<SUBMISSION>
<ACCESSION-NUMBER>0000074145-01-500018
<TYPE>10-Q
<PUBLIC-DOCUMENT-COUNT>2
<PERIOD>20010930
<FILING-DATE>20011114
<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>1788414
</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>oge10q0901.htm
<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 September 30, 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 77,923,603  Shares of Common  Stock,  par  value
$0.01  per  share,  outstanding  as of October 31, 2001.</FONT></P>


<HR SIZE=3 NOSHADE>

<PAGE>

<H3 ALIGN=CENTER>&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;<U>Page</U></H3>
<P ALIGN=LEFT><B>PART I - FINANCIAL INFORMATION</B><BR>
&nbsp;&nbsp;&nbsp;&nbsp;Item 1. Financial Statements<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Consolidated Statements of Income:<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
Three and Nine Months Ended September 30, 2001&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;2<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Consolidated Balance Sheet&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;3<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Consolidated Statements of Cash Flows&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;4<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Notes to Consolidated Financial Statements
&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;5<BR>
&nbsp;&nbsp;&nbsp;&nbsp;Item 2. Management's Discussion and Analysis of Financial Condition<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
and Results of Operations&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;8</P>

<P ALIGN=LEFT><B>PART II - OTHER INFORMATION</B><BR>
&nbsp;&nbsp;&nbsp;&nbsp;Item 1. Legal Proceedings&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;21<BR>
&nbsp;&nbsp;&nbsp;&nbsp;Item 6. Exhibits and Reports on Form 8-K&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;21<BR>
&nbsp;&nbsp;&nbsp;&nbsp;Signature&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;22</P>

<P ALIGN=CENTER>1</P>
<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 INCOME<BR>
<FONT SIZE=2>(Unaudited)</FONT></B></P>

<PRE>
                                                                        <B>3 Months Ended
                                                                         September 30
                                                              --------------------------------
                                                                   2001              2000</B>
                                                              --------------    --------------
                                                              <I>(thousands except per share data)</I>

OPERATING REVENUES.........................................   $     827,766     $   1,007,966

COST OF GOODS SOLD.........................................         487,842           659,030
                                                              --------------    --------------
  Gross margin on revenues.................................         339,924           348,936
  Other operation and maintenance..........................          91,237            83,181
  Depreciation and amortization............................          44,935            45,487
  Taxes other than income..................................          16,157            15,208
                                                              --------------    --------------
OPERATING INCOME...........................................         187,595           205,060
                                                              --------------    --------------
OTHER INCOME (EXPENSES), net...............................            (277)             (216)
                                                              --------------    --------------
EARNINGS BEFORE INTEREST AND TAXES.........................         187,318           204,844

INTEREST INCOME (EXPENSES):
  Interest income..........................................             741             1,039
  Interest on long-term debt...............................         (24,012)          (25,354)
  Interest on trust preferred securities...................          (4,317)           (4,317)
  Allowance for borrowed funds used during construction....             158               259
  Other interest charges...................................          (3,802)           (3,876)
                                                              --------------    --------------
    Net interest expenses..................................         (31,232)          (32,249)
                                                              --------------    --------------
INCOME BEFORE TAXES........................................         156,086           172,595

INCOME TAX EXPENSE.........................................          59,033            65,288
                                                              --------------    --------------
NET INCOME.................................................   $      97,053     $     107,307
                                                              ==============    ==============
AVERAGE COMMON SHARES OUTSTANDING (thousands)..............          77,923            77,863

EARNINGS PER AVERAGE COMMON SHARE..........................   $        1.25     $        1.38
                                                              ==============    ==============
AVERAGE COMMON SHARES OUTSTANDING
  ASSUMING DILUTION (thousands)............................          77,824            77,863

EARNINGS PER AVERAGE COMMON SHARE
  ASSUMING DILUTION (thousands)............................   $        1.25     $        1.38
                                                              ==============    ==============
DIVIDENDS DECLARED PER SHARE...............................   $      0.3325     $      0.3325

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

<P ALIGN=CENTER><B>CONSOLIDATED STATEMENTS OF INCOME<BR>
<FONT SIZE=2>(Unaudited)</FONT></B></P>

<PRE>
                                                                        <B>9 Months Ended                       6 Months Ended
                                                                         September 30                               June 30
                                                              --------------------------------
                                                                   2001              2000</B>
                                                              --------------    --------------
                                                              <I>(thousands except per share data)</I>

OPERATING REVENUES.........................................   $   2,639,244     $   2,316,452

COST OF GOODS SOLD.........................................       1,908,271         1,562,784
                                                              --------------    --------------
  Gross margin on revenues.................................         730,973           753,668
  Other operation and maintenance..........................         282,769           262,224
  Depreciation and amortization............................         135,181           135,403
  Taxes other than income..................................          49,067            47,039
                                                              --------------    --------------
OPERATING INCOME...........................................         263,956           309,002
                                                              --------------    --------------
OTHER INCOME (EXPENSES), net...............................          (1,058)            4,438
                                                              --------------    --------------
EARNINGS BEFORE INTEREST AND TAXES.........................         262,898           313,440

INTEREST INCOME (EXPENSES):
  Interest income..........................................           3,068             3,244
  Interest on long-term debt...............................         (75,384)          (76,658)
  Interest on trust preferred securities...................         (12,951)          (12,951)
  Allowance for borrowed funds used during construction....             575             1,989
  Other interest charges...................................         (11,020)          (13,021)
                                                              --------------    --------------
    Net interest expenses..................................         (95,712)          (97,397)
                                                              --------------    --------------
INCOME BEFORE TAXES........................................         167,186           216,043

INCOME TAX EXPENSE.........................................          60,308            76,216
                                                              --------------    --------------
NET INCOME.................................................   $     106,878     $     139,827
                                                              ==============    ==============
AVERAGE COMMON SHARES OUTSTANDING (thousands)..............          77,923            77,863

EARNINGS PER AVERAGE COMMON SHARE..........................   $        1.37     $        1.80
                                                              ==============    ==============
AVERAGE COMMON SHARES OUTSTANDING
  ASSUMING DILUTION (thousands)............................          77,845            77,863

EARNINGS PER AVERAGE COMMON SHARE
  ASSUMING DILUTION........................................   $        1.37     $        1.80
                                                              ==============    ==============
DIVIDENDS DECLARED PER SHARE...............................   $      0.9975     $      0.9975

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

<P ALIGN=CENTER>2</P>
<PAGE>

<P ALIGN=CENTER><B>CONSOLIDATED BALANCE SHEETS<BR>
<FONT SIZE=2>(Unaudited)</FONT></B></P>
<PRE>
                                                                      <B>September 30       December 31
                                                                          2001              2000</B>
                                                                     -------------      --------------
                                                                          <I>(dollars in thousands)</I>
<B>ASSETS</B>
CURRENT ASSETS:
  Cash and cash equivalents.....................................     $        559       $         454
  Accounts receivable - customers, less reserve of $7,184 and
    $4,135, respectively........................................          277,381             446,185
  Accrued unbilled revenues.....................................           51,300              49,000
  Accounts receivable - other, less reserve of $874 and
    $2,545, respectively........................................           18,684              24,713
  Fuel inventories..............................................           78,257             200,316
  Materials and supplies, at average cost.......................           39,618              41,517
  Prepayments and other.........................................            7,984              45,715
  Price risk management.........................................           25,696              45,727
  Accumulated deferred tax assets...............................           10,435              10,669
                                                                     -------------      --------------
    Total current assets........................................          509,914             864,296
                                                                     -------------      --------------
OTHER PROPERTY AND INVESTMENTS, at cost.........................           40,058              36,980
                                                                     -------------      --------------
PROPERTY, PLANT AND EQUIPMENT:
  In service....................................................        5,447,653           5,323,541
  Construction work in progress.................................           77,143              47,016
                                                                     -------------      --------------
    Total property, plant and equipment.........................        5,524,796           5,370,557
      Less accumulated depreciation.............................        2,258,084           2,151,093
                                                                     -------------      --------------
    Net property, plant and equipment...........................        3,266,712           3,219,464
                                                                     -------------      --------------
DEFERRED CHARGES:
  Advance payments for gas......................................           12,500              12,500
  Income taxes recoverable through future rates.................           37,875              38,654
  Price risk management.........................................           21,848               5,668
  Other.........................................................           96,648             142,068
                                                                     -------------      --------------
    Total deferred charges......................................          168,871             198,890
                                                                     -------------      --------------
TOTAL ASSETS....................................................     $  3,985,555       $   4,319,630
                                                                     =============      ==============

<B>LIABILITIES AND STOCKHOLDERS' EQUITY</B>
CURRENT LIABILITIES:
  Short-term debt...............................................     $    125,512       $     284,500
  Accounts payable..............................................          132,844             330,445
  Dividends payable.............................................           25,910              25,890
  Customers' deposits...........................................           27,017              22,647
  Accrued taxes.................................................           78,772              33,067
  Accrued interest..............................................           30,545              40,699
  Long-term debt due within one year............................          115,000               2,000
  Price risk management.........................................           12,897              33,709
  Other.........................................................           44,342              36,975
                                                                     -------------      --------------
    Total current liabilities...................................          592,839             809,932
                                                                     -------------      --------------
LONG-TERM DEBT..................................................        1,538,139           1,648,523
                                                                     -------------      --------------
DEFERRED CREDITS AND OTHER LIABILITIES:
  Accrued pension and benefit obligation........................            6,271              14,256
  Accumulated deferred income taxes.............................          641,240             618,360
  Accumulated deferred investment tax credits...................           53,566              57,429
  Price risk management.........................................            3,080               3,001
  Other.........................................................           58,142             103,821
                                                                     -------------      --------------
    Total deferred credits and other liabilities................          762,299             796,867
                                                                     -------------      --------------
STOCKHOLDERS' EQUITY:
  Common stockholders' equity...................................          443,202             443,298
  Retained earnings.............................................          650,140             621,010
  Accumulated other comprehensive income........................           (1,064)                  -
                                                                     -------------      --------------
    Total stockholders' equity..................................        1,092,278           1,064,308
                                                                     -------------      --------------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY......................     $  3,985,555       $   4,319,630
                                                                     =============      ==============

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

<P ALIGN=CENTER>3</P>
<PAGE>
<P ALIGN=CENTER><B>CONSOLIDATED STATEMENTS OF<BR>
CASH FLOWS<BR>
<FONT SIZE=2>(Unaudited)</FONT></B></P>
<PRE>                                                                                  <B>9 Months Ended
                                                                                   September 30
                                                                             2001               2000</B>
                                                                        --------------     --------------
                                                                             <I>(dollars in thousands)</I>
CASH FLOWS FROM OPERATING ACTIVITIES:
  Net Income.........................................................   $     106,878      $     139,827
  Adjustments to Reconcile Net Income to Net
   Cash Provided from Operating Activities:
    Depreciation and amortization....................................         135,181            135,403
    Deferred income taxes and investment tax credits, net............          21,126             37,086
    Gain on sale of assets...........................................            (293)            (4,850)
    Change in Certain Assets and Liabilities:
      Accounts receivable - customers................................         168,804           (103,069)
      Accrued unbilled revenues......................................          (2,300)           (15,400)
      Fuel, materials and supplies inventories.......................         123,958            (40,296)
      Other current assets...........................................          44,437            (28,436)
      Accounts payable...............................................        (197,601)            99,370
      Accrued taxes..................................................          45,705             43,497
      Accrued interest...............................................         (10,154)               501
      Other current liabilities......................................          11,757              6,118
    Other operating activities.......................................         (20,705)             3,729
                                                                        --------------     --------------
        Net cash provided from operating activities..................         426,793            273,480
                                                                        --------------     --------------
CASH FLOWS FROM INVESTING ACTIVITIES:
  Capital expenditures...............................................        (182,177)          (137,866)
  Proceeds from sale of assets.......................................           1,263             15,859
  Other investing activities.........................................             277                402
                                                                        --------------     --------------
        Net cash used in investing activities........................        (180,637)          (121,605)
                                                                        --------------     --------------
CASH FLOWS FROM FINANCING ACTIVITIES:
  Retirement of long-term debt.......................................         (10,390)           (58,000)
  Proceeds from long-term debt.......................................               -            400,000
  Decrease in short-term debt, net...................................        (158,988)          (419,000)
  Retirement of common stock.........................................             (96)                 -
  Contribution from minority interest................................           1,449                  -
  Payment of obligation under capital lease..........................            (279)                 -
  Cash dividends declared on common stock............................         (77,747)           (77,667)
                                                                        --------------     --------------
        Net cash used in financing activities........................        (246,051)          (154,667)
                                                                        --------------     --------------
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS.................             105             (2,792)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD.....................             454              7,271
                                                                        --------------     --------------
CASH AND CASH EQUIVALENTS AT END OF PERIOD...........................   $         559      $       4,479
                                                                        ==============     ==============
---------------------------------------------------------------------------------------------------------
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
  CASH PAID DURING THE PERIOD FOR:
    Interest (net of amount capitalized).............................   $      95,562      $      88,441
    Income taxes.....................................................   $       5,991      $       7,680
---------------------------------------------------------------------------------------------------------
NON-CASH INVESTING AND FINANCING ACTIVITIES:
    Interest rate swap...............................................   $     (12,848)     $           -
    Change in fair value of long-term debt...........................   $      12,848      $           -
    Other investing and financing activities.........................   $           -      $       2,400
---------------------------------------------------------------------------------------------------------
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></PRE>
<P ALIGN=CENTER>4</P>
<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 accounting  principles
     generally  accepted  in the United  States 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 September
     30, 2001,  and  December&#160;31,&#160;2000,  and the results of operations
     and   the    changes    in   cash    flows    for   the    periods    ended
     September&#160;30,&#160;2001,  and September&#160;30,&#160;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&#160;31,&#160;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> 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,
     Enogex 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,  Enogex
     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.<BR><BR>

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

<LI> Effective  January 1, 2001,  the Company  adopted  Statement  of  Financial
     Accounting  Standards  (&#147;SFAS&#148;)  No.  133,  &#147;Accounting  for
     Derivative  Instruments  and Hedging  Activities&#148;,  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.  Changes 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 are deemed to be normal  purchases or normal sales are not  accounted
     for as derivatives.  However, 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.<BR><BR>

     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  $26.9 million ($16.5 million
     net of tax).  This  unrealized loss is related to the derivative fair value
     of  qualifying  cash flow  hedges as of the date of  adoption  and is being
     amortized to earnings as the related hedged transactions occur.<BR><BR>

     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
     (&#147;LIBOR&#148;)  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.
     The objective of these  interest rate swaps was to raise the  percentage of
     total corporate  floating rate debt more in line with industry standard and
     to achieve a lower cost of debt.  These  interest  rate swaps  qualified as
     fair  value  hedges  under  SFAS No.  133 and meet all  requirements  for a
     determination  that there was no  ineffective  portion as allowed under the
     shortcut method under SFAS No. 133.<BR><BR>

     On April 6, 2001,  the Company  entered into a one-year  interest rate swap
     agreement  to lock in a fixed  rate of 4.41  percent,  effective  April 10,
     2001, on $140 million of variable rate  short-term  debt.  The objective of
     this interest rate swap was to reduce exposure to short-term  interest rate
     volatility  associated with the  Company&#146;s  commercial  paper program.
     This interest rate swap initially qualified for hedge accounting  treatment
     as a cash flow hedge under SFAS No. 133. However, due to unexpected changes
     in the level of  commercial  paper issued during the third  quarter,  hedge
     accounting  treatment  under  SFAS No. 133 was  discontinued  as of July 1,
     2001, and all subsequent  changes in the market value of the swap are being
     recorded   in   earnings   as   required   by   SFAS   No.   133.   As   of
     September&#160;30,&#160;2001,  a total of  approximately  $930,000 has been
     recorded in earnings. This amount represents the change in the market value
     of the swap since July 1, 2001.<BR><BR>

     As of  September  30,  2001,  a  deferred  loss of  approximately  $325,000
     ($198,000  net of tax),  was recorded in  Accumulated  Other  Comprehensive
     Income which represents the unamortized balance of the effective portion of
     the interest rate swap as of June 30, 2001.  Approximately  $161,000 of the
     unamortized  balance was amortized in the third quarter,  and

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

     will continue to be amortized  over the remaining life of the original term
     of the swap, which was set to expire on April 10, 2002.<BR><BR>

     The Company  recorded a gain,  related to the ineffective  portion of hedge
     derivatives,  for production  hedges,  of $4.7 million ($2.9 million net of
     tax) for the nine months ended September&#160;30,&#160;2001.<BR><BR>

     As of September 30, 2001, a deferred loss of $1.3 million ($0.9 million net
     of  tax),  related  to an  effective  cash  flow  hedge 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
     quarter of 2001, as the hedged natural gas production is sold.<BR><BR>

<LI> In  accordance  with SFAS No.  130,  Reporting  Comprehensive  Income,  the
     following are components of Other Comprehensive Income:<BR><BR>
<PRE>
                                                                       9 Months Ended
                                                                        September 30
                                                                 <B>2001</B>                 2000
                                                           -----------------    -----------------
                                                                  <I>(dollars in thousands)</I>

Net income..............................................   $        106,878     $        139,827
                                                           -----------------    -----------------
Other comprehensive income (loss), net of tax:
  Transition adjustment.................................            (16,492)                   -
  Gain on qualifying cash flow hedging instruments......             15,987                    -
  Reclassification adjustments - contract settlements...               (559)                   -
                                                           -----------------    -----------------
Total other comprehensive (loss), net of tax............             (1,064)                   -
                                                           -----------------    -----------------
Total comprehensive income..............................   $        105,814     $        139,827
                                                           =================    =================
</PRE>

<LI> In June 2001, the Financial Accounting  Standards Board  (&#147;FASB&#148;)
     issued   SFAS   No.   143,    &#147;Accounting    for   Asset    Retirement
     Obligations&#148;.  SFAS No.  143 will  affect the  Company&#146;s  accrued
     plant removal costs for generation, transmission,  distribution and oil and
     gas  production  facilities  and will  require  that  the  fair  value of a
     liability for an asset retirement obligation be recognized in the period in
     which it is incurred if a reasonable estimate of fair value can be made. If
     a reasonable  estimate of fair value cannot be made in the period the asset
     retirement is incurred, the liability shall be recognized when a reasonable
     estimate of fair value can be made. The associated  asset  retirement costs
     are  capitalized as part of the carrying  amount of the  long-lived  asset.
     Adoption of SFAS No. 143 is required for financial  statements  for periods
     beginning  after June 15,  2002.  The Company  will adopt this new standard
     effective January&#160;1,&#160;2003. Management has not yet determined what
     the  impact  of this new  standard  will be on its  consolidated  financial
     position or results of operation.<BR><BR>

<LI> In August  2001,  the FASB issued SFAS No.  144,  &#147;Accounting  for the
     Impairment  or Disposal of Long-Lived  Assets&#148;.  SFAS No. 144 requires
     that an  impairment  loss be  recognized  only if the carrying  amount of a
     long-lived asset is not recoverable  from its  undiscounted  cash flows and
     that the measurement of any impairment  loss be the difference<BR><BR>

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

     between the carrying  amount and fair value of the asset.  Adoption of SFAS
     No. 144 is required for financial  statements for periods  beginning  after
     December  15,  2001.  The Company  will adopt this new  standard  effective
     January 1, 2002, and management  believes the adoption of this new standard
     will not have a material impact on its consolidated  financial  position or
     results of operation.</OL><BR>



<P ALIGN=LEFT><B><FONT SIZE=4>Item 2  MANAGEMENT'S  DISCUSSION AND ANALYSIS OF
FINANCIAL<BR>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;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 and nine months ended September 30, 2001 (respectively,
the "current periods"),  and the financial position as of September 30, 2001, of
the  Company  and  its  subsidiaries:  OG&amp;E  and  Enogex.  Unless  indicated
otherwise, all comparisons are with the corresponding periods of the prior year.
The table below shows the earnings contributions  of OG&amp;E and Enogex for the
period indicated. All references to earnings per share are to earnings per share
of the Company's Common Stock.</P>
<PRE>
                                              3 Months Ended                 9 Months Ended
                                               September 30                   September 30
                                       --------------------------     ---------------------------
                                           <B>2001</B>          2000             <B>2001</B>           2000
                                       ------------  ------------     ------------   ------------
                                                       <I>(dollars in thousands)</I>

OG&amp;E.................................  $      1.29   $      1.38      $      1.63    $      1.72
Enogex...............................            -          0.06            (0.13)          0.23
Holding company (stand-alone basis)..        (0.04)        (0.06)           (0.13)         (0.15)
                                       ------------  ------------     ------------   ------------
  Consolidated Earnings per Share....  $      1.25   $      1.38      $      1.37    $      1.80
                                       ============  ============     ============   ============
</PRE>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The decrease in
OG&amp;E's  contribution  to  earnings  per  share  in the  current  period  was
primarily attributable to milder weather and increased operation and maintenance
expenses.  Of the $0.06 and $0.36 decreases in Enogex's contribution to earnings
per  share  for  the  current  periods,   approximately  $0.10  and  $0.46  were
attributable  to poorer  margins in Enogex's gas processing  business.  The last
component  of earnings per share are the results on a  stand-alone  basis of the
Company (i.e., a holding company) which has expenses but no revenues,  and which
posted a loss of $0.04 and $0.13 for the  current  periods,  which  reflects  an
increase of $0.02 each period as compared to results in 2000.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;For  the  current
three and nine months  periods,  approximately  39 percent and 55 percent of the
Company's revenues consisted of the non-utility  operations of Enogex, while the
remaining  61 percent and 45 percent  was  provided  by the  regulated  sales of
electricity by OG&amp;E,  a public  utility.  Revenues from sales of electricity
are  somewhat  seasonal,  with a large  portion of</P>

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

<P>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.  In September  2001, the director of the Oklahoma
Corporation  Commission's  ("OCC") public utility  division filed an application
with the OCC to review the rates of OG&amp;E. See "Regulation and Rates - Recent
Regulatory Matters" for a further discussion of this matter. Deregulation of the
electric  industry  in Oklahoma  has been  postponed  until at least  2003.  See
"Regulation and Rates - Recent Regulatory Matters" for a related discussion.</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 "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;Net income
decreased  $10.3 million or 9.6 percent in the three months ended  September 30,
2001. Of the $10.3 million decrease, approximately $7.2 million was attributable
to OG&amp;E and $4.6 million was  attributable  to Enogex.  These decreases were
partially  offset by  decreased  losses of  approximately  $1.5  million  at the
holding  company.  OG&amp;E's  decrease in earnings  for the three  months ended
September 30, 2001, was primarily  attributable  to milder weather and increased
operation and maintenance  expenses.  The decrease in earnings at Enogex for the
three months ended  September  30, 2001,  was primarily  attributable  to poorer
margins  in the gas  processing  business,  a loss in the energy  marketing  and
trading  business  and to a  one-time  cost  adjustment  stemming  from the 1999
Transok  acquisition.  The decreased losses at the holding company resulted from
decreased other operation and maintenance costs.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;For    the   nine
months ended  September  30, 2001,  net income  decreased  $32.9 million or 23.6
percent.  Of  the  $32.9  million  decrease,  approximately  $27.7  million  was
attributable  to Enogex.  The  decline in  earnings  at Enogex was  attributable
primarily to poor fractionation spreads.  Fractionation spreads are the value of
liquids after they are  processed  out of natural gas,  compared to the price of
the gas itself.  During parts of the first  quarter of 2001,  these spreads were
actually  negative.  Also, in the current periods and,  particularly  during the
first  quarter of 2001,  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</P>

<P ALIGN=CENTER>9</P>

<P>March  1,  2001,  subject to refund.  The impact of this  filing was  minimal
during the first quarter of 2001,  but enabled Enogex to  significantly  improve
recovery of pipeline  system fuel  expenses  during the second  quarter.  Enogex
earnings also were adversely  affected by lower margins in its energy  marketing
and  trading  business  compared  to the  prior  period.  Earnings  at  OG&amp;E
decreased  $6.5 million in the nine months ended  September 30, 2001,  primarily
due to milder weather and increased operation and maintenance expenses.</P>

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

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The  Company  has
revised its  previously  projected  2001 earnings to $1.45 to $1.50 a share from
$1.70 to $1.80,  based on nine-month  actual  results and  expectations  for the
fourth quarter.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The       Company
currently  expects  2002  earnings  to fall within a range of $1.80 to $2.00 per
share.  Achievement of these earnings goals assumes,  among other things, normal
weather at the utility, an expected return to a more stable price environment in
natural gas processing, the addition of new natural gas transportation contracts
at Enogex and lower interest expenses.</P>

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

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total   operating
revenues  decreased  $180.2  million or 17.9  percent in the three  months ended
September 30, 2001 and increased $322.8 or 13.9 percent in the nine months ended
September 30, 2001.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&amp;E's
revenues  decreased  $20.9  million  or 3.9  percent in the three  months  ended
September  30,  2001,  and  increased  $84.6  million or 7.6 percent in the nine
months  ended  September  30,  2001.  The  decrease  in the three  months  ended
September 30, 2001, was primarily  attributable to milder weather (approximately
a 6.6 percent decrease in the cooling degree days as compared to the same period
in 2000),  resulting in a 1.2 percent  decrease in electricity  sales to Company
customers  ("system sales"),  and a 2.9 percent decrease in electricity sales to
other utilities and power marketers ("off-system sales").</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The  increase  in
OG&amp;E's  operating  revenues  for the nine months ended  September  30, 2001,
resulted  primarily from the recovery of higher fuel costs.  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
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  OCC,  the  Arkansas  Public  Service
Commission  ("APSC")  and  the  FERC.  See  "Regulation  and  Rates."  Partially
offsetting the increased  recoveries  under the fuel  adjustment  clauses in the
nine months  ended  September  30, 2001,  were  decreased  recoveries  under the
Generation  Efficiency  Performance  Rider ("GEP  Rider") of $3.4  million,  the
Acquisition  Premium  Credit Rider ("APC  Rider") of $2.0  million,  and the Gas
Transportation  Adjustment  Credit Rider  ("GTAC  Rider") of $0.9  million.  See
"Regulation and Rates - Recent Regulatory Matters" for a related discussion.  In
the nine months ended September 30, 2001, system sales increased 0.2 percent and
off-system sales increased 3.5 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=CENTER>10</P>
<PAGE>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Enogex revenues,
after eliminating  intercompany  transactions,  decreased $159.3 million or 33.3
percent in the three  months ended  September  30,  2001.  Approximately  $151.9
million of the decrease was due to lower  revenues  from natural gas sales.  The
primary  driver  of this  reduction  was a 60.7  percent  decline  in the  price
recovered   per  MMBTU.   Approximately   $13.5  million  of  the  decrease  was
attributable  to the gas processing  business,  which  experienced a 4.6 percent
decrease in the volume of natural gas liquids sold and a 10.9  percent  decrease
in liquids  prices.  Partially  offsetting  these  decreases  were revenues from
gathering  and  transmitting  natural gas which  increased  $6.5 million or 28.8
percent.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Enogex  revenues,
after eliminating  intercompany  transactions,  increased $238.2 million or 19.7
percent in the nine months ended September 30, 2001. This increase was primarily
attributable  to increased  natural gas sales of  approximately  $238.9 million.
Revenues from power marketing activities  increased  approximately $17.3 million
or 49.3 percent resulting from a 58.4 percent increase in the number of megawatt
hours sold.  Revenues for  gathering and  transmission  of natural gas increased
$14.7 million or 22.7 percent.  This increase was primarily  driven by increased
volume transported.  Gas storage services contributed approximately $2.7 million
to the increase in revenues.  These revenues  resulted from marketing,  on a fee
basis, a portion of Enogex's storage capacity to its partners in 2001.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Offsetting  these
increases  was a $35.8  million  decrease  in  natural  gas liquid  sales.  This
decrease was primarily due to a 13.6 percent decrease in volumes sold.</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,
decreased $177.5 million or 26.7 percent in the three months ended September 30,
2001 and  increased  $339.2  million or 21.6  percent in the nine  months  ended
September  30,  2001.  The  specific  components  of cost of goods  sold for the
reported periods are as follows:</P>
<PRE>
                                                    3 Months Ended                 9 Months Ended
                                                     September 30                   September 30
                                             --------------------------     ---------------------------
                                                 <B>2001</B>          2000             <B>2001</B>           2000
                                             ------------  ------------     ------------   ------------
                                                             <I>(dollars in thousands)</I>

Fuel.......................................  $   145,993   $   161,713      $   374,230    $   321,643
Purchased Power............................       70,595        68,644          218,000        191,309
Gas and electricity purchased for resale...      244,407       363,377        1,187,008        928,447)
Natural gas purchases - other..............       26,847        65,296          129,033        121,385
                                             ------------  ------------     ------------   ------------
  Total cost of goods sold.................  $   487,842   $   659,030      $ 1,908,271    $ 1,562,784
                                             ============  ============     ============   ============
</PRE>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&amp;E's   fuel
expense  decreased  $15.7  million  or 9.7  percent  in the three  months  ended
September 30, 2001, primarily due to decreased generation levels associated with
milder weather.  OG&amp;E's fuel expense increased $52.6 million or 16.3 percent
in the nine months ended  September  30, 2001,  primarily  due to a  significant
increase in the average cost of fuel (particularly  natural gas during the first
quarter of 2001).</P>

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

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&amp;E
increased its  purchased  power by $2.0 million or 2.8 percent and $26.7 million
or 14.0 percent in the current periods. These increases were primarily due to an
increase in capacity purchases under a wholesale purchase contract that OG&amp;E
maintains  with  Southwestern  Public  Service  Corp.  and the  availability  of
wholesale electricity at favorable prices.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Enogex's  natural
gas and  electricity  purchased  for  resale  decreased  $119.0  million or 32.7
percent in the three  months  ended  September  30,  2001,  due  primarily  to a
decrease in price of natural gas purchased for resale to third parties.  For the
nine months ended  September  30,  2001,  Enogex's  natural gas and  electricity
purchased for resale increased $258.6 million or 27.8 percent due to an increase
in the volumes of natural gas purchased for resale to third  parties,  primarily
attributable to increased sales activity by Enogex's energy  marketing  business
in the first quarter of 2001.</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  and, to a lesser extent,  pipeline  system fuel expenses and pipeline
compressor  fuel expense,  decreased  $38.5 million or 58.9 percent in the three
months ended September 30, 2001,  primarily  attributable to lower fuel expense.
In the nine months ended  September  30, 2001  Enogex's  natural gas purchases -
other  increased  $7.6  million or 6.3  percent  due to the  increased  price of
natural gas.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other   operation
and  maintenance  increased $8.1 million or 9.7 percent and $20.5 million or 7.8
percent in the current periods  primarily due to increased  employee pension and
benefit costs, outside services and increased bad debt expense.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Interest  charges
decreased  $1.0 million or 3.2 percent in the three months ended  September  30,
2001,  primarily  due to a decrease in long-term  debt. In the nine months ended
September  30,  2001,  interest  charges  decreased  $1.7 million or 1.7 percent
primarily due to a decrease in short-term debt and lower interest rates.</P>

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

<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  meets its cash needs  through a  combination  of  internally  generated
funds, short-term borrowings and permanent financing.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;For the nine
months ended September 30, 2001, the Company satisfied its capital  expenditures
of $182.1 million through internally generated funds and short-term  borrowings.
The Company expects that internally  generated funds will be adequate during the
remainder of 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 lines of credit for up to
$315 million,  of which $200 million  expires on January 15, 2002,  $100 million
expires on January 15,  2004,  and $15  million  expires on June 28,  2002.  The
Company   expects  to  replace  these  lines  of  credit  on  or  prior  to  the
expiration.</P>

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

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The Company's
capital  structure and cash flow remained strong throughout the current periods.
The  Company's  combined  cash  and  cash  equivalents  increased  approximately
$105,000 during the nine months ended September 30, 2001. The increase  reflects
the  Company's  cash  flow  from  operations,  net of  cash  used  in  investing
activities,   retirement  of  long-term  debt  and  common  stock,  payments  of
short-term  debt,  capital  lease and cash  dividends.  Variations  in  accounts
receivable  and fuel  inventories  reflect the seasonal  nature of the Company's
utility business.</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  discussion  of  significant  contingencies  that could
affect the Company,  reference is made to Part II, Item 1 - "Legal  Proceedings"
of this Form 10-Q,  to Part II, Item 1 - "Legal  Proceedings"  in the  Company's
Form 10-Q for the  quarters  ended  March  31,  2001 and June 30,  2001,  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=LEFT><B>MARKET RISK</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 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. The objective of
these interest rate swaps was to raise the percentage of total</P>

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

<P>  corporate  floating  rate debt more in line with  industry  standard and to
achieve a lower cost of debt.  These interest rate swaps qualified as fair value
hedges under SFAS No. 133 and meet all  requirements  for a  determination  that
there was no ineffective portion as allowed under the shortcut method under SFAS
No. 133.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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. The objective of this interest rate swap was to reduce
exposure to short-term  interest rate  volatility  associated with the Company's
commercial paper program.  This interest rate swap initially qualified for hedge
accounting  treatment as a cash flow hedge under SFAS No. 133.  However,  due to
unexpected  changes in the level of  commercial  paper  issued  during the third
quarter,  hedge  accounting  treatment under SFAS No. 133 was discontinued as of
July 1, 2001,  and all  subsequent  changes in the market  value of the swap are
being recorded through earnings as required by SFAS No. 133. As of September 30,
2001,  a total of  approximately  $930,000 has been  recorded in earnings.  This
amount  represents  the  change in the  market  value of the swap  since July 1,
2001.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;As  of  September
30, 2001, a deferred loss of approximately  $325,000  ($198,000 net of tax), was
recorded  in  Accumulated  Other  Comprehensive   Income  which  represents  the
unamortized  balance of the  effective  portion of the interest  rate swap as of
June 30, 2001.  Approximately  $161,000 of the unamortized balance was amortized
in the third quarter,  and will continue to be amortized over the remaining life
of the original term of the swap, which was set to expire on April 10, 2002.</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 9-30-01
---------------------------------------------------------------------------------------------------
Fixed rate debt:
  Principal amount....... $  1.0  $115.0  $ 14.3  $ 53.0  $153.0  $    861.3  $1,197.6  $  1,281.0
  Weighted-average
    interest rate........  7.15%   7.34%   7.70%   7.22%   7.09%       7.48%     7.33%           -
Variable-rate debt:
  Principal amount.......      -       -       -       -       -  $    458.2  $  458.2  $    458.2
  Weighted-average
    interest rate........      -       -       -       -       -       4.99%     4.99%           -
===================================================================================================
</PRE>

<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&#146;s  market risk sensitive  instruments and positions
are  the  potential   loss  in  value  arising  from  adverse   changes  in  the
Company&#146;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</P>

<P ALIGN=CENTER>14</P>
<PAGE>

<P> market  fluctuations,  the Company may hedge  (through  the  utilization  of
derivatives)  a portion of the  Company&#146;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 September 30,
2001:</P>
<PRE>
                                       Wholesale               Non-Trading
--------------------------------------------------------------------------------
Commodity market risk, net......        $78,957                   $ 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 ($16.5 million net of tax). For further  discussion  regarding the
adoption  of SFAS  No.  133,  see  Note 4 of  Notes  to  Consolidated  Financial
Statements.</P>

<P ALIGN=LEFT><B>REGULATION AND RATES</B></P>

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

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;As     previously
reported,  the OCC Staff ("Staff")  annually conducts a review ("Matrix Review")
to assess utility operations.  The purpose of the Matrix Review is to enable the
Staff  to  specifically  identify  regulated  utilities  that  have  experienced
material  or  significant  changes  in  operating  characteristics,  or  in  the
underlying  cost of service,  as a means of  evaluating  the need to pursue rate
hearings.  The Staff also uses the Matrix Review to identify regulated utilities
that require a Staff review of some specific  operational  activity conducted by
the utility.  The Matrix Review is composed of 11 indicators  that are the basic
guide for the Staff's initial review of a regulated  utility.  The 11 indicators
include such items as the time from a utility's last rate review</P>

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

<P> and service  quality  complaints.  Each  indicator  is given a rating by the
Staff from zero to three. A rating of zero is considered not relevant,  a rating
of one is considered slightly relevant, a rating of two is considered moderately
relevant,  while a rating of three is  considered  significantly  relevant.  The
Staff believes that an aggregate  rating of less than ten and with no individual
indicator  receiving  a  rating  of  three,  should  indicate  that  no  further
assessment  is  required.  Any rating above these levels could result in a Staff
recommendation  requesting  that a further  review should be performed.  In July
2001,  the OCC held a hearing  at which the Staff  reported  the  results of its
Matrix Review of OG&amp;E.  The review  resulted in an aggregate score of 17 for
OG&amp;E,  with  only one  indicator  "Time  since  last  formal  rate  review",
achieving  a rating of three.  OG&amp;E's  last  formal rate review by the Staff
occurred in 1995. As part of its written report,  the Staff  recommended  that a
general rate review be performed on OG&amp;E.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;In September
2001, the director of the OCC public utility  division filed an application with
the OCC to review the rates of OG&amp;E.  In the filing, the Staff requests that
OG&amp;E submit information in accordance with OCC standard filing  requirements
by January 28, 2002,  for a test year ending  September  30, 2001. At this time,
management  cannot  predict the outcome of this rate review or the impact on its
consolidated financial position or results of operation.  Hearing's in this case
are expected to commence in July 2002.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;As previously
reported,  certain  aspects of  OG&amp;E's  electric  rates  recently  have been
addressed by the OCC. In March 2000, the OCC approved, and OG&amp;E implemented,
the APC Rider  reflecting  the  completion  of the recovery of the  amortization
premium paid by OG&amp;E when it acquired  Enogex in 1986. The effect of the APC
Rider is to remove $10.7  million  annually  from the amount being  recovered by
OG&amp;E from its Oklahoma customers in current rates.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;In June 2000, the
OCC  approved   modifications  to  OG&amp;E's  GEP  Rider.  The  GEP  Rider  was
established  initially in 1997 in connection  with  OG&amp;E's last general rate
review and was  intended  to  encourage  OG&amp;E to lower its fuel costs by (i)
allowing OG&amp;E to collect one-third of the amount by which its fuel costs was
below a specified  percentage  (96.261%)  of the  average  fuel costs of certain
other investor-owned utilities in the region and (ii) disallowing the collection
of  one-third  of the  amount  by which  its fuel  costs  exceeded  a  specified
percentage  (103.739%)  of  the  average  fuel  costs  of  other  investor-owned
utilities. The modifications enacted in June 2000 had the effect of reducing the
amount  OG&amp;E  could recover under the GEP Rider,  and for the period between
July 1, 2001 and June 30, 2002, the Company  estimates that it will recover $5.1
million under the GEP Rider.  The GEP Rider is scheduled to expire in June 2002,
however,  the OCC could  decide to  establish a similar  reward  mechanism  in a
subsequent  action upon proper showing.  For a more detailed  explanation of the
GEP Rider see the Company's 2000 Form 10-K.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;The  final action
addresses the  competitive  bid process of OG&amp;E's gas  transportation  needs
following  which  OG&amp;E's  affiliate,   Enogex,  contracted  to  provide  gas
transportation  service to all of OG&amp;E's generation plants. For a discussion
of the  background  of the  competitive  bid  process,  see  Note 11 of Notes to
Financial Statements in the Company's 2000 Form 10-K.</P>

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

<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
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.</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;In June 2001, the
Staff approved the  Stipulation  declaring the  Stipulation to be fair, just and
reasonable and  representing  a reasonable  settlement of the issues and thereby
serving the public interest.  OG&amp;E had previously collected $28.5 million on
an annual  basis  through  its base  rate and APC  Rider for gas  transportation
services from Enogex for the power plant requirements covered by the competitive
bid. The Stipulation  permits OG&amp;E to recover $25.2 million annually for the
gas transportation services provided by Enogex. The Stipulation directs OG&amp;E
to reduce rates to its Oklahoma retail customers by  approximately  $2.7 million
per year through the  implementation of a GTAC Rider. The GTAC Rider is a credit
for gas  transportation  cost  recovery and is applicable to and becomes part of
each Oklahoma  retail rate  schedule to which  OG&amp;E's  Fuel Cost  Adjustment
rider applies.  The GTAC Rider became  effective with the first billing cycle of
July 2001,  and will remain in effect until amended by OG&amp;E at the direction
of the OCC.</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.  In May 2001, the Oklahoma  Legislature  passed Senate Bill 440
("SB 440"), which postponed the scheduled start date for customer choice of July
1, 2002 until at least 2003.  In addition to  postponing  the date for  customer
choice,  the SB 440 calls for a  nine-member  task  force to  further  study the
issues  surrounding  deregulation.  The task force  includes the Governor or his
designee,  the Attorney General, the Oklahoma  Corporation  Commission Chair and
several  legislative  leaders,  among  others.  The  Company  will  continue  to
participate  actively  in the  legislative  process  and  expects  to  remain  a
competitive  supplier of  electricity.  The Company cannot predict what, if any,
legislation will be adopted at the next legislative session.</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,  will
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</P>

<P ALIGN=CENTER>17</P>
<PAGE>

<P> 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>REPORT OF BUSINESS SEGMENTS</B></P>

<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 for the three and nine months ended September 30, 2001 and September 30,
2000.</P>

<PRE>
========================================================================================================
          Three Months Ended               Electric
          September 30, 2001                Utility     Non-utility    Intersegment            Total
--------------------------------------------------------------------------------------------------------
<I>(dollars in thousands)</I>

 Operating revenues...................   $   508,142    $   328,933    $    (9,309)   (A)   $   827,766
 Fuel.................................       155,072              -         (9,079)             145,993
 Purchased power......................        70,595              -              -               70,595
 Gas and electricity purchased
   for resale.........................             -        244,637           (230)             244,407
 Natural gas purchases - other........             -         26,847              -               26,847
--------------------------------------------------------------------------------------------------------
 Cost of goods sold...................       225,667        271,484         (9,309)             487,842
--------------------------------------------------------------------------------------------------------
 Gross margin on sales................       282,475         57,449              -              339,924
--------------------------------------------------------------------------------------------------------
 Other operation and maintenance......        69,480         21,757              -               91,237
 Depreciation and amortization........        29,251         15,684              -               44,935
 Taxes other than income..............        11,434          4,723              -               16,157
--------------------------------------------------------------------------------------------------------
 Operating income.....................       172,310         15,285              -              187,595
--------------------------------------------------------------------------------------------------------
 Other expenses.......................          (260)           (17)             -                 (277)
--------------------------------------------------------------------------------------------------------
 Earnings before interest and taxes...   $   172,050    $    15,268    $         -          $   187,318

 Net income (loss)....................   $   100,117    $    (3,064)   $         -          $    97,053
========================================================================================================
</PRE>
<P ALIGN=CENTER>18</P>
<PAGE>
<PRE>
========================================================================================================
          Three Months Ended               Electric
          September 30, 2000                Utility     Non-utility    Intersegment            Total
--------------------------------------------------------------------------------------------------------
<I>(dollars in thousands)</I>

 Operating revenues...................   $   528,993    $   601,641    $  (122,668)   (A)   $ 1,007,966
 Fuel.................................       170,793              -         (9,080)             161,713
 Purchased power......................        68,644              -              -               68,644
 Gas and electricity purchased
   for resale.........................             -        476,965       (113,588)             363,377
 Natural gas purchases - other........             -         65,296              -               65,296
--------------------------------------------------------------------------------------------------------
 Cost of goods sold...................       239,437        542,261       (122,668)             659,030
--------------------------------------------------------------------------------------------------------
 Gross margin on sales................       289,556         59,380              -              348,936
--------------------------------------------------------------------------------------------------------
 Other operation and maintenance......        62,587         20,594              -               83,181
 Depreciation and amortization........        30,841         14,646              -               45,487
 Taxes other than income..............        11,079          4,129              -               15,208
--------------------------------------------------------------------------------------------------------
 Operating income.....................       185,049         20,011              -              205,060
--------------------------------------------------------------------------------------------------------
 Other income expenses................           (14)          (202)             -                 (216)
--------------------------------------------------------------------------------------------------------
 Earnings before interest and taxes...   $   185,035    $    19,809    $         -          $   204,844

 Net income (loss)....................   $   107,327    $       (20)   $         -          $   107,307
========================================================================================================

========================================================================================================
          Nine Months Ended                Electric
          September 30, 2001                Utility     Non-utility    Intersegment            Total
--------------------------------------------------------------------------------------------------------
<I>(dollars in thousands)</I>

 Operating revenues...................   $ 1,194,458    $ 1,477,673    $   (32,887)   (A)   $ 2,639,244
 Fuel.................................       401,469              -        (27,239)             374,230
 Purchased power......................       218,000              -              -              218,000
 Gas and electricity purchased
   for resale.........................             -      1,192,656         (5,648)           1,187,008
 Natural gas purchases - other........             -        129,033              -              129,033
--------------------------------------------------------------------------------------------------------
 Cost of goods sold...................       619,469      1,321,689        (32,887)           1,908,271
--------------------------------------------------------------------------------------------------------
 Gross margin on sales................       574,989        155,984              -              730,973
--------------------------------------------------------------------------------------------------------
 Other operation and maintenance......       212,978         69,791              -              282,769
 Depreciation and amortization........        89,774         45,407              -              135,181
 Taxes other than income..............        34,575         14,492              -               49,067
--------------------------------------------------------------------------------------------------------
 Operating income.....................       237,662         26,294              -              263,956
--------------------------------------------------------------------------------------------------------
 Other income (expenses)..............        (1,551)           493              -               (1,058)
--------------------------------------------------------------------------------------------------------
 Earnings before interest and taxes...   $   236,111    $    26,787    $         -          $   262,898

 Net income (loss)....................   $   127,145    $   (20,267)   $         -          $   106,878
========================================================================================================
</PRE>
<P ALIGN=CENTER>19</P>
<PAGE>
<PRE>
========================================================================================================
          Nine Months Ended                Electric
          September 30, 2000                Utility     Non-utility    Intersegment            Total
--------------------------------------------------------------------------------------------------------
<I>(dollars in thousands)</I>

 Operating revenues...................   $ 1,109,898    $ 1,432,459    $  (225,905)   (A)   $ 2,316,452
 Fuel.................................       349,999              -        (28,356)             321,643
 Purchased power......................       191,309              -              -              191,309
 Gas and electricity purchased
   for resale.........................             -      1,125,996       (197,549)             928,447
 Natural gas purchases - other........             -        121,385              -              121,385
--------------------------------------------------------------------------------------------------------
 Cost of goods sold...................       541,308      1,247,381       (225,905)           1,562,784
--------------------------------------------------------------------------------------------------------
 Gross margin on sales................       568,590        185,078              -              753,668
--------------------------------------------------------------------------------------------------------
 Other operation and maintenance......       196,923         65,301              -              262,224
 Depreciation and amortization........        91,355         44,048              -              135,403
 Taxes other than income..............        33,814         13,225              -               47,039
--------------------------------------------------------------------------------------------------------
 Operating income.....................       246,498         62,504              -              309,002
--------------------------------------------------------------------------------------------------------
 Other income (expenses)..............        (1,415)         5,853              -                4,438
--------------------------------------------------------------------------------------------------------
 Earnings before interest and taxes...   $   245,083    $    68,357    $         -          $   313,440

 Net income...........................   $   133,661    $     6,166    $         -          $   139,827
========================================================================================================

(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>Item 3 QUANTITATIVE AND QUALITATIVE DISCLOSURES<BR>
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
ABOUT MARKET RISK</B></P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;See
Item 2,  &#147;Management  Discussion  and Analysis of Financial  Condition  and
Results of Operations - Market Risk&#148;.</P>

<P ALIGN=CENTER>20</P>
<PAGE>



<P ALIGN=CENTER><B>PART II. OTHER INFORMATION</B></P>

<P ALIGN=LEFT><B>Item 1. LEGAL PROCEEDINGS</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  and to  Part  II,  Item 1 of the
Company's  Form 10-Q for the quarters ended March 31, 2001 and June 30, 2001 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  United  States  Court of  Appeals  for the  Tenth  Circuit  issued an order
reversing  the trial court  judgment in favor of Trigen and  remanding  the case
back to the trial  court with  orders to dismiss  the case in its  entirety.  On
October 29, 2001, the United States Supreme Court denied  Trigen's  petition for
certiorari, asking the Supreme Court to review the Court of Appeals decision. As
a result of the Supreme Court's denial of Trigen's petition, the Company expects
that the trial court will dismiss the charges against OG&amp;E,  and the Company
considers this matter closed.</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, Enogex was sued by
Melvin Scoggin and Oak Tree Resources,  LLC, in February 1998 in the District of
Oklahoma  County,  state of Oklahoma,  for alleged  breach of  contract,  fraud,
breach of fiduciary duty,  misappropriation  and unjust enrichment  arising from
communications   that  allegedly  created  agreements   regarding  oil  and  gas
exploration activities.  Plaintiffs' sought damages in excess of $25 million. On
October 20, 1999, the trial judge granted  Enogex's motions for summary judgment
and entered  judgment in favor of Enogex on all claims raised by the Plaintiffs.
The Plaintiffs appealed the trial court decision and the Court of Appeals upheld
the trial court's  judgment on all counts.  The  Plaintiffs  requested  that the
Supreme Court of Oklahoma review the Court of Appeals'  decision,  which request
was recently denied by the Supreme Court. The Company  considers this case to be
closed.</P>

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

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)&nbsp;&nbsp;
&nbsp;&nbsp;Reports on Form 8-K</P>

<P>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;
&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(1) Item 5.
Other Events, dated September 11, 2001.</P>

<P ALIGN=CENTER>21</P>
<PAGE>


<P ALIGN=CENTER><B>SIGNATURES</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>


<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>November 14, 2001</P><BR>

<P ALIGN=CENTER>22</P>

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