UNITED STATES
                       SECURITIES AND EXCHANGE COMMISSION

                             WASHINGTON, D.C. 20549

                                    FORM 10-Q
          (X) COMBINED QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D)
                     OF THE SECURITIES EXCHANGE ACT OF 1934

                    FOR THE QUARTER ENDED SEPTEMBER 30, 1997

                                       OR
              ( ) TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D)
                     OF THE SECURITIES EXCHANGE ACT OF 1934
                   FOR THE TRANSITION PERIOD FROM _____TO_____

COMMISSION         REGISTRANT, STATE OF INCORPORATION,        I.R.S. EMPLOYER
FILE NUMBER          ADDRESS AND TELEPHONE NUMBER             IDENTIFICATION NO.

1-1443             CENTRAL AND SOUTH WEST CORPORATION             51-0007707
                   (A Delaware Corporation)
                   1616 Woodall Rodgers Freeway
                   Dallas, Texas 75202-1234
                   (214) 777-1000

0-346              CENTRAL POWER AND LIGHT COMPANY                74-0550600
                   (A Texas Corporation)
                   539 North Carancahua Street
                   Corpus Christi, Texas 78401-2802
                   (512) 881-5300

0-343              PUBLIC SERVICE COMPANY OF OKLAHOMA             73-0410895
                   (An Oklahoma Corporation)
                   212 East 6th Street
                   Tulsa, Oklahoma 74119-1212
                   (918) 599-2000

1-3146             SOUTHWESTERN ELECTRIC POWER COMPANY            72-0323455
                   (A Delaware Corporation)
                   428 Travis Street
                   Shreveport, Louisiana 71156-0001
                   (318) 222-2141

0-340              WEST TEXAS UTILITIES COMPANY                   75-0646790
                   (A Texas Corporation)
                   301 Cypress Street
                   Abilene, Texas 79601-5820
                   (915) 674-7000

            INDICATE BY CHECK MARK WHETHER THE REGISTRANTS (1) HAVE 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
REGISTRANTS WERE REQUIRED TO FILE SUCH REPORTS), AND (2) HAVE BEEN SUBJECT TO
SUCH FILING REQUIREMENTS FOR THE PAST 90 DAYS. YES X NO

Common Stock Outstanding at November 7, 1997                      Shares
   Central and South West Corporation                           212,235,320
   Central Power and Light Company                                6,755,535
   Public Service Company of Oklahoma                             9,013,000
   Southwestern Electric Power Company                            7,536,640
   West Texas Utilities Company                                   5,488,560

            This Combined Form 10-Q is separately filed by Central and South
West Corporation, Central Power and Light Company, Public Service Company of
Oklahoma, Southwestern Electric Power Company and West Texas Utilities Company.
Information contained herein relating to any individual Registrant is filed by
such Registrant on its own behalf. Each Registrant makes no representation as to
information relating to the other Registrants.


<PAGE> 2


           CENTRAL AND SOUTH WEST CORPORATION AND SUBSIDIARY COMPANIES

               TABLE OF CONTENTS TO QUARTERLY REPORT ON FORM 10-Q
                               SEPTEMBER 30, 1997


                                                                           PAGE


GLOSSARY OF TERMS.............................................................3


FORWARD LOOKING INFORMATION...................................................4


PART I.  FINANCIAL INFORMATION................................................5

   ITEM 1.  FINANCIAL STATEMENTS..............................................5
      Central And South West Corporation And Subsidiary Companies............10
      Central Power And Light Company........................................14
      Public Service Company Of Oklahoma.....................................22
      Southwestern Electric Power Company....................................29
      West Texas Utilities Company...........................................36
      Notes To Financial Statements..........................................44

   ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
                 AND RESULTS OF OPERATIONS...................................56


PART II - OTHER INFORMATION..................................................67

   ITEM 1.  LEGAL PROCEEDINGS................................................67

   ITEM 5.  OTHER INFORMATION................................................68

   ITEM 6.  EXHIBITS AND REPORTS ON FORM 8-K.................................70


SIGNATURES...................................................................71

<PAGE> 3
GLOSSARY OF TERMS
The following abbreviations or acronyms used in this text are defined below:

ABBREVIATION OR ACRONYM                DEFINITION
ANI....................................American Nuclear Insurance
Burlington Northern....................Burlington Northern Railroad Company
Cajun..................................Cajun Electric Power Cooperative, Inc.
CLECO..................................Central Louisiana Electric Company, Inc.
Committee of Certain Members...........The members committee of Cajun, which 
                                       currently represents 7 of the 11 
                                       Louisiana member distribution 
                                       cooperatives that are served by Cajun
Court of Appeals.......................Court of Appeals, Third District of 
                                       Texas, Austin, Texas
CPL....................................Central Power and Light Company, Corpus 
                                       Christi, Texas
CPL 1997 Final Order...................Final orders received from the Texas 
                                       Commission in CPL's rate case Docket No.
                                       14965, including both the order received
                                       on September 10, 1997 and the revised
                                       order received on October 16, 1997
CPL 1996 Fuel Agreement................Fuel settlement agreement entered into by
                                       CPL and other parties in March 1996
CPL 1997 Original Rate Order...........Final order issued on March 31, 1997 by 
                                       the Texas Commission in CPL's rate case
                                       Docket No. 14965
CSW....................................Central and South West Corporation, 
                                       Dallas, Texas
CSW Credit.............................CSW Credit, Inc., Dallas, Texas
CSW Energy.............................CSW Energy, Inc., Dallas, Texas
CSW ESI................................CSW Energy Services, Inc., Dallas, Texas
CSW International......................CSW International, Inc., Dallas, Texas
CSW PMI................................CSW Power Marketing, Inc., Dallas, Texas
CSW Services...........................Central and South West Services, Inc., 
                                       Dallas, Texas and Tulsa, Oklahoma
CSW System.............................CSW and its subsidiaries
CWIP...................................Construction work in progress
DGES...................................Director General Electricity Supply
DHMV...................................Dolet Hills Mining Venture
ECOM...................................Excess cost over market
El Paso................................El Paso Electric Company
El Paso Merger.........................The proposed merger whereby El Paso would
                                       have become a wholly-owned subsidiary of
                                       CSW
Entergy Texas..........................Entergy Texas Utilities Company
EPA....................................Environmental Protection Agency
ERCOT..................................Electric Reliability Council of Texas
Exchange Act...........................Securities Exchange Act of 1934, as 
                                       amended
FERC...................................Federal Energy Regulatory Commission
HL&P...................................Houston Lighting & Power Company
Holding Company Act....................Public Utility Holding Company Act of 
                                       1935, as amended
ITC....................................Investment tax credit
LIFO...................................Last-in First-out (inventory accounting 
                                       method)
MD&A...................................Management's Discussion and Analysis of 
                                       Financial Condition and Results of
                                       Operations
MDEQ...................................Mississippi Department of Environmental 
                                       Quality
Merger Agreement.......................Agreement and Plan of Merger between El 
                                       Paso and CSW, dated as of May 3, 1993, as
                                       amended
MGP....................................Manufactured gas plant or coal 
                                       gasification plant
Mirror CWIP............................Mirror Construction Work in Progress
Mississippi Power......................Mississippi Power Company
MMbtu..................................Million Btu (British thermal unit)
MWH....................................Megawatt-hour
National Grid..........................National Grid Group plc
NEIL...................................Nuclear Electric Insurance Limited
OCC Staff..............................Staff of the Oklahoma Commission
Oklahoma Commission....................Corporation Commission of the State of 
                                       Oklahoma
<PAGE> 4
GLOSSARY OF TERMS  (CONTINUED)

ABBREVIATION OR ACRONYM                DEFINITION
Oklaunion..............................Oklaunion Power Station
PCB....................................Polychlorinated biphenyl
PRP....................................Potentially responsible party
PSO....................................Public Service Company of Oklahoma, 
                                       Tulsa, Oklahoma
PSO 1997 Rate Settlement Agreement.....Joint stipulation agreement reached by 
                                       PSO and other parties to settle PSO's 
                                       current rate inquiry
Registrant(s)..........................CSW, CPL, PSO, SWEPCO and WTU
Rights Plan............................Stockholder Rights Agreement between CSW
                                       and CSW Services, as Rights Agent
RUS....................................Rural Utilities Service of the federal 
                                       government
SEC....................................United States Securities and Exchange 
                                       Commission
SEEBOARD...............................SEEBOARD plc., Crawley, West Sussex, 
                                       United Kingdom
SEEBOARD U.S.A.........................CSW's investment in SEEBOARD consolidated
                                       and converted to U.S. Generally Accepted
                                       Accounting Principles
SFAS...................................Statement of Financial Accounting 
                                       Standards
SFAS No. 52............................Foreign Currency Translation
SFAS No. 71............................Accounting for the Effects of Certain 
                                       Types of Regulation
SFAS No. 87............................Employers' Accounting for Pensions
STP....................................South Texas Project nuclear electric 
                                       generating station, jointly owned by CPL,
                                       HL&P, City of Austin, and City of San 
                                       Antonio
STPNOC.................................South Texas Project Nuclear Operating 
                                       Company, a non-profit Texas corporation,
                                       jointly owned by CPL, HL&P, City of 
                                       Austin, and City of San Antonio
Subsidiary obligated, mandatorily
    redeemable, trust preferred 
    securities.........................Collective term for securities issued by
                                       business trusts of CPL, PSO and SWEPCO
SWEPCO.................................Southwestern Electric Power Company, 
                                       Shreveport, Louisiana
SWEPCO Plan............................The plan of reorganization for Cajun 
                                       filed by the Committee of Certain 
                                       Members, SWEPCO and Entergy Texas on 
                                       October 26, 1996 with the U.S. Bankruptcy
                                       Court for the Middle District of 
                                       Louisiana
Texas Commission.......................Public Utility Commission of Texas
Transok................................Transok, Inc. and subsidiaries, a former
                                       wholly-owned subsidiary of CSW
U.S. Electric(s) or U.S. Electric
    Operating Companies................CPL, PSO, SWEPCO and WTU
Vale...................................Empresa De Electrcidade Vale 
                                       Paranapanema S/A
WTU....................................West Texas Utilities Company, Abilene, 
                                       Texas


FORWARD LOOKING INFORMATION

This report made by CSW and its subsidiaries contains forward looking statements
within the meaning of Section 21E of the Exchange Act. Although CSW and each of
its subsidiaries believe that, in making any such statements, their expectations
are based on reasonable assumptions, any such statements may be influenced by
factors that could cause actual outcomes and results to be materially different
from those projected. Important factors that could cause actual results to
differ materially from those in the forward looking statements include, but are
not limited to: the impact of general economic changes in the U.S. and in
countries in which CSW either currently has made or in the future may make
investments; the impact of deregulation on the U.S. electric utility business;
increased competition and electric utility industry restructuring in the U.S.;
federal and state regulatory developments and changes in law which may have a
substantial adverse impact on the value of CSW System assets; timing and
adequacy of rate relief; adverse changes in electric load and customer growth;
climatic changes or unexpected changes in weather patterns; changing fuel
prices, generating plant and distribution facility performance; decommissioning
costs associated with nuclear generating facilities; uncertainties in foreign
operations and foreign laws affecting CSW's investments in those countries; the
effects of retail competition in the natural gas and electricity distribution
and supply businesses in the United Kingdom; and the timing and success of
efforts to develop domestic and international power projects. In the non-utility
area, the aforementioned factors would also apply, and, in addition, would
include, but are not limited to: the ability to compete effectively in new
areas, including telecommunications, power marketing and brokering, and other
energy related services, as well as evolving federal and state regulatory
legislation and policies that may adversely affect those industries generally or
the CSW System's business in areas in which it operates.


<PAGE> 4



CSW


                       CENTRAL AND SOUTH WEST CORPORATION
                            AND SUBSIDIARY COMPANIES




                          PART I. FINANCIAL INFORMATION.

                          ITEM 1. FINANCIAL STATEMENTS.


<PAGE> 6
                       CENTRAL AND SOUTH WEST CORPORATION

                        CONSOLIDATED STATEMENTS OF INCOME
                                   (unaudited)

                                        Three Months Ended   Nine Months Ended
                                           September 30,        September 30,
                                        -----------------    ----------------
                                          1997      1996      1997      1996
                                        -------    ------    ------    ------
                                         (millions, except per share amounts)
OPERATING REVENUES
    U.S. Electric                        $1,054    $1,028    $2,562    $2,555
    United Kingdom                          401       391     1,324     1,322
    Other diversified                        22        19        53        43
                                        -------    ------    ------    ------
                                          1,477     1,438     3,939     3,920
OPERATING EXPENSES AND TAXES
    U.S. Electric fuel                      370       347       892       885
    U.S. Electric purchased power            18        20        61        60
    United Kingdom cost of sales            276       274       927       961
    Operating and maintenance               254       232       769       670
    Provision for CPL 1997 Final Order        3        --        18        --
    El Paso Merger litigation                --        --        35        --
    Depreciation and amortization           121       122       360       356
    Taxes, other than income                 49        49       143       138
    Income taxes                             83       110       135       208
                                        -------    ------    ------    ------
                                          1,174     1,154     3,340     3,278
                                        -------    ------    ------    ------
OPERATING INCOME                            303       284       599       642
                                        -------    ------    ------    ------

OTHER INCOME AND DEDUCTIONS
    U.S. Electric reserves for utility
      plant development costs, net of
      income tax benefit of $1 for 1997
      and $33 for 1996                       --        --        (2)      (84)
    Other                                    10        11        29        15
                                        -------    ------    ------    ------
                                             10        11        27       (69)
                                        -------    ------    ------    ------
INCOME BEFORE INTEREST CHARGES              313       295       626       573
                                        -------    ------    ------    ------

INTEREST AND OTHER CHARGES
Interest on long-term debt                   84        80       251       240
Distributions on Subsidiary
  obligated, mandatorily redeemable,
  trust preferred securities                  7        --        11        --
Interest on short-term debt and
 other                                       23        21        59        76
                                        -------    ------    ------    ------
                                            114       101       321       316
                                        -------    ------    ------    ------

INCOME FROM CONTINUING OPERATIONS           199       194       305       257

DISCONTINUED OPERATIONS
    Income, net of income tax of $6          --        --        --        12
    Gain on the sale, net of income tax
      of $71                                 --        --        --       113
                                        -------    ------    ------    ------
                                             --        --        --       125
                                        -------    ------    ------    ------

INCOME BEFORE EXTRAORDINARY ITEM            199       194       305       382

EXTRAORDINARY ITEM-United Kingdom windfall
      profits tax                          (176)       --      (176)       --
                                        -------    ------    ------    ------

NET INCOME                                   23       194       129       382
  Less: Preferred stock dividends             3         4        10        13
  Gain on reacquired preferred stock         --        --        10        --
                                        -------    ------    ------    ------
NET INCOME FOR COMMON STOCK                $ 20     $ 190     $ 129     $ 369
                                        =======    ======    ======    ======

Average Common Shares Outstanding         212.2     210.3     212.1     206.3

Earnings per Share of Common Stock from 
     Continuing Operations                 0.93      0.90      1.44      1.18
Earnings per Share of Common Stock from
      Discontinued Operations                --        --        --      0.61
                                        -------    ------    ------    ------
Earnings per Share of Common Stock before
      Extraordinary Item                   0.93      0.90      1.44      1.79
Loss per Share of Common Stock from
      Extraordinary Item                  (0.83)       --     (0.83)       --
                                        -------    ------    ------    ------
Earnings per Share of Common Stock        $0.10     $0.90     $0.61     $1.79
                                        =======    ======    ======    ======

Dividends Paid per Share of Common Stock $0.435    $0.435    $1.305    $1.305
                                        =======    ======    ======    ======

   The accompanying notes to consolidated financial statements are an integral
                           part of these statements.

<PAGE> 7


                       CENTRAL AND SOUTH WEST CORPORATION

                           CONSOLIDATED BALANCE SHEETS

                                                   September 30,    December 31,
                                                       1997             1996
                                                    (unaudited)       (audited)
                                                   -------------    ------------
                                                             (millions)
ASSETS

FIXED ASSETS
    Electric
        Production                                 $ 5,825               $ 5,830
        Transmission                                 1,561                 1,538
        Distribution                                 4,352                 4,237
        General                                      1,358                 1,318
        Construction work in progress                  169                   230
        Nuclear fuel                                   195                   184
                                                   -------               -------
            Total Electric                          13,460                13,337
    Other diversified                                  191                    84
                                                   -------               -------
                                                    13,651                13,421
  Less - Accumulated depreciation and amortization   5,117                 4,940
                                                   -------               -------
                                                     8,534                 8,481
                                                   -------               -------
CURRENT ASSETS
    Cash and temporary cash investments                390                   254
    Accounts receivable                              1,208                   837
    Materials and supplies, at average cost            176                   185
    Electric utility fuel inventory                     71                   102
    Under-recovered fuel costs                          99                    46
    Prepayments and other                               58                    85
                                                   -------               -------
                                                     2,002                 1,509
                                                   -------               -------
DEFERRED CHARGES AND OTHER ASSETS
    Deferred plant costs                               505                   509
    Mirror CWIP asset                                  289                   299
    Other non-utility investments                      441                   371
    Income tax related regulatory assets, net          248                   236
    Goodwill                                         1,405                 1,525
    Other                                              379                   402
                                                   -------               -------
                                                     3,267                 3,342
                                                   -------               -------
                                                   $13,803               $13,332
                                                   =======               =======



       The accompanying notes to consolidated financial statements are an
                       integral part of these statements.

<PAGE> 8





                       CENTRAL AND SOUTH WEST CORPORATION

                           CONSOLIDATED BALANCE SHEETS

                                                    September 30,   December 31,
                                                        1997            1996
                                                    (unaudited)      (audited)
                                                   --------------  -------------
                                                            (millions)
CAPITALIZATION AND LIABILITIES

CAPITALIZATION
   Common stock equity
     Common stock: $3.50 par value
         Authorized: 350.0 million shares
         Issued and outstanding: 212.2 million
           shares in 1997 and 211.5 million
           shares in 1996                          $   743             $   740
     Paid-in capital                                 1,039               1,022
     Retained earnings                               1,815               1,963
     Foreign currency translation adjustment
           and other                                    33                  77
                                                   -------             -------
                                                     3,630               3,802
   Preferred stock
     Not subject to mandatory redemption               176                 292
     Subject to mandatory redemption                    26                  33
   Subsidiary obligated, mandatorily redeemable,
      trust preferred securities                       323                  --
   Long-term debt                                    3,933               4,024
                                                   -------             -------
                                                     8,088               8,151
                                                   -------             -------

CURRENT LIABILITIES
    Long-term debt and preferred stock due
     within twelve months                              204                 204
    Short-term debt                                    439                 364
    Short-term debt - CSW Credit, Inc.                 849                 579
    Loan notes                                          65                  76
    Accounts payable                                   510                 630
    Accrued taxes                                      447                 324
    Accrued interest                                   129                  82
    Other                                              303                 166
                                                   -------             -------
                                                     2,946               2,425
                                                   -------             -------

DEFERRED CREDITS
    Accumulated deferred income taxes                2,235               2,272
    Investment tax credits                             282                 291
    Other                                              252                 193
                                                   -------             -------
                                                     2,769               2,756
                                                   -------             -------
                                                   $13,803             $13,332
                                                   =======             =======





       The accompanying notes to consolidated financial statements are an
                       integral part of these statements.

<PAGE> 9

                       CENTRAL AND SOUTH WEST CORPORATION

                      CONSOLIDATED STATEMENTS OF CASH FLOWS
                                   (unaudited)
                                                         Nine Months Ended 
                                                   September 30,   September 30,
                                                   -----------------------------
                                                     1997                 1996
                                                   --------            ---------
OPERATING ACTIVITIES                                         (millions)
    Net Income                                     $   129             $   382
    Non-cash Items Included in Net Income
        Depreciation and amortization                  385                 403
        Deferred income taxes and investment
          tax credits                                  (11)                 17
        Utility plant and other development costs        1                 141
        Provision for CPL 1997 Final Order              18                  --
        Gain on sale of subsidiary                      --                (184)
        Refund due customers - PSO                      29
    Changes in Assets and Liabilities
        Accounts receivable                           (383)               (177)
        Fuel recovery                                  (23)                 --
        Accounts payable                                 5                 (92)
        Accrued taxes                                  125                 109
    Other                                              134                (122)
                                                   -------             -------
                                                       409                 477
                                                   -------             -------
INVESTING ACTIVITIES
    Construction expenditures                         (345)               (343)
    Acquisition expenditures                            --              (1,391)
    CSW Energy/CSW International projects             (187)                (52)
    Sale of National Grid assets                        --                  99
    Cash proceeds from sale of subsidiary               --                 690
    Other                                               --                  (5)
                                                   -------             -------
                                                      (532)             (1,002)
                                                   -------             -------
FINANCING ACTIVITIES
    Common stock sold                                   20                 451
    Proceeds from issuance of long-term debt            --                 238
    SEEBOARD acquisition financing                      --                 517
    Reacquisition and retirement of long-term
      debt                                             (52)               (238)
    Reacquisition and retirement of preferred
      stock                                           (114)                 --
    Proceeds from issuance of Subsidiary
      obligated, mandatorily redeemable,
      trust preferred securities                       323                  --
    Other financing activities                          34                  --
    Change in short-term debt                          345                (151)
    Payment of dividends                              (290)               (279)
                                                   -------             -------
                                                       266                 538
                                                   -------             -------

Effect of exchange rate changes on cash and
     cash equivalents                                   (7)                  8

Net change in cash and cash equivalents                136                  21
Cash and cash equivalents - beginning of period        254                 401
                                                   -------             -------
Cash and cash equivalents - end of period          $   390             $   422
                                                   =======             =======

SUPPLEMENTARY INFORMATION
    Interest paid less amounts capitalized
     (includes distributions on trust preferred
      securities)                                  $   282             $   261
                                                   =======             =======
    Income taxes paid                              $   247             $   139
                                                   =======             =======


       The accompanying notes to consolidated financial statements are an
                       integral part of these statements.
<PAGE> 10


CENTRAL AND SOUTH WEST CORPORATION AND SUBSIDIARY COMPANIES
RESULTS OF OPERATIONS

         Set forth below is information concerning the consolidated results of
operations of CSW for the three and nine month periods ended September 30, 1997
and September 30, 1996. For information concerning the results of operations for
each of the U.S. Electric Operating Companies, see the discussions under the
heading RESULTS OF OPERATIONS following the financial statements of each of the
U.S. Electric Operating Companies.


COMPARISON OF THE QUARTERS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock decreased to $20 million in the third
quarter of 1997 from $190 million in 1996 due primarily to the accrual of the
one-time United Kingdom windfall profits tax of (pound)109.5 million at SEEBOARD
(or $176 million when converted at (pound)1.00=$1.61). Also contributing to the
decrease in earnings was the $16 million effect of the PSO 1997 Rate Settlement
Agreement. See NOTE 2. LITIGATION AND REGULATORY PROCEEDINGS and NOTE 9.
EXTRAORDINARY ITEM for additional information on the PSO 1997 Rate Settlement
Agreement and the windfall profits tax, respectively. Higher interest and other
charges also contributed to the decline in earnings due primarily to the
distributions on newly issued trust preferred securities. Partially offsetting
these reductions in earnings was an adjustment to deferred tax balances of $15
million resulting from a 2% reduction in the United Kingdom Corporation Tax
rate. Increased MWH sales resulting from customer growth and usage at the U.S.
Electric Operating Companies also served to offset the decline in earnings by
approximately $10 million.

         In the third quarter of 1997, the U.S. Electric Operating Companies and
SEEBOARD U.S.A. contributed the following percentages to CSW's results of 
operations.
                                                           Corporate
                              U.S.     SEEBOARD   Total    Items and
                            Electric    U.S.A.   Electric    Other      Total
                           ---------------------------------------------------

Operating Revenues            72%        27%        99%        1%        100%
Operating Income              78%        18%        96%        4%        100%
Net Income for CSW Common
  before Extraordinary Item   91%        13%       104%       (4)%       100%

         U.S. Electric revenues increased $26 million, or 3%, in the third
quarter of 1997 compared to the same period a year ago due to several factors.
Higher MWH sales resulting from customer growth and usage at the U.S. Electric
Operating Companies increased U.S. Electric revenues by $15 million and the new
transmission access revenues at CPL and WTU increased U.S. Electric revenues by
$17 million. The impact on net income of the transmission access revenues was
almost entirely offset by a corresponding amount of transmission access expense.
Also contributing to the increase in U.S. Electric revenues were higher fuel
revenue of $19 million, as it relates to fuel expense discussed below. Partially
offsetting these increases in U.S. Electric revenues was a $26 million revenue
reduction resulting from the PSO 1997 Rate Settlement Agreement. Also partially
offsetting the increase was a revenue reduction of $2 million due to milder
weather in the third quarter of 1997. See NOTE 2. LITIGATION AND REGULATORY
PROCEEDINGS for additional information on the PSO 1997 Rate Settlement
Agreement. United Kingdom revenues increased $10 million, or 3%, in the third
quarter of 1997 compared to the third quarter of 1996 due primarily to the
effect of the exchange rate movement between the British pound and the U.S.
dollar, partially offset by a reduction in the fossil fuel levy collected on
behalf of the United Kingdom Government. Other diversified revenues increased $3
<PAGE> 11
million, or 16%, in the third quarter of 1997 compared to the same period last
year due primarily to increased revenues from CSW Credit and CSW International,
partially offset by lower revenues from CSW Energy.

         U.S. Electric fuel expense increased $23 million to $370 million in the
third quarter of 1997 compared to the third quarter of 1996 due in part to a 5%
increase in generation to meet customer demand. Also contributing to the higher
fuel expense was an increase in the average cost of fuel to $1.87 per MMbtu from
$1.77 per MMbtu, reflecting higher spot market natural gas prices.

         Operating and maintenance expense increased $22 million to $254 million
in the third quarter of 1997 compared to the same period last year due primarily
to $16 million in new transmission access expense recorded at CPL and WTU
related to FERC Order No. 888 and the Texas Commission rules regarding
transmission access and pricing. The third quarter effect of the CPL 1997 Final
Order further increased operating and maintenance expense by approximately $6
million. See NOTE 2. LITIGATION AND REGULATORY PROCEEDINGS for additional
information on the CPL 1997 Final Order. Also contributing to the increase was
higher operating and maintenance expense at SEEBOARD U.S.A. due primarily to the
change in the exchange rate. Income tax expense decreased $27 million to $83
million in the third quarter of 1997 due primarily to lower pre-tax income and a
$15 million adjustment to deferred income tax balances resulting from a 2%
reduction in the United Kingdom Corporation Tax rate.

         Long-term interest expense increased $4 million, or 5%, in the third
quarter of 1997 due primarily to the addition in 1997 of interest expense
resulting from a fourth quarter 1996 debt issuance by CSW Energy. Distributions
on newly-issued Subsidiary obligated, mandatorily redeemable, trust preferred
securities increased interest and other charges by $7 million in the third
quarter of 1997, the net income effect of which was partially offset by lower
dividend requirements resulting from the related preferred stock reacquisitions
at the U.S. Electric Operating Companies. See NOTE 6. LONG-TERM FINANCING for
additional information on the new securities.


COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock decreased to $129 million in the first nine
months of 1997 from $369 million in the same period of 1996 due primarily to the
accrual of the one-time United Kingdom windfall profits tax of (pound)109.5
million at SEEBOARD (or $176 million when converted at (pound)1.00=$1.61). The
impact of CSW's final settlement of litigation with El Paso of $23 million,
after tax, contributed to the decline in earnings as well. Also contributing to
the decrease in earnings was the approximately $17 million effect of the PSO
1997 Rate Settlement Agreement and the $40 million effect of the CPL 1997 Final
Order. See NOTE 2. LITIGATION AND REGULATORY PROCEEDINGS for additional
information on CSW's final settlement of litigation with El Paso, the PSO 1997
Rate Settlement Agreement and the CPL 1997 Final Order. See NOTE 9.
EXTRAORDINARY ITEM for additional information on the windfall profits tax.
Partially offsetting the lower earnings was the gain of approximately $10
million on the reacquisition of a portion of the U.S. Electric Operating
Companies' preferred stock and also an adjustment to deferred tax balances of
$15 million resulting from a 2% reduction in the United Kingdom Corporation Tax
rate. Further offsetting the decline in earnings was an increase in non-fuel
electric revenues discussed below.

         In addition, several items that occurred in the first nine months of
1996 were not present in the comparable period in 1997. Prior to the June 6,
1996 sale of Transok, CSW realized $12 million of earnings from Transok's
<PAGE> 12
operations and as a result of the sale, CSW also recorded an after-tax gain of
approximately $113 million in June 1996. However, the U.S. Electric Operating
Companies and CSW Energy recorded reserves and write-offs totaling $102 million,
after-tax, for certain investments and contingencies in the second quarter of
1996 which decreased earnings. See NOTE 8. DISCONTINUED OPERATIONS for
additional information concerning the effects of the sale of Transok.

         In the first nine months of 1997, the U.S. Electric Operating Companies
and SEEBOARD U.S.A. contributed the following percentages to CSW's results of 
operations.
                                                              Corporate
                               U.S.      SEEBOARD    Total    Items and
                             Electric     U.S.A.    Electric    Other    Total
                            ---------------------------------------------------

Operating Revenues             65%         34%         99%        1%      100%
Operating Income               76%         24%        100%       --       100%
Net Income for CSW Common
  before Extraordinary Item    94%         22%        116%      (16)%     100%

         U.S. Electric revenues increased $7 million in the first nine months of
1997 compared to the same period a year ago due primarily to increased MWH sales
resulting from customer growth and usage of $25 million and new transmission
access revenues at CPL and WTU of $49 million in accordance with FERC Order No.
888 and the Texas Commission's rule regarding transmission access and pricing.
The impact on net income of the transmission revenues was almost entirely offset
by a corresponding amount of transmission expense. Revenues increased due in
part to the absence in 1997 of the $14 million revenue decrease in 1996 from the
CPL 1996 Fuel Agreement. Partially offsetting the revenue increase was a
decrease in weather related demand of $44 million due to mild weather in the
first nine months of 1997. Further offsetting the increase in U.S. Electric
revenues was the revenue decrease from both the CPL 1997 Final Order of $31
million and the PSO 1997 Rate Settlement Agreement of $29 million. See NOTE 2.
LITIGATION AND REGULATORY PROCEEDINGS for additional information on the PSO 1997
Rate Settlement Agreement and the CPL 1997 Final Order. Other diversified
revenues increased $10 million, or 23%, in the first nine months of 1997
compared to the first nine months of 1996 due primarily to increased revenues
from CSW International and CSW Credit.

         U.S. Electric fuel expense increased $7 million to $892 million in the
first nine months of 1997 compared to the same period last year due in part to
an increase in natural gas fuel costs to $2.54 per MMbtu from $2.30 per MMbtu.
Also contributing to the increase was the absence in 1997 of a one-time
reduction to fuel expense of approximately $9 million in the first quarter of
1996 related to the CPL 1996 Fuel Agreement. Partially offsetting these
increases in fuel expense was the effect of lower cost coal. United Kingdom cost
of sales decreased approximately $34 million to $927 million in the first nine
months of 1997 compared to the same period a year ago due primarily to a
reduction in the fossil fuel levy collected on behalf of the United Kingdom
government, which was partially offset by the effect of the exchange rate
movement between the British pound and the U.S. dollar.

         Operating and maintenance expense increased $99 million to $769 million
in the first nine months of 1997 compared to the same period last year due in
part to the absence in 1997 of a $27 million pension adjustment recorded in the
second quarter of 1996 at SEEBOARD which decreased pension expense. The effect
of the exchange rate movement between the British pound and U.S. dollar also
contributed to the increase in operating and maintenance expense of SEEBOARD
U.S.A. In addition, approximately $47 million in new transmission access expense
was recorded at CPL and WTU in the first nine months of 1997 related to FERC
Order No. 888 and the Texas Commission rules regarding transmission access and
pricing. Also contributing to the increase in operating and maintenance expense
was the $28 million impact of the CPL 1997 Final Order. See NOTE 2. LITIGATION
<PAGE> 13
AND REGULATORY PROCEEDINGS for additional information on the CPL 1997 Final
Order. CSW also recorded $7 million of additional charges in 1997 associated
with the true-up of restructuring costs that nearly offset the cost increases
that were originally estimated and accrued in 1996. Partially offsetting the
increase in operating and maintenance expense were reduced pension expenses in
1997 resulting from changes made to the pension plan for CSW's domestic
employees. See NOTE 7. PENSION PLAN AMENDMENT for additional information related
to the changes in the pension plan. Income tax expense decreased $73 million to
$135 million in the first nine months of 1997 due primarily to lower pre-tax
income and a $15 million adjustment to deferred income tax balances resulting
from a 2% reduction in the United Kingdom Corporation Tax rate.

         CPL recorded a $41 million reserve in the first quarter of 1997 related
to the CPL 1997 Original Rate Order issued by the Texas Commission. In the
second quarter of 1997, CPL reclassified into specific accounts most of the
effects of the reserve recorded in the first quarter to reflect the effects of
both the CPL 1997 Original Rate Order and the Texas Commission's June 20, 1997
modifications to the CPL 1997 Original Rate Order into specific accounts.
Approximately $18 million remains as the provision for CPL 1997 Final Order. See
NOTE 2. LITIGATION AND REGULATORY PROCEEDINGS for additional information.

         Other income and deductions increased to $27 million in the first nine
months of 1997 from a loss of $69 million in the same period in 1996 due
primarily to the absence in 1997 of reserves for certain investments and
contingencies recorded in the second quarter of 1996 of approximately $84
million, after tax, at the U.S. Electric Operating Companies and $18 million at
CSW Energy. Long-term interest expense increased $11 million, or 5%, in the
first nine months of 1997 due primarily to interest expense resulting from a
fourth quarter 1996 debt issuance by CSW Energy. Short-term and other interest
expense decreased $17 million to $59 million in the first nine months of 1997
when compared to the same period a year ago due primarily to lower levels of
short-term borrowings. Distributions on newly-issued Subsidiary obligated,
mandatorily redeemable, trust preferred securities increased interest and other
charges by $11 million in the first nine months of 1997, the net income effect
of which was partially offset by lower dividend requirements resulting from the
related preferred stock reacquisitions at the U.S. Electric Operating Companies.
See NOTE 6. LONG-TERM FINANCING for additional information on the new
securities.


<PAGE> 14


CPL


                         CENTRAL POWER AND LIGHT COMPANY




                         PART I. FINANCIAL INFORMATION.

                          ITEM 1. FINANCIAL STATEMENTS.



<PAGE> 15
                         CENTRAL POWER AND LIGHT COMPANY

                        CONSOLIDATED STATEMENTS OF INCOME
                                   (unaudited)


                                  Three Months Ended      Nine Months Ended
                                     September 30,          September 30,
                                 --------------------  ------------------------
                                    1997      1996        1997          1996
                                 ---------  ---------  -----------  -----------
                                                 (thousands)

ELECTRIC OPERATING REVENUES       $444,964   $410,899   $1,060,746   $1,026,352

OPERATING EXPENSES AND TAXES
  Fuel                             129,296    101,994      291,492      256,489
  Purchased power                   11,705     19,293       39,856       48,593
  Other operating                   66,489     56,480      212,413      166,242
  Provision for CPL 1997 Final 
    Order                            3,122       --         18,160         --
  Maintenance                       16,985     11,080       46,418       40,190
  Depreciation and amortization     39,349     43,907      117,256      126,044
  Taxes, other than income          20,455     22,699       61,383       62,040
  Income taxes                      45,753     42,774       66,524       85,805
                                 ---------  ---------  -----------  -----------
                                   333,154    298,227      853,502      785,403
                                 ---------  ---------  -----------  -----------

OPERATING INCOME                   111,810    112,672      207,244      240,949
                                 ---------  ---------  -----------  -----------

OTHER INCOME AND DEDUCTIONS
  Reserve for utility plant
    development costs, net of
    tax benefit of $779 for
    1997 and $5,893 for 1996          --         --         (1,282)     (15,481)
  Allowance for equity funds
    used during construction           849        100        1,622          100
  Other                              2,555      1,398        5,339        4,608
                                 ---------  ---------  -----------  -----------
                                     3,404      1,498        5,679      (10,773)
                                 ---------  ---------  -----------  -----------

INCOME BEFORE INTEREST CHARGES     115,214    114,170      212,923      230,176
                                 ---------  ---------  -----------  -----------

INTEREST AND OTHER CHARGES
  Interest on long-term debt        26,864     28,407       80,982       83,072
  Interest on short-term debt
    and other                        3,783      3,355       11,994       14,485
  Distributions on CPL obligated,
    mandatorily redeemable, trust
    preferred securities             2,985       --          4,533         --
  Allowance for borrowed funds 
    used during construction          (644)      (194)      (1,770)      (1,410)
                                 ---------  ---------  -----------  -----------
                                    32,988     31,568       95,739       96,147
                                 ---------  ---------  -----------  -----------

NET INCOME                          82,226     82,602      117,184      134,029

  Less:  Preferred stock 
    dividends                        2,039      3,386        7,649       10,183
  Gain on reacquired preferred 
    stock                             (284)      --          2,422         --
                                 ---------  ---------  -----------  -----------

NET INCOME FOR COMMON STOCK        $79,903    $79,216     $111,957     $123,846
                                 =========  =========  ===========  ===========

   The accompanying notes to consolidated financial statements as they relate
                to CPL are an integral part of these statements.
<PAGE> 16
                         CENTRAL POWER AND LIGHT COMPANY

                           CONSOLIDATED BALANCE SHEETS

                                                     September 30,  December 31,
                                                         1997          1996
                                                      (unaudited)    (audited)
                                                       ----------   ----------
ASSETS                                                       (thousands)

 ELECTRIC UTILITY PLANT
     Production                                        $3,109,241   $3,102,929
     Transmission                                         512,958      505,801
     Distribution                                       1,002,532      956,928
     General                                              281,264      271,347
     Construction work in progress                         88,469       95,336
     Nuclear fuel                                         194,864      184,229
                                                       ----------   ----------
                                                        5,189,328    5,116,570

  Less - Accumulated depreciation and amortization      1,796,886    1,697,552
                                                       ----------   ----------
                                                        3,392,442    3,419,018
                                                       ----------   ----------

CURRENT ASSETS
     Cash and temporary cash investments                  106,232        3,299
     Advances to affiliates                                24,350         --
     Accounts receivable                                   65,528       53,038
     Materials and supplies, at average cost               70,681       75,732
     Fuel inventory                                        13,748       15,461
     Under-recovered fuel costs                            54,175       26,298
     Prepayments and other                                  3,910        4,484
                                                       ----------   ----------
                                                          338,624      178,312
                                                       ----------   ----------

DEFERRED CHARGES AND OTHER ASSETS
     Deferred STP costs                                   485,192      486,978
     Mirror CWIP asset                                    288,870      298,708
     Income tax related regulatory assets, net            325,878      335,226
     Other                                                103,603      110,021
                                                       ----------   ----------
                                                        1,203,543    1,230,933
                                                       ----------   ----------

                                                       $4,934,609   $4,828,263
                                                       ==========   ==========










   The accompanying notes to consolidated financial statements as they relate
                to CPL are an integral part of these statements.
<PAGE> 17
                         CENTRAL POWER AND LIGHT COMPANY

                           CONSOLIDATED BALANCE SHEETS

                                                     September 30,  December 31,
                                                          1997          1996
                                                      (unaudited)    (audited)
                                                       ----------   ----------
CAPITALIZATION AND LIABILITIES                               (thousands)

CAPITALIZATION
    Common stock:   $25 par value
       Authorized shares:   12,000,000
       Issued and outstanding shares:   6,755,535        $168,888     $168,888
    Paid-in capital                                       405,000      405,000
    Retained earnings                                     871,890      868,932
                                                       ----------   ----------
                                                        1,445,778    1,442,820

     Preferred stock                                      163,204      250,351
     CPL obligated, mandatorily redeemable,
       trust preferred securities                         144,706         --
     Long-term debt                                     1,328,848    1,323,054
                                                       ----------   ----------
                                                        3,082,536    3,016,225
                                                       ----------   ----------

CURRENT LIABILITIES
     Long-term debt due within twelve months              200,000      200,000
     Advances from affiliates                                --         52,525
     Payables to affiliates                                 8,510       23,995
     Accounts payable                                      77,319       45,946
     Accrued taxes                                         78,918       64,207
     Accrued interest                                      34,939       31,566
     Refund due customers                                 106,131       43,266
     Provision for CPL 1997 Final Order                    18,160         --
     Accumulated deferred income taxes                     17,384        7,310
     Other                                                 17,163       19,048
                                                       ----------   ----------
                                                          558,524      487,863
                                                       ----------   ----------

DEFERRED CREDITS
     Accumulated deferred income taxes                  1,134,917    1,162,051
     Investment tax credits                               143,673      147,191
     Other                                                 14,959       14,933
                                                       ----------   ----------
                                                        1,293,549    1,324,175
                                                       ----------   ----------

                                                       $4,934,609   $4,828,263
                                                       ==========   ==========







   The accompanying notes to consolidated financial statements as they relate
                to CPL are an integral part of these statements.
<PAGE> 18
                         CENTRAL POWER AND LIGHT COMPANY

                      CONSOLIDATED STATEMENTS OF CASH FLOWS
                                   (unaudited)
                                                          Nine Months Ended
                                                            September 30,
                                                       ----------------------
                                                         1997         1996
                                                       ---------    ---------
OPERATING ACTIVITIES                                         (thousands)
     Net Income                                         $117,184     $134,029
     Non-cash Items Included in Net Income
         Depreciation and amortization                   133,610      144,374
         Deferred income taxes and
           investment tax credits                        (11,230)      15,964
         Provision for CPL 1997 Final Order               18,160         --
         Utility plant development costs                   2,061       21,374
         Inventory reserve                                  --            487
     Changes in Assets and Liabilities
         Accounts receivable                             (12,490)       8,885
         Fuel inventory                                    1,713       10,340
         Materials and supplies                            5,051       (4,744)
         Accrued interest                                  3,373        2,977
         Accounts payable                                 15,535         (172)
         Accrued taxes                                    14,711       37,237
         Under-recovered fuel costs                      (27,877)     (35,313)
         Refund due customers                             62,865         --
     Other                                                11,073       (5,036)
                                                       ---------    ---------
                                                         333,739      330,402
                                                       ---------    ---------
INVESTING ACTIVITIES
     Construction expenditures                          (101,164)     (82,245)
     Other                                                 6,870        1,005
                                                       ---------    ---------
                                                         (94,294)     (81,240)
                                                       ---------    ---------
FINANCING ACTIVITIES
     Proceeds from issuance of long-term debt               --         63,967
     Reacquisition and retirement of
       long-term debt                                       --         (6,371)
     Special deposits for reacquisitions
       of long-term debt                                    --        (60,000)
     Redemption of preferred stock                       (84,725)        --
     Proceeds from issuance of CPL obligated,
       mandatorily redeemable, trust
       preferred securities                              144,706         --
     Change in advances from affiliates                  (52,525)    (118,279)
     Payment of dividends                               (119,577)    (125,416)
     Other                                                   (41)        --
                                                       ---------    ---------
                                                        (112,162)    (246,099)
                                                       ---------    ---------

NET CHANGE IN CASH AND CASH EQUIVALENTS                  127,283        3,063
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD           3,299        2,883
                                                       ---------    ---------
CASH AND CASH EQUIVALENTS AT END OF PERIOD              $130,582       $5,946
                                                       =========    =========

SUPPLEMENTARY INFORMATION
     Interest paid less amounts capitalized (includes
       distributions on trust preferred securities)      $82,716      $85,876
                                                       =========    =========
     Income taxes paid                                   $61,510      $26,721
                                                       =========    =========
                                                                            

   The accompanying notes to consolidated financial statements as they relate
                to CPL are an integral part of these statements.

<PAGE> 19

CENTRAL POWER AND LIGHT COMPANY
RESULTS OF OPERATIONS


COMPARISON OF THE QUARTERS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock increased $0.7 million, or 1%, from $79.2
million in the third quarter of 1996 to $79.9 million in the third quarter of
1997. Although net income for common stock was relatively stable for the two
periods, the following components fluctuated as described below.

         Total electric operating revenues increased $34.1 million, or 8%, in
the third quarter of 1997 compared to the third quarter of 1996 primarily due to
increased fuel related revenue as a result of higher fuel costs, as discussed
below. Also contributing to the increase were $11.9 million of transmission
revenues as a result of the January 1997 implementation of open access tariffs
in accordance with FERC Order No. 888 and the Texas Commission rules regarding
transmission access and pricing. The impact on net income of the increase in
transmission access revenues was almost entirely offset by a corresponding
increase in transmission expense.

         Fuel expense increased $27.3 million, or 27%, in the third quarter of
1997 compared with the third quarter of 1996 primarily as a result of an
increase in the average unit cost of fuel from $1.68 per MMbtu in the third
quarter of 1996 to $1.90 per MMbtu in the third quarter of 1997. This increase
resulted primarily from higher spot market prices for natural gas during the
third quarter of 1997. Purchased power expense decreased 39% from $19.3 million
in the third quarter of 1996 to $11.7 million in the third quarter of 1997 due
primarily to a reduction in economy energy purchases.

         Other operating expense increased 18% to $66.5 million in the third
quarter of 1997 compared to the third quarter of 1996 due to higher nuclear
operations expense, an increase in transmission operations expenses as a result
of the January 1997 implementation of open access tariffs in accordance with
FERC Order No. 888 and the Texas Commission rules regarding transmission access
and pricing, as well as the write-off of rate case and demand side management
expenditures resulting from the CPL 1997 Final Order. These increases also were
partially offset by decreased property insurance expense and decreased pension
expense. See NOTE 7. PENSION PLAN AMENDMENT for additional information related
to changes in the pension plan. Maintenance expenses increased to $17.0 million
in the third quarter of 1997 from $11.1 million in the third quarter of 1996 due
primarily to increased steam and nuclear production expense.

         Depreciation and amortization expenses decreased $4.6 million, or 10%,
compared to the third quarter of 1996 due to the implementation in 1997 of lower
depreciation rates in accordance with an administrative law judge's report
issued in the current CPL rate case. Income taxes increased approximately $3.0
million to $45.8 million in the third quarter of 1997 compared to the third
quarter of 1996 resulting from higher pre-tax income.

         Other income and deductions increased $1.9 million due primarily to
increased interest income from a higher level of short-term investments.

         Interest and other charges increased $1.4 million or 4% in the 3rd
quarter of 1997 when compared to the same period in 1996 due primarily to the
distributions on newly-issued CPL obligated, mandatorily redeemable, trust
preferred securities partially offset by a decrease in long-term debt expense
due to refinancing activities in 1996. Preferred stock dividends decreased $1.3
<PAGE> 20
million in the third quarter of 1997 when compared to the same period in 1996 as
a result of the reacquisition of certain CPL preferred stock.


COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock decreased $11.8 million, or 10%, from
$123.8 million for the first nine months of 1996 to $112.0 million for the first
nine months of 1997. The major reason for the decrease was the impact of the CPL
1997 Final Order, which decreased earnings by approximately $40 million. This
decrease was partially offset by an increase in other income and deductions due
to the absence in 1997 of a one-time charge associated with certain investments
for plant sites, engineering studies and lignite reserves of $15.5 million, net
of tax, recorded in the second quarter of 1996. See NOTE 2. LITIGATION AND
REGULATORY PROCEEDINGS for more information related to the CPL 1997 Final Order.

         Total electric operating revenues increased $34.4 million or 3% in the
first nine months of 1997 when compared to the first nine months of 1996 due
primarily to higher retail MWH sales resulting from increased customers and
demand as well as higher fuel related revenue due to higher fuel costs, as
discussed below. Other factors that contributed to the increase included a $35.5
million increase in transmission revenues as a result of the January 1997
implementation of open access tariffs in accordance with FERC Order No. 888 and
the Texas Commission rules regarding transmission access and pricing offset by a
decrease related to provisions for refunds in 1997 and 1996 associated with the
CPL rate case. The impact on net income of the increase in transmission access
revenues was almost entirely offset by a corresponding increase in transmission
expense.

         Fuel expense increased $35.0 million as a result of an increase in the
average unit cost of fuel from $1.54 per MMbtu in the first nine months of 1996
to $1.76 per MMbtu in the first nine months of 1997. This increase resulted
primarily from higher spot market prices for natural gas. Also contributing to
this increase was the absence in 1997 of a one-time $8.8 million reduction in
fuel expense recorded in the first quarter of 1996 in accordance with the CPL
1996 Fuel Agreement. Purchased power expense decreased 18% from $48.6 million
for the first nine months of 1996 to $39.9 million in the first nine months of
1997 due primarily to decreased economy energy purchases.

         Other operating expense increased 28% to $212.4 million in the first
nine months of 1997 due primarily to an increase in transmission operations
expenses as a result of the January 1997 implementation of open access tariffs
in accordance with FERC Order No. 888 and the Texas Commission rules regarding
transmission access and pricing and the write-off of previously deferred rate
case expenses in accordance with the settlement in principle of the rate case
expense phase of CPL's Rate Review Docket 14965. These increases were offset in
part by reductions in pension expense and other employee related expenses. See
NOTE 7. PENSION PLAN AMENDMENT for additional information related to changes in
the pension plan. Maintenance expense increased $6.2 million or 15% in the first
nine months of 1997 as compared to 1996 due primarily to higher steam and
nuclear production and distribution overhead line expenses in 1997.

         CPL recorded a $40.9 million reserve in the first quarter of 1997
related to the CPL 1997 Original Rate Order issued by the Texas Commission. In
the second quarter of 1997, CPL reclassified into specific accounts most of the
effects of the reserve recorded in the first quarter to reflect the effects of
both the CPL 1997 Original Rate Order and the Texas Commission's June 20, 1997
modifications to the CPL 1997 Original Rate Order into specific accounts.
Approximately $18 million remains as the provision for CPL 1997 Final Order. See
<PAGE> 21
NOTE 2. LITIGATION AND REGULATORY PROCEEDINGS for additional information.

         Depreciation and amortization expenses decreased $8.8 million compared
to the first nine months of 1996 due to the implementation in 1997 of lower
depreciation rates in accordance with an administrative law judge's report
issued in connection with the current CPL rate case. Income taxes decreased
$19.3 million in the first nine months of 1997 compared with the first nine
months of 1996 resulting primarily from the income tax effect of the CPL 1997
Final Order.

         Other income and deductions increased $16.5 million from a loss of
$10.8 million in 1996 to $5.7 million in 1997 due primarily to the absence in
1997 of the one-time charge associated with certain investments for plant sites,
engineering studies and lignite reserves of approximately $15.5 million, net of
tax, recorded in the second quarter of 1996. Also contributing to this increase
was additional interest income in 1997 due primarily to a higher level of
short-term investments.

         Interest and other charges decreased $0.4 million in the first nine
months of 1997 when compared to the same period in 1996 due primarily to a
decrease in short-term debt expense resulting from the repayment of short-term
debt outstanding as well as a decrease in long-term debt expense due to
refinancing activities in 1996. Partially offsetting this decrease were the
distributions on newly-issued CPL obligated, mandatorily redeemable, trust
preferred securities of $4.5 million. Preferred stock dividends decreased $2.5
million in the first nine months of 1997 as compared to the same period in 1996
as a result of the reacquisition of certain CPL preferred stock outstanding. CPL
also recognized a $2.4 million gain associated with the reacquisition in 1997.


<PAGE> 22

PSO



                       PUBLIC SERVICE COMPANY OF OKLAHOMA




                         PART I. FINANCIAL INFORMATION.

                          ITEM 1. FINANCIAL STATEMENTS.

<PAGE> 23
                       PUBLIC SERVICE COMPANY OF OKLAHOMA

                        CONSOLIDATED STATEMENTS OF INCOME
                                   (unaudited)


                                      Three Months Ended    Nine Months Ended
                                         September 30,        September 30,
                                     --------------------  --------------------
                                        1997       1996       1997      1996
                                     ---------  ---------  ---------  ---------
                                                     (thousands)

ELECTRIC OPERATING REVENUES           $222,235   $250,015   $544,092   $579,021

OPERATING EXPENSES AND TAXES
  Fuel                                  89,577     93,670    211,385    224,914
  Purchased power                        9,979     10,012     34,419     28,451
  Other operating                       28,707     30,818     86,782     88,340
  Maintenance                            7,732      8,777     23,088     26,487
  Depreciation and amortization         20,412     19,559     60,229     57,990
  Taxes, other than income               6,953      6,461     21,357     19,870
  Income taxes                          18,738     27,172     28,406     39,069
                                     ---------  ---------  ---------  ---------
                                       182,098    196,469    465,666    485,121
                                     ---------  ---------  ---------  ---------

OPERATING INCOME                        40,137     53,546     78,426     93,900
                                     ---------  ---------  ---------  ---------

OTHER INCOME AND DEDUCTIONS
  Allowance for equity funds
    used during construction               395       --          652       --
  Reserve for utility plant
    development costs, net of
    tax benefit of $48 for 1997
    and $15,302 for 1996                  --         --          (75)   (35,552)
  Other                                    307         38        992        237
                                     ---------  ---------  ---------  ---------
                                           702         38      1,569    (35,315)
                                     ---------  ---------  ---------  ---------

INCOME BEFORE INTEREST CHARGES          40,839     53,584     79,995     58,585
                                     ---------  ---------  ---------  ---------

INTEREST AND OTHER CHARGES
  Interest on long-term debt             7,618      7,821     22,855     22,936
  Interest on short-term debt
    and other                              683      1,130      3,349      4,452
  Distributions on PSO obligated,
    mandatorily redeemable, trust
    preferred securities                 1,499       --        2,467       --
  Allowance for borrowed funds used
     during construction                  (221)      (376)    (1,141)    (1,075)
                                     ---------  ---------  ---------  ---------
                                         9,579      8,575     27,530     26,313
                                     ---------  ---------  ---------  ---------

NET INCOME                              31,260     45,009     52,465     32,272

  Less: Preferred stock dividends           53        204        310        612
  Gain on reacquired preferred stock      (217)      --        4,227       --
                                     ---------  ---------  ---------  ---------

NET INCOME FOR COMMON STOCK            $30,990    $44,805    $56,382    $31,660
                                     =========  =========  =========  =========



   The accompanying notes to consolidated financial statements as they relate
                to PSO are an integral part of these statements.
<PAGE> 24
                       PUBLIC SERVICE COMPANY OF OKLAHOMA

                           CONSOLIDATED BALANCE SHEETS


                                                  September 30,    December 31,
                                                      1997            1996
                                                   (unaudited)      (audited)
                                                   ----------      ----------
ASSETS                                                     (thousands)

 ELECTRIC UTILITY PLANT
     Production                                      $907,468        $902,813
     Transmission                                     372,572         368,280
     Distribution                                     811,163         773,590
     General                                          205,701         186,252
     Construction work in progress                     32,077          59,241
                                                   ----------      ----------
                                                    2,328,981       2,290,176

  Less - Accumulated depreciation and amortization  1,030,610         987,283
                                                   ----------      ----------
                                                    1,298,371       1,302,893
                                                   ----------      ----------

CURRENT ASSETS
     Cash and temporary cash investments               40,261           1,479
     Advances to affiliates                             8,321            --
     Accounts receivable                               27,119          11,069
     Materials and supplies, at average cost           33,361          34,542
     Fuel inventory                                    14,434          14,061
     Accumulated deferred income taxes                   --             2,558
     Prepayments and other                                430           2,991
                                                   ----------      ----------
                                                      123,926          66,700
                                                   ----------      ----------

DEFERRED CHARGES AND OTHER ASSETS                      71,257          62,004
                                                   ----------      ----------

                                                   $1,493,554      $1,431,597
                                                   ==========      ==========















   The accompanying notes to consolidated financial statements as they relate
                to PSO are an integral part of these statements.
<PAGE> 25
                       PUBLIC SERVICE COMPANY OF OKLAHOMA

                           CONSOLIDATED BALANCE SHEETS


                                                   September 30,    December 31,
                                                       1997             1996
                                                    (unaudited)      (audited)
                                                    -----------     ----------
CAPITALIZATION AND LIABILITIES                              (thousands)

CAPITALIZATION
     Common stock:  $15 par value
       Authorized shares: 11,000,000
       Issued shares: 10,482,000
       Outstanding shares: 9,013,000                   $157,230       $157,230
     Paid-in capital                                    180,000        180,000
     Retained earnings                                  162,325        145,943
                                                    -----------     ----------
                                                        499,555        483,173

     Preferred stock                                      5,287         19,826
     PSO obligated, mandatorily redeemable,
       trust preferred securities                        72,506           --
     Long-term debt                                     421,442        420,301
                                                    -----------     ----------
                                                        998,790        923,300
                                                    -----------     ----------

CURRENT LIABILITIES
     Advances from affiliates                              --           42,867
     Payables to affiliates                              12,087         27,425
     Accounts payable                                    43,910         47,604
     Payables to customers                               16,464         14,329
     Accrued taxes                                       38,947         12,306
     Accrued interest                                    10,936          9,193
     Refund due customers                                29,000           --
     Accumulated deferred income taxes                      685           --
     Other                                                7,495          7,421
                                                    -----------     ----------
                                                        159,524        161,145
                                                    -----------     ----------

DEFERRED CREDITS
     Accumulated deferred income taxes                  242,136        251,007
     Investment tax credits                              42,000         43,438
     Income tax related regulatory liabilities, net      43,259         46,007
     Other                                                7,845          6,700
                                                    -----------     ----------
                                                        335,240        347,152
                                                    -----------     ----------

                                                     $1,493,554     $1,431,597
                                                    ===========     ==========




   The accompanying notes to consolidated financial statements as they relate
                to PSO are an integral part of these statements.
<PAGE> 26
                       PUBLIC SERVICE COMPANY OF OKLAHOMA

                      CONSOLIDATED STATEMENTS OF CASH FLOWS
                                   (unaudited)
                                                            Nine Months Ended
                                                               September 30,
                                                          ---------------------
                                                             1997        1996
                                                          ---------   ---------
OPERATING ACTIVITIES                                           (thousands)
     Net Income                                             $52,465     $32,272
     Non-cash Items Included in Net Income
         Depreciation and amortization                       64,417      62,457
         Deferred income taxes and investment tax credits    (9,814)    (10,338)
         Utility plant development costs                         75      50,854
         Inventory reserve                                     --         3,945
         Refund due customers                                29,000        --
     Changes in Assets and Liabilities
         Accounts receivable                                (16,050)     (8,766)
         Accounts payable                                   (17,439)    (19,769)
         Accrued taxes                                       26,641      17,375
      Other                                                    (473)     (3,151)
                                                          ---------   ---------
                                                            128,822     124,879
                                                          ---------   ---------

INVESTING ACTIVITIES
     Construction expenditures                              (55,851)    (56,830)
     Other                                                   (4,734)     (5,430)
                                                          ---------   ---------
                                                            (60,585)    (62,260)
                                                          ---------   ---------

FINANCING ACTIVITIES
     Proceeds from issuance of long-term debt                  --        51,785
     Retirement of long-term debt                              --       (25,000)
     Reacquisition of long-term debt                           --       (13,040)
     Reacquisition of preferred stock                       (10,312)       --
     Proceeds from issuance of PSO obligated, mandatorily
       redeemable, trust preferred securities                72,506        --
     Change in advances from affiliates                     (42,867)    (40,725)
     Payment of dividends                                   (40,461)    (35,636)
                                                          ---------   ---------
                                                            (21,134)    (62,616)
                                                          ---------   ---------

NET CHANGE IN CASH AND CASH EQUIVALENTS                      47,103           3
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD              1,479         744
                                                          ---------   ---------
CASH AND CASH EQUIVALENTS AT END OF PERIOD                  $48,582        $747
                                                          =========   =========

SUPPLEMENTARY INFORMATION
     Interest paid less amounts capitalized (includes
       distributions on trust preferred securities)         $24,501     $22,686
                                                          =========   =========
     Income taxes paid                                      $22,095     $20,142
                                                          =========   =========




   The accompanying notes to consolidated financial statements as they relate
                to PSO are an integral part of these statements.

<PAGE> 27
PUBLIC SERVICE COMPANY OF OKLAHOMA
RESULTS OF OPERATIONS


COMPARISON OF THE QUARTERS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock decreased $13.8 million in the third
quarter of 1997 to $31.0 million compared to $44.8 million in the third quarter
of 1996. The decrease resulted primarily from the impact of the PSO 1997 Rate
Settlement Agreement in September 1997. See NOTE 2. LITIGATION AND REGULATORY
PROCEEDINGS for additional information related to the PSO 1997 Rate Settlement
Agreement.

         Electric operating revenues were $222.2 million in the third quarter of
1997, an 11% decrease from the third quarter of 1996. The decrease was due
primarily to an additional $25.9 million added to the provision for rate refund
to fully reflect the PSO 1997 Rate Settlement Agreement as well as a decrease in
fuel related revenues of $4.6 million.

         Fuel expense decreased $4.1 million, or 4%, for the third quarter of
1997 compared to the third quarter of 1996 due primarily to an increase in
under-recovered fuel costs partially offset by a 3% increase in generation. The
average unit cost of fuel remained relatively stable in 1997 when compared to
the same period of 1996.

         Other operating expenses decreased $2.1 million in the third quarter of
1997 to $28.7 million compared to $30.8 million in the third quarter of 1996 due
primarily to a true-up for a reduction of depreciation rates associated with the
PSO 1997 Rate Settlement Agreement, the final classification of which is pending
approval from the FERC, as well as lower pension expense. Partially offsetting
the decrease was the write-off of rate case related expenses associated with the
aforementioned agreement. See NOTE 7. PENSION PLAN AMENDMENT for additional
information related to changes in the pension plan. Maintenance expense
decreased 12% to $7.7 million in the third quarter of 1997 from $8.8 million in
the third quarter of 1996 due to the timing of maintenance projects.

         Depreciation and amortization expense increased 4% to $20.4 million in
the third quarter of 1997 from $19.6 million in the third quarter of 1996
primarily as a result of increased depreciable property and software
amortization. Income taxes decreased to $18.7 million in the third quarter of
1997 compared to $27.2 million in the same period of 1996 due primarily to lower
taxable income in 1997.

         Interest and other charges increased $1.0 million or 12% in the third
quarter of 1997 when compared to the same period in 1996 due primarily to the
distributions on newly issued PSO obligated, mandatorily redeemable, trust
preferred securities partially offset by a decrease in short-term interest
expense as a result of the repayment of short-term debt in 1997.


COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock increased to $56.4 million in the first
nine months of 1997 from $31.7 million in the same period of 1996. The increase
resulted primarily from the absence in 1997 of a one-time charge for certain
investments for plant sites, engineering studies and lignite reserves of
approximately $35.6 million, net of tax, recorded in 1996 partially offset by
the impact of recording the effects of the PSO 1997 Rate Settlement Agreement in
<PAGE> 28
September 1997. See NOTE 2. LITIGATION AND REGULATORY PROCEEDINGS for additional
information related to the PSO 1997 Rate Settlement Agreement.

         Electric operating revenues were $544.1 million for the first nine
months of 1997, a 6% decrease from $579.0 million for the same period in 1996.
The decrease was due primarily to the establishment of a $29.0 million provision
for rate refund related to the PSO 1997 Rate Settlement Agreement as well as a
decline in residential MWH sales of 4% due to mild weather.

         Fuel expense decreased $13.5 million for the first nine months of 1997
compared to the first nine months of 1996 due primarily to a decrease in the
average unit cost of fuel from $2.04 per MMbtu in the first nine months of 1996
to $1.95 per MMbtu for the same period in 1997. The decline in the average unit
cost of fuel was due primarily to utilizing lower cost coal in place of higher
cost spot market natural gas. Additionally, a 7% decrease in generation
primarily attributable to lower residential MWH sales also contributed to this
decrease. Partially offsetting the decrease in fuel expense was a decline in
under-recovered fuel costs in 1997 when compared to 1996. Purchased power
expenses increased 21% to $34.4 million for the first nine months of 1997 from
$28.5 million in the same period of 1996 as a result of increased purchases of
economy energy.

         Other operating expenses were $86.8 million during the first nine
months of 1997, a 2% decrease from $88.3 million during the same period in 1996
due primarily to a true-up for a reduction of depreciation rates associated with
the PSO 1997 Rate Settlement Agreement, the final classification of which is
pending approval from the FERC, as well as lower pension expense. Partially
offsetting the decrease was the write-off of rate case related expenses
associated with the aforementioned agreement. See NOTE 7. PENSION PLAN AMENDMENT
for additional information related to changes in the pension plan. Maintenance
expense decreased 13% to $23.1 million in the first nine months of 1997 from
$26.5 million in the first nine months of 1996 primarily as a result of the 1996
write-down of production inventory. Depreciation and amortization expense
increased 4% to $60.2 million in 1997 from $58.0 million in 1996 as a result of
an increase in depreciable property. Taxes, other than income were $21.4 million
in 1997, a 7% increase from $19.9 million in 1996 as a result of higher ad
valorem tax expense in 1997. Operating income taxes were $28.4 million in the
first nine months of 1997 compared to $39.1 million in the same period of 1996
due primarily to lower taxable operating income in 1997.

         Other income and deductions increased $36.9 million in the first nine
months of 1997 compared to the same period in 1996 primarily as a result of the
absence in 1997 of a one-time charge for certain investments for plant sites,
engineering studies and lignite reserves of approximately $35.6 million, net of
tax, recorded in the second quarter of 1996.

         Interest and other charges increased $1.2 million or 5% in the first
nine months of 1997 when compared to the same period in 1996 due primarily to
the distributions on newly-issued PSO obligated, mandatorily redeemable, trust
preferred securities partially offset by a decrease in short-term interest
expense as a result of the repayment of short-term debt in 1997. PSO recognized
a $4.2 million gain associated with the reacquisition of certain PSO preferred
stock.

<PAGE> 29

SWEPCO


                       SOUTHWESTERN ELECTRIC POWER COMPANY




                         PART I. FINANCIAL INFORMATION.

                          ITEM 1. FINANCIAL STATEMENTS.



<PAGE> 30
                       SOUTHWESTERN ELECTRIC POWER COMPANY

                        CONSOLIDATED STATEMENTS OF INCOME
                                   (unaudited)


                                      Three Months Ended    Nine Months Ended
                                         September 30,        September 30,
                                     --------------------  --------------------
                                        1997       1996       1997       1996
                                     ---------  ---------  ---------  ---------
                                                     (thousands)

ELECTRIC OPERATING REVENUES           $291,539   $278,227   $722,146   $715,671

OPERATING EXPENSES AND TAXES
  Fuel                                 116,294    116,612    294,876    301,530
  Purchased power                        7,456      4,845     17,895     20,943
  Other operating                       35,318     35,887    101,074     99,360
  Maintenance                            9,984     10,406     31,424     31,444
  Depreciation and amortization         24,138     23,010     71,166     67,949
  Taxes, other than income              14,339     12,746     40,432     36,158
  Income taxes                          22,561     20,904     39,399     38,100
                                     ---------  ---------  ---------  ---------
                                       230,090    224,410    596,266    595,484
                                     ---------  ---------  ---------  ---------

OPERATING INCOME                        61,449     53,817    125,880    120,187
                                     ---------  ---------  ---------  ---------

OTHER INCOME AND DEDUCTIONS
  Reserve for utility plant
    development costs, net of
    tax benefit of $260 for
    1997 and $7,847 for 1996              --         --         (483)   (21,743)
  Allowance for equity funds
    used during construction               413         (1)       589        325
  Other                                  1,890         12      2,754        937
                                     ---------  ---------  ---------  ---------
                                         2,303         11      2,860    (20,481)
                                     ---------  ---------  ---------  ---------

INCOME BEFORE INTEREST CHARGES          63,752     53,828    128,740     99,706
                                     ---------  ---------  ---------  ---------

INTEREST AND OTHER CHARGES
  Interest on long-term debt             9,811     11,542     30,631     33,537
  Distributions on SWEPCO
    obligated, mandatorily 
    redeemable, trust preferred 
    securities                           2,167       --        3,565       --
  Interest on short-term debt 
    and other                            1,028      2,055      4,619      7,012
  Allowance for borrowed funds 
    used during construction              (202)      (465)      (944)    (1,691)
                                     ---------  ---------  ---------  ---------
                                        12,804     13,132     37,871     38,858
                                     ---------  ---------  ---------  ---------

NET INCOME                              50,948     40,696     90,869     60,848

  Less: Preferred stock dividends          589        758      1,922      2,295
  Gain on reacquired preferred stock      (528)      --        1,652       --
                                     ---------  ---------  ---------  ---------

NET INCOME FOR COMMON STOCK            $49,831    $39,938    $90,599    $58,553
                                     =========  =========  =========  =========




   The accompanying notes to consolidated financial statements as they relate
               to SWEPCO are an integral part of these statements.
<PAGE> 31
                       SOUTHWESTERN ELECTRIC POWER COMPANY

                           CONSOLIDATED BALANCE SHEETS


                                            September 30,          December 31,
                                                1997                  1996
                                             (unaudited)            (audited)
                                             ----------             ----------
ASSETS                                                  (thousands)

 ELECTRIC UTILITY PLANT
     Production                              $1,390,255             $1,407,134
     Transmission                               467,569                463,425
     Distribution                               859,367                844,503
     General                                    310,101                283,878
     Construction work in progress               34,769                 45,374
                                             ----------             ----------
                                              3,062,061              3,044,314

  Less - Accumulated depreciation             1,209,277              1,192,356
                                             ----------             ----------
                                              1,852,784              1,851,958
                                             ----------             ----------

CURRENT ASSETS
     Cash and temporary cash investments         26,592                  1,879
     Advances to affiliates                       5,023                   --
     Accounts receivable                         50,994                 68,140
     Materials and supplies, at average cost     25,402                 29,265
     Fuel inventory                              28,774                 55,775
     Under-recovered fuel costs                  18,982                  9,120
     Prepayments and other                       15,975                 13,499
                                             ----------             ----------
                                                171,742                177,678
                                             ----------             ----------

DEFERRED CHARGES AND OTHER ASSETS                85,355                 69,520
                                             ----------             ----------

                                             $2,109,881             $2,099,156
                                             ==========             ==========
















   The accompanying notes to consolidated financial statements as they relate
               to SWEPCO are an integral part of these statements.
<PAGE> 32
                       SOUTHWESTERN ELECTRIC POWER COMPANY

                           CONSOLIDATED BALANCE SHEETS


                                                      September 30, December 31,
                                                          1997         1996
                                                       (unaudited)   (audited)
                                                       ----------   ----------
CAPITALIZATION AND LIABILITIES                               (thousands)

CAPITALIZATION
     Common stock:  $18 par value
        Authorized shares: 7,600,000
        Issued and outstanding shares: 7,536,640        $ 135,660    $ 135,660
     Paid-in capital                                      245,000      245,000
     Retained earnings                                    349,394      321,801
                                                       ----------   ----------
                                                          730,054      702,461
     Preferred stock
        Not subject to mandatory redemption                 4,709       16,032
        Subject to mandatory redemption                    25,930       32,464
     SWEPCO obligated, mandatorily redeemable,
       trust preferred securities                         106,245         --
     Long-term debt                                       547,152      597,151
                                                       ----------   ----------
                                                        1,414,090    1,348,108
                                                       ----------   ----------

CURRENT LIABILITIES
     Long-term debt and preferred stock due within
       twelve months                                        3,732        3,760
     Advances from affiliates                                --         57,495
     Accounts payable                                      58,449       48,826
     Payable to affiliates                                 60,292       68,708
     Customer deposits                                     11,995       10,497
     Accrued taxes                                         41,729       25,241
     Accumulated deferred income taxes                      7,726        4,162
     Accrued interest                                      12,256       14,782
     Other                                                 12,298       27,449
                                                       ----------   ----------
                                                          208,477      260,920
                                                       ----------   ----------

DEFERRED CREDITS
     Accumulated deferred income taxes                    392,635      372,552
     Investment tax credits                                68,010       71,507
     Income tax related regulatory liabilities, net        17,912       36,106
     Other                                                  8,757        9,963
                                                       ----------   ----------
                                                          487,314      490,128
                                                       ----------   ----------

                                                       $2,109,881   $2,099,156
                                                       ==========   ==========




   The accompanying notes to consolidated financial statements as they relate
               to SWEPCO are an integral part of these statements.
<PAGE> 33
                       SOUTHWESTERN ELECTRIC POWER COMPANY

                      CONSOLIDATED STATEMENTS OF CASH FLOWS
                                   (unaudited)
                                                          Nine Months Ended
                                                            September 30,
                                                       ----------------------
                                                          1997         1996
                                                       ---------    ---------
OPERATING ACTIVITIES                                         (thousands)
     Net Income                                          $90,869      $60,848
     Non-cash Items Included in Net Income
         Depreciation and amortization                    74,775       75,686
         Deferred income taxes and investment
           tax credits                                     1,956       (2,417)
         Utility plant development costs                     743       29,590
         Inventory reserve                                  --          1,130
     Changes in Assets and Liabilities
         Accounts receivable                              17,146       (5,680)
         Fuel inventory                                   27,001        9,125
         Deferred charges and other assets               (15,835)     (24,628)
         Accounts payable                                 10,126        8,935
         Payable to affiliates                            (8,416)         653
         Accrued taxes                                    16,488       17,007
         Accrued interest                                 (2,526)      (5,931)
         Fuel recovery                                    (9,862)     (19,000)
    Other                                                (11,599)      (1,991)
                                                       ---------    ---------
                                                         190,866      143,327
                                                       ---------    ---------

INVESTING ACTIVITIES
     Construction expenditures                           (73,268)     (67,837)
     Other                                                (2,990)      (5,901)
                                                       ---------    ---------
                                                         (76,258)     (73,738)
                                                       ---------    ---------

FINANCING ACTIVITIES
     Proceeds from issuance of long-term debt               --         79,273
     Reacquisition of long-term debt                        --        (83,334)
     Retirement of long-term debt                        (52,278)      (3,561)
     Redemption of preferred stock                       (16,210)      (1,200)
     Proceeds from issuance of SWEPCO
       obligated, mandatorily redeemable,
       trust preferred securities                        106,245         --
     Change in advances from affiliates                  (57,495)     (22,747)
     Payment of dividends                                (65,134)     (37,865)
                                                       ---------    ---------
                                                         (84,872)     (69,434)
                                                       ---------    ---------

NET CHANGE IN CASH AND CASH EQUIVALENTS                   29,736          155
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD           1,879        1,702
                                                       ---------    ---------
CASH AND CASH EQUIVALENTS AT END OF PERIOD               $31,615       $1,857
                                                       =========    =========

SUPPLEMENTARY INFORMATION
     Interest paid less amounts capitalized (includes
       distributions on trust preferred securities)      $39,119      $43,686
                                                       =========    =========
     Income taxes paid                                   $33,507      $25,736
                                                       =========    =========



   The accompanying notes to consolidated financial statements as they relate
               to SWEPCO are an integral part of these statements.
<PAGE> 34
SOUTHWESTERN ELECTRIC POWER COMPANY
RESULTS OF OPERATIONS


COMPARISON OF THE QUARTERS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock increased $9.9 million to $49.8 million in
the third quarter of 1997 from $39.9 million in the third quarter of 1996. The
increase resulted primarily from increased MWH sales and the gain on the sale of
lignite properties in the third quarter of 1997.

         Electric operating revenues increased $13.3 million to $291.5 million
for the third quarter of 1997 from $278.2 million for the third quarter of 1996.
The increase was attributable to a $9.2 million increase in retail non-fuel
revenue resulting from a 5% increase in retail MWH sales attributable to
weather-related demand and customer growth, an increase in non-fuel wholesale
sales of $3.6 million and a $0.5 million increase in fuel-related revenue.

         Fuel and purchased power expense increased in the third quarter of 1997
compared to the third quarter of 1996. Fuel expense decreased $0.3 million,
resulting from an under-recovery of fuel costs in the third quarter of 1997
compared to an over-recovery of fuel costs in the third quarter of 1996, offset
in part by increases in average unit fuel costs and increased generation in
1997. Average unit fuel costs increased from $1.66 per MMbtu in 1996 to $1.70
per MMbtu in 1997 due to an increase in the spot market price of natural gas
offset in part by lower coal transportation charges as well as purchases of
lower priced spot market coal. MWH generation increased 5% during the third
quarter of 1997. Purchased power expenses increased $2.6 million in the third
quarter of 1997 compared to the third quarter of 1996 as a result of an increase
in economy energy purchases.

         Depreciation and amortization expenses increased $1.1 million or 5% in
the third quarter of 1997 compared to the same period of 1996 due primarily to
increased depreciable plant. Taxes, other than income increased $1.6 million, or
12%, as a result of increased ad valorem taxes due to higher assessed values.
Income taxes increased $1.7 million due primarily to higher taxable income.

         Other income and deductions increased $2.3 million for the third
quarter of 1997 compared to the same period of 1996 due primarily to the $1.1
million, net of tax, gain on the sale of lignite properties recorded in the
third quarter of 1997.



COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock increased $32.0 million to $90.6 million
for the first nine months of 1997 compared to $58.6 million for the same period
of 1996. The increase resulted primarily from the absence in 1997 of a one-time
charge associated with certain investments for plant sites, engineering studies
and lignite reserves of approximately $21.7 million, net of tax, recorded in the
second quarter of 1996, increased electric operating revenues and the gain on
reacquisition of preferred stock of $1.7 million recorded during 1997.

         Electric operating revenues increased $6.5 million to $722.1 million
for the first nine months of 1997 from $715.7 million for the same period in
1996. The increase was due primarily to an increase in non-fuel revenue of $16.5
<PAGE> 35
million, including $9.1 million in non-fuel wholesale sales, offset in part by a
$10.0 million decrease in fuel revenue.

         Fuel and purchased power expense decreased for the first nine months of
1997 compared to the same period of 1996. Fuel expense decreased $6.7 million,
or 2%, due primarily to a decrease in average unit fuel costs from $1.77 per
MMbtu in 1996 to $1.69 per MMbtu in 1997 which resulted from lower coal
transportation charges as well as purchases of lower priced spot market coal. A
decrease in natural gas generation because of its relative higher cost per MMbtu
also contributed to the lower fuel expense for the first nine months of 1997.
Purchased power expenses decreased $3.1 million, or 15%, for the first nine
months of 1997 compared to the same period in 1996 as a result of a decrease in
economy energy purchases.

         Other operating expenses increased $1.7 million to $101.1 million for
the first nine months of 1997 compared to the same period in 1996. The increase
was attributable to increased transmission access expenses and increased
customer assistance expenses, offset in part by decreased pension expenses. See
NOTE 7. PENSION PLAN AMENDMENT for additional information related to changes in
the pension plan. Depreciation and amortization expenses increased $3.2 million,
or 5%, due primarily to increased depreciable plant. Taxes, other than income
increased $4.3 million to $40.4 million as a result of increased ad valorem
taxes due to higher assessed values. Income taxes increased $1.3 million due
primarily to higher taxable income.

         Other income and deductions increased $23.3 million for the first nine
months of 1997 compared to the same period of 1996 due primarily to a one-time
charge associated with certain investments for plant sites, engineering studies
and lignite reserves of approximately $21.7 million, net of tax, recorded in the
second quarter of 1996, offset in part by the $1.1 million, net of tax, gain on
the sale of lignite properties recorded in the third quarter of 1997.

         Interest and other charges decreased $1.0 million in the first nine
months of 1997 when compared to the same period of 1996 due primarily to a
decrease in short-term debt interest expense of $2.4 million resulting from the
repayment of short-term debt outstanding as well as a decrease in long-term debt
interest expense of $2.9 million due to retirement of long-term debt in 1997.
Partially offsetting these decreases were the distributions on newly-issued
SWEPCO obligated, mandatorily redeemable, trust preferred securities of $3.6
million. SWEPCO also recognized a $1.7 million gain associated with the
reacquisition of preferred stock in 1997.

<PAGE> 36


WTU



                          WEST TEXAS UTILITIES COMPANY




                         PART I. FINANCIAL INFORMATION.

                          ITEM 1. FINANCIAL STATEMENTS.

<PAGE> 37
                          WEST TEXAS UTILITIES COMPANY

                              STATEMENTS OF INCOME
                                   (unaudited)


                                      Three Months Ended     Nine Months Ended
                                         September 30,         September 30,
                                     --------------------  --------------------
                                       1997       1996       1997       1996
                                     ---------  ---------  ---------  ---------
                                                     (thousands)

ELECTRIC OPERATING REVENUES           $124,984   $113,314   $308,867   $295,690

OPERATING EXPENSES AND TAXES
  Fuel                                  34,450     35,177     94,361    102,982
  Purchased power                       16,559      8,918     34,984     21,442
  Other operating                       20,920     16,133     64,038     50,835
  Maintenance                            3,239      3,007     10,393     10,698
  Depreciation and amortization         10,741     10,081     31,067     29,591
  Taxes, other than income               6,347      5,940     18,148     17,121
  Income taxes                           9,139      9,367     12,425     14,402
                                     ---------  ---------  ---------  ---------
                                       101,395     88,623    265,416    247,071
                                     ---------  ---------  ---------  ---------

OPERATING INCOME                        23,589     24,691     43,451     48,619
                                     ---------  ---------  ---------  ---------

OTHER INCOME AND DEDUCTIONS
  Reserve for utility plant
    development costs, net of
    tax benefit of $20 for 1997
    and $3,988 for 1996                   --         --          (38)   (10,917)
  Allowance for equity funds used
    during construction                     26         64        125        232
  Other                                    150        140        587        629
                                     ---------  ---------  ---------  ---------
                                           176        204        674    (10,056)
                                     ---------  ---------  ---------  ---------

INCOME BEFORE INTEREST CHARGES          23,765     24,895     44,125     38,563
                                     ---------  ---------  ---------  ---------

INTEREST AND OTHER CHARGES
  Interest on long-term debt             5,088      5,815     15,264     16,407
  Interest on short-term
     debt and other                      1,127      1,043      3,911      3,788
  Allowance for borrowed
     funds used during
     construction                         (132)      (183)      (599)      (687)
                                     ---------  ---------  ---------  ---------
                                         6,083      6,675     18,576     19,508
                                     ---------  ---------  ---------  ---------

NET INCOME                              17,682     18,220     25,549     19,055

  Less: Preferred stock dividends           26         66        118        198
  Gain on reacquired preferred stock      (101)      --        1,082       --
                                     ---------  ---------  ---------  ---------

NET INCOME FOR COMMON STOCK            $17,555    $18,154    $26,513    $18,857
                                     =========  =========  =========  =========







          The accompanying notes to financial statements as they relate
                to WTU are an integral part of these statements.
<PAGE> 38
                          WEST TEXAS UTILITIES COMPANY

                                 BALANCE SHEETS


                                                      September 30, December 31,
                                                          1997         1996
                                                      (unaudited)    (audited)
                                                       ----------   ----------
ASSETS                                                        (thousands)

 ELECTRIC UTILITY PLANT
     Production                                          $418,036     $417,467
     Transmission                                         207,631      200,688
     Distribution                                         360,378      347,328
     General                                              100,543       92,622
     Construction work in progress                         13,761       30,036
                                                       ----------   ----------
                                                        1,100,349    1,088,141

  Less - Accumulated depreciation
         and amortization                                 432,981      414,777
                                                       ----------   ----------
                                                          667,368      673,364
                                                       ----------   ----------

CURRENT ASSETS
     Cash                                                   1,497          664
     Accounts receivable                                   30,864       24,123
     Materials and supplies, at average cost               15,249       15,966
     Fuel inventory                                        14,736       16,674
     Accumulated deferred income taxes                       --          1,079
     Under-recovered fuel costs                            14,438        7,857
     Prepayments and other                                  2,014        2,435
                                                       ----------   ----------
                                                           78,798       68,798
                                                       ----------   ----------

DEFERRED CHARGES AND OTHER ASSETS
     Deferred Oklaunion costs                              19,569       22,365
     Restructuring related regulatory assets                9,438       10,854
     Other                                                 41,068       34,998
                                                       ----------   ----------
                                                           70,075       68,217
                                                       ----------   ----------

                                                         $816,241     $810,379
                                                       ==========   ==========












          The accompanying notes to financial statements as they relate
                to WTU are an integral part of these statements.
<PAGE> 39
                          WEST TEXAS UTILITIES COMPANY

                                 BALANCE SHEETS


                                                      September 30, December 31,
                                                          1997         1996
                                                      (unaudited)    (audited)
                                                        --------     --------
CAPITALIZATION AND LIABILITIES                               (thousands)

CAPITALIZATION
     Common stock:  $25 par value
        Authorized shares: 7,800,000
        Issued and outstanding shares: 5,488,560        $137,214     $137,214
     Paid-in capital                                       2,236        2,236
     Retained earnings                                   131,589      123,077
                                                        --------     --------
                                                         271,039      262,527

     Preferred stock                                       2,483        6,291
     Long-term debt                                      277,748      275,070
                                                        --------     --------
                                                         551,270      543,888
                                                        --------     --------

CURRENT LIABILITIES
     Advances from affiliates                              3,330       14,833
     Payables to affiliates                               11,584       13,578
     Accounts payable                                     20,005       19,669
     Accrued taxes                                        13,566       13,463
     Accrued interest                                      8,682        5,403
     Accumulated deferred income taxes                     3,137         --
     Other                                                 3,524        4,124
                                                        --------     --------
                                                          63,828       71,070
                                                        --------     --------

DEFERRED CREDITS
     Accumulated deferred income taxes                   144,660      144,146
     Investment tax credits                               28,249       29,239
     Income tax related regulatory liabilities, net       16,255       16,918
     Other                                                11,979        5,118
                                                        --------     --------
                                                         201,143      195,421
                                                        --------     --------

                                                        $816,241     $810,379
                                                        ========     ========









          The accompanying notes to financial statements as they relate
                to WTU are an integral part of these statements.
<PAGE> 40
                          WEST TEXAS UTILITIES COMPANY

                            STATEMENTS OF CASH FLOWS
                                   (unaudited)
                                                              Nine Months Ended
                                                                September 30,
                                                             ------------------
                                                                1997     1996
                                                             --------  --------
OPERATING ACTIVITIES                                             (thousands)
     Net Income                                               $25,549   $19,055
     Non-cash Items Included in Net Income
         Depreciation and amortization                         32,286    30,816
         Deferred income taxes and investment tax credits       3,077      (930)
         Utility plant development costs                           58    14,905
         Inventory reserve                                       --       1,103
     Changes in Assets and Liabilities
         Accounts receivable                                   (6,741)    7,960
         Accounts payable                                      (1,163)   (2,456)
         Accrued taxes                                            103     5,117
         Fuel recovery                                         (6,581)   (7,961)
     Other                                                      9,090    (1,165)
                                                             --------  --------
                                                               55,678    66,444
                                                             --------  --------

INVESTING ACTIVITIES
     Construction expenditures                                (21,448)  (28,243)
     Other                                                     (1,008)   (1,290)
                                                             --------  --------
                                                              (22,456)  (29,533)
                                                             --------  --------

FINANCING ACTIVITIES
     Proceeds from issuance of long-term debt                    --      43,368
     Reaquisition of long-term debt                              --     (45,639)
     Redemption of preferred stock                             (2,727)     --
     Change in advances from affiliates                       (11,503)  (15,668)
     Payment of dividends                                     (18,159)  (19,132)
                                                             --------  --------
                                                              (32,389)  (37,071)
                                                             --------  --------

NET CHANGE IN CASH AND CASH EQUIVALENTS                           833      (160)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD                  664       717
                                                             --------  --------
CASH AND CASH EQUIVALENTS AT END OF PERIOD                     $1,497      $557
                                                             ========  ========

SUPPLEMENTARY INFORMATION
     Interest paid less amounts capitalized                   $11,773   $11,563
                                                             ========  ========
     Income taxes paid                                         $9,407    $5,384
                                                             ========  ========





          The accompanying notes to financial statements as they relate
                to WTU are an integral part of these statements.
<PAGE> 41
WEST TEXAS UTILITIES COMPANY
RESULTS OF OPERATIONS


COMPARISON OF THE QUARTERS ENDED SEPTEMBER 30, 1997 AND 1996

         Net income for common stock decreased $0.6 million to $17.6 million for
the third quarter of 1997 from net income of $18.2 million in the third quarter
of 1996. Operating revenues increased for the period, but this increase was
offset by an increase in other operating expenses, as discussed below.

         Electric operating revenues increased $11.7 million, or 10%, in the
third quarter of 1997 compared to the third quarter of 1996 due primarily to a
4% increase in MWH sales. Also contributing to the increase was approximately
$4.9 million in transmission revenues as a result of the January 1997
implementation of open access tariffs in accordance with FERC Order No. 888 and
the Texas Commission rules regarding transmission access and pricing. The impact
on net income of the transmission revenues was almost entirely offset by a
corresponding increase in transmission expense.

         Fuel expense decreased $0.7 million in the third quarter of 1997 when
compared to the same period of 1996. The decrease was due primarily to a 6%
decrease in MWH generation and an increase in economy energy purchases, offset
in part by an increase in average unit fuel costs. Average unit fuel costs
increased from $2.23 per MMbtu in 1996 to $2.42 per MMbtu in the same period of
1997 due to an increase in the spot market price of natural gas. Purchased power
expense increased $7.6 million, or 86%, to $16.6 million in the third quarter of
1997 when compared to the third quarter of 1996 due primarily to the Oklaunion
power plant being out of service for several days as well as increased economy
energy purchases due to higher spot market natural gas prices.

         Other operating expenses increased approximately $4.8 million, or 30%,
for the third quarter of 1997 compared to the third quarter of 1996. The
increase was due primarily to a $4.2 million increase in transmission expenses
as a result of the January 1997 implementation of open access tariffs in
accordance with FERC Order No. 888 and the Texas Commission rules regarding
transmission access and pricing.


COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 1997 AND 1996

         For the first nine months of 1997, net income for common stock
increased to $26.5 million from $18.9 million in 1996. The increase resulted
primarily from the absence in 1997 of a one-time charge incurred in 1996
associated with certain investments for plant sites, engineering studies and
lignite reserves of approximately $10.9 million, net of tax, and the gain on
reacquisition of preferred stock of $1.1 million recognized in 1997.

         Electric operating revenues increased approximately $13.2 million, or
4%, in the first nine months of 1997 compared to 1996. The increase was due
primarily to $13.9 million in additional transmission revenues as a result of
the January 1997 implementation of open access tariffs in accordance with FERC
Order No. 888 and the Texas Commission rules regarding transmission access and
pricing. The impact on net income of the transmission revenues was largely
offset by a corresponding $12.5 million increase in transmission expense related
to these tariffs and rules. Also contributing to the increase was $2.5 million
in additional fuel revenues due to higher purchased power expenses as discussed
below.
<PAGE> 42
         Fuel expense decreased $8.6 million, or 8%, for the first nine months
of 1997 compared to 1996 due primarily to lower-priced spot coal and a 20%
decrease in natural gas generation. Purchased power expenses increased
approximately $13.5 million for the first nine months of 1997 as compared to
1996, primarily as a result of additional economy purchases at a higher cost per
MWH.

         Other operating expenses increased approximately $13.2 million for the
first nine months of 1997 compared to 1996 due primarily to a $12.5 million
increase in transmission expenses as a result of the January 1997 implementation
of open access tariffs in accordance with FERC Order No. 888 and the Texas
Commission rules regarding transmission access and pricing. Partially offsetting
the increase in other operating expenses was a decrease in pension expense. See
NOTE 7. PENSION PLAN AMENDMENT for additional information related to changes in
the pension plan. Income taxes decreased $2.0 million in the first nine months
of 1997 compared to the same period a year ago due primarily to lower taxable
income in 1997.

         Other income and deductions increased $10.7 million for the first nine
months of 1997 compared with 1996 as a result of the absence in 1997 of a
one-time charge incurred in 1996 associated with certain investments for plant
sites, engineering studies and lignite reserves of approximately $10.9 million,
net of tax.

<PAGE> 43


INDEX TO APPLICABLE NOTES TO FINANCIAL STATEMENTS
BY REGISTRANT





NOTE 1.      PRINCIPLES OF PREPARATION       CSW, CPL, PSO, SWEPCO, WTU

NOTE 2.      LITIGATION AND REGULATORY       CSW, CPL, PSO, SWEPCO, WTU
             PROCEEDINGS

NOTE 3.      COMMITMENTS AND CONTINGENT
             LIABILITIES                     CSW, CPL, SWEPCO

NOTE 4.      COMMON STOCK AND DIVIDENDS      CSW, CPL, PSO, SWEPCO, WTU

NOTE 5.      INCOME TAXES                    CSW, CPL, PSO, SWEPCO, WTU

NOTE 6.      LONG-TERM FINANCING             CSW, CPL, PSO, SWEPCO, WTU

NOTE 7.      PENSION PLAN AMENDMENT          CSW, CPL, PSO, SWEPCO, WTU

NOTE 8.      DISCONTINUED OPERATIONS         CSW

NOTE 9.      EXTRAORDINARY ITEM              CSW

<PAGE> 44


NOTES TO FINANCIAL STATEMENTS
(UNAUDITED)


1.  PRINCIPLES OF PREPARATION

         The condensed financial statements of the Registrants included herein
have been prepared by each Registrant pursuant to the rules and regulations of
the SEC. Certain information and note disclosures normally included in financial
statements prepared in accordance with generally accepted accounting principles
have been condensed or omitted pursuant to such rules and regulations, although
each Registrant believes that the disclosures are adequate to make the
information presented not misleading. These condensed financial statements
should be read in conjunction with the financial statements and the notes
thereto included in the Registrants' Combined Annual Report on Form 10-K for the
year ended December 31, 1996 and the Registrants' Combined Quarterly Reports on
Form 10-Q for the quarters ended March 31, 1997 and June 30, 1997.

         The unaudited financial information furnished herewith reflects all
adjustments which are, in the opinion of management of such Registrant,
necessary for a fair statement of the results of operations for the interim
periods. Information for quarterly periods is affected by seasonal variations in
sales, rate changes, timing of fuel expense recovery and other factors.

         The financial statements of SEEBOARD and its related entities have been
translated from British pounds to U.S. dollars in accordance with SFAS No. 52.
SFAS No. 52 requires the translation of income statement items at average rates
and balance sheet accounts at current rates. All resulting translation
adjustments are recorded directly to Foreign currency translation adjustment on
CSW's consolidated balance sheets.

         Effective January 1, 1997, CPL and WTU began utilizing the LIFO method
for the valuation of all fossil fuel inventories. Previously, CPL had used the
weighted average cost method and WTU had used the LIFO method for coal and the
weighted average cost method for other fuel inventories. PSO utilizes the LIFO
method. SWEPCO continues to utilize the weighted average cost method pending
approval of the Arkansas Public Service Commission to utilize the LIFO method.
The change in accounting did not affect the results of operations due to the
regulatory treatment of such costs.

         Cash equivalents are considered to be highly liquid debt instruments
purchased with a maturity of three months or less. Accordingly, temporary cash
investments and advances to affiliates are considered cash equivalents.

         Certain financial statement items for prior years have been
reclassified to conform to the 1997 presentation.


2.  LITIGATION AND REGULATORY PROCEEDINGS

         See the Registrants' Combined Annual Report on Form 10-K for the year
ended December 31, 1996 and the Registrants' Combined Quarterly Reports on Form
10-Q for the periods ended March 31, 1997 and June 30, 1997 for additional
discussion of litigation and regulatory proceedings. Reference is also made to
NOTE 3. COMMITMENTS AND CONTINGENT LIABILITIES, MD&A - RATES AND REGULATORY
MATTERS, CPL RATE REVIEW - DOCKET NO. 14965 and PSO 1997 RATE SETTLEMENT
<PAGE> 45
AGREEMENT and also to PART II - OTHER INFORMATION, ITEM 1. for additional 
discussion of litigation and regulatory matters.

         SETTLEMENT OF LITIGATION RELATED TO TERMINATION OF EL PASO MERGER
         In May 1993, CSW entered into a merger agreement pursuant to which El 
Paso would have emerged from bankruptcy as a wholly owned subsidiary of CSW.
In June 1995, following its notification that CSW was terminating the Merger 
Agreement, El Paso filed suit against CSW seeking a $25 million termination fee
from CSW, unspecified damages for various contract and tort claims, punitive 
damages, interest as permitted by law and certain other costs. Subsequently, CSW
filed suit against El Paso seeking a $25 million termination fee from El Paso 
based on El Paso's alleged breach of the Merger Agreement, at least $3.6 million
in rate case expenses incurred by CSW on behalf of El Paso related to state 
regulatory merger proceedings and a declaratory judgment that CSW properly 
terminated the Merger Agreement. In June 1996, CSW filed an amended complaint 
seeking a first priority administrative expense claim of $50 million from El 
Paso based upon El Paso's alleged breach of the Merger Agreement.

         The United States Bankruptcy Court for the Western District of Texas,
Austin Division, consolidated the El Paso suit and the CSW suit into one
adversary proceeding and the trial was completed on January 30, 1997. On April
11, 1997, the court issued an interim order in which it ruled that CSW owed El
Paso a $25 million termination fee pursuant to the terms of the Merger
Agreement. The court reserved judgment on CSW's liability for interim interest
on the termination fee.

         In July 1997, CSW and El Paso reached a settlement agreement that
resolved all of the pending litigation resulting from the termination of the
proposed merger. Under the terms of the settlement agreement, CSW and El Paso
agreed to dismiss all pending claims in the litigation and give a mutual release
from any potential claims related to the Merger Agreement or the pending
litigation, and CSW paid $35 million to El Paso, various of its creditor groups
under its plan of reorganization, and its attorneys. CSW recorded a charge of
$25 million in the first quarter of 1997 following the court's interim order and
recorded an additional charge of $10 million in the second quarter of 1997 to
fully recognize the $35 million settlement amount. The bankruptcy court vacated
the interim order and approved the settlement agreement.

         CPL RATE REVIEW - DOCKET NO. 14965
         As previously reported, in November 1995, CPL filed with the Texas
Commission a request to increase its retail base rates by $71 million, and in
May 1996, CPL placed a $70 million base rate increase into effect under bond,
subject to refund based on the receipt of a final order of the Texas Commission.
On March 31, 1997, the Texas Commission issued the CPL 1997 Original Rate Order
in CPL's Rate Review, Docket No. 14965. Thereafter, CPL filed a motion for
rehearing which requested the reconsideration of numerous provisions of the
order. Motions for rehearing were also filed by other parties to the rate
proceeding. In response to the motions for rehearing, in June 1997, the Texas
Commission made several modifications to the CPL 1997 Original Rate Order and
also agreed to rehear on remand several other issues. CPL restored its rates in
July 1997, with two exceptions, to levels existing prior to the May 1996
implementation of bonded rates. On August 21, 1997, after reconsidering the
issues on remand, the Texas Commission voted to issue a revised final order and
on September 10, 1997, CPL received the CPL 1997 Final Order. CPL filed its
second motion for rehearing on September 30, 1997. The second motion for
rehearing again requested reconsideration of numerous issues in the rate case.
On October 16, 1997 the Texas Commission issued its second revised final order.
This order lowers the annual retail base rates of CPL by approximately $19
million, or 2.5%, from CPL's rate level existing prior to May 1996. The Texas
Commission also included a "Glide Path" rate methodology in the CPL 1997 Final
<PAGE> 46
Order pursuant to which CPL's annual rates will be reduced by an additional $13
million in mid-1998 and another $13 million in mid-1999.

         The CPL 1997 Original Rate Order established a separate docket, Docket
No. 17280, to consider the recoverability of $20 million of rate case expenses
incurred in the current rate case and in two prior dockets. CPL reached a
settlement with all parties to resolve Docket No. 17280 which provides for CPL
to recover $14 million out of the total $20 million of rate case expenses
originally requested. Approximately $8 million of the rate case expenses will be
recovered as an offset to the refund in the rate case, and the remaining $6
million of expenses will be surcharged to customers over three years. CPL
expensed the $6 million in foregone rate case expenses during the first quarter
of 1997.

         As previously stated, CPL implemented bonded rates subject to refund in
May 1996. On July 17, 1997, CPL restored its rates, with two exceptions, to
levels existing prior to the implementation of the bonded rates. The two
exceptions are for industrial interruptible rates and customer service charges
for which the Texas Commission approved the increases requested by CPL. On
October 31, 1997, CPL filed with the Texas Commission a proposed methodology for
issuing an interim $41.5 million refund to customers in December 1997. A second
refund, currently estimated at $29.2 million, is proposed for March 1998.
Because of the existence of several different components that are all
incorporated into the December 1997 refund to be made to customers, a breakdown
of the December 1997 refund, as well as the estimated March 1998 refund as
currently proposed by CPL, is shown here (in millions).

 December 1997
  Base rate refund (with interest)                                  $78.4
  Surcharge for rate case expenses                                  (13.3)
  Surcharge for fuel cost under-recovery                            (23.6)
                                                                  -------
     Net refund to customers                                        $41.5
                                                                  -------

 March 1998 (estimated)
  Amount collected from customers under bond                        $62.7
  Anticipated surcharge for fuel cost under-recovery                (33.5)
                                                                  -------
     Net refund to customers                                        $29.2
                                                                  -------

         The following table details the financial impact of the CPL 1997 Final
Order as compared to the rates existing prior to CPL placing bonded rates into
effect. Although the entire impact has been recorded in CPL's 1997 results of
operations, the breakdown between the retroactive impact as it relates to 1996
and for the nine months ended September 30, 1997 is as follows.

                                                  1996          1997 Only
                                               Retroactive        Impact
                                                  Impact        To 9/30/97
                                                ------------------------
                                                        (millions)

         Decrease in revenue                      $(15.8)         $(15.1)
                                                --------        --------

         Items included in decrease in 
           revenue with an offsetting 
           effect on expense:
             Accelerated recovery of STP (ECOM)     13.3            15.0
             Change in depreciation                 (4.6)           (5.5)
             Decommissioning                         1.9             3.2
             Other                                    --             5.3
                                                --------        --------
                                                    10.6            18.0
                                                --------        --------
         Change in current year income 
           before tax                              (26.4)          (33.1)
         Federal income taxes                        8.7            10.9
                                                --------        --------
         Impact on net income - all recorded 
           in 1997                                $(17.7)         $(22.2)
                                                --------        --------

<PAGE> 47

         CPL will likely appeal the CPL 1997 Final Order to the Texas State
District Court by the end of 1997 to challenge the resolution of several issues
in the rate case after the rehearing process has concluded. The primary issues
include: (i) the classification of $800 million of invested capital in STP as
ECOM which was also assigned a lower return on equity than non-ECOM property,
(ii) the Texas Commission's use of the "Glide Path" rate reduction methodology
to be applied to rates in mid-1998 and mid-1999, and (iii) the $18 million of
disallowed affiliate transactions from CSW Services. Management is unable to
predict how the final resolution of these issues will ultimately affect CSW's
and CPL's results of operations and financial condition.

         See MD&A - RATES AND REGULATORY MATTERS, CPL RATE REVIEW - DOCKET NO.
14965 for additional discussion of the CPL 1997 Final Order, including the
estimated ongoing financial impact of the final order and information regarding
the difference between the rates originally requested by CPL and those ordered
by the Texas Commission.

         CPL FUEL PROCEEDING
         As previously reported, CPL filed with the Texas Commission an
Application for Authority to Implement an increase in fuel factors of $34.4
million, or 15.4%, on an annual basis. In addition, CPL proposed to implement a
fuel surcharge of $23.4 million, including accumulated interest, over a twelve
month period. On February 10, 1997, CPL filed a stipulation with the Texas
Commission which would surcharge customers the $23.4 million and would
coordinate the surcharge with any refund in CPL's current rate case as described
in CPL RATE REVIEW - DOCKET NO. 14965. In the stipulation, CPL's fuel factors
were increased approximately $29.4 million, or 13.2%, on an annual basis. The
Texas Commission's interim approval of the stipulated fuel factors permitted a
March 1997 implementation of the fuel factors. The CPL 1997 Original Rate Order
confirmed the stipulated fuel factors.

         PSO 1997 RATE SETTLEMENT AGREEMENT
         On October 15, 1997, PSO reached a stipulated agreement with parties to
settle the rate inquiry that was pending before the Oklahoma Commission and on
October 23, 1997, a final order approving the settlement was issued by the
Oklahoma Commission. The PSO 1997 Rate Settlement Agreement calls for PSO to
lower its retail base rates beginning with the December 1997 billing cycle by
approximately $35.9 million annually, or a 5.3 percent decrease below the
current level of retail rates. Part of the rate reduction includes a reduction
in annual depreciation expense of approximately $10.9 million. In addition, the
PSO 1997 Rate Settlement Agreement will result in PSO making a one-time $29
million refund to customers, which is expected to be made to customers in
December 1997.

         Through the third quarter of 1997, PSO has recorded the estimated
financial impact of the PSO 1997 Rate Settlement Agreement, including
recognition of the full $29 million refund obligation. The PSO 1997 Rate
Settlement Agreement also provides that PSO completely eliminate or amortize
before its next rate filing approximately $41 million in certain deferred
assets, approximately $26 million of which had been expensed in 1996. Included
in the remaining $15 million of deferred assets are approximately $9 million of
costs incurred for customer energy management incentive programs. PSO is
continuing to analyze the implications of the PSO 1997 Rate Settlement
Agreement. For additional discussion of the PSO rate proceeding, including the
estimated financial impact of the PSO 1997 Rate Settlement Agreement, see MD&A -
RATES AND REGULATORY MATTERS, PSO 1997 RATE SETTLEMENT AGREEMENT.

         SWEPCO FUEL PROCEEDING
         In April 1997, SWEPCO filed with the Texas Commission an application
concerning fuel cost under-recoveries and a possible fuel surcharge which
included a motion to either abate the requested interim surcharge and
<PAGE> 48
consolidate the surcharge with a filed fuel reconciliation as discussed below,
or alternatively, implement an interim surcharge in the months of July 1997
through June 1998. The Texas Commission's Office of Policy Development, on
behalf of the Texas Commission, approved such consolidation. In addition, the
Texas Commission has waived the requirement for SWEPCO to file biannual
surcharge requests while this proceeding is pending, and has deferred the
implementation of any surcharge and interest until after final disposition.

         In May 1997, SWEPCO filed with the Texas Commission an application to
reconcile fuel costs and implement a 12 month surcharge of fuel cost
under-recoveries. Because of the uncertainty as to when a surcharge may
commence, SWEPCO did not establish a proposed surcharge period or a total
surcharge amount which would reflect interest through the entire surcharge
period in its filing. In its filing, SWEPCO indicated that it had an
under-recovered Texas jurisdictional fuel cost balance of approximately $16.8
million, including interest, through December 1996. Included in the $16.8
million balance are fuel related litigation expenses of $5.0 million and an
interest return of $2.0 million on the unamortized balance of a fuel contract
termination payment.

         In November 1997, SWEPCO and the other parties to the above
consolidated proceedings before the Texas Commission agreed to a settlement in
principle except for one issue which will be decided by the Texas Commission.
The settlement in principle is subject to the development of a comprehensive
settlement agreement and approval by the Texas Commission. Of the $16.8 million
in under-recovered fuel costs as of December 31, 1996, the settlement in
principle would result in a decrease of the under-recovered fuel costs, and the
resulting surcharge recovery, by approximately $6.0 million. This disallowance
will not result in an increase to fuel expense since the $5.0 million of
litigation expense and the interest return of $2.0 million included in the
requested surcharge amount were previously expensed. The settlement in principle
also finds SWEPCO's fuel and fuel-related expenses attributable to the
reconciliation period reasonable and necessary and would allow them to be
reconciled as eligible fuel. In addition, the settlement in principle finds
SWEPCO's actions in litigating and renegotiating certain fuel and fuel-related
contracts, together with the prices, terms and condition of the renegotiated
contracts, to be prudent. The $6.0 million reduction is not associated with any
particular activity or issue within the fuel proceedings. SWEPCO cannot state
with certainty that a comprehensive settlement agreement will be completed or
that approval will be granted by the Texas Commission.

         WTU FUEL PROCEEDING
         As previously reported, in February 1997, WTU filed with the Texas
Commission an Application for Authority to Implement an increase in fuel factors
of $4.2 million, or 4.2%, on an annual basis. Additionally, WTU proposed to
implement a fuel surcharge of $13.3 million, including accumulated interest,
over a twelve month period to collect its under-recovered fuel costs. WTU
requested authority to implement the revised fuel factors with its May 1997
billings and to commence the surcharge with its June 1997 billings. On April 14,
1997, an agreement in principle was reached among the parties to settle this
docket. Under the proposed settlement, WTU agreed not to increase the fuel
factors and to implement the $13.3 million surcharge over the period June 1997
through February 1999. The Texas Commission approved this settlement in May
1997.

         CPL INDUSTRIAL ROAD AND INDUSTRIAL METALS SITE
         As previously reported, three suits naming CPL and others as defendants
relating to a third-party owned and operated site in Corpus Christi, Texas
formerly used for commercial reclamation of used electrical transformers, lead
acid batteries and other scrap metals, were pending in federal and state court
in Corpus Christi, Texas. The plaintiffs' complaints sought damages for alleged
property damage and health impairment as a result of operations on the site and
<PAGE> 49
cleanup activities. During 1997, CPL settled these suits with no material
adverse effect on CPL's results of operation or financial condition.

         PSO SAND SPRINGS/GRANDFIELD, OKLAHOMA SITES
         As previously reported, in 1989, PSO found some PCB contamination in a
Sand Springs, Oklahoma PCB storage facility. The EPA-approved cleanup began in
1994. In 1996, the EPA filed a complaint against PSO alleging that PSO failed to
comply with provisions of the Toxic Substances Control Act. The complaint has
three counts, two of which pertain to the Sand Springs facility and the third of
which deals with a substation in Grandfield, Oklahoma. The EPA alleges improper
disposal of PCBs at the Sand Springs site due to the length of time between
discovery of the contamination and the actual cleanup at the site. The complaint
at the Grandfield site alleges failure to date PCB articles at the site. The
total proposed penalty for the three counts, which has been accrued by PSO, was
$479,000. PSO settled two of the three complaints for a total amount of $7,000.
However, PSO has been unable to resolve the third count. A hearing before an EPA
administrative law judge to hear PSO's response on the single remaining count
has been scheduled for January 1998, and PSO intends to vigorously defend itself
against the allegations the EPA has asserted. Although PSO is unable to predict
the outcome of this matter, PSO believes that the resolution of this matter will
not have a material adverse effect on PSO's results of operation or financial
condition.


3.  COMMITMENTS AND CONTINGENT LIABILITIES

         CPL DEFERRED ACCOUNTING
         By orders issued in 1989 and 1990, the Texas Commission authorized CPL
to defer certain STP Unit 1 and Unit 2 costs incurred between the commercial
operation dates of those units and the effective date of rates reflecting the
operation of those units. Upon appeal of the 1989 CPL order, and a related order
involving another utility, the Supreme Court of Texas in 1994 sustained deferred
accounting as an appropriate mechanism for the Texas Commission to use in
preserving the financial integrity of CPL, but remanded CPL's case to the Court
of Appeals to consider certain substantial evidence points of error not
previously decided by the Court of Appeals. On August 16, 1995, the Court of
Appeals rendered its opinion in the remand proceeding and affirmed the Texas
Commission's order in all respects.

         By orders issued in October 1990 and December 1990, the Texas
Commission quantified the STP Unit 1 and Unit 2 deferred accounting costs and
authorized the inclusion of the amortization of the costs and associated return
in CPL's retail rates. These Texas Commission orders were appealed to the Travis
County District Court, where the appeals are still pending. Language in the
opinion of the Supreme Court of Texas on the appeal of the deferred accounting
authorization case suggests that the appropriateness of including deferred
accounting costs in rates charged to customers is dependent on a finding, in the
first case in which the deferred STP costs are to be recovered through rates,
that the deferral was actually necessary to preserve the utility's financial
integrity. If, in the appeals of the October 1990 and December 1990 rate orders,
the courts decide that subsequent review under the financial integrity standard
is required and was not made in those orders, then such rate orders would be
remanded to the Texas Commission for the purpose of entering findings applying
the financial integrity standard. Pending the ultimate resolution of CPL's
deferred accounting issues, CPL is unable to predict how its deferred accounting
orders will ultimately be resolved by the Texas Commission.

         If CPL's deferred accounting matters are not favorably resolved, CSW
and CPL could experience a material adverse effect on their respective results
of operations and financial condition. While CPL's management is unable to
predict the ultimate outcome of these matters, management believes either CPL
<PAGE> 50
will receive approval of its deferred accounting amounts or CPL will be
successful in renegotiation of its rate orders, so that there will be no
material adverse effect on CSW's or CPL's results of operations or financial
condition.

         CPL NUCLEAR INSURANCE
         In connection with the licensing and operation of STP, the owners have
purchased nuclear property and liability insurance coverage as required by law,
and have executed indemnification agreements with the Nuclear Regulatory
Commission in accordance with the financial protection requirements of the
Price-Anderson Act. The Price-Anderson Act, a comprehensive statutory
arrangement providing limitations on nuclear liability and governmental
indemnities, is in effect until August 1, 2002. The limit of liability under the
Price-Anderson Act for licensees of nuclear power plants is $8.92 billion per
incident, effective as of December 1996. The owners of STP are insured for their
share of this liability through a combination of private insurance amounting to
$200 million and a mandatory industry-wide program for self-insurance totaling
$8.72 billion. The maximum amount that each licensee may be assessed under the
industry-wide program of self-insurance following a nuclear incident at an
insured facility is $75.5 million per reactor, which may be adjusted for
inflation, plus a five percent charge for legal expenses, but not more than $10
million per reactor for each nuclear incident in any one year. CPL and each of
the other STP owners are subject to such assessments, which CPL and the other
owners have agreed will be allocated on the basis of their respective ownership
interests in STP. CPL has a 25.2% ownership interest in STP. For purposes of
these assessments, STP has two licensed reactors.

         The owners of STP currently maintain on-site decontamination liability
and property damage insurance in the amount of $2.75 billion provided by ANI and
NEIL. Policies of insurance issued by ANI and NEIL stipulate that policy
proceeds must be used first to pay decontamination and cleanup costs before
being used to cover direct losses to property. Under project agreements, CPL and
the other owners of STP will share the total cost of decontamination liability
and property insurance for STP, including premiums and assessments, on a pro
rata basis, according to each owner's respective ownership interest in STP.

         CPL purchased, for its own account, a NEIL I Business Interruption
and/or Extra Expense policy. This insurance will reimburse CPL for extra
expenses incurred for replacement generation or purchased power as a result of a
covered accident that shuts down production at one or both of the STP Units for
more than 21 consecutive weeks. In the event of an outage of STP Units 1 and 2
and the outage is the result of the same accident, such insurance will reimburse
CPL up to 80% of the single unit recovery. The maximum amount recoverable for a
single unit outage is $118.6 million for both Units 1 and 2. CPL is subject to
an additional assessment of up to $1.8 million for the current policy year in
the event insured losses at a nuclear facility covered under the NEIL I policy
exceed the accumulated funds available under the policy.

         SWEPCO BILOXI, MISSISSIPPI MANUFACTURED GAS PLANT SITE
         As previously reported, SWEPCO was notified by Mississippi Power in
1994 that it may be a PRP at a MGP site in Biloxi, Mississippi, which was
formerly owned and operated by a predecessor of SWEPCO. Since then, SWEPCO has
worked with Mississippi Power on both the investigation of the extent of
contamination on the site as well as on the subsequent sampling of the site. The
sampling results indicated contamination at the property as well as the
possibility of contamination of an adjacent property. A risk assessment was
submitted to the MDEQ, and the MDEQ requested that a future residential exposure
scenario be evaluated for comparison with commercial and industrial exposure
scenarios. However, Mississippi Power and SWEPCO do not believe that cleanup to
a residential scenario is appropriate since this site has been
industrial/commercial for more than 100 years, and Mississippi Power plans to
<PAGE> 51
continue this type of usage. Mississippi Power and SWEPCO also presented a
report to the MDEQ demonstrating that the ground water on the site was not
potable, further demonstrating that cleanup to residential standards is not
necessary.

         The MDEQ has not agreed to a non-residential future land use scenario
and has requested further testing. Following the additional testing and
resolution of whether cleanup is necessary to meet a residential usage scenario
or if cleanup to a commercial/industrial scenario is appropriate, a feasibility
study will be conducted to more definitively evaluate remedial strategies for
the property. The feasibility study process will require public input prior to a
final decision being made.

         At the present time, SWEPCO has not had any further substantive
discussions with MDEQ regarding the ultimate resolution of this issue.
Therefore, a final range of cleanup costs is not determinable at this time.
Based on its preliminary estimates, SWEPCO has incurred approximately $200,000
to date for its portion of the cleanup of this site and anticipates that an
additional $2 million may be required. Accordingly, SWEPCO has accrued $2
million for the cleanup of the site.

         SWEPCO VODA PETROLEUM SUPERFUND SITE
         As previously reported, in April 1996, SWEPCO received correspondence
from the EPA notifying SWEPCO that it is a PRP to a cleanup action planned for
the Voda Petroleum Superfund Site located in Clarksville, Texas. SWEPCO is
conducting a records review to compile documentation relating to SWEPCO's past
use of the Voda Petroleum site. The proposed cleanup of the site is estimated by
the EPA to cost approximately $2 million and to take approximately twelve months
to complete. An option for over 30 PRPs to conduct the cleanup in lieu of EPA
conducting the cleanup is under consideration. Any SWEPCO liability associated
with this project is not expected to have a material adverse effect on its
results of operations or financial condition.

         SWEPCO HENRY W. PIRKEY POWER PLANT
         In connection with the South Hallsville lignite mining contract for its
Henry W. Pirkey Power Plant, SWEPCO has agreed, under certain conditions, to
assume the obligations of the mining contractor. As of September 30, 1997, the
maximum amount SWEPCO would have to assume was $60.3 million. The maximum amount
may vary as the mining contractor's need for funds fluctuates. The contractor's
actual obligation outstanding as of September 30, 1997 was $55.6 million.

         SWEPCO SOUTH HALLSVILLE LIGNITE MINE
         As part of the process to receive renewal of a Texas Railroad
Commission permit for lignite mining at the South Hallsville lignite mine and
expansion into the Marshall South Lignite Project area, SWEPCO has agreed to
provide guarantees of mine reclamation in the amount of $85 million. Since
SWEPCO uses self-bonding, the guarantee provides for SWEPCO to commit to use its
resources to complete the reclamation in the event the work is not completed by
the third party miner. The current cost to reclaim the mine is estimated to be
approximately $36 million.


4.  COMMON STOCK AND DIVIDENDS

         CSW's earnings per share of common stock are computed by dividing net
income for common stock by the average number of common shares outstanding for
the respective periods. CSW's dividends per common share reflect per share
amounts paid for each of the periods. See MD&A - LIQUIDITY AND CAPITAL 
RESOURCES, CAPITAL STRUCTURE for information related to CSW's common stock.
<PAGE> 52
         At September 30, 1997, approximately $1.4 billion of CSW's subsidiary
companies' retained earnings were available for payment of cash dividends by
such subsidiaries to CSW. The mortgage indentures, as amended and supplemented,
at CPL and PSO contain certain restrictions on the use of their retained
earnings for cash dividends on their common stock. These restrictions do not
currently limit the ability of CSW to pay dividends to its shareholders. The
amounts of retained earnings available for dividends attributable to each the
U.S. Electric Operating Companies at September 30, 1997 is as follows.

        CPL - $768 million  PSO - $162 million  SWEPCO - $349 million   
                            WTU - $132 million


5.  INCOME TAXES

         The following tables provide a reconciliation of the differences
between total income tax expense (income taxes included in Operating Expenses
and Taxes as well as Other Income and Deductions) at the federal statutory tax
rate and the effective tax rate for the Registrants.

                                     CSW      CPL      PSO     SWEPCO     WTU
                                   --------------------------------------------
                                  (millions)           (thousands)
                                            -----------------------------------
QUARTER ENDED SEPTEMBER 30, 1997
Income before taxes and extraordinary 
  item attributable to:
    Domestic operations              $269
    Foreign operations                 15
                                     ----
Income before taxes                  $284   $127,785  $49,597  $73,521  $26,620

Tax at U.S. statutory rate            $99    $44,725  $17,359  $25,732   $9,317
Differences
  Amortization of ITC                  (2)      (622)     (46)  (1,165)    (330)
  Non-deductible goodwill
    amortization                        3         --       --       --       --
  United Kingdom deferred
    income tax adjustment             (15)        --       --       --       --
  Prior period adjustments             --         --       --      150       --
  Other                                (2)     1,455      865   (2,144)     (46)
                                      -----------------------------------------
Tax expense                           $83    $45,558  $18,178  $22,573   $8,941
                                      -----------------------------------------

Effective tax rate                    29%        36%      37%      31%      34%


QUARTER ENDED SEPTEMBER 30, 1996 
Income before taxes attributable to:
   Domestic operations               $280
   Foreign operations                  22
                                      ---   
Income before taxes                  $302   $125,507  $72,022  $61,634  $27,473

Tax at U.S. statutory rate           $106    $43,927  $25,208  $21,572   $9,616
 Differences
   Amortization of ITC                 (4)    (1,447)    (696)  (1,182)    (330)
   Non-deductible goodwill
     amortization                       3         --       --       --       --
   Prior period adjustments            (3)    (3,000)      --       --       --
   Other                                6      3,425    2,501      548      (33)
                                      -----------------------------------------
 Tax expense                         $108    $42,905  $27,013  $20,938   $9,253
                                      -----------------------------------------

 Effective tax rate                   36%        34%      38%      34%      34%

<PAGE> 53
                                     CSW      CPL      PSO     SWEPCO     WTU
                                   --------------------------------------------
                                  (millions)           (thousands)
                                            -----------------------------------
 NINE MONTHS ENDED SEPTEMBER 30, 1997
Income before taxes and extraordinary 
  item attributable to:
    Domestic operations              $363
    Foreign operations                 74
                                      ---
Income before taxes                  $437   $180,921  $79,826 $129,107  $37,598

Tax at U.S. statutory rate           $153    $63,322  $27,939  $45,187  $13,159
Differences
  Amortization of ITC                  (9)    (3,517)  (1,438)  (3,497)    (991)
  Non-deductible goodwill
    amortization                        9         --       --       --       --
  United Kingdom deferred
    income tax adjustment             (15)        --       --       --       --
  Prior period adjustments             (2)    (1,720)    (261)     102     (123)
  Other                                (4)     5,651    1,121   (3,555)       7
                                      -----------------------------------------
Tax expense                          $132    $63,736  $27,361  $38,237  $12,052
                                      -----------------------------------------

Effective tax rate                    30%        35%      34%      30%       32%


NINE MONTHS ENDED SEPTEMBER 30, 1996 
Income before taxes attributable to:
   Domestic operations               $532
   Foreign operations                  94
                                      ---
Income before taxes                  $626   $212,202  $55,064  $89,925  $29,089

Tax at U.S. statutory rate           $219    $74,271  $19,272  $31,474  $10,181
 Differences
   Amortization of ITC                (11)    (4,342)  (2,088)  (3,547)    (991)
   Non-deductible goodwill
     amortization                       9         --       --       --       --
   State Income Taxes from
     the Sale of Transok                7         --       --       --       --
   Permanent effect of reserves
     for property development
     costs                              9      1,390    4,382    2,330      977
   Prior period adjustments            --        198      549      269      143
   Other                               11      6,657      677   (1,414)    (276)
                                      -----------------------------------------
 Tax expense                         $244    $78,174  $22,792  $29,112  $10,034
                                      -----------------------------------------

 Effective tax rate                   39%        37%      41%      32%      34%


6.  LONG-TERM FINANCING

         The following trust preferred securities issued by the wholly-owned
statutory business trusts of CPL, PSO and SWEPCO were outstanding at September
30, 1997. They are classified on the balance sheets as Subsidiary obligated,
mandatorily redeemable, trust preferred securities.

                                             Amount   Description of Underlying
Business Trust     Security       Units    (millions)  Debentures of Registrant
--------------------------------------------------------------------------------

CPL Capital I    8.00%, Series A  6,000,000    $150    CPL, $154.6 million, 
                                                         8.00%, Series A
PSO Capital I    8.00%, Series A  3,000,000      75    PSO, $77.3 million, 
                                                         8.00%, Series A
SWEPCO Capital I 7.875%, Series A 4,400,000     110    SWEPCO, $113.4 million, 
                                                         7.875%, Series A
                                 ----------    ----
                                 13,400,000    $335
                                 ----------    ----
        
         Each of the business trusts will be treated as a subsidiary of its
parent company. The only assets of the business trusts are the subordinated
<PAGE> 54
debentures issued by their parent company as specified above. In addition to the
obligations under their subordinated debentures, each of the parent companies
has also agreed to a security obligation which represents a full and
unconditional guarantee of its capital trust's obligation.

         Through the third quarter of 1997, each of the U.S. Electric Operating
Companies had reacquired a significant portion of its outstanding preferred
stock. As a result of differences between the coupon rates on the reacquired
securities and prevailing market rates, CSW realized an overall gain of
approximately $10 million on the transactions. This gain is shown separately, as
Gain on reacquired preferred stock, on the statements of income. The following
table shows the results of the tender offers of the U.S. Electric Operating
Companies' preferred stock.

                                                Shares       Shares
                                              Reacquired    Remaining
                                             ------------ -------------
     CPL
        Series 4.00%                            57,952        42,048
        Series 4.20%                            57,524        17,476
        Series 7.12%                           260,000            --
        Series 8.72%                           500,000            --

     PSO
        Series 4.00%                            53,260        44,640
        Series 4.24%                            91,931         8,069

     SWEPCO
        Series 4.28%                            52,614         7,386
        Series 4.65%                            23,092         1,908
        Series 5.00%                            37,240        37,760
        Series 6.95%                            65,990       274,010

     WTU
        Series 4.40%                            36,323        23,677


7.  PENSION PLAN AMENDMENT

         CSW maintains a tax qualified, non-contributory defined benefit pension
plan covering substantially all CSW employees in the United States. The CSW
board of directors approved an amendment, effective July 1, 1997, which converts
the existing pension plan into a cash balance pension plan. The purpose of the
plan change is to continue to provide retirement income benefits which are
competitive both within the utility industry as well as with other companies
within the United States.

         As the plan sponsor, CSW will continue to reflect the costs of the
pension plan according to the provisions of SFAS No. 87 and allocate such costs
to each of the participating employers. As a result of the July 1, 1997
amendment, preliminary estimates indicate that CSW will realize a savings in
1997 of approximately $20 million in pension expense and will also realize
significant ongoing reductions in operating and maintenance expense because of
the change. The change to the pension plan was applied retroactively to the
beginning of 1997, so these savings are being recognized evenly throughout 1997
with a portion being capitalized. The projected amounts of savings attributable
to the U.S. Electric Operating Companies for 1997 are as follows.

CPL - $5.0 million PSO - $3.9 million SWEPCO - $4.5 million  WTU - $2.7 million

<PAGE> 55

8.  DISCONTINUED OPERATIONS

         On June 6, 1996, CSW sold Transok, an intrastate natural gas pipeline
and gas marketing company that was previously a wholly owned subsidiary of CSW,
to Tejas Gas Corporation. Accordingly, the results of operations for Transok
have been reported as discontinued operations and no assets or liabilities
related to Transok are contained in CSW's Consolidated Balance Sheets. Since
Transok was sold in June 1996, CSW's results of operations do not reflect any
earnings from Transok for either the three or nine month periods ended September
30, 1997, nor do they reflect any earnings for the three month period ended
September 30, 1996. Operating results of Transok that are included in CSW's
Statements of Income for the nine month period ended September 30, 1996 are
summarized in the following table (in millions, transactions with CSW affiliates
have not been eliminated).

     Total revenue                                       $362
     
     Operating income before income taxes                  23
     
     Earnings before income taxes                          18
     Income taxes                                          (6)
                                                   ----------
     Net income from discontinued operations              $12
                                                   ----------


9.  EXTRAORDINARY ITEM

         In the general election held in the United Kingdom on May 1, 1997, the
United Kingdom's Labour Party won control of the government with a considerable
majority. Prior to the general election, the Labour Party had announced that, if
elected, it would impose a windfall profits tax on certain industries in the
United Kingdom, including the privatized utilities, to fund a variety of social
improvement programs. On July 2, 1997, the one-time windfall profits tax was
introduced in the Labour Party's Budget and the legislation enacting the tax
subsequently was passed during the third quarter of 1997. Accordingly, during
the third quarter of 1997, SEEBOARD U.S.A. accrued, as an extraordinary item,
(pound)109.5 million (or $176 million when converted at (pound)1.00=$1.61) for a
one-time, windfall profits tax enacted by the United Kingdom government.

         The windfall profits tax is payable in two equal installments, due
December 1, 1997 and December 1, 1998. The tax was charged at a rate of 23% on
the difference between nine times the average profits after tax for the four
years following flotation in 1990, and SEEBOARD's market capitalization
calculated as the number of shares issued at flotation multiplied by the
flotation price per share.

         As enacted, the windfall profits tax is not tax deductible for United
Kingdom purposes. To date, no United States income tax benefit has been
recognized due to the uncertainty as to the impact on the use of foreign tax
credits. CSW continues to analyze the potential United States income tax benefit
from the use of foreign tax credits.


<PAGE> 56


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

         Reference is made to Management's Discussion and Analysis of Financial
Condition and Results of Operations included in the Registrants' Combined Annual
Report on Form 10-K for the year ended December 31, 1996 and the Registrants'
Combined Quarterly Reports on Form 10-Q for the quarters ended March 31, 1997
and June 30, 1997. Reference is also made to each Registrant's unaudited
Financial Statements and related Notes to Financial Statements included herein.
The information included therein should be read in conjunction with, and is
essential in understanding, the following discussion and analysis.


RESULTS OF OPERATIONS

         Reference is made to ITEM 1. FINANCIAL STATEMENTS for each of the
Registrants' RESULTS OF OPERATIONS for the three and nine month periods ended
September 30, 1997.

         FACTORS IMPACTING CSW'S 1997 ANNUAL EARNINGS
         CSW expects its 1997 net income for common stock to be substantially
lower than it has been in the past. Several factors discussed in this Combined
Form 10-Q have had a material adverse effect on CSW's 1997 results of
operations. These factors include the windfall profits tax in the United
Kingdom, the settlement of litigation related to the termination of the El Paso
Merger, the CPL 1997 Final Order and the PSO 1997 Rate Settlement Agreement. The
windfall profits tax and the charge for the settlement with El Paso are one-time
events. However, the new rates at both CPL and PSO will have an ongoing impact
on CSW's consolidated results of operations compared to prior periods. The
estimated after-tax impact of these items for 1997 compared to 1996 on a net
income for common stock basis is shown in the following table.

                                                        Estimated
     Factors Impacting 1997 Earnings                      Impact
     -------------------------------------------------- -----------
                                                        (millions)

     United Kingdom windfall profits tax                    $176
     Settlement of El Paso litigation                         23
     CPL 1997 Final Order (1996 effect)                       18
     CPL 1997 Final Order (1997 effect)                       30
     PSO 1997 Rate Settlement Agreement                       17
                                                        -----------
     Total estimated 1997 impact                            $264

     1996 Net Income for Common Stock                       $429

     Percentage of prior year                                62%

         This table is intended to highlight several items that will have a
material adverse impact on CSW's 1997 results of operations. For additional
information about these matters, see NOTE 2. LITIGATION AND REGULATORY 
PROCEEDINGS, NOTE 9.  EXTRAORDINARY ITEM and RATES AND REGULATORY MATTERS.

         The foregoing discussion of FACTORS IMPACTING CSW'S 1997 ANNUAL
EARNINGS constitutes forward looking information within the meaning of Section
21E of the Exchange Act. Actual results may differ materially from such
projected information. See FORWARD LOOKING INFORMATION.


<PAGE> 57


LIQUIDITY AND CAPITAL RESOURCES

         OVERVIEW OF CSW OPERATING, INVESTING AND FINANCING ACTIVITIES
         Net cash flows from operating activities decreased to $409 million for
the nine months ended September 1997 from $477 million for the comparable period
in 1996. The decrease was attributable to increased factored accounts receivable
purchases at CSW Credit, federal and state income tax payments for the gain on
CSW's 1996 sale of Transok which totaled approximately $122 million (after being
offset in part by the utilization of Alternative Minimum Tax credits that CSW
had previously generated), and a $35 million payment related to the settlement
of litigation between CSW and El Paso.

         Although construction expenditures remained comparable for the first
nine months of 1997 compared to the same period in 1996, overall net cash
outflows from investing activities decreased substantially for several reasons.
There were no acquisition expenditures during 1997 while SEEBOARD acquisition
expenditures were made during 1996. In addition, during 1996, the National Grid
shares were sold in conjunction with SEEBOARD acquisition activities and CSW
also received cash proceeds of $690 million on the 1996 sale of Transok. CSW
Energy obtained permanent external financing during March 1997 for the Orange
Cogeneration project and subsequently reduced its equity investment in the
project. For additional information related to this transaction, see LONG-TERM
FINANCING. During the first quarter of 1997, CSW Energy made its final purchase
agreement payment on the Ft. Lupton cogeneration project. In addition, because
construction of CSW Energy's Sweeny project began in mid-1996, the $102 million
in construction expenditures incurred during 1997 were much larger than
expenditures incurred during the comparable period in 1996. Likewise, CSW
International continued to provide the construction financing for its Enertek
project throughout 1997. Construction on this project, located in Altamira,
Mexico, began during the third quarter of 1996.

         Net cash inflows from financing activities decreased substantially
during the first nine months of 1997 compared to same period in 1996. During
1996, CSW incurred substantial amounts of debt to finance the acquisition of
SEEBOARD. In addition, during 1996, CSW sold approximately 15.5 million shares
of common stock and received net proceeds of approximately $398 million in a
primary public offering. The proceeds were subsequently used to repay a portion
of the debt incurred in connection with the SEEBOARD acquisition. In addition,
in April 1997, CSW made changes in its common stock plans and stopped issuing
original shares through these plans. However, partially offsetting these
activities, business trusts of CPL, PSO and SWEPCO received cash proceeds of
approximately $323 million on the issuance of trust preferred securities during
1997. A portion of these proceeds was used to redeem preferred stock of these
companies. See CAPITAL STRUCTURE and NOTE 6. LONG TERM FINANCING for additional
information related to these matters.

         CONSTRUCTION EXPENDITURES
         CSW's construction expenditures, including allowance for funds used
during construction, totaled $352 million for the nine months ended September
30, 1997. Such expenditures for the U.S. Electric Operating Companies totaled
$105 million, $58 million, $75 million and $22 million, for CPL, PSO, SWEPCO and
WTU, respectively. Construction expenditures at the U.S. Electric Operating
Companies were primarily for improvements to existing production, transmission
and distribution facilities. The improvements are required to meet the needs of
new customers and to satisfy the changing requirements of existing customers.
CSW anticipates that all funds required for construction for the remainder of
the year will be provided from internal sources.



<PAGE> 58


         CAPITAL STRUCTURE
         The CSW System is committed to maintaining financial flexibility by
having a strong capital structure and favorable securities ratings which help to
assure future access to capital markets when required. At September 30, 1997,
the capitalization ratios of each of the Registrants is presented in the
following table.
                                             Trust
            Common        Preferred        Preferred       Long
          Stock Equity      Stock       Securities (1)   Term Debt        Total
         --------------  ------------  ---------------  ------------   ---------

CSW           45%             2%               4%           49%            100%
CPL           47%             5%               5%           43%            100%
PSO           50%             1%               7%           42%            100%
SWEPCO        51%             2%               8%           39%            100%
WTU           49%             1%              --%           50%            100%

(1)  classified on the balance sheets as Subsidiary (CPL, PSO, SWEPCO)
     obligated, mandatorily redeemable, trust preferred securities

         CSW can issue common stock, either through open market purchases or
original issue shares, through a long-term incentive plan, the PowerShare
Dividend Reinvestment and Stock Purchase Plan and the ThriftPlus plan. Following
the issuance of the CPL 1997 Original Rate Order and the decline in the market
price of CSW's common stock, which CSW believes is attributable in part to the
CPL 1997 Original Rate Order, the determination was made that it was appropriate
for CSW to begin funding these plans through open market purchases, effective
April 1, 1997.

         The CSW System uses short-term debt to meet fluctuations in working
capital requirements and other interim capital needs. CSW has established a
system money pool to coordinate short-term borrowings for certain of its
subsidiaries, primarily the U.S. Electric Operating Companies. In addition, CSW
also incurs borrowings for other subsidiaries that are not included in the money
pool. As of September 30, 1997, CSW had revolving credit facilities totaling
$800 million to back up its commercial paper program.

         CSW has recently made several finance-related filings with the SEC
under the Holding Company Act which, if approved, are expected to increase CSW's
financial flexibility and to permit CSW to respond promptly to competitive
pressures and take advantage of favorable market conditions. In the first of
these filings, CSW has requested authority to repurchase up to ten percent of
its outstanding common stock as of June 30, 1997, from its stock and employee
benefit plans (pursuant to the terms and conditions of such plans) from time to
time through December 31, 2002, and to utilize its short-term borrowing program,
including funds borrowed through its commercial paper program, to finance its
repurchase in the open market of up to twenty percent of its outstanding common
stock as of June 30, 1997. No decision regarding this application has been made
by the SEC. Although such authority would increase CSW's flexibility to adjust
its capital structure, CSW currently has no plans to repurchase any of its
common stock.

         The second filing requests authority through December 31, 2002 for CSW,
the U.S. Electric Operating Companies and CSW Services to finance ongoing
business, repay short-term debt and finance the potential repurchase of
outstanding securities. CSW has requested authority to issue common stock, while
the U.S. Electric Operating Companies and CSW Services have requested authority
to issue common stock, preferred stock and debt. Such authority would give CSW
the flexibility to take advantage of favorable market conditions for routine
financings. The SEC has not yet issued an order with respect to this

<PAGE> 59

application. The third filing requests an increase in the authorized short-term
borrowing limitation of CSW and certain of its subsidiaries. The SEC has not
issued an order with respect to this application.

         OTHER FINANCING ISSUES
         Several legal and regulatory developments, which have been disclosed
elsewhere in this Combined Form 10-Q, will require cash payments by CSW's
subsidiaries through December 1998. The PSO Rate Settlement Agreement requires
PSO to refund $29 million to customers in December 1997. The windfall profits
tax, enacted by the United Kingdom government, is payable by SEEBOARD in two
equal installments of approximately (pound)55 million each (or $88 million when
converted at (pound)1.00=$1.61), due December 1, 1997 and December 1, 1998.
Based upon the CPL 1997 Final Order, CPL filed with the Texas Commission a
proposed methodology for issuing an interim $41.5 million refund to customers in
December 1997. A second refund, currently estimated at $29.2 million, is
proposed in March 1998. In addition, on October 1, 1997, CPL retired at maturity
$200 million of its Series BB, 6% first mortgage bonds. A combination of cash
from operations and short-term debt are expected to be used to fund these cash
requirements. CSW may also consider other options to meet these cash needs.


RATES AND REGULATORY MATTERS

         CPL RATE REVIEW - DOCKET NO. 14965
         As previously reported, in November 1995, CPL filed with the Texas
Commission a request to increase its retail base rates by $71 million, and in
May 1996, CPL placed a $70 million base rate increase into effect under bond,
subject to refund based on the receipt of the CPL 1997 Original Rate Order of
the Texas Commission. On March 31, 1997, the Texas Commission issued a rate
order in CPL's Rate Review, Docket No. 14965. Thereafter, CPL filed a motion for
rehearing which requested the reconsideration of numerous provisions of the
order. Motions for rehearing were also filed by other parties to the rate
proceeding. In response to the motions for rehearing, in June 1997, the Texas
Commission made several modifications to the CPL 1997 Original Rate Order and
also agreed to rehear on remand several other issues. CPL restored its rates in
July 1997, with two exceptions, to levels existing prior to the May 1996
implementation of bonded rates. On August 21, 1997, after reconsidering the
issues on remand, the Texas Commission voted to issue a revised final order and
on September 10, 1997, CPL received the CPL 1997 Final Order. CPL filed its
second motion for rehearing on September 30, 1997. The second motion for
rehearing again requested reconsideration of numerous issues in the rate case.
On October 16, 1997 the Texas Commission issued its second revised final order.
This order lowers the annual retail base rates of CPL by approximately $19
million, or 2.5%, from CPL's rate level existing prior to May 1996. The Texas
Commission also included a "Glide Path" rate methodology in the CPL 1997 Final
Order pursuant to which CPL's annual rates will be reduced by an additional $13
million in mid-1998 and another $13 million in mid-1999.

         There are numerous contributing factors to the difference between the
$71 million retail base rate increase originally requested by CPL and the $19
million retail base rate reduction included in the CPL 1997 Final Order. The CPL
1997 Final Order decreased CPL's requested return on equity of 12.25% on its
retail rate base to a 10.9% return on equity for all non-ECOM invested capital,
which results in an approximate $30 million decrease in CPL's rate request. The
CPL 1997 Final Order provides for the disallowance of approximately $18 million
of affiliate transactions. In addition, the CPL 1997 Final Order denied CPL's
request to use straight line amortization for CPL's deferred accounting costs.
Instead, the CPL 1997 Final Order requires CPL to continue to use the mortgage
amortization method to amortize its deferred accounting costs, resulting in a
reduction of $14 million from CPL's rate request. The CPL 1997 Final Order also
decreases other depreciation by $17.4 million from CPL's rate request.


<PAGE>  60


         Another major provision of the CPL 1997 Final Order was the Texas
Commission's categorization of $800 million of CPL's investment in STP,
including Mirror CWIP and deferred accounting, as ECOM. The term ECOM has been
used to refer to the amount of costs that potentially would become "stranded" if
retail competition were mandated and prices were set in the market, rather than
the price being determined by current regulatory standards of reasonable and
necessary cost of providing service. The CPL 1997 Final Order reduced CPL's
equity return on the ECOM portion of CPL's investment in STP to 7.96%, compared
to the 10.9% return on common equity approved for all other invested capital,
resulting in a $15.9 million decrease in CPL's rate request. At the same time,
the CPL 1997 Final Order accelerated the recovery of the $800 million designated
as ECOM to 20 years from the remaining 32-year life of STP.

         The following table contains details of the estimate of the financial 
impact of the CPL 1997 Final Order.
                                              1997           1998          1999
                                              ----------------------------------
                                                          (millions)

Decrease in revenue                           $(20.9)       $(28.7)      $(41.9)
                                              -------       -------      -------

Items included in decrease in revenue with
 an offsetting effect on expense:
      Accelerated recovery of STP (ECOM)        40.0          40.0         40.0
      Change in depreciation                   (27.3)        (27.3)       (27.3)
      Decommissioning                            4.3           4.3          4.3
      Other                                      6.6           4.5          4.5
                                              -------       -------      -------
                                                23.6          21.5         21.5

                                              -------       -------      -------
Change in current year income before tax       (44.5)        (50.2)       (63.4)
Federal income taxes                            14.7          16.8         21.2
                                              -------       -------      -------
Current year impact on net income              (29.8)        (33.4)       (42.2)

1996 effect                                    (17.7)          --           --
                                              -------       -------      -------
Estimated impact on net income                $(47.5)       $(33.4)      $(42.2)
                                              -------       -------      -------

         CPL will likely appeal the CPL 1997 Final Order to the Texas State
District Court by the end of 1997 to challenge the resolution of several issues
in the rate case after the rehearing process has concluded. The primary issues
include: (i) the classification of $800 million of invested capital in STP as
ECOM which was also assigned a lower return on equity than non-ECOM property,
(ii) the Texas Commission's use of the "Glide Path" rate reduction methodology
to be applied to rates in mid-1998 and mid-1999, and (iii) the $18 million of
disallowed affiliate transactions from CSW Services. Management is unable to
predict how the final resolution of these issues will ultimately affect CSW's
and CPL's results of operations and financial condition.

         CPL currently accounts for the economic effects of regulation in
accordance with SFAS No. 71. Pursuant to the provisions of SFAS No. 71, CPL had
recorded approximately $1.2 billion of regulatory related assets at December 31,
1996. The application of SFAS No. 71 is conditioned upon CPL's rates being set
based on the cost of providing service. In the event management concludes that
as a result of changes in regulation, legislation, the competitive environment,
or other factors, including the CPL 1997 Final Order, CPL no longer meets the
criteria for following SFAS No. 71, a write-off of regulatory assets would be
required. In addition, CPL would be required to determine any impairment to
carrying costs of plant investments. If CPL no longer met the criteria for
following SFAS No. 71 and a write-off of regulatory assets was required, CPL and
CSW could experience, depending on the timing and amount of any write-off, a
material adverse effect on their results of operations and financial condition.


<PAGE> 61

         The foregoing discussion of CPL RATE REVIEW - DOCKET NO. 14965
constitutes forward looking information within the meaning of Section 21E of the
Exchange Act. Actual results may differ materially from such projected
information. See FORWARD LOOKING INFORMATION.

         PSO 1997 RATE SETTLEMENT AGREEMENT
         On October 15, 1997, PSO reached a stipulated agreement with parties to
settle the rate inquiry that was pending before the Oklahoma Commission and on
October 23, 1997, a final order approving the agreement was issued by the
Oklahoma Commission. The PSO 1997 Rate Settlement Agreement calls for PSO to
lower its retail base rates beginning with the December 1997 billing cycle by
approximately $35.9 million annually, or a 5.3 percent decrease below the
current level of retail rates. Part of the rate reduction includes a reduction
in annual depreciation expense of approximately $10.9 million. In addition, the
PSO 1997 Rate Settlement Agreement will result in PSO making a one-time $29
million refund to customers. Through the third quarter of 1997, PSO has recorded
the estimated financial impact of the PSO 1997 Rate Settlement Agreement,
including recognition of the full $29 million refund obligation.
The refund is expected to be made to customers in December 1997.

         As previously reported, in July 1996, the OCC Staff filed an
application seeking a review of PSO's earnings. In accordance with the
established schedule, PSO subsequently filed financial data, cost of service and
rate design testimony supporting both its current rates and an increase in
annual depreciation expense of $26 million. In July 1997, the OCC Staff and
other intervenors to the proceeding filed their revenue requirements testimony.
In its filing, the OCC Staff recommended a rate reduction of $76.8 million for
PSO. Although the OCC Staff's recommended rate reduction included a $109 million
rate base reduction and a specific percentage return on capital, these issues
were not specifically addressed in the PSO 1997 Rate Settlement Agreement.

         The PSO 1997 Rate Settlement Agreement also provides that PSO
completely eliminate or amortize before its next rate filing approximately $41
million in certain deferred assets, approximately $26 million of which had been
expensed in 1996. Included in the remaining $15 million of deferred assets are
approximately $9 million of costs incurred for customer energy management
incentive programs. PSO is continuing to analyze the implications of the PSO
1997 Rate Settlement Agreement. The following table is management's estimate of
the financial impact of the PSO 1997 Rate Settlement Agreement on PSO's 1997
results of operations and also its ongoing annual impact on net income in
successive years.

                                                                   Ongoing
                                                    1997           Annual
                                                   Impact          Impact
                                                 ----------- --- -----------
                                                         (millions)

Change in revenues                                   $(31.5)        $(35.9)
                                                 -----------     -----------

Changes in expenses (offsetting 
 impact included in revenues)
   Depreciation                                        (6.3)         (10.9)
   Rate case deferred costs                             2.2            --
   Income tax                                         (10.2)          (8.8)
                                                 -----------     -----------
                                                      (14.3)         (19.7)

                                                 -----------     -----------
Estimated impact on net income                       $(17.2)        $(16.2)
                                                 -----------     -----------

         The PSO 1997 Rate Settlement Agreement resulted in an adverse effect on
PSO's results of operations for 1997 that will have a continuing impact because
of the rate decrease, but importantly, it also reduced significant risks for PSO
related to this regulatory proceeding and will enable PSO's rates to remain
competitive for the foreseeable future.


<PAGE> 62


         The foregoing discussion of PSO 1997 RATE SETTLEMENT AGREEMENT
constitutes forward looking information within the meaning of Section 21E of the
Exchange Act. Actual results may differ materially from such projected
information. See FORWARD LOOKING INFORMATION.

         SEEBOARD RECENT REGULATORY ACTIONS
         Following the opening of the United Kingdom domestic and small business
electricity market to competition, from April 1998, these customers will be able
to choose the supplier from which they purchase electricity. SEEBOARD will
compete for customers in its own area as well as throughout the rest of the
United Kingdom. The DGES has allowed most of the system development costs
associated with the introduction of competition to be recovered by the regional
electricity companies through a charge to all customers over the next five
years. The DGES has also announced price restraints which set a maximum amount
that existing electricity supply companies can charge their domestic and small
business customers over the first two years following the introduction of
competition, taking into account his view of future electricity purchase costs.
For SEEBOARD, this proposal reduces prices in real terms by 6% for the
regulatory period ending March 31, 1999 and a further 3% for the following
regulatory period ending March 31, 2000.

         OTHER
         Reference is made to NOTE 2. LITIGATION AND REGULATORY PROCEEDINGS for
information regarding fuel proceedings at CPL, SWEPCO and WTU.


STRATEGIC INITIATIVES

         A vital part of CSW's future business strategy involves initiatives
that are complementary to but outside of the traditional United States electric
utility industry. This is due in large measure to the well-documented
fundamental changes currently impacting the electric utility industry. CSW has
undertaken several such initiatives in the past, and will continue to pursue
them in the future provided they are consistent with the overall vision for the
company which is articulated as "CSW is an innovative leader in the global
energy and related services markets." Several initiatives have recently been
undertaken in support of this vision.

         In June 1997, the FERC approved the request of CSW PMI to sell power
and energy at market-based rates, rather than prices based on cost-of-service,
in the wholesale electricity market. Although CSW PMI is subject to the
jurisdiction of the FERC, it will not be subject to rate jurisdiction of any
state utility commissions. CSW has also made an equity investment in a firm that
provides technical consulting services to both the nuclear industry and to
governmental agencies associated with the energy industry. In addition, CSW has
formed CSW ESI, a company that will spearhead CSW's competitive efforts in the
retail electricity markets of states outside of CSW's historical service
territories. CSW ESI will not only attempt to secure electricity supply business
in the markets which soon will have retail competition, but will also permit CSW
to extend its business reach and name recognition beyond CSW's traditional
customer base.

         CSW International acquired a minority interest in Vale, a Brazilian
electric utility company, for an initial investment of approximately $40 million
in December 1996. In October 1997, CSW International made an additional equity
investment of approximately $40 million in Vale. The $80 million used to make
both equity investments was funded through loans to CSW International by CSW
Energy. CSW Energy obtained the funds from its $200 million Senior Note issuance
in October 1996.


<PAGE> 63

         In October 1997, SEEBOARD, through CSW International, announced a joint
venture to develop a new electricity generating station in southeast England.
The South Coast Power joint venture between Scottish Power and SEEBOARD is
currently finalizing proposals for the new 500 megawatt combined cycle gas
turbine power station. The development cost of the project is expected to total
approximately $340 million. South Coast Power already holds governmental permits
to build and operate a station on the site, but because of technological
advances since the permits were initially obtained, certain modifications must
be made to the permits to reflect the current construction plans. Financing
plans for South Coast Power are scheduled to be completed in the first quarter
of 1998.


RECENT DEVELOPMENTS

         FERC ORDER NO. 888/TEXAS COMMISSION ERCOT TRANSMISSION RULES
         As previously reported, the FERC issued Order No. 888, which is the
final comparable open access transmission service rule, in 1996. The provisions
of FERC Order No. 888 provide for comparable transmission service between
utilities and their transmission customers by requiring utilities to take
transmission service under their open access tariffs for all of their new
wholesale sales and purchases and by requiring utilities to rely on the same
information that their transmission customers rely on to make wholesale
purchases and sales.

         In addition, the Texas Commission adopted a rule governing transmission
access and pricing for ERCOT in 1996. The pricing method adopted by the Texas
Commission is a hybrid combination of an ERCOT-wide postage stamp rate covering
70% of total ERCOT transmission costs and a distance-sensitive component which
recovers the remaining 30% of ERCOT's transmission costs. CPL and WTU began
recording transmission revenues and expenses in accordance with the Texas
Commission's rule on January 1, 1997.

         FERC Order No. 888 requires holding companies to offer single system
transmission rates. However, because the transmission rates of PSO and SWEPCO
are under the exclusive jurisdiction of the FERC while the transmission rates of
CPL and WTU are under the exclusive jurisdiction of the Texas Commission and the
two commissions have different approaches to defining and implementing
comparable open access transmission service, Order No. 888 granted the U.S.
Electric Operating Companies an exemption permitting them an opportunity to
propose a solution that provides comparability to all wholesale users. On
November 1, 1996, the U.S. Electric Operating Companies filed a system-wide
tariff to comply with Order No. 888 and, on December 31, 1996, the FERC accepted
for filing the system-wide tariff which became effective on January 1, 1997,
subject to refund and to the issuance of further orders. CSW and the U.S.
Electric Operating Companies believe that their system-wide tariff complies with
the requirements of both the FERC and the Texas Commission although the tariff
does not offer a single system rate.

         INDUSTRY RESTRUCTURING INITIATIVES
         As previously reported, several initiatives regarding restructuring the
electric utility industry have recently been undertaken in the four states in
which the U.S. Electric Operating Companies operate. Such actions have taken
various forms, including proposed legislation. Legislation was enacted in
Oklahoma that provides for retail competition by July 2002. However, legislative
activities in Texas, Louisiana and Arkansas stopped short of any such definitive
action.

         In April 1997, the Oklahoma Legislature enacted legislation dealing
with industry restructuring in Oklahoma, which provides for retail competition

<PAGE> 64

by July 1, 2002. The legislation directs the Oklahoma Commission to study all
relevant issues relating to restructuring and develop a framework for a
restructured industry. The legislation divides the study of restructuring issues
by the Oklahoma Commission into four parts: (i) independent system operator
issues; (ii) technical issues; (iii) financial issues; and (iv) consumer issues.
At the end of each of these studies, the Oklahoma Commission must provide
reports along with legislative recommendations. The legislation directs the
Oklahoma Tax Commission to study the impact of electric utility restructuring on
state tax revenues and the existing tax structure, consider the establishment of
a uniform consumption tax, and report to the Oklahoma Legislature by December
31, 1998. The legislation prohibits the establishment of retail competition
until a uniform tax policy is established. The legislation also creates a Joint
Electric Utility Task Force, a 14-member panel composed of an equal number of
representatives from the Oklahoma House of Representatives and the Oklahoma
Senate. The duties of this task force include the oversight and direction of the
studies by the Oklahoma Commission and the Oklahoma Tax Commission. Management
is unable to predict the outcome of these studies or their ultimate impact on
the results of operations and financial condition of CSW and PSO.

         In March 1997, the Arkansas Legislature passed a resolution directing
interim legislative committees to study competition in the electric power
industry in Arkansas. The study began in October 1997. Although several bills
addressing industry restructuring and retail competition were introduced in the
recent sessions of the Texas and Louisiana legislatures, no such legislation was
adopted. The Louisiana Senate did adopt a resolution creating a special
committee to assess the impact of retail competition on the state of Louisiana.
The committee is scheduled to issue a report before the next regular session of
the Louisiana Legislature. Management cannot predict the outcome of the studies
in Arkansas and Louisiana or their ultimate impact on the results of operations
and financial condition of CSW and SWEPCO.

         CLEAN AIR ENVIRONMENTAL ISSUES
         The EPA recently promulgated revised, more stringent ambient air
quality standards for ozone and particulates. While these standards do not
mandate emission levels for facilities such as electricity generating power
plants, they may result in more areas being designated as non-attainment for
these two pollutants. States will be required to develop strategies to achieve
compliance in these areas, strategies that may include lower emission levels for
electricity generating power plants, possibly including facilities within the
CSW System. The impact, if any, on CSW or the U.S. Electric Operating Companies
cannot yet be determined and might be ten years from the present, but the impact
could ultimately be significant.

         International negotiations continue over the issue of global warming.
If a treaty emerges that is signed by the United States and is ratified by the
United States Congress which places limitations or roll backs of any greenhouse
gas emissions from electricity generating power plants, CSW and the U.S.
Electric Operating Companies could be significantly affected, though the
magnitude and timing of the effect is indeterminable at this point.


MERGER AND ACQUISITION ACTIVITIES

         SWEPCO CAJUN ASSET PURCHASE PROPOSAL
         As previously reported, Cajun filed a petition for reorganization under
Chapter 11 of the United States Bankruptcy Code on December 21, 1994 and is
currently operating under the supervision of the United States Bankruptcy Court
for the Middle District of Louisiana. In October 1996, SWEPCO, together with
Entergy Texas and the Committee of Certain Members, which currently consists of
seven of the twelve distribution cooperatives served by Cajun, filed the SWEPCO
Plan in the bankruptcy court. In April 1997, the Committee of Certain Members as
well as another cooperative signed term sheets that support the SWEPCO Plan. In

<PAGE> 65

signing the term sheets, the Committee of Certain Members agreed to support the
SWEPCO Plan throughout the confirmation process, and if the SWEPCO Plan is
confirmed, to sign power supply agreements that meet the conditions of the term
sheets.

         Under the SWEPCO Plan, which amended other plans filed earlier in 1996,
a SWEPCO subsidiary or affiliate would acquire all of the non-nuclear assets of
Cajun for approximately $780 million in cash and up to an additional $20 million
to pay certain other bankruptcy claims and expenses. SWEPCO would acquire claims
of unsecured creditors of up to $7 million. In addition, the SWEPCO Plan
provides for the Cajun member cooperatives to enter into new 25-year power
supply agreements which will provide the Cajun member cooperatives with two
wholesale rate options while permitting the Cajun member cooperatives the
flexibility to acquire power on the open market when their requirements exceed
mutually agreed upon levels of generating capacity. The cooperatives could also
elect, once every five years, to move from one rate option to the other. The
SWEPCO Plan would settle power supply contract claims and related litigation in
the bankruptcy case. The term sheets signed by the eight cooperatives contain
the major provisions of the SWEPCO Plan.

         Two competing plans of reorganization for Cajun have also been filed
with the bankruptcy court, each with different rate paths, asset purchase
proposals and other provisions. One of the competing plans has the support of
both the bankruptcy court-appointed trustee and Cajun's largest creditor, the
RUS. This plan also has the support of the three cooperatives not currently
supporting the SWEPCO Plan, although the support is based upon signed memoranda
of understanding which allow the cooperatives to support other competing
parties. In September 1997, SWEPCO reached a contingent settlement in principle
with the RUS whereby the RUS would support SWEPCO if certain contingencies are
met. SWEPCO is currently pursuing certain aspects of this settlement while also
evaluating other conditions of the settlement. However, SWEPCO is currently
unable to predict whether settlement with the RUS will ultimately be achieved.

         Confirmation hearings in Cajun's bankruptcy case are now scheduled
through January 1998. Consummation of the SWEPCO Plan is conditioned upon
confirmation by the bankruptcy court, the receipt by SWEPCO and CSW of all
requisite state and federal regulatory approvals and receipt of their
corresponding board approvals. If the SWEPCO Plan is confirmed, CSW and SWEPCO
expect to utilize a combination of external borrowings and internally generated
funds to initially finance the acquisition of Cajun's non-nuclear assets.

         The foregoing discussion of SWEPCO CAJUN ASSET PURCHASE PROPOSAL
constitutes forward looking information within the meaning of Section 21E of the
Exchange Act. Actual results may differ materially from such projected
information. See FORWARD LOOKING INFORMATION.

         TERMINATION OF EL PASO MERGER
         Reference is made to NOTE 2.  LITIGATION AND REGULATORY PROCEEDINGS.


RISK MANAGEMENT

         In October 1997, CSW's board of directors adopted a risk management
resolution authorizing CSW to engage in currency, interest rate and energy spot
and forward transactions and related derivative transactions on behalf of the
corporation with foreign and domestic parties as deemed appropriate by executive
officers of CSW. The risk management program is necessary to meet the growing
demands of CSW's customers for competitive prices and price stability, to enable

<PAGE> 66

CSW to compete in a deregulated power industry, to manage the risks associated
with domestic and foreign investments and to take advantage of strategic
investment opportunities.

         The U.S. Electric Operating Companies experience commodity price
exposures related to the purchase of fuel supplies for the generation of
electricity and for the purchase of power and energy from other generation
sources. Contracts that provide for the future delivery of these commodities can
be considered forward contracts which contain pricing and/or volume terms
designed to stabilize the cost of the commodity. Consequently, the U.S. Electric
Operating Companies manage their price exposure for the benefit of customers by
balancing their commodity purchases through a combination of long-term and
short-term (spot-market) agreements. In addition, CSW has been exposed to
currency and interest rate risks which reflect the changing exchange rate that
exists between the U.S. dollar and the British pound since its purchase of
SEEBOARD in 1995. CSW has utilized certain risk management tools to manage
adverse changes in exchange rates and to facilitate financing transactions
resulting from CSW's acquisition of SEEBOARD.

<PAGE> 67
PART II - OTHER INFORMATION

         For background and earlier developments relating to PART II
information, reference is made to the Registrants' Combined Annual Report on
Form 10-K for the year ended December 31, 1996 and Combined Quarterly Reports on
Form 10-Q for the quarters ended March 31, 1997 and June 30, 1997.


ITEM 1.  LEGAL PROCEEDINGS

         CPL MUNICIPAL FRANCHISE FEE LITIGATION
         As previously reported, in May 1996, the city of San Juan, Texas filed
a class action in Hidalgo County, Texas District Court on behalf of all cities
served by CPL based upon CPL's alleged underpayment of municipal franchise fees.
The city of San Juan asserts various contract and tort claims against CPL as
well as certain audit rights. The suit seeks unspecified damages and attorneys'
fees. CPL filed a counterclaim for any overpayment of franchise fees it may have
made as well as its attorneys' fees. CPL also filed a motion to transfer venue
to Nueces County, Texas, and a plea to the jurisdiction and pleas in abatement
asserting that the Texas Commission has primary jurisdiction over the claims
filed by the city of San Juan. In January, 1997, CPL filed an original petition
at the Texas Commission requesting the Texas Commission to declare its
jurisdiction over CPL's collection and payment of municipal franchise fees.

         In April 1997, the Texas Commission issued a declaratory order in which
it declined to assert jurisdiction over the claims of the city of San Juan. CPL
appealed the Texas Commission's decision to the Travis County, Texas District
Court. After the Texas Commission's order, the Hidalgo County court overruled
CPL's plea to the jurisdiction and plea in abatement. In July 1997, the Hidalgo
County court entered an order certifying the case as a class action. CPL
appealed this order to the Corpus Christi Court of Appeals. In May 1996 and
December 1996, respectively, the cities of Pharr, Texas and San Benito, Texas
filed individual suits making claims identical to those claimed by the city of
San Juan.

         Although CPL believes that it has substantial defenses to the cities'
claims and intends to defend itself against the cities' claims and pursue its
counterclaims vigorously, CPL cannot predict the outcome of these lawsuits.

         SWEPCO BURLINGTON NORTHERN TRANSPORTATION CONTRACT
         In January 1995, a state district court in Bowie County, Texas entered
judgment in favor of SWEPCO against Burlington Northern in a lawsuit regarding
rates charged under two rail transportation contracts for delivery of coal to
SWEPCO's Welsh and Flint Creek power stations. The court awarded SWEPCO
approximately $72 million that would inure to the benefit of customers, if
collected, representing damages for the period from April 27, 1989 through
September 26, 1994, as well as post-judgment interest and attorneys' fees and
granted certain declaratory relief requested by SWEPCO. Burlington Northern
appealed the state district court's judgment to the Texarkana, Texas Court of
Appeals and, in April 1996, that court reversed the judgment of the state
district court. In October 1996, SWEPCO filed an application with the Supreme
Court of Texas to grant a writ of error to review and reverse the judgment of
the Texarkana, Texas Court of Appeals. In June 1997, the Supreme Court of Texas
granted SWEPCO's application for writ of error. Oral argument was held before
the Supreme Court of Texas in October 1997, and the matter is now pending.


<PAGE> 68
         SWEPCO LIGNITE MINING AGREEMENT LITIGATION
         SWEPCO and CLECO are each a 50% owner of Dolet Hills Power Station Unit
1 and jointly own lignite reserves in the Dolet Hills area of northwestern
Louisiana. In 1982 the SWEPCO and CLECO entered into a lignite mining agreement
with the DHMV, a partnership for the mining and delivery of lignite from a
portion of these reserves.

         On April 15, 1997, SWEPCO and CLECO filed suit against DHMV and its
partners in the United States District Court for the Western District of
Louisiana seeking to enforce various obligations of DHMV to SWEPCO and CLECO
under the lignite mining agreement, including provisions relating to the quality
of the delivered lignite, pricing, and mine reclamation practices. On June 15,
1997, DHMV filed an answer denying the allegations in the suit and filed a
counterclaim asserting various contract-related claims against SWEPCO and CLECO.
SWEPCO and CLECO have denied the allegations in the counterclaims.

         SWEPCO intends to vigorously prosecute the claims against DHMV and
defend against the counterclaims which DHMV has asserted. Although SWEPCO cannot
predict the ultimate outcome of this matter, management believes that the
resolution of this matter will not have a material adverse effect on SWEPCO's
results of operations or financial condition.

         OTHER LEGAL CLAIMS AND PROCEEDINGS
         The CSW System is party to various other legal claims and proceedings
arising in the normal course of business. Management does not expect disposition
of these matters to have a material adverse effect on the Registrants' results
of operations or financial condition. See PART I - NOTE 2.  LITIGATION AND
REGULATORY PROCEEDINGS and NOTE 3.  COMMITMENTS AND CONTINGENT LIABILITIES.


ITEM 5.  OTHER INFORMATION

         ADOPTION OF RIGHTS PLAN
         In September 1997, CSW's board of directors adopted a Rights Plan,
which is subject to SEC approval under the Holding Company Act. An application
to the SEC requesting approval of the Rights Plan was filed on September 29,
1997. The Rights Plan was adopted as part of the fiduciary responsibility of
CSW's board of directors, and was not adopted because of any takeover offer or
threat. The Rights Plan is intended to assure fair and equal treatment for all
of CSW's stockholders in the event of a hostile takeover attempt and to
encourage a potential acquirer to negotiate with CSW's board of directors before
attempting a takeover so as to assure a fair price for all stockholders.

         Following SEC approval of the Rights Plan, CSW will make a dividend
distribution of one right for each outstanding share of its common stock, as of
a record date to be determined by its board of directors. CSW stockholders are
not required to take any action to receive their rights distribution. Prior to
the date upon which the rights become exercisable under the Rights Plan, CSW's
outstanding stock certificates will represent both the shares of common stock
and the rights, and the rights will trade only together with the shares.

         Upon a "triggering event" under the Rights Plan, which would occur ten
days after a person or group acquires or announces a tender or exchange offer to
acquire fifteen percent or more of CSW's outstanding common stock, the rights

<PAGE> 69

will become exercisable and will trade independently of CSW's common stock.
After a person or group acquires fifteen percent or more of CSW's outstanding
common stock, each right, except those held by such acquiring person or group,
whose rights would become void, will entitle the holder to purchase, at the
exercise price, additional CSW common shares having a current market value of
two times the exercise price. If CSW is acquired in a merger or other business
combination, each right will entitle the holder to purchase, at the exercise
price, common stock of the acquiror having a current market value of two times
the exercise price. In either case, after a triggering event occurs but before
an acquiring person becomes the owner of at least fifty percent of CSW's
outstanding common stock, CSW's board of directors may direct the exchange of
one share of CSW's common stock for each right then outstanding and not
exercised.

         CSW's board of directors may redeem the rights for a price of one cent
per right prior to the earlier of the rights becoming exercisable or the
expiration of the Rights Plan. The rights will expire in ten years from the
effective date unless they are earlier redeemed or exchanged by CSW. CSW will
mail additional information to its stockholders as of the record date for
distribution of the rights, which is expected to be the tenth day following
approval of the Rights Plan by the SEC.

         NEW MANAGEMENT OF STP
         In September 1997, STPNOC was formed to begin the transition from HL&P
as the STP Project Manager to an independent STP operator. Each of the four STP
co-owners will be represented on the STPNOC board of directors. The CPL
representative has been elected as the initial chairman of the board of
directors. CPL believes the formation of STPNOC is in the best interest of CPL
and of each of the other STP co-owners.

         The establishment of the independent operating company provides the
following advantages: (i) allows the management and work force to focus
exclusively on the safe, reliable and efficient operation of the STP units; (ii)
removes most of the possibility of disputes between the four owners over the
operation of the facility; (iii) removes dissension over the potential liability
of HL&P who was acting as the project manager; and (iv) allows the management of
the facility to tailor a total compensation package for the STP work force which
best suits that work force and its needs. In addition, the formation and
operation of STPNOC is expected to result in a decrease in costs allocable to
CPL related to its investment in STP.

         On October 1, 1997, all HL&P employees assigned to STP were transferred
from HL&P to STPNOC. HL&P will be removed as the STP Project Manager on
completion of various transition agreements, including an amended participation
agreement. The replacement of HL&P as STP Project Manager with STPNOC is
anticipated to be completed before the end of 1997.

         SALE OF CSW ENERGY SWEENY OWNERSHIP INTEREST
         In August 1997, an affiliate of CSW Energy sold 50% of its 100%
interest in the Sweeny Cogeneration project. The sale of the ownership interest
was necessary for the Sweeny Cogeneration project to maintain its qualifying
facility status under the Public Utility Regulatory Policy Act of 1978. CSW
Energy provided the $56.5 million non-recourse financing for the sale which is
expected to be repaid from project distributions or proceeds from sale, as
defined in the sales agreements. Construction on the 330 megawatt electricity
generating facility is estimated to be completed in early 1998 with a commercial
operation date soon thereafter. CSW Energy did not recognize a gain or loss on
this transaction.


<PAGE> 70
ITEM 6.  EXHIBITS AND REPORTS ON FORM 8-K

(A)  EXHIBITS:

     (3)   ARTICLES OF INCORPORATION AND BY-LAWS OF CSW ESI
           1  Certificate of Incorporation, filed herewith.
           2  Bylaws, filed herewith.

     (4)   INSTRUMENTS DEFINING THE RIGHTS OF SECURITY HOLDERS
           1  CSW Shareholder Rights Plan adopted September 27, 1997, filed
              herewith.

     (12)  COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
           CPL - (Exhibit 12.1), filed herewith. 
           PSO - (Exhibit 12.2), filed herewith. 
           SWEPCO - (Exhibit 12.3), filed herewith. 
           WTU - (Exhibit 12.4), filed herewith.

     (27)  FINANCIAL DATA SCHEDULES
           CSW - (Exhibit 27.1), filed herewith.


(B)  REPORTS FILED ON FORM 8-K:

           CSW
           ITEM 5. OTHER EVENTS, dated July 2, 1997, reporting information
           related to the United Kingdom Windfall Profits Tax.
           ITEM 5. OTHER EVENTS, dated July 16, 1997, reporting the settlement
           of litigation related to the termination of the proposed El Paso
           Merger. 
           ITEM 5.OTHER EVENTS, and ITEM 7. FINANCIAL STATEMENTS AND EXHIBITS,
           dated September 27, 1997, reporting CSW's adoption of the Rights 
           Plan.

           CSW AND CPL
           ITEM 5. OTHER EVENTS, dated September 10, 1997, providing certain
           information related to CPL's rate review.

           CSW AND PSO
           ITEM 5. OTHER EVENTS, dated July 17, 1997, reporting information
           related to PSO's rate review.
           ITEM 5. OTHER EVENTS, dated October 15, 1997, reporting the PSO 1997
           Rate Settlement Agreement.

           SWEPCO, WTU
           None


<PAGE> 71



SIGNATURES

         Pursuant to the requirements of the Securities Exchange Act of 1934,
each Registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized. The signature for each undersigned
Registrant shall be deemed to relate only to matters having reference to such
Registrant or its subsidiaries.


                       CENTRAL AND SOUTH WEST CORPORATION


Date:  November 13, 1997                 /S/ LAWRENCE B. CONNORS
                                         --------------------------
                                         Lawrence B. Connors
                                         Controller and Chief Accounting Officer
                                         (Principal Accounting Officer)



                                         CENTRAL POWER AND LIGHT COMPANY
                                         PUBLIC SERVICE COMPANY OF OKLAHOMA
                                         SOUTHWESTERN ELECTRIC POWER COMPANY
                                         WEST TEXAS UTILITIES COMPANY


Date:  November 13, 1997                 /S/ R. RUSSELL DAVIS
                                         -----------------------
                                         R. Russell Davis
                                         Controller and Chief Accounting Officer
                                         (Principal Accounting Officer)