (18,616)             249,541
 Natural gas purchases - other........           ---         27,923            ---               27,923
--------------------------------------------------------------------------------------------------------
 Cost of goods sold...................       132,791        296,080        (28,865)             400,006
--------------------------------------------------------------------------------------------------------
 Gross margin on sales................       112,541         69,034            ---              181,575
--------------------------------------------------------------------------------------------------------
 Other operation and maintenance......        65,253         23,099            ---               88,352
 Depreciation and amortization........        30,151         14,768            ---               44,919
 Taxes other than income..............        11,369          4,739            ---               16,108
--------------------------------------------------------------------------------------------------------
 Operating income.....................         5,768         26,428            ---               32,196
--------------------------------------------------------------------------------------------------------
 Other income (expenses)..............          (634)           433            ---                 (201)
--------------------------------------------------------------------------------------------------------
 Earnings before interest and taxes...   $     5,134    $    26,861    $       ---          $    31,995
 Net income (loss)....................   $    (3,226)   $     4,002    $       ---          $       776
========================================================================================================

(A)  Intersegment  revenues  are  recorded at prices  comparable  to those of
unaffiliated customers and are affected by regulatory considerations.
</PRE><BR>

<P ALIGN=LEFT><B><FONT SIZE=4>Item 3  QUANTITATIVE AND QUALITATIVE DISCLOSURES<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;ABOUT
MARKET RISK</FONT></B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;See Item 2,
"Management  Discussion  and  Analysis  of  Financial  Condition  and Results of
Operations - Market Risk".</P>

<P ALIGN=CENTER>15</P><BR>
<PAGE>

<P ALIGN=CENTER><B><FONT SIZE=4>PART II. OTHER INFORMATION</FONT></B></P><BR>

<P ALIGN=LEFT><B><FONT SIZE=4>Item 1 LEGAL PROCEEDINGS</FONT></B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Reference is made
to Item 3 of the  Company's  2000 Form 10-K for a  description  of certain legal
proceedings  presently  pending.  There are no new  significant  cases to report
against the Company or its  subsidiaries  and there have been no notable changes
in the previously reported proceedings, except as set forth below:</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;As   reported  in
the Company's  Form 10-K for the year ended  December 31, 2000,  Trigen-Oklahoma
City Energy  Corporation  ("Trigen") sued OG&amp;E in the United States District
Court, Western District of Oklahoma,  Case No.  CIV-96-1595-M.  On April 3, 2001
the U.S.  Court of Appeals for the Tenth Circuit  issued an order  reversing the
trial  court's  judgment in favor of Trigen and  remanding  the case to the U.S.
District Court with orders to dismiss the case in its entirety. Trigen's request
for  rehearing  before the Tenth  Circuit  was  denied.  In light of the amounts
involved, Trigen  may seek  review  by the  U.S.  Supreme
Court.</P><BR>

<P   ALIGN=LEFT><B><FONT   SIZE=4>Item   6   EXHIBITS   AND   REPORTS   ON  FORM
8-K</FONT></B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)&nbsp;&nbsp;
Exhibits<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;None<BR>
<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(b)&nbsp;&nbsp;
Reports on Form 8-K<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;None</P><BR>

<P ALIGN=CENTER>16</P><BR>
<PAGE>


<P ALIGN=CENTER><B><FONT SIZE=4>SIGNATURES</FONT></B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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.</P><BR>


<P ALIGN=CENTER><B>OGE ENERGY CORP.</B><BR>
(Registrant)</P><BR><BR>


<P ALIGN=CENTER><U>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
By&nbsp;&nbsp;&nbsp;&nbsp;/s/ Donald R. Rowlett&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;</U><BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
Donald R. Rowlett<BR>
&nbsp;&nbsp;Vice President and Controller</P>

<P ALIGN=CENTER>(On behalf of the registrant and in<BR>
his capacity as Chief Accounting Officer)</P>

<P ALIGN=LEFT>May 15, 2001</P><BR>

<P ALIGN=CENTER>17</P>


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