<PAGE>

================================================================================

                                 UNITED STATES
                      SECURITIES AND EXCHANGE COMMISSION
                            Washington, D.C. 20549

                               -----------------

                                  FORM 10-Q/A

                                AMENDMENT NO. 1

[X] Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange
    Act of 1934

               For the quarterly period ended September 30, 2002

[_] Transition Report Pursuant to Section 13 or 15(d) of the Securities
    Exchange Act of 1934

          For the transition period from ____________ to ____________

                        Commission file number: 1-15659

                               -----------------

                                  DYNEGY INC.
            (Exact name of registrant as specified in its charter)

                     Illinois                  74-2928353
                  (State or other           (I.R.S. Employer
                   jurisdiction            Identification No.)
                of incorporation or
                   organization)

                          1000 Louisiana, Suite 5800
                             Houston, Texas 77002
                   (Address of principal executive offices)
                                  (Zip Code)

                                (713) 507-6400
             (Registrant's telephone number, including area code)

   Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes [X] No [_]

   Number of shares outstanding of each of the issuer's classes of common
stock, as of the latest practicable date: Class A Common Stock, no par value
per share, 274,476,836 shares outstanding as of November 12, 2002; Class B
Common Stock, no par value per share, 96,891,014 shares outstanding as of
November 12, 2002.

================================================================================

<PAGE>

                                  DYNEGY INC.

                               TABLE OF CONTENTS

<TABLE>
<CAPTION>
                                                                                        Page
                                                                                        ----
<S>                                                                                     <C>
Part I.  Financial Information

   Item 1.  Condensed Consolidated Financial Statements (Unaudited and Restated):

   Condensed Consolidated Balance Sheets:
       September 30, 2002 and December 31, 2001........................................   3
   Condensed Consolidated Statements of Operations:
       For the three months ended September 30, 2002 and 2001..........................   4
   Condensed Consolidated Statements of Operations:
       For the nine months ended September 30, 2002 and 2001...........................   5
   Condensed Consolidated Statements of Cash Flows:
       For the nine months ended September 30, 2002 and 2001...........................   6
   Notes to Condensed Consolidated Financial Statements................................   7

   Item 2.  Management's Discussion and Analysis of Financial Condition and Results of
     Operations........................................................................  52

   Item 3.  Quantitative and Qualitative Disclosures About Market Risk.................  84

   Item 4.  Controls and Procedures....................................................  85

Part II.  Other Information

   Item 1.  Legal Proceedings..........................................................  85

   Item 5.  Other Information..........................................................  85

   Item 6.  Exhibits and Reports on Form 8-K...........................................  85
</TABLE>

                               INTRODUCTORY NOTE

   Dynegy Inc. is filing this Amendment No. 1 on Form 10-Q/A ("Amendment No.
1") to reflect restatements relating to its audited consolidated financial
statements as of December 31, 2001 and its unaudited condensed consolidated
financial statements for the three- and nine-month periods ended September 30,
2002 and 2001. These financial statements were previously included in Dynegy's
Quarterly Report on Form 10-Q for the quarter ended September 30, 2002, which
was originally filed with the SEC on November 14, 2002 (the "Original Filing").
These financial statements and the other financial information included in the
Original Filing have been revised to reflect the restatement items described in
the Explanatory Note to the accompanying unaudited condensed consolidated
financial statements. Revised financial information for the periods presented
reflecting these restatements was previously included in Dynegy's Annual Report
on Form 10-K for the fiscal year ended December 31, 2001, which was most
recently amended by Amendment No. 2 thereto filed with the SEC on April 11,
2003 (the "2001 Form 10-K/A"), and Dynegy's Annual Report on Form 10-K for the
fiscal year ended December 31, 2002, which also was filed with the SEC on April
11, 2003 (the "2002 Form 10-K"). The restated financial and other information
included in this Amendment No. 1 should be read together with the 2001 Form
10-K/A and the 2002 Form 10-K. Certain of the operating, investing and
financing cash flow data included in this Amendment No. 1 has been revised from
the comparable data included in Note 19--Quarterly Financial Information
(Unaudited) beginning on page F-76 of the 2002 Form 10-K. This revised data,
which reflects minor corrections for errors, should be read to replace and
supersede the data previously included in the 2002 Form 10-K. In addition to
the restatements described elsewhere herein, this Amendment No. 1 also includes
certain other revisions to the Original Filing. Dynegy's periodic SEC reports,
including this Amendment No. 1, remain subject to an ongoing review by the SEC
Division of Corporation Finance.

   PLEASE NOTE THAT THE INFORMATION CONTAINED IN THIS AMENDMENT NO. 1,
INCLUDING THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS AND THE
NOTES THERETO, DOES NOT REFLECT EVENTS OCCURRING AFTER NOVEMBER 14, 2002 (THE
DATE OF THE ORIGINAL FILING). FOR A DESCRIPTION OF THESE EVENTS, PLEASE READ
DYNEGY'S EXCHANGE ACT REPORTS FILED SINCE NOVEMBER 14, 2002, INCLUDING ITS
ANNUAL REPORT ON FORM 10-K FOR THE FISCAL YEAR ENDED DECEMBER 31, 2002. SEE
NOTE 15--SUBSEQUENT EVENTS FOR FURTHER DISCUSSION.

                                      2

<PAGE>

                                  DYNEGY INC.

               CONDENSED CONSOLIDATED BALANCE SHEETS (RESTATED)
                      SEE EXPLANATORY NOTE--RESTATEMENTS
                 (unaudited) (in millions, except share data)

<TABLE>
<CAPTION>
                                                                                                               September 30,
                                                                                                                   2002
                                                                                                               -------------
                                                    ASSETS
<S>                                                                                                            <C>
Current Assets
Cash and cash equivalents.....................................................................................    $   863
Restricted cash...............................................................................................        207
Accounts receivable, net of allowance for doubtful accounts of $114 million and $113 million, respectively....      2,632
Accounts receivable, affiliates...............................................................................         69
Inventory.....................................................................................................        221
Assets held for sale (Note 3).................................................................................         32
Assets from risk-management activities........................................................................      4,004
Prepayments and other assets..................................................................................        770
                                                                                                                  -------
      Total Current Assets....................................................................................      8,798
                                                                                                                  -------
Property, Plant and Equipment.................................................................................      9,612
Accumulated depreciation......................................................................................     (1,206)
                                                                                                                  -------
      Property, Plant and Equipment, Net......................................................................      8,406
Other Assets
Unconsolidated investments (Note 6)...........................................................................        716
Investment in Northern Natural Gas Company (Note 3)...........................................................         --
Assets held for sale (Note 3).................................................................................        644
Assets from risk-management activities........................................................................      4,036
Goodwill......................................................................................................        396
Other assets..................................................................................................        724
                                                                                                                  -------
      Total Assets............................................................................................    $23,720
                                                                                                                  =======
                                     LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
Accounts payable..............................................................................................    $ 1,679
Accounts payable, affiliates..................................................................................        274
Accrued liabilities and other.................................................................................      1,321
Liabilities from risk-management activities...................................................................      3,881
Notes payable and current portion of long-term debt...........................................................      1,526
Liabilities held for sale (Note 3)............................................................................         30
                                                                                                                  -------
      Total Current Liabilities...............................................................................      8,711
                                                                                                                  -------
Long-Term Debt................................................................................................      4,838
Other Liabilities
Transitional funding trust notes..............................................................................        452
Liabilities held for sale (Note 3)............................................................................        211
Liabilities from risk-management activities...................................................................      3,677
Deferred income taxes.........................................................................................        927
Other long-term liabilities...................................................................................        875
                                                                                                                  -------
      Total Liabilities.......................................................................................     19,691
                                                                                                                  -------
Minority Interest.............................................................................................        185
Serial Preferred Securities of a Subsidiary...................................................................         11
Company Obligated Preferred Securities of Subsidiary Trust....................................................        200
Series B Convertible Redeemable Preferred Securities..........................................................      1,130
Commitments and Contingencies (Note 11)
Stockholders' Equity
Class A Common Stock, no par value, 900,000,000 shares authorized at September 30, 2002 and December 31, 2001,
 272,960,450 and 269,984,456 shares issued and outstanding at September 30, 2002 and December 31, 2001,
 respectively outstanding at September 30, 2002 and December 31, 2001, respectively...........................      2,851
Class B Common Stock, no par value, 360,000,000 shares authorized at September 30, 2002 and December 31, 2001,
 96,891,014 and 86,499,914 shares issued and outstanding at September 30, 2002 and December 31, 2001,
 respectively.................................................................................................      1,006
Additional paid-in capital....................................................................................        660
Subscriptions receivable (Note 8).............................................................................        (12)
Accumulated other comprehensive income (loss), net of tax.....................................................         13
Retained earnings (accumulated deficit).......................................................................     (1,947)
Treasury stock, at cost, 1,679,183 shares at September 30, 2002 and 1,766,800 shares at December 31, 2001.....        (68)
                                                                                                                  -------
      Total Stockholders' Equity..............................................................................      2,503
                                                                                                                  -------
         Total Liabilities and Stockholders' Equity...........................................................    $23,720
                                                                                                                  =======
</TABLE>
<TABLE>
<CAPTION>
                                                                                                               December 31,
                                                                                                                   2001
                                                                                                               ------------
                                                    ASSETS
<S>                                                                                                            <C>
Current Assets
Cash and cash equivalents.....................................................................................   $   208
Restricted cash...............................................................................................        28
Accounts receivable, net of allowance for doubtful accounts of $114 million and $113 million, respectively....     3,083
Accounts receivable, affiliates...............................................................................        36
Inventory.....................................................................................................       256
Assets held for sale (Note 3).................................................................................        --
Assets from risk-management activities........................................................................     3,953
Prepayments and other assets..................................................................................     1,392
                                                                                                                 -------
      Total Current Assets....................................................................................     8,956
                                                                                                                 -------
Property, Plant and Equipment.................................................................................    10,135
Accumulated depreciation......................................................................................      (934)
                                                                                                                 -------
      Property, Plant and Equipment, Net......................................................................     9,201
Other Assets
Unconsolidated investments (Note 6)...........................................................................       944
Investment in Northern Natural Gas Company (Note 3)...........................................................     1,501
Assets held for sale (Note 3).................................................................................        --
Assets from risk-management activities........................................................................     2,214
Goodwill......................................................................................................     1,561
Other assets..................................................................................................       791
                                                                                                                 -------
      Total Assets............................................................................................   $25,168
                                                                                                                 =======
                                     LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
Accounts payable..............................................................................................   $ 2,064
Accounts payable, affiliates..................................................................................        38
Accrued liabilities and other.................................................................................     2,617
Liabilities from risk-management activities...................................................................     3,361
Notes payable and current portion of long-term debt...........................................................       458
Liabilities held for sale (Note 3)............................................................................        --
                                                                                                                 -------
      Total Current Liabilities...............................................................................     8,538
                                                                                                                 -------
Long-Term Debt................................................................................................     4,500
Other Liabilities
Transitional funding trust notes..............................................................................       516
Liabilities held for sale (Note 3)............................................................................        --
Liabilities from risk-management activities...................................................................     1,871
Deferred income taxes.........................................................................................     1,568
Other long-term liabilities...................................................................................     1,070
                                                                                                                 -------
      Total Liabilities.......................................................................................    18,063
                                                                                                                 -------
Minority Interest.............................................................................................     1,040
Serial Preferred Securities of a Subsidiary...................................................................        46
Company Obligated Preferred Securities of Subsidiary Trust....................................................       200
Series B Convertible Redeemable Preferred Securities..........................................................       882
Commitments and Contingencies (Note 11)
Stockholders' Equity
Class A Common Stock, no par value, 900,000,000 shares authorized at September 30, 2002 and December 31, 2001,
 272,960,450 and 269,984,456 shares issued and outstanding at September 30, 2002 and December 31, 2001,
 respectively outstanding at September 30, 2002 and December 31, 2001, respectively...........................     2,786
Class B Common Stock, no par value, 360,000,000 shares authorized at September 30, 2002 and December 31, 2001,
 96,891,014 and 86,499,914 shares issued and outstanding at September 30, 2002 and December 31, 2001,
 respectively.................................................................................................       801
Additional paid-in capital....................................................................................       688
Subscriptions receivable (Note 8).............................................................................       (38)
Accumulated other comprehensive income (loss), net of tax.....................................................       (27)
Retained earnings (accumulated deficit).......................................................................       798
Treasury stock, at cost, 1,679,183 shares at September 30, 2002 and 1,766,800 shares at December 31, 2001.....       (71)
                                                                                                                 -------
      Total Stockholders' Equity..............................................................................     4,937
                                                                                                                 -------
         Total Liabilities and Stockholders' Equity...........................................................   $25,168
                                                                                                                 =======
</TABLE>

         See the notes to condensed consolidated financial statements.

                                      3

<PAGE>

                                  DYNEGY INC.

          CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (RESTATED)
                      SEE EXPLANATORY NOTE--RESTATEMENTS
               (unaudited) (in millions, except per share data)

<TABLE>
<CAPTION>
                                                                                         Three Months Ended
                                                                                          September 30,
                                                                                         -----------------
                                                                                           2002     2001
                                                                                         -------   ------
<S>                                                                                      <C>       <C>
Revenues (Note 1)....................................................................... $ 1,582   $2,442
Cost of sales (exclusive of depreciation shown separately below) (Note 1)...............   1,373    1,793
Depreciation and amortization...........................................................     117      115
Goodwill impairment (Note 4)............................................................     897       --
Impairment and other charges (Note 4)...................................................      29       --
General and administrative expenses.....................................................     128      152
Loss (gain) on sale of assets...........................................................      (9)       2
                                                                                         -------   ------
       Operating income (loss)..........................................................    (953)     380
Earnings (losses) from unconsolidated investments (Notes 4 and 6).......................    (120)      85
Other income (expense), net (Note 4)....................................................     (38)      (1)
Interest expense........................................................................    (103)     (65)
Minority interest expense...............................................................       2       (8)
Accumulated distributions associated with trust preferred securities....................      (4)      (6)
                                                                                         -------   ------
Income (loss) from continuing operations before income taxes............................  (1,216)     385
Income tax provision (benefit)..........................................................    (120)     147
                                                                                         -------   ------
Income (loss) from continuing operations................................................  (1,096)     238
Discontinued operations (Note 3):
   Loss from discontinued operations (including loss on disposal of Northern Natural of
     $586 million)......................................................................    (569)      --
   Income tax benefit...................................................................     (14)      --
                                                                                         -------   ------
Loss on discontinued operations.........................................................    (555)      --
                                                                                         -------   ------
Net Income (Loss)....................................................................... $(1,651)  $  238
Less: preferred stock dividends.........................................................      83       --
                                                                                         -------   ------
Net Income (Loss) applicable to common stockholders..................................... $(1,734)  $  238
                                                                                         =======   ======
Net Income (Loss) Per Share:
Basic earnings (loss) per share:
   Income (loss) from continuing operations............................................. $ (3.20)  $ 0.73
   Loss from discontinued operations....................................................   (1.51)      --
                                                                                         -------   ------
Basic earnings (loss) per share......................................................... $ (4.71)  $ 0.73
                                                                                         -------   ------
Diluted earnings (loss) per share (Note 9):
   Income (loss) from continuing operations............................................. $ (3.20)  $ 0.71
   Loss from discontinued operations....................................................   (1.51)      --
                                                                                         -------   ------
Diluted earnings (loss) per share (Note 9).............................................. $ (4.71)  $ 0.71
                                                                                         -------   ------
Basic shares outstanding................................................................     368      326
                                                                                         -------   ------
Diluted shares outstanding..............................................................     369      337
                                                                                         -------   ------
</TABLE>

         See the notes to condensed consolidated financial statements.

                                      4

<PAGE>

                                  DYNEGY INC.

    CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (RESTATED)--(Continued)
                      SEE EXPLANATORY NOTE--RESTATEMENTS
               (unaudited) (in millions, except per share data)

<TABLE>
<CAPTION>
                                                                                         Nine Months Ended
                                                                                          September 30,
                                                                                         ---------------
                                                                                           2002     2001
                                                                                         -------   ------
<S>                                                                                      <C>       <C>
Revenues (Note 1)....................................................................... $ 4,804   $7,669
Cost of sales, exclusive of depreciation shown separately below (Note 1)................   4,263    6,163
Depreciation and amortization...........................................................     347      337
Goodwill impairment (Note 4)............................................................     897       --
Impairment and other charges (Note 4)...................................................     695       --
General and administrative expenses.....................................................     355      388
Gain on sale of assets..................................................................     (10)     (32)
                                                                                         -------   ------
       Operating income (loss)..........................................................  (1,743)     813
Earnings (losses) from unconsolidated investments (Notes 4 and 6).......................    (116)     195
Other income (expense), net (Note 4)....................................................     (15)      (2)
Interest expense........................................................................    (255)    (199)
Minority interest expense...............................................................     (37)     (76)
Accumulated distributions associated with trust preferred securities....................     (13)     (18)
                                                                                         -------   ------
Income (loss) from continuing operations before income taxes and change in accounting
  principle.............................................................................  (2,179)     713
Income tax provision (benefit)..........................................................    (471)     283
                                                                                         -------   ------
Income (loss) from continuing operations................................................  (1,708)     430
Discontinued operations (Note 3):
   Loss from discontinued operations (including loss on disposal of Northern Natural of
     $586 million)......................................................................    (511)      --
   Income tax provision.................................................................       6       --
                                                                                         -------   ------
Loss on discontinued operations.........................................................    (517)      --
Cumulative effect of change in accounting principle, net (Notes 1 and 5)................    (234)       2
                                                                                         -------   ------
Net Income (loss)....................................................................... $(2,459)  $  432
                                                                                         -------   ------
Net income (loss)....................................................................... $(2,459)  $  432
Less: preferred stock dividends.........................................................     248       --
                                                                                         -------   ------
Net income (loss) applicable to common stockholders..................................... $(2,707)  $  432
                                                                                         =======   ======
Net Income (loss) Per Share:
Basic earnings (loss) per share:
   Income (loss) from continuing operations............................................. $ (5.36)  $ 1.32
   Loss from discontinued operations....................................................   (1.42)      --
   Cumulative effect of change in accounting principle, net.............................   (0.64)    0.01
                                                                                         -------   ------
Basic earnings (loss) per share......................................................... $ (7.42)  $ 1.33
                                                                                         -------   ------
Diluted earnings (loss) per share (Note 9):
   Income (loss) from continuing operations............................................. $ (5.36)  $ 1.27
   Loss from discontinued operations....................................................   (1.42)      --
   Cumulative effect of change in accounting principle, net.............................   (0.64)    0.01
                                                                                         -------   ------
Diluted earnings (loss) per share (Note 9).............................................. $ (7.42)  $ 1.28
                                                                                         -------   ------
Basic shares outstanding................................................................     365      325
                                                                                         -------   ------
Diluted shares outstanding..............................................................     369      338
                                                                                         -------   ------
</TABLE>

         See the notes to condensed consolidated financial statements.

                                      5

<PAGE>

                                  DYNEGY INC.

          CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (RESTATED)
                      SEE EXPLANATORY NOTE--RESTATEMENTS
                           (unaudited) (in millions)
<TABLE>
<CAPTION>
                                                                                                           Nine Months
                                                                                                              Ended
                                                                                                          September 30,
                                                                                                        ----------------
                                                                                                          2002     2001
                                                                                                        -------  -------
<S>                                                                                                     <C>      <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)...................................................................................... $(2,459) $   432
Items not affecting cash flows from operating activities:
    Depreciation and amortization......................................................................     413      335
    Goodwill impairment (Note 4).......................................................................     897       --
    Impairment and other charges.......................................................................     699       --
    (Earnings) losses from unconsolidated investments, net of cash distributions.......................     192     (167)
    Risk-management activities.........................................................................     527     (104)
    Deferred income taxes..............................................................................    (414)     203
    Loss on sale of Northern Natural (Note 3)..........................................................     586       --
    Minority interest..................................................................................      --       31
    Cumulative effect of change in accounting principle (Notes 1 and 5)................................     234       (2)
    Other..............................................................................................      27      (13)
                                                                                                        -------  -------
Operating cash flows before changes in working capital.................................................     702      715
Changes in working capital:
    Accounts receivable................................................................................     587    1,416
    Inventory..........................................................................................      (1)     224
    Prepayments and other assets (includes $270 million cash collateral postings in the 2002 period)...    (323)    (159)
    Accounts payable and accrued liabilities...........................................................    (636)  (1,801)
    Other, net.........................................................................................     (67)      63
                                                                                                        -------  -------
Net cash provided by operating activities..............................................................     262      458
                                                                                                        -------  -------

CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures...................................................................................    (796)  (2,149)
Unconsolidated investments.............................................................................     (14)     (52)
Business acquisitions, net of cash acquired............................................................     (20)     (21)
Proceeds from asset sales..............................................................................   1,105    1,051
Other investing, net...................................................................................      75     (237)
                                                                                                        -------  -------
Net cash provided by (used in) investing activities....................................................     350   (1,408)
                                                                                                        -------  -------

CASH FLOWS FROM FINANCING ACTIVITIES:
Net proceeds from long-term borrowings.................................................................     574    1,402
Repayments of long-term borrowings.....................................................................    (570)    (251)
Net proceeds from short-term borrowings................................................................     437       --
Net cash flow from commercial paper and revolving lines of credit......................................    (303)     (14)
Proceeds from sale of capital stock, options and warrants..............................................     240       57
Purchase of serial preferred securities of a subsidiary................................................     (28)      --
Decrease (increase) in restricted cash.................................................................    (179)     (14)
Purchase of treasury stock.............................................................................      (1)     (59)
Dividends and other distributions, net.................................................................     (55)     (74)
Other financing, net...................................................................................     (14)      65
                                                                                                        -------  -------
Net cash provided by financing activities..............................................................     101    1,112
                                                                                                        -------  -------
Effect of exchange rate changes on cash................................................................     (58)       3
Net increase in cash and cash equivalents..............................................................     655      165
Cash and cash equivalents, beginning of period.........................................................     208       59
                                                                                                        -------  -------
Cash and cash equivalents, end of period............................................................... $   863  $   224
                                                                                                        =======  =======
</TABLE>

         See the notes to condensed consolidated financial statements.

                                      6

<PAGE>

                                  DYNEGY INC.

             NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

                           (UNAUDITED AND RESTATED)

           FOR THE INTERIM PERIODS ENDED SEPTEMBER 30, 2002 AND 2001

Explanatory Note--Restatements

   This Amendment No. 1 on Form 10-Q/A of Dynegy Inc. ("Dynegy" or the
"Company") includes restatements relating to the Company's audited consolidated
financial statements as of December 31, 2001 and its unaudited condensed
consolidated financial statements for the three- and nine-month periods ended
September 30, 2002 and 2001. On April 11, 2003, Dynegy filed its Annual Report
on Form 10-K for the fiscal year ended December 31, 2002 (the "2002 Form
10-K"), which included restated financial statements for each of the two years
in the period ended December 31, 2001. The 2002 Form 10-K also included
restated financial information for the three- and nine-month periods ended
September 30, 2002 and 2001. The restatements relate to the following:

  .   the Project Alpha structured natural gas transaction,

  .   a balance sheet reconciliation project relating principally to the
      Company's natural gas marketing business,

  .   corrections to the Company's previous hedge accounting for certain
      contracts resulting in the Company accounting for these contracts
      pursuant to the mark-to-market method under Statement of Financial
      Accounting Standards No. 133, "Accounting for Derivative Instruments and
      Hedging Activities," as amended ("Statement No. 133"); in addition, the
      Company determined that it had incorrectly accounted for certain
      derivative transactions prior to the adoption of Statement No. 133,

  .   the valuation used in the Company's 2000 acquisition of Extant, Inc.,

  .   the restatement of the Company's forward power curve methodology to
      reflect forward power and market prices more closely,

  .   the recognition of additional assets, accrued liabilities and debt
      associated with certain lease arrangements, as well as impairment,
      depreciation and amortization expense for the related assets,

  .   a correction to the measurement date relating to the implied dividend the
      Company previously recorded related to the in-the-money beneficial
      conversion option in the $1.5 billion in Series B preferred stock issued
      to ChevronTexaco in November 2001,

  .   the recognition of an other-than-temporary decline in value of a
      technology investment in the third quarter of 2001 rather than the second
      quarter of 2002,

  .   corrections to the Company's previous accounting for income taxes, and

  .   other adjustments that arose during the re-audit of the Company's
      1999-2001 financial statements.

   Specifically, the restatements are as follows:

   Project Alpha.  Dynegy entered into the Project Alpha structured natural gas
transaction in April 2001. As described in a Current Report on Form 8-K dated
April 25, 2002 (the "Alpha Form 8-K"), Dynegy restated the cash flow associated
with the related gas supply contract as a financing activity in its
Consolidated Statements of Cash Flows for 2001. The effect of this restatement
was to reclassify approximately $180 million and $290 million of previously
disclosed operating cash flow to financing cash flow for the nine-month period
ended September 30, 2001 and year ended December 31, 2001, respectively.
Following the disclosure in the Alpha Form 8-K and in connection with a further
review of Project Alpha, Arthur Andersen LLP ("Andersen") informed the Company
that it could no longer support its tax opinion relating to the transaction.
Andersen's change in position was based in part on its conclusion that the
reclassification of cash flow from operations to

                                      7

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

cash flow from financing lessened the factual basis for the opinion. Dynegy's
financial statement recognition of the tax benefit in 2001 was based
principally on the Company's assessment of the relevant issues, as corroborated
by Andersen's tax opinion. After the withdrawal of Andersen's tax opinion,
management concluded that sufficient support to include the income tax benefit
for financial statement presentation purposes no longer existed, the effect of
which was a reversal of approximately $79 million of tax benefit previously
recognized by the Company during the 2001 period. Andersen further advised the
Company that its audit opinion relating to 2001 should no longer be relied upon
as a result of the pending restatements relating to Project Alpha and such
audit opinion has been withdrawn. Dynegy subsequently concluded that its
restated consolidated financial statements would include the consolidation of
ABG Gas Supply, LLC ("ABG"), one of the entities formed in connection with the
transaction. The consolidation of ABG is included herein based on compilations
of financial information received from an agent of ABG's equity holders. Dynegy
reflected these restatements in its third quarter 2002 Form 10-Q originally
filed on November 14, 2002 (the "Original Filing").

   Balance Sheet Reconciliation Project.  Dynegy recognized an after-tax charge
of approximately $80 million ($124 million pre-tax) in the second quarter 2002
related to a balance sheet reconciliation project undertaken by the Company at
the beginning of 2002. The charge related principally to the Company's natural
gas marketing business and was associated with the process of reconciling
accrued to actual results. Accrual accounting for natural gas marketing
involves the estimation of gas volumes bought, sold, transported and stored, as
well as the subsequent reconciliation of estimated to actual volumes. The
Company has restated its financial statements to allocate this $80 million
charge from the second quarter 2002 back to the periods in which the
transactions giving rise to the charge originally occurred.

   The table below reflects the impact of this restatement on net income and
diluted earnings per share for the three and nine months ended September 30,
2002 and 2001. Dynegy partially reflected this restatement in its Original
Filing; consequently, the amounts included below are incremental to the related
amounts originally reported in the Original Filing.

<TABLE>
<CAPTION>
                                            Three Months Nine Months
                                               Ended        Ended
                                            September 30 September 30
                                            ------------ ------------
                                                  (in millions,
                                             except per share data)
          <S>                               <C>          <C>
          Net Income (Loss)
          2001.............................    $  (28)      $  36
          2002.............................        --           8
          Diluted Earnings (Loss) per Share
          2001.............................    $(0.08)      $0.11
          2002.............................        --        0.02
</TABLE>

   Corrected Hedge Accounting.  The Company adopted Statement No. 133 effective
January 1, 2001 and reflected certain contracts as cash flow hedges upon such
adoption. Management has subsequently determined that following the initial
adoption of Statement No. 133, the documentation of compliance requirements
under the standard, particularly as it relates to documentation and the
periodic assessment of hedge effectiveness, was inadequate to support the
accounting method previously applied. In addition, the Company determined that
it had incorrectly accounted for certain derivative transactions prior to the
adoption of Statement No. 133. The resulting restatement reflects the
accounting for these contracts on a mark-to-market basis rather than on the
hedge

                                      8

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

accounting basis previously employed. This correction had no impact on
previously reported cash flows from operations in any period.

   The table below reflects the impact of this restatement on net income and
diluted earnings per share as originally reported for the three and nine months
ended September 30, 2002 and 2001. Dynegy reflected portions of this
restatement in the Original Filing. The restatement items identified subsequent
to November 14, 2002 are included in the following table:

<TABLE>
<CAPTION>
                                               Three
                                               Months    Nine Months
                                               Ended        Ended
                                            September 30 September 30
                                            ------------ ------------
                                                  (in millions,
                                               except share data)
          <S>                               <C>          <C>
          Net Income (Loss)
          2001.............................    $    5       $   28
          2002.............................        (2)         (24)
          Diluted Earnings (Loss) per Share
          2001.............................    $ 0.01       $ 0.08
          2002.............................     (0.01)       (0.07)
</TABLE>

   Valuation of Extant, Inc. Purchase.  On September 29, 2000, Dynegy completed
the acquisition of Extant, Inc., a privately held entity engaged in the
communications business. The transaction was accounted for as a purchase. In
2000, the Company incorrectly valued the shares of Class A common stock it
issued as consideration for the acquisition at $49.59 per share, rather than
$36.59 per share, which amount represented the average share price during the
five days surrounding the announcement of the acquisition. The $49.59 per share
originally utilized in the valuation was incorrectly based on the average
closing price of Dynegy's Class A common stock during the 30 days prior to the
closing date, which was consistent with the valuation provisions in the merger
agreement. As a result, the purchase price allocated to the assets acquired and
liabilities assumed in the purchase was overstated by $23 million in 2000. This
error resulted in an overstatement of the amortization of goodwill acquired in
the transaction during 2001 and 2000. Additionally, as a result of this error,
the Company overstated by $22 million the impairment of goodwill recorded in
2002 associated with the Company's January 1, 2002 adoption of Statement of
Financial Accounting Standard No. 142, "Goodwill and Other Intangible Assets."
The Company reflected this restatement in the Original Filing.

   Restated Forward Power Curve Methodology.  The Company values substantially
all of its natural gas marketing, power marketing and portions of its natural
gas liquids marketing operations under a mark-to-market accounting methodology.
The estimated fair value of the marketing and trading portfolio is computed by
multiplying all existing positions in the portfolio by estimated prices,
reduced by a LIBOR-based time value of money adjustment and deduction of
reserves for credit, price and market liquidity risks. Dynegy uses a
combination of market quotes, derivatives of market quotes and proprietary
models to periodically value this portfolio as required by generally accepted
accounting principles. Market quotes are used for near-term transactions, where
such quotes are generally available; derivatives of market quotes are used for
mid-term transactions, where broker quotes are only marginally available; and
proprietary models are used for long-term transactions, where broker quotes or
other objective pricing indicators typically are not available. Beginning in
the third quarter 2001, the Company began to enter into longer-term power
transactions in the United States with respect to which no broker quotes or
other market data was available; consequently, the Company applied a

                                      9

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

proprietary model to estimate forward prices and, in turn, the fair market
value of these longer-term power transactions.

   During January 2003, in connection with the re-audit of the Company's
1999-2001 financial statements and an assessment of various accounting
policies, the Company reconsidered the model-based methodology used to value
the portions of its power marketing and trading portfolio for which broker
quotes were not available. Under the Company's prior methodology, forward
curves used to calculate the value of its long-term U.S. power contracts were
derived from a proprietary model based on a required rate of return on
investments in new generation facilities. The primary disadvantage of this type
of methodology, which was confirmed by the Company's former independent
auditors prior to the withdrawal of their audit opinion for unrelated matters,
is that, in certain circumstances, it may not reflect true market prices in
future years. After reconsidering the appropriateness of this methodology in
light of changing industry circumstances and in connection with the re-audit,
in late January 2003, the Company determined that, beginning with the third
quarter 2001, a different forward power curve methodology would more
appropriately reflect the value of its long-term power contracts.

   Upon making this determination, the Company corrected the forward power
curve methodology it used to estimate the fair market value of its U.S. power
marketing and trading portfolio. This corrected methodology incorporates
forward energy prices derived from broker quotes and values from executed
transactions to estimate forward price curves for periods where broker quotes
and transaction data cannot be obtained. Further, the Company determined that
in order to adequately reflect its results, it was appropriate to restate its
prior period financial statements, beginning with the third quarter 2001, to
reflect the corrected methodology.

   The table below reflects the impact of this restatement on net income and
diluted earnings per share as originally reported for the three and nine months
ended September 30, 2002 and 2001.

<TABLE>
<CAPTION>
                                            Three Months Nine Months
                                               Ended        Ended
                                            September 30 September 30
                                            ------------ ------------
                                                  (in millions,
                                               except share data)
          <S>                               <C>          <C>
          Net Income (Loss)
          2001.............................    $  (25)      $  (25)
          2002.............................       133          (69)
          Diluted Earnings (Loss) per Share
          2001.............................    $(0.07)      $(0.07)
          2002.............................      0.36        (0.19)
</TABLE>

   Restated Lease Accounting.  The Company previously accounted for seven
generation lease arrangements and one communications lease arrangement as
operating leases. Its previous accounting treatment of these lease
arrangements, which was confirmed by the Company's former independent auditors
prior to the withdrawal of their audit opinion for unrelated matters, reflected
its belief that these arrangements satisfied the applicable generally accepted
accounting principles ("GAAP") requirements so as to justify their treatment as
operating leases. However, these requirements are very technical and subject to
a high degree of interpretation. During the course of the re-audit of the
Company's financial statements for 1999-2001, the Company analyzed its
accounting for these arrangements and considered a variety of factors,
including interpretations of the applicable GAAP requirements. Upon completion
of this analysis and discussions with PricewaterhouseCoopers LLP, in January
2003, the Company determined it was necessary to correct its accounting for
these lease arrangements to

                                      10

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

recognize on its balance sheet the related assets as of the inception of six of
these arrangements. Although the Company previously amended the agreements
relating to six generation lease arrangements so as to require them to be
treated as capital leases in the second quarter 2002, the restatement of the
accounting originally applied to these arrangement results in the recognition
of the related assets as of an earlier date. Consequently, the Company's
previously reported net income has been reduced reflecting the recognition of
depreciation, impairment and amortization expenses associated with the related
assets.

   In addition, balance sheet amounts have been adjusted for this change as
follows:

<TABLE>
<CAPTION>
                                          September 30, December 31,
                                              2002          2001
                                          ------------- ------------
                                               ($ in millions)
            <S>                           <C>           <C>
            Restricted cash..............     $ --         $   17
            Property, plant and equipment      (22)         1,094
            Accrued liabilities and other       (2)           445
            Long-term debt...............      348            666
</TABLE>

Please read Note 7--Debt in the Company's Annual Report on Form 10-K for the
fiscal year ended December 31, 2001, as most recently amended by Amendment No.
2 thereto filed with the SEC on April 11, 2003 (the "2001 Form 10-K/A"), for
further discussion.

   The table below reflects the impact of this restatement on net income and
diluted earnings per share as originally reported for the three and nine months
ended September 30, 2002 and 2001.

<TABLE>
<CAPTION>
                                            Three Months Nine Months
                                               Ended        Ended
                                            September 30 September 30
                                            ------------ ------------
                                                  (in millions,
                                               except share data)
          <S>                               <C>          <C>
          Net Income (Loss)
          2001.............................    $   (2)      $   (2)
          2002.............................        13         (215)
          Diluted Earnings (Loss) per Share
          2001.............................    $(0.00)      $(0.01)
          2002.............................      0.04        (0.58)
</TABLE>

   Change in Implied Preferred Dividends.  In November 2001, the Company issued
$1.5 billion in Series B preferred stock to ChevronTexaco. This preferred stock
is convertible by ChevronTexaco into shares of Dynegy's Class B common stock at
a conversion price of $31.64. This conversion price represents an approximate
5% discount to the Company's stock price on November 7, 2001, the date the
conversion price was negotiated. Based on the implied value of this beneficial
conversion option as of November 7, Dynegy recognized a $65 million preferred
stock dividend to be amortized over the two-year period leading up to the
mandatory redemption date for the shares. During the course of the re-audit of
the Company's financial statements for 1999-2001, the Company analyzed its
accounting for the beneficial conversion option and determined it necessary to
correct the commitment date used for valuing this beneficial conversion option
to November 13, 2001, the date ChevronTexaco funded and consummated its
preferred stock purchase and the preferred securities were issued. The
Company's stock price increased significantly between November 7 and

                                      11

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

November 13 after the announcement of the proposed Enron Corp. merger. As a
result of the increase in the intrinsic value of ChevronTexaco's beneficial
conversion option, the restated preferred stock dividend amount is calculated
based on a two-year amortization of the beneficial conversion option's implied
value of approximately $660 million--an increase of approximately $595 million
over the $65 million originally reported.

   The table below reflects the impact of this restatement on net income
available to common stockholders and diluted earnings per share as originally
reported for the three and nine months ended September 30, 2002 and 2001. The
restatement had no impact on net income or cash flows.

<TABLE>
<CAPTION>
                                                     Three Months Nine Months
                                                        Ended        Ended
                                                     September 30 September 30
                                                     ------------ ------------
                                                           (in millions,
                                                        except share data)
  <S>                                                <C>          <C>
  Net Income (Loss) Available to Common Stockholders
  2001..............................................    $   --       $   --
  2002..............................................       (75)        (224)
  Diluted Earnings (Loss) per Share
  2001..............................................    $   --       $   --
  2002..............................................     (0.20)       (0.61)
</TABLE>

   Valuation of Technology Investment.  Dynegy acquired the common stock of a
technology investment in the second quarter 2000. In the second quarter 2002,
after several quarters of declines in the market price of the investment, the
Company determined that the decline in value was other-than-temporary. As such,
the Company recognized a $12 million after-tax charge during the second quarter
2002. Upon further review, the Company determined that it incorrectly delayed
recognition of the charge associated with this investment, as the decline in
value through September 30, 2001 met the "other-than-temporary" threshold.
Therefore, the Company has restated the financial statements to record the
impairment in the third quarter 2001.

   The table below reflects the impact of this restatement on net income and
diluted earnings per share as originally reported for the three and nine months
ended September 30, 2002 and 2001.

<TABLE>
<CAPTION>
                                            Three Months Nine Months
                                               Ended        Ended
                                            September 30 September 30
                                            ------------ ------------
                                                  (in millions,
                                               except share data)
          <S>                               <C>          <C>
          Net Income (Loss)
          2001.............................    $  (12)      $  (12)
          2002.............................         2           12
          Diluted Earnings (Loss) per Share
          2001.............................    $(0.03)      $(0.04)
          2002.............................      0.01         0.03
</TABLE>

   Correction for Income Taxes.  During the course of the re-audit of its
1999-2001 financial statements, the Company reviewed its previous accounting
for income taxes and determined that it made errors in accounting for certain
tax matters. These errors related to book-tax basis differences that were
reflected as permanent differences as opposed to temporary differences, the
failure to record differences between the amounts recognized as income tax
provision and the amounts actually reflected in the applicable income tax
returns,

                                      12

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

adjustments related to book and tax-basis balance sheet reconciliations and
changes in estimates of tax contingencies. The Company has restated its
financial statements to correct these errors, resulting in additional deferred
tax expense as further detailed below.

   The table below reflects the impact of these restatements on net income and
diluted earnings per share as originally reported for the three and nine months
ended September 30, 2002 and 2001.

<TABLE>
<CAPTION>
                                            Three Months Nine Months
                                               Ended        Ended
                                            September 30 September 30
                                            ------------ ------------
                                                  (in millions,
                                               except share data)
          <S>                               <C>          <C>
          Net Income (Loss)
          2001.............................    $   (3)      $  (11)
          2002.............................        (3)          (7)
          Diluted Earnings (Loss) per Share
          2001.............................    $(0.01)      $(0.03)
          2002.............................     (0.01)       (0.02)
</TABLE>

   Other Adjustments Arising During the Re-Audit.  PricewaterhouseCoopers LLP
re-audited Dynegy's 1999-2001 financial statements. The re-audit was completed
in April 2003. The Company has restated its 1999-2001 financial statements to
correct various errors that were identified during the course of the re-audit,
which restatements are reflected in the 2001 Form 10-K/A and the 2002 Form
10-K. The corrections principally relate to the timing on which various
transactions were recorded in the ordinary course of business.

   The table below reflects the impact of these restatements on net income
(loss) and diluted earnings (loss) per share as originally reported for the
three and nine months ended September 30, 2002 and 2001.

<TABLE>
<CAPTION>
                                            Three Months Nine Months
                                               Ended        Ended
                                            September 30 September 30
                                            ------------ ------------
                                                  (in millions,
                                               except share data)
          <S>                               <C>          <C>
          Net Income (Loss)
          2001.............................    $  29        $  (34)
          2002.............................       10             1
          Diluted Earnings (Loss) per Share
          2001.............................    $0.08        $(0.10)
          2002.............................     0.02          0.00
</TABLE>

                                      13

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   A synopsis of the aggregate financial impact of these restatements on the
amounts originally reported in the Original Filing is as follows (in millions):

                     RESTATED SELECTED BALANCE SHEET DATA

<TABLE>
<CAPTION>
                                             September 30,
                                                 2002
                                             -------------
                                             (in millions)
                      <S>                    <C>
                      Current Assets
                         As Reported........    $ 9,424
                         Restatement Effect.       (626)
                                                -------
                         As Restated........    $ 8,798
                                                =======
                      Total Assets
                         As Reported........    $25,147
                         Restatement Effect.     (1,427)
                                                -------
                         As Restated........    $23,720
                                                =======
                      Current Liabilities
                         As Reported........    $ 9,323
                         Restatement Effect.       (612)
                                                -------
                         As Restated........    $ 8,711
                                                =======
                      Total Liabilities
                         As Reported........    $20,669
                         Restatement Effect.       (978)
                                                -------
                         As Restated........    $19,691
                                                =======
                      Stockholders' Equity
                         As Reported........    $ 2,590
                         Restatement Effect.        (87)
                                                -------
                         As Restated........    $ 2,503
                                                =======
</TABLE>

                                      14

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


                        RESTATED RESULTS OF OPERATIONS
<TABLE>
<CAPTION>
                                                 Three Months     Nine Months
                                                     Ended           Ended
                                                 September 30,   September 30,
                                                 -------------   -------------
                                                 (in millions, except per share
                                                          amounts)
    <S>                                          <C>             <C>
    2002
    Net Loss:
       As Reported..............................    $(1,804)        $(2,165)
       Restatement Effect.......................        153            (294)
                                                    -------         -------
       As Restated..............................    $(1,651)        $(2,459)
                                                    =======         =======
    Net Loss Available to Common Stockholders:
       As Reported..............................    $(1,812)        $(2,189)
       Restatement Effect.......................         78            (518)
                                                    -------         -------
       As Restated..............................    $(1,734)        $(2,707)
                                                    =======         =======
    Loss Per Diluted Share:
       As Reported..............................    $ (4.92)        $ (6.00)
       Restatement Effect.......................       0.21           (1.42)
                                                    -------         -------
       As Restated..............................    $ (4.71)        $ (7.42)
                                                    =======         =======
    2001
    Net Income:
       As Reported..............................    $   274         $   452
       Restatement Effect.......................        (36)            (20)
                                                    -------         -------
       As Restated..............................    $   238         $   432
                                                    =======         =======
    Net Income Available to Common Stockholders:
       As Reported..............................    $   274         $   452
       Restatement Effect.......................        (36)            (20)
                                                    -------         -------
       As Restated..............................    $   238         $   432
                                                    =======         =======
    Earnings Per Diluted Share:
       As Reported..............................    $  0.81         $  1.34
       Restatement Effect.......................      (0.10)          (0.06)
                                                    -------         -------
       As Restated..............................    $  0.71         $  1.28
                                                    =======         =======
</TABLE>

                                      15

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


                       RESTATED SELECTED CASH FLOW DATA

<TABLE>
<CAPTION>
                                              Nine Months
                                                 Ended
                                             September 30,
                                             -------------
                                             (in millions)
                      <S>                    <C>
                      2002
                      Operating Cash Flows:
                         As Reported........    $   261
                         Restatement Effect.          1
                                                -------
                         As Restated........    $   262
                                                =======
                      Investing Cash Flows:
                         As Reported........    $   412
                         Restatement Effect.        (62)
                                                -------
                         As Restated........    $   350
                                                =======
                      Financing Cash Flows:
                         As Reported........    $    48
                         Restatement Effect.         53
                                                -------
                         As Restated........    $   101
                                                =======
                      2001
                      Operating Cash Flows:
                         As Reported........    $   452
                         Restatement Effect.          6
                                                -------
                         As Restated........    $   458
                                                =======
                      Investing Cash Flows:
                         As Reported........    $  (852)
                         Restatement Effect.       (556)
                                                -------
                         As Restated........    $(1,408)
                                                =======
                      Financing Cash Flows:
                         As Reported........    $   548
                         Restatement Effect.        564
                                                -------
                         As Restated........    $ 1,112
                                                =======
</TABLE>

                                      16

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   PLEASE NOTE THAT THESE FINANCIAL STATEMENTS AND THE NOTES THERETO DO NOT
REFLECT EVENTS OCCURRING AFTER NOVEMBER 14, 2002 (THE DATE ON WHICH DYNEGY
ORIGINALLY FILED ITS THIRD QUARTER 2002 FORM 10-Q). FOR A DESCRIPTION OF THESE
EVENTS, PLEASE READ THE COMPANY'S EXCHANGE ACT REPORTS FILED SINCE NOVEMBER 14,
2002, INCLUDING ITS ANNUAL REPORT ON FORM 10-K FOR THE FISCAL YEAR ENDED
DECEMBER 31, 2002. SEE NOTE 15--SUBSEQUENT EVENTS FOR FURTHER DISCUSSION.

Note 1--Accounting Policies

   The accompanying unaudited condensed consolidated financial statements have
been prepared in accordance with the instructions to interim financial
reporting as prescribed by the Securities and Exchange Commission ("SEC").
These interim financial statements and notes thereto should be read in
conjunction with the restated consolidated financial statements and notes
thereto included in the 2001 Form 10-K/A, which includes restated financial
statements for 1999-2001 reflecting the revisions described in the Explanatory
Note above.

   The financial statements contained in this quarterly report include all
material adjustments that, in the opinion of management, are necessary for a
fair presentation of the results for the interim periods. Interim period
results are not necessarily indicative of the results for the full year. The
preparation of the condensed consolidated financial statements in conformity
with generally accepted accounting principles requires management to develop
estimates and make assumptions that affect reported financial position and
results of operations and that impact the nature and extent of disclosure, if
any, of contingent assets and liabilities. The Company reviews significant
estimates affecting its consolidated financial statements on a recurring basis
and records the effect of any necessary adjustments prior to their publication.
Judgments and estimates are based on the Company's beliefs and assumptions
derived from information available at the time such judgments and estimates are
made. Adjustments made with respect to the use of these estimates often relate
to information not previously available. Uncertainties with respect to such
estimates and assumptions are inherent in the preparation of financial
statements. Estimates are primarily used in (1) developing fair value
assumptions, including estimates of future cash flows and discount rates, (2)
analyzing tangible and intangible assets for impairment and (3) determining the
amounts to accrue related to contingencies. Actual results could differ
materially from any such estimates. Certain reclassifications have been made to
prior period amounts in order to conform to current year presentation.

   Change in Accounting Principle. EITF Issue 98-10.  In October 2002, the
Emerging Issues Task Force ("EITF" or "Task Force") reached a consensus to
rescind EITF Issue 98-10, "Accounting for Contracts Involved in Energy Trading
and Risk Management Activities" ("EITF Issue 98-10"). As such, all new energy
trading contracts entered into after October 25, 2002 that do not qualify as
derivatives under Statement No. 133 will not be accounted for using mark to
market accounting. All derivative contracts will continue to be accounted for
in accordance with Statement No. 133. With the rescission of this standard,
Dynegy will no longer record trading inventories at fair market value. The
effective date for the full rescission of EITF Issue 98-10 will be January 1,
2003. The effect of the rescission of EITF Issue 98-10 will be reported as the
cumulative effect of a change in accounting principle at the time of adoption:
however, the impact is not known.

   Accounting Principles Adopted. EITF Issue 02-3.  In June 2002, the Task
Force reached consensus on two of three issues presented in EITF Issue 02-3,
"Accounting for Contracts Involved in Energy Trading and

                                      17

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

Risk Management Activities" ("EITF Issue 02-3"). First, the Task Force
concluded that all mark-to-market gains and losses on energy trading contracts
(whether realized or unrealized) should be shown net in the income statement,
irrespective of whether the contract is physically or financially settled.
Beginning in the third quarter 2002, Dynegy is presenting all mark-to-market
gains and losses on a net basis to reflect this change in accounting principle.
In accordance with the transition provisions in the consensus, comparative
period financial statements have been conformed to reflect this change in
accounting principle, Dynegy has historically classified net unrealized gains
and losses from energy trading contracts as revenue in its consolidated
statement of operations. Transactions that were realized and settled were
previously reflected gross in revenues and cost of sales. This change in
accounting classification has no impact on operating income, net income,
earnings per share or cash flow from operations.

   The following table reconciles the revenues and costs of sales as previously
reported to the restated amounts herein (in millions):

<TABLE>
<CAPTION>
                                             Three Months   Nine Months
                                                 Ended         Ended
                                             September 30, September 30,
                                                 2001          2001
                                             ------------- -------------
        <S>                                  <C>           <C>
        Revenues as previously reported.....    $ 8,551      $ 33,467
        Restatements (see Explanatory Note).         27           254
                                                -------      --------
        Adjusted revenues...................      8,578        33,721
        Change in accounting principle......     (6,136)      (26,052)
                                                -------      --------
        Revenues as reported herein.........    $ 2,442      $  7,669
                                                -------      --------
        Cost of sales as previously reported    $ 7,879      $ 32,007
        Restatements (see Explanatory Note).         50           208
                                                -------      --------
        Adjusted cost of sales..............      7,929        32,215
        Change in accounting principle......     (6,136)      (26,052)
                                                -------      --------
        Cost of sales as reported herein....    $ 1,793      $  6,163
                                                -------      --------
</TABLE>

   The second consensus reached by the Task Force in June 2002 related to
required disclosures regarding energy trading operations. However, in October
2002, the Task Force rescinded its earlier consensus. With the rescission of
EITF Issue 98-10, as discussed above, the additional disclosures previously
called for under EITF Issue 02-3 are no longer applicable.

   The third issue addressed by the Task Force in EITF Issue 02-3 deals with
the recognition of unrealized gains and losses at inception of an energy
trading contract (commonly referred to as dealer profit). The Task Force did
not reach a consensus on this issue in October 2002.

   Finally, it is unclear whether the scope of future activities will include a
comprehensive conclusion regarding the appropriateness of the use of models as
a fundamental method for valuing transactions when market quotations are
unavailable. Should the Task Force issue definitive guidance on one or more of
these issues, such guidance may impact Dynegy. However, the extent of the
financial impact to Dynegy, if any, cannot be predicted with any degree of
certainty until the scope of the Task Force's conclusion is known and the
transition alternative is determined. If the Task Force prefers a retroactive
or a cumulative effect transition alternative, then Dynegy's historical
financial position and results of operations will be impacted negatively. If

                                      18

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

the Task Force prefers a prospective transition alternative, then Dynegy's
current financial position will be unaffected and the impact to future
operations is not expected to be material as a result of the Company's decision
to exit third party risk management aspects of the marketing and trading
business. Please see Note 4 for further discussion.

   FASB Statement No. 142.  In July 2001, the FASB issued Statement of
Financial Accounting Standards No. 142. "Goodwill and Other Intangible Assets"
("Statement No. 142"). Statement No. 142 discontinued goodwill amortization
over its estimated useful life and provided that goodwill is subject to at
least an annual fair-value based impairment test. The Company adopted Statement
No. 142 effective January 1, 2002. The estimation of fair value is highly
subjective, inherently imprecise and can change materially from period to
period based on, among other things, an assessment of market conditions,
projected cash flows and discount rate. Accordingly, if conditions change in
the future, the Company may record further impairment losses. On an annual
basis, absent any impairment indicators, the Company expects to perform its
annual impairment analysis in the fourth quarter after the annual budgetary
process. The changes in the carrying amount of goodwill for each of Dynegy's
reportable business segments for the nine-month period ended September 30, 2002
are as follows (in millions):

<TABLE>
<CAPTION>
                                          Wholesale  Dynegy   Transmission
                                           Energy   Midstream      &       Dynegy Global
                                           Network  Services  Distribution Communications  Total
                                          --------- --------- ------------ -------------- ------
<S>                                       <C>       <C>       <C>          <C>            <C>
Balances as of January 1, 2002...........   $ 930      $16       $ 381         $ 234      $1,561
Cumulative effect of change in accounting
  principle..............................      --       --          --          (234)       (234)
Goodwill acquired during the period......      --       --         887            --         887
Purchase price adjustments...............     (33)      --         (28)           --         (61)
Goodwill impaired during the period......    (897)      --          --            --        (897)
Sale of Canadian crude business..........      --       (1)         --            --          (1)
Sale of Northern Natural Gas Company.....      --       --        (859)           --        (859)
                                            -----      ---       -----         -----      ------
Balances as of September 30, 2002........   $  --      $15       $ 381         $  --      $  396
                                            -----      ---       -----         -----      ------
</TABLE>

   The purchase price adjustments relate to the United Kingdom natural gas
storage assets purchased in late 2001 and to the acquisition of Northern
Natural Gas Company ("Northern Natural") in early 2002, each of which was sold
within one year. Please see Note 4 for further discussion.

                                      19

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   The following table sets forth what Dynegy's net income and earnings per
share ("EPS") would have been in the three- and nine-month periods ended
September 30, 2001 if goodwill had not been amortized during those periods,
compared to the net loss and loss per share Dynegy recorded for the three- and
nine-month periods ended September 30, 2002 (in millions, except per share
data).

<TABLE>
<CAPTION>
                                                    Three Months   Nine Months
                                                       Ended          Ended
                                                   September 30,  September 30,
                                                   -------------- --------------
                                                     2002   2001    2002   2001
                                                   -------  ----- -------  -----
<S>                                                <C>      <C>   <C>      <C>
Reported net income (loss)........................ $(1,651) $ 238 $(2,459) $ 432
Add back: Goodwill amortization...................      --     12      --     36
                                                   -------  ----- -------  -----
Adjusted net income (loss)........................ $(1,651) $ 250 $(2,459) $ 468
Less: preferred stock dividends...................      83     --     248     --
                                                   -------  ----- -------  -----
Net income (loss) available to common stockholders $(1,734) $ 250 $(2,707) $ 468
                                                   -------  ----- -------  -----
Basic EPS:
Reported net income (loss)........................ $ (4.71) $0.73 $ (7.42) $1.33
Goodwill amortization.............................      --   0.04      --   0.11
                                                   -------  ----- -------  -----
Adjusted net income (loss)........................ $ (4.71) $0.77 $ (7.42) $1.44
                                                   -------  ----- -------  -----
Diluted EPS:
Reported net income (loss)........................ $ (4.71) $0.71 $ (7.42) $1.28
Goodwill amortization.............................      --   0.04      --   0.11
                                                   -------  ----- -------  -----
Adjusted net income (loss)........................ $ (4.71) $0.75 $ (7.42) $1.39
                                                   -------  ----- -------  -----
</TABLE>

   FASB Statement No. 144.  In August 2001, the FASB issued Statement of
Financial Accounting Standards No. 144, "Accounting for the Impairment or
Disposal of Long-Lived Assets" ("Statement No. 144"). Statement No. 144
addresses the accounting and reporting for the impairment or disposal of
long-lived assets and supersedes FASB Statement No. 121, "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of"
and APB Opinion No. 30, "Reporting the Results of Operations--Reporting the
Effects of Disposal of a Segment of a Business, and Extraordinary, Unusual and
Infrequently Occurring Events and Transactions." The Company's adoption of
Statement No. 144 on January 1, 2002 did not have any impact on its financial
position, results of operations or cash flows. However, see Note 3 below
regarding the Company's treatment of assets held for sale at September 30,
2002, and see Note 4 below regarding the impairment of the telecommunications
business in the second quarter 2002.

   Accounting Principles Not Yet Adopted, FASB Statement No. 143.  Also during
2001, the FASB issued Statement of Financial Accounting Standards No. 143,
"Accounting for Asset Retirement Obligations" ("Statement No. 143"). Statement
No. 143 requires that the fair value of a liability for an asset retirement
obligation be recognized in the period in which it is incurred with the
associated asset retirement costs being capitalized as a part of the carrying
amount of the long-lived asset. The Company is evaluating the future financial
effects of adopting Statement No. 143 and will adopt the standard effective
January 1, 2003.

   FASB Statement No. 146.  In July 2002, the FASB issued Statement of
Financial Accounting Standards No. 146, "Accounting for Exit or Disposal
Activities" ("Statement No. 146"). Statement No. 146 addresses issues regarding
the recognition, measurement and reporting of costs that are associated with
exit and disposal

                                      20

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

activities, including restructuring activities that are accounted for pursuant
to the guidance that the EITF has set forth in EITF Issue No. 94-3, "Liability
Recognition for Certain Employee Termination Benefits and Other Costs to Exit
an Activity (including Certain Costs Incurred in a Restructuring)." Statement
No. 146 requires costs to be accrued as incurred rather than when an approved
plan is in place. The scope of Statement No. 146 also includes (1) costs
related to terminating a contract that is not a capital lease and (2)
termination benefits that employees who are involuntarily terminated receive
under the terms of a one-time benefit arrangement that is not an ongoing
benefit arrangement or an individual deferred compensation contract. Statement
No. 146 will be effective for exit or disposal activities that are initiated
after December 31, 2002, although early adoption of the standard is encouraged.
The Company is evaluating the impact of this standard on its current
restructuring initiative and will apply provisions of the standard accordingly.

Note 2--Liquidity and Industry Conditions

   Dynegy believes its current liquidity position should be sufficient to
permit the Company to meet its debt maturities and other obligations through
the first quarter 2003. The sufficiency of the Company's liquidity will depend
upon:

  .   Dynegy's continued compliance with the covenants in its bank credit and
      other debt instruments or its ability to negotiate waivers in the event
      of a covenant default;

  .   Dynegy's ability to repay or refinance the Dynegy Holdings Inc. ("DHI")
      and Illinois Power Company ("IP") credit facilities that mature in the
      second quarter 2003;

  .   Dynegy's ability to manage its exit from third party risk management
      aspects of the marketing and trading business and the timing of the
      expected cash flows and reduction in collateral from this exit;

  .   the level of earnings and cash flow from Dynegy's assets and businesses,
      which is subject to the effect of changes in commodity prices,
      particularly natural gas and power;

  .   Dynegy's non-investment grade credit ratings, the effect of these ratings
      on Dynegy's ability to access capital markets and to conduct normal
      commercial operations and the effect of any further downgrade in these
      credit ratings on refinancings;

  .   ongoing investigations and litigation relating to Project Alpha, Dynegy's
      trading practices and its activities in the California power markets;

  .   confidence in Dynegy's financial reporting in light of the previously
      announced restatements and the ongoing re-audit of its 1999-2001
      financial statements; and

  .   Dynegy's ability to eliminate or further reduce net cash outflows
      associated with its telecommunications business.

   Dynegy's liquidity may be significantly adversely affected if it is unable
to refinance the DHI and IP credit facilities that mature in the second quarter
2003. Dynegy also faces the risk of a covenant default on these facilities or
other debt instruments prior to maturity. The DHI and IP credit facilities and
the Company's telecommunications lease financing contain various covenants,
including EBITDA-to-interest and debt-to-capitalization financial covenants.
The Company was in compliance with the covenants in its credit facilities and
other debt instruments at September 30, 2002. While many of the charges
incurred by the Company during 2002 are excluded from the compliance
calculations, continued weakness in the Company's operating results

                                      21

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

compared with results in 2001 will make it more difficult for the Company to
continue to comply with certain of its financial covenants. Compliance with
these financial covenants is measured on a quarterly basis.

   Any failure to satisfy one or more of these financial covenants would
constitute a breach giving rise to a default under the applicable debt
instrument and would permit the lenders under such debt instrument to
accelerate the maturity of Dynegy's outstanding obligations thereunder.
Depending upon the particular debt instrument, such a breach or any action by
the lenders to accelerate the maturity of amounts owing would result in a
default under or trigger cross-acceleration provisions in a significant portion
of the Company's other outstanding debt instruments. In the event of
non-compliance, Dynegy would seek waivers from the lenders under these debt
instruments or attempt to repay or refinance the affected debt instruments. The
Company cannot provide any assurance that it could repay, obtain waivers with
respect to or refinance such debt instruments in the event of any such default.

   Dynegy has executed on the principal elements of its capital plan in order
to meet its current obligations as they mature and provide the necessary
collateral to support its commercial operations. Dynegy believes that the
combination of its liquidity initiatives and the roll off of collateral and
cash flow from its exit from third party risk management aspects of the
marketing and trading business should enable the Company to refinance all or a
sufficient portion of its second quarter 2003 maturities. However, the Company
faces significant risks related to its ongoing operations and other matters
discussed above. Dynegy also faces the risk that it may not be able to reach
agreement with its lenders on mutually acceptable terms. If Dynegy fails to
execute the remaining elements of its strategy, it may be forced to consider
other strategic alternatives including a possible reorganization under the
protection of federal bankruptcy laws.

   The accompanying unaudited condensed consolidated financial statements have
been prepared assuming that the Company will continue as a going concern. This
basis of accounting contemplates the recovery of the Company's assets and the
satisfaction of its liabilities in the normal course of conducting business,
which in turn is subject to the risks and contingencies discussed above.
Management believes that actions presently being taken relative to the
Company's capital plan, its revolving credit facilities and other strategic
alternatives should enable the Company to meet its obligations in a manner
consistent with this accounting treatment.

Note 3--Acquisitions and Dispositions

   Northern Natural Gas.  In November 2001, Dynegy acquired 1,000 shares of
Series A Preferred Stock ("Series A Preferred Stock") in Northern Natural for
$1.5 billion. DHI, a wholly owned subsidiary, concurrently acquired an option
to purchase all of the equity of Northern Natural's indirect parent company.
DHI exercised its option to acquire the indirect parent of Northern Natural in
November 2001 upon termination of Dynegy's merger agreement with Enron Corp.
("Enron"), and the closing of the option exercise occurred on January 31, 2002.

   On August 16, 2002, Dynegy sold Northern Natural to MidAmerican Energy
Holdings Company ("MidAmerican") for $928 million in cash, subject to
adjustment for changes in working capital. Under the terms of this agreement,
MidAmerican acquired all of the common and preferred stock of Northern Natural
and assumed all of Northern Natural's $950 million of debt. Dynegy incurred a
pre-tax loss of approximately $586 million ($566 million after-tax) associated
with the sale. Subject to resolution of the working capital adjustments
relating to the sale, Dynegy could incur an additional loss ranging from zero
to $20 million in the fourth quarter 2002.

                                      22

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   On September 30, 2002, DHI sold $90 million in 6.875 percent senior notes of
Northern Natural due May 2005 for approximately $96 million including accrued
interest of $2 million. DHI acquired the notes at par value in April 2002
pursuant to a tender offer that it agreed to effect in order to obtain a
bondholder consent in connection with the acquisition of Northern Natural. The
gain on sale of approximately $4 million is reflected in other income (expense)
and is net of accrued interest.

   As a result of the disposition during the quarter, Northern Natural is
reported as a discontinued operation in the accompanying financial statements
and these notes. Revenues from Northern Natural were $30 million and $201
million, respectively, for the three- and nine-month periods ended September
30, 2002. Income before taxes was zero and $38 million for the three- and
nine-month periods ended September 30, 2002.

   Illinois Power Transmission.  On October 9, 2002, IP announced that it
agreed to sell its high-voltage electric transmission system to Trans-Elect
Inc., an independent transmission company, for $239 million. The sale is
expected to close in the first half of 2003 and is subject to customary closing
conditions, including required approvals from the SEC, the Federal Trade
Commission, the Illinois Commerce Commission and the FERC. With respect to the
FERC, the sale is conditioned on its approving the levelized rates application
to be filed by Trans-Elect seeking a 13% return on equity. If the FERC does not
approve levelized rates in substantially the form sought by Trans-Elect, then
Trans-Elect is not obligated to close on the sale. The purchase price also is
subject to adjustment with respect to certain items, including a final
determination of the transmission assets to be sold, any variance in the
assumed amount of inventory on hand and the amount of accounts payable at
closing. A change in interest rates from those estimated by Trans-Elect in
contemplating its financing for the sale also could cause an adjustment to the
purchase price or postponement of the closing, at IP's option. The pre-tax gain
on the sale, which will be recorded at closing, is estimated to be
approximately $47 million. In addition, as a result of the sale, IP expects to
accelerate approximately $90 million of regulatory asset amortization.

   Marketing & Trading.  In October 2002, the Company announced it would exit
third party risk management aspects of the marketing and trading business. The
decision to exit this business is expected to reduce significantly the
Company's collateral requirements and overall corporate expenses. The Company
expects to complete a significant portion of this exit over the next three to
six months. During this period and thereafter, the Company will maintain the
resources and make the necessary arrangements to meet its customer commitments,
including retaining personnel and risk management capabilities. This decision
to exit third party risk management aspects of the marketing and trading
business will not change the commercial activities of Dynegy's midstream or
generation businesses. The midstream business will continue to manage commodity
price risk associated with its operations related to fuel procurement and to
market natural gas and natural gas liquids. Further, the generation business
will continue to manage commodity price risk existing in its physical asset
positions through optimizing fuel procurement and to market power from these
assets.

   Canadian Gas Marketing.  On October 17, 2002, Dynegy entered into a letter
of intent to sell a portion of its Canadian natural gas marketing business to
The Seminole Group Inc. The sale is expected to close in November 2002, subject
to regulatory approvals and other customary closing conditions. Any loss on the
sale is expected to be less than $10 million and will be recorded upon
consummation of the sale. The remaining Canadian business will consist
primarily of existing power marketing positions and physical gas in storage.

   United Kingdom Storage.  On September 30, 2002, the Company sold a
subsidiary that owned the Hornsea onshore natural gas storage facility in the
United Kingdom for net cash proceeds of approximately $189 million.

                                      23

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

No gain or loss was recognized on the transaction. On November 14, 2002, the
Company sold the subsidiaries that owned the Rough offshore natural gas field
in the North Sea and the Easington natural gas processing terminal on the East
Yorkshire coast for cash proceeds of approximately $500 million. The Company
does not expect to recognize a material gain or loss on this transaction. The
results of operations for the United Kingdom storage business are included
within discontinued operations in the accompanying Condensed Consolidated
Statements of Operations. Revenues from the United Kingdom storage business
were $47 million and $128 million, respectively, for the three- and nine-month
periods ended September 30, 2002. Income before taxes was $17 million and $37
million, respectively, for the three- and nine-month periods ended September
30, 2002. Additionally, at September 30, 2002, the Rough and Easington assets
were classified as held for sale in accordance with Statement No. 144. The
major classes of assets and liabilities classified as "Assets Held for Sale" or
Liabilities Held for Sale" in the accompanying September 30, 2002 Condensed
Consolidated Balance Sheet are as follows (in millions):

<TABLE>
<CAPTION>
                                                   September 30,
                                                       2002
                                                   -------------
               <S>                                 <C>
               Current Assets:
               Accounts receivable................     $ 13
               Inventory..........................       15
               Other..............................        4
                                                       ----
                      Total Current Assets........       32
                                                       ----
               Other Assets:
               Property, plant and equipment, net.      638
               Other..............................        6
                                                       ----
                      Total Other Assets..........      644
                                                       ----
                      Total Assets................     $676
                                                       ----
               Current Liabilities................     $ 30
               Other Liabilities:
               Deferred taxes.....................      133
               Other..............................       78
                                                       ----
                      Total Other Liabilities.....      211
                                                       ----
                      Total Liabilities...........     $241
                                                       ====
</TABLE>

Note 4--Restructuring and Impairment Charges

   In the first quarter 2002, the Company recognized a $234 million pre-tax
charge to write-down goodwill in its telecommunications business in connection
with the adoption of Statement No. 142 and reflected such charge as a
cumulative effect of a change in accounting principle. As there was no tax
basis in this goodwill, $234 million represents the pre-tax and after-tax
impact on earnings. The Company also recorded pre-tax charges of $65 million
($42 million after-tax) primarily related to its investment in the
telecommunications business.

   During the second quarter 2002, the Company recognized a $683 million
pre-tax ($444 million after-tax) charge principally related to the impairment,
write-off or obsolescence of certain assets and an accrual for severance
related to a corporate restructuring. The charge primarily relates to the
impairment of the Company's

                                      24

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

investment in the communications business, the impairment of investments in
securities of entities engaged in technology-related ventures and a severance
charge related to the corporate restructuring.

   During the third quarter 2002, the Company recognized a $1,693 million
pre-tax ($1,600 million after-tax) charge principally related to the impairment
of goodwill associated with the Company's Wholesale Energy Network ("WEN")
segment, a loss on the sale of Northern Natural, an impairment of investments
in generating facilities and the write-off of other obsolete assets.

   The pre-tax charges consisted of the following for the periods ended
September 30, 2002 (in millions):

<TABLE>
<CAPTION>
                                                    Three Months   Nine Months
                                                        Ended         Ended
                                                    September 30, September 30,
                                                        2002          2002
                                                    ------------- -------------
<S>                                                 <C>           <C>
Impairment of goodwill.............................     $  897       $  897
Loss on sale of Northern Natural...................        586          586
Cumulative effect of change in accounting principle         --          234
Impairment of telecommunications business..........          4          635
Impairment of generation investments...............        144          144
Impairment of technology investments...............         12           80
Severance charge...................................         --           37
Enron settlement...................................         25           25
Write-off other obsolete assets....................         25           37
                                                       -------       ------
   Total...........................................     $1,693       $2,675
                                                       =======       ======
</TABLE>

   Impairment of goodwill.  The value of goodwill associated with the WEN
segment was reviewed for impairment at September 30, 2002. Based on this
assessment, an after-tax charge to earnings of $897 million was recorded to
impair substantially all of the goodwill associated with the WEN segment. The
fair value of WEN consists of value associated with marketing and trading as
well as the value associated with power generation. The fair values of the
respective components were estimated utilizing the expected discounted future
cash flows. The primary factors leading to this impairment are : (1) the
reduction in near-term power prices, (2) an increase in the rate of return
required for investors to enter the energy merchant sector and (3) the
Company's decision to exit third party risk management aspects of the marketing
and trading business. The charge was recorded in Goodwill Impairment in the
accompanying Condensed Consolidated Statement of Operations.

   Loss on Sale of Northern Natural.  On August 16, 2002, Dynegy sold Northern
Natural to MidAmerican for $928 million in cash, subject to adjustment for
changes in working capital. MidAmerican acquired all of the common and
preferred stock of Northern Natural and assumed all of Northern Natural's $950
million of debt, which debt had a book value of approximately $890 million.
Dynegy incurred a pre-tax loss of $586 million ($566 million after-tax)
associated with the sale. This charge is recorded in Discontinued Operations in
the accompanying Condensed Consolidated Statement of Operations.

   For federal income tax purposes, the sale resulted in a capital loss, which
may be deducted solely against capital gains, if any, realized by the
enterprise in its consolidated federal tax returns. There is a five-year
carryforward for capital losses under existing federal statutes. For financial
reporting purposes, the Company

                                      25

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

recorded a valuation allowance against substantially all of the potential tax
benefit as a result of uncertainty as to the ability to generate capital gains
in the future.

   Cumulative effect of change in accounting principle.  During the first
quarter 2002, the Company recognized a $234 million charge to impair goodwill
related to its Dynegy Global Communications ("DGC") segment in accordance with
Statement No. 142 and reflected such charge as a cumulative effect of a change
in accounting principle. The fair value of that reporting segment was estimated
using the expected present value of future cash flows. The value was negatively
impacted by continued weakness in the telecommunications and broadband markets.
This charge is reflected as a Cumulative Effect of Change in Accounting
Principle in the accompanying Condensed Consolidated Statement of Operations.

   Impairment of telecommunications business.  During the second quarter 2002,
prospects for the telecommunications sector continued to deteriorate as
evidenced by an increased number of bankruptcies in the sector, continued
devaluation of debt and equity securities, a lack of financing sources and
further pricing pressures resulting from challenges faced by major industry
participants. As a result of this deterioration, a continuing negative outlook
for the industry and Dynegy's desire to improve its own liquidity, management
began to take measures to reduce cash losses in the business, including
reducing capital spending and lowering operating and administrative expenses.
Management is pursuing partnership and sale opportunities for this business
segment, although no formal plans are in place.

   Dynegy's impairment analysis at June 30, 2002, calculated in accordance with
the guidelines set forth in Statement No. 144, indicated future cash flows from
DGC's operations were insufficient to cover the carrying value of that
segment's long-lived assets. As a result, a pre-tax non-cash impairment charge
totaling $611 million ($397 million after-tax) was recorded in the second
quarter 2002 in Impairment and Other Charges. For the nine-month period ended
September 30, 2002, a cumulative impairment charge totaling $635 million ($414
million after-tax) was recorded in Impairment and Other Charges, Cost of Sales
and Other Income (Expense) in the accompanying Condensed Consolidated
Statements of Operations.

   Impairment of generation investments.  In conjunction with its review of the
carrying value of goodwill, the Company assessed the carrying value of its
generation portfolio on an asset-by-asset basis. The generation portfolio
includes wholly owned generating facilities, which are reflected in Property,
Plant and Equipment, as well as investments in partnerships and limited
liability companies that own generating facilities, which are reflected in
Unconsolidated Investments. Based on this review, the carrying value associated
with the wholly owned generation facilities was considered realizable. However,
certain investments were considered impaired, resulting in a pre-tax charge of
$144 million ($94 million after-tax), which is reflected in Earnings (Losses)
from Unconsolidated Investments in the accompanying Condensed Consolidated
Statement of Operations. This diminution in the fair value of these investments
is a result of depressed energy prices and an increase in the rate of return
required by investors to enter into the power generating business.

   Impairment of technology investments.  At June 30, 2002, the valuations of
technology investments were assessed in light of the Company's decision to
pursue partnership and sale opportunities for its telecommunications business.
These investments were originally entered into in order to leverage existing
commercial relationships or as a means of expanding new relationships.
Historically, the Company viewed these investments as strategic and core to its
telecommunications strategy. Accordingly, Dynegy expected to hold these
investments for the long term and viewed trends in the sector as cyclical.
These investments include ownership in

                                      26

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

public and private companies and investment funds focused in the technology
sector. The continued downturn in the technology sector during the second
quarter 2002 combined with the Company's change in strategy resulted in an
impairment charge relative to these investments. In the second quarter 2002,
the Company recorded a $23 million pre-tax ($15 million after-tax) charge in
Earnings (Losses) From Unconsolidated Investments in the accompanying Condensed
Consolidated Statements of Operations. This is in addition to the first quarter
pre-tax charge of $45 million ($30 million after-tax) resulting from
unfavorable market conditions.

   These investments were reevaluated at September 30, 2002 based on the
Company's inability to sell certain investments for their adjusted carrying
values and the continued depressed conditions in the technology sector. Based
on this assessment, the remaining carrying value of such investments were
written off, resulting in a pre-tax charge of $12 million ($8 million
after-tax). The cumulative pre-tax charge related to technology investments for
the nine months ended September 30, 2002 was $80 million ($53 million
after-tax).

   Severance Charge.  The Company recognized a pre-tax charge of approximately
$37 million ($24 million after-tax) in the second quarter 2002 for severance
benefits for approximately 325 employees who were from various segments and
included all staffing levels, including the Company's former Chief Executive
Officer and Chief Financial Officer. The charge is included in Impairment and
Other Charges in the accompanying Condensed Consolidated Statements of
Operations. The following is a schedule of the reduction in the liability
related to this charge (in millions):

<TABLE>
<CAPTION>
                                                      Balance At September 30,
 Original Charge Amount        Cash Utilization                 2002
 ----------------------        ----------------       ------------------------
<S>                        <C>                        <C>
           $37                       $(15)                       $22
</TABLE>

   A substantial amount of the balance at September 30, 2002 relates to
severance that has not been paid to the Company's former Chief Executive
Officer and Chief Financial Officer.

   Enron settlement.  In August 2002, Dynegy agreed to pay Enron $25 million to
settle the lawsuit Enron had filed alleging wrongful termination of the
parties' November 2001 merger agreement, $10 million of which was paid to Enron
upon approval of the settlement agreement by the Bankruptcy Court, with the
remaining $15 million escrowed until the settlement becomes final. This pre-tax
$25 million ($16 million after-tax) charge was recorded in Other Income
(Expense) in the accompanying Condensed Consolidated Statements of Operations
for the nine months ended September 30, 2002. Please see Note 11 for further
discussion.

   Write-off of other obsolete assets.  The Company recognized a pre-tax charge
of $12 million ($8 million after-tax) in the second quarter 2002 related to the
retirement of partially depreciated information technology equipment and
software replaced during the quarter with new system applications and
arrangements as well as miscellaneous deposits that are not expected to provide
future value. The charge was recorded in Impairment and Other Charges in the
accompanying Condensed Consolidated Statements of Operations.

   As a result of the Company's decision to exit third party risk management
aspects of the marketing and trading business, its investment in Dynegydirect
was written off in the third quarter 2002, resulting in a pre-tax charge of $25
million ($16 million after-tax). The charge was recorded in Impairment and
Other Charges in the accompanying Condensed Consolidated Statements of
Operations.

   Corporate Restructuring.  In October 2002, the Company announced that it is
implementing a restructuring plan designed to improve operational efficiencies
and performance across its lines of business. The

                                      27

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

Company will adopt a decentralized business structure consisting of a
streamlined corporate center and operating units in power generation, natural
gas liquids, regulated energy delivery and communications. As a result of this
restructuring, the Company will recognize pre-tax charges of approximately $50
million ($33 million after-tax) and $6 million ($4 million after-tax) in the
fourth quarter 2002 and first quarter 2003, respectively, for severance
benefits for approximately 780 employees who were from various segments and
included all staff levels.

   The Company is assessing other potential fourth quarter charges, which may
include, but are not limited to, charges associated with the recently announced
reduction in workforce and organizational restructuring and charges associated
with exiting third party risk management aspects of the marketing and trading
business.

Note 5--Commercial Operations, Risk Management Activities and Financial
Instruments

   Provisions in Statement No. 133 affect the accounting and disclosure of
certain contractual arrangements and operations of the Company. Under Statement
No. 133, all derivative instruments are recognized in the balance sheet at
their fair values and changes in fair value are recognized immediately in
earnings, unless the derivatives (which are not a part of the Company's
marketing activities) qualify and are designated as hedges of future cash
flows, fair values or net investments or qualify, and are designated, as normal
purchases or sales. Derivatives treated as normal purchases or sales are
recorded and recognized in income using accrual accounting.

   The nature of the Company's business necessarily involves certain market and
financial risks. The Company routinely enters into financial instrument
contracts in an attempt to mitigate or eliminate these various risks. These
risks and the Company's strategy for mitigating these risks are more fully
described in Note 3 to the 2001 Form 10-K.

   Changes in stockholders' equity related to derivatives for the nine-month
period ended September 30, 2002 were as follows, net of tax (in millions):

<TABLE>
                <S>                                       <C>
                Balance at December 31, 2001............. $  8
                Current period changes in fair value, net  (22)
                Reclassifications to earnings, net.......   17
                                                          ----
                Balance at September 30, 2002............ $  3
                                                          ----
</TABLE>

   Accumulated other comprehensive income, net of tax, is included in
Stockholders' Equity on the Condensed Consolidated Balance Sheets as follows
(in millions):

<TABLE>
 <S>                                                                       <C>
 Statement No. 133, net................................................... $ 3
 Currency translation adjustment..........................................  10
                                                                           ---
 Accumulated other comprehensive income, net of tax, at September 30, 2002 $13
                                                                           ---
</TABLE>

                                      28

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   Other comprehensive income (loss) is as follows (in millions):

<TABLE>
<CAPTION>
                                                   Nine Months
                                                      Ended
                                                  September 30,
                                                  -------------
                                                    2002   2001
                                                  -------  ----
                <S>                               <C>      <C>
                Net income (loss)................ $(2,459) $432
                Other comprehensive income (loss)      40     7
                                                  -------  ----
                Total comprehensive income (loss) $(2,419) $439
                                                  =======  ====
</TABLE>

   The Company adopted Statement No. 133, effective January 1, 2001, resulting
in an after-tax cumulative effect gain of approximately $2 million.

   From time to time the Company enters into various financial derivative
instruments which qualify as cash flow hedges. For derivatives treated as
hedges of future cash flows, the effective portion of changes in fair value is
recorded in other comprehensive income until the related hedged items impact
earnings. Any ineffective portion of a hedge is reported in earnings
immediately. Instruments related to the Company's customer and risk-management
and midstream liquids businesses are entered into for purposes of hedging
forward fuel requirements for certain power generation facilities, locking in
future margin in the domestic midstream liquids business and hedging price risk
in the global liquids business. Interest rate swaps are used to convert the
floating interest rate component of certain obligations to fixed rates.

   Dynegy recognized a charge of less than $1 million relating to hedge
ineffectiveness during the nine months ended September 30, 2002, and no amounts
were excluded from the assessment of hedge effectiveness related to the hedge
of future cash flows. Additionally, no amounts were reclassified to earnings in
connection with forecasted transactions that were no longer considered probable
of occurring.

   The balance in other comprehensive income at September 30, 2002 associated
with these cash flow hedges is expected to be reclassified to future earnings
contemporaneously with the related purchases of fuel, sales of electricity or
liquids and payments of interest as applicable to each type of hedge. Of this
amount, an approximate $17 million loss, net of taxes, is estimated to be
reclassed into earnings over the 12-month period ending September 30, 2003.
Actual amounts ultimately reclassed to earnings over the next 12 months could
vary materially from this estimated amount as a result of changes in market
conditions.

   The Company also enters into derivative instruments which qualify as fair
value hedges. For derivatives treated as fair value hedges, changes in the fair
value of the derivative and changes in the fair value of the related asset or
liability are recorded in current period earnings. The Company uses interest
rate swaps to convert a portion of its fixed-rate debt into variable-rate debt.
During the nine months ended September 30, 2002 and 2001, there was no
ineffectiveness from changes in fair value of hedge positions, and no amounts
were excluded from the assessment of hedge effectiveness. Additionally, no
amounts were recognized in relation to firm commitments that no longer
qualified as fair value hedge items.

   The Company has investments in foreign subsidiaries, the net assets of which
are exposed to currency exchange-rate volatility. The Company uses derivative
financial instruments to hedge this exposure. For derivatives treated as hedges
of net investments in foreign operations, the effective portion of changes in
the fair

                                      29

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

value of the derivative is recorded in the cumulative translation adjustment.
Any ineffective portion of a hedge is reported in earnings immediately. For the
nine months ended September 30, 2002, approximately $61 million of net losses
related to these contracts were included in the cumulative translation
adjustment. During the nine months ended September 30, 2002, ineffectiveness
from changes in fair value of net investment hedge positions was a loss of
approximately $7 million. There were no net investment hedges during the nine
months ended September 30, 2001.

Note 6--Unconsolidated Investments

   Investments in affiliates that are not controlled by the Company but where
the Company has significant influence over operations are accounted for by the
equity method. The Company's share of net income from these affiliates is
reflected in the Condensed Consolidated Statements of Operations as Earnings
(Losses) from Unconsolidated Investments. The Company's principal equity method
investments consist of entities that operate generation assets and natural gas
liquids assets. These equity investments totaled $684 million and $830 million
at September 30, 2002 and December 31, 2001, respectively. The Company entered
into these ventures principally for the purpose of sharing risk and leveraging
existing commercial relationships. These ventures maintain independent capital
structures and have financed their operations on a non-recourse basis to the
Company.

   Generation Assets.  Generation investments primarily include ownership
interests in eight joint ventures that own fossil fuel electric generation
facilities as well as a limited number of international ventures. The Company
ownership is 50 percent in the majority of these ventures. The Company's
aggregate net investment of $568 million at September 30, 2002 represents
approximately 2,400 MW of net generating capacity. Dynegy's most significant
investment in generating capacity is its interest in West Coast Power,
representing approximately 1,400 MW of net generating capacity in California.
The net investment in West Coast Power totaled approximately $355 million and
$330 million at September 30, 2002 and December 31, 2001, respectively. West
Coast Power provided equity earnings of approximately $49 million and $157
million in the nine months ended September 30, 2002 and 2001, respectively. NRG
Energy Inc. ("NRG"), the parent company of Dynegy's partner in two joint
ventures, including West Coast Power, recently announced that it has presented
a restructuring proposal to representatives of its bank lenders and
bondholders. NRG also indicated that a Chapter 11 filing may ultimately be the
means for it to implement any restructuring proposal with its creditors. Dynegy
cannot predict with any degree of certainty the effects of these or similar
actions by NRG on the operations or collateral obligations of these two joint
ventures.

   Midstream Investments.  Midstream investments include a 23 percent ownership
interest in a venture that operates a natural gas liquids ("NGL") processing,
extraction, fractionation and storage facility in the Gulf Coast region as well
as a 39 percent ownership interest in a venture that fractionates NGLs on the
Gulf Coast. At September 30, 2002 and December 31, 2001, the Company's
aggregate net investment in these midstream businesses totaled approximately
$116 million and $146 million, respectively. The $146 million of investments at
December 31, 2001 included Dynegy's investment in West Texas LPG Pipeline
Limited Partnership ("WTLPS"), which was transferred to ChevronTexas
Corporation in August 2002. Please see Note 8 for further discussion of this
transaction.

                                      30

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   Summarized aggregate financial information for these generation and
midstream investments and Dynegy's equity share thereof was ($ in millions):

<TABLE>
<CAPTION>
                                   Nine Months Ended September 30,
                                   -------------------------------
                                       2002            2001
                                   --------------- ---------------
                                           Equity          Equity
                                   Total   Share   Total   Share
                                   ------  ------  ------  ------
                  <S>              <C>     <C>     <C>     <C>
                  Revenues........ $2,786  $1,075  $3,444  $1,333
                                   ------  ------  ------  ------
                  Operating margin $  572  $  204  $  764  $  299
                                   ------  ------  ------  ------
                  Net income...... $  281  $  108  $  461  $  193
                                   ------  ------  ------  ------
</TABLE>

   In addition to its equity share of net income from these investments, the
Company recognized an impairment charge of $144 million, which is also included
in Earnings (Losses) from Unconsolidated Investments. See Note 4 for further
discussion regarding the impairment of certain of these assets in the third
quarter 2002.

   Other Investments.  In addition to these equity investments, the Company
holds interests in non-public companies for which it does not have significant
influence over the operations. These investments are generally accounted for by
the cost method. Such investments totaled $32 million and $84 million at
September 30, 2002 and December 31, 2001, respectively. During the third
quarter of 2001, the Company recognized an $19 million pre-tax loss on a
technology investment due to impairments that were determined by management to
be other-than-temporary. During the nine-months ended September 30, 2002, the
Company wrote down the remaining values of its available-for-sale securities.
See Note 4--Restructuring and Impairment Charges.

                                      31

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


Note 7--Debt

   Near-Term Maturities.  As of November 14, 2002, our debt maturities and
related obligations through December 31, 2003 were approximately as follows:

<TABLE>
<CAPTION>
                                                                     Amount
       Date                            Type                     Outstanding/Owed
       ----                            ----                     ----------------
<S>                 <C>                                         <C>
Fourth Quarter 2002 Canadian Credit Facility                     $  40 million
                    IP Transitional Funding Trust Notes(1)       $21.6 million
                    ABG Gas Supply(2)                            $11.7 million

First Quarter 2003. Renaissance/Rolling Hills Interim Financing  $ 200 million
                    IP Transitional Funding Trust Notes(1)       $21.6 million
                    Black Thunder Financing(3)                   $18.9 million
                    ABG Gas Supply(2)                            $17.8 million

Second Quarter 2003 DHI $900 million Revolving Credit Facility   $ 789 million (4)
                    DHI $400 million Revolving Credit Facility   $ 382 million (5)
                    IP Bank Credit Facility                      $ 300 million
                    IP Transitional Funding Trust Notes(1)       $21.6 million
                    Black Thunder Financing(3)                   $21.6 million
                    ABG Gas Supply(2)                            $18.1 million

Third Quarter 2003. IP Maturing Mortgage Bonds                   $ 190 million
                    IP Transitional Funding Trust Notes(1)       $21.6 million
                    Black Thunder Financing(3)                   $21.6 million
                    ABG Gas Supply(2)                            $18.4 million

Fourth Quarter 2003 IP Transitional Funding Trust Notes(1)       $21.6 million
                    Black Thunder Financing(3)                   $21.6 million
                    ABG Gas Supply(2)                            $18.7 million
</TABLE>
--------
(1) Reflects required quarterly payments which are made with cash set aside
    from IP customer billings.
(2) Reflects required payments associated with Project Alpha as further
    described in the Explanatory Note.
(3) Reflects required quarterly payments under Dynegy's Black Thunder financing.
(4) Reflects amounts outstanding under the DHI $900 million revolving credit
    facility, including $661 million in outstanding letters of credit.
(5) Reflects amounts outstanding under the DHI $400 million revolving credit
    facility, including $382 million in outstanding letters of credit.

   The Company's decision to exit third party risk management aspects of the
marketing and trading business is expected to reduce significantly its future
requirements to post collateral in the form of cash or letters of credit.
Accordingly, upon successful execution of the Company's exit from this
business, a corresponding reduction in the Company's second quarter 2003
maturities is anticipated. Please read "Management's Discussion and Analysis of
Financial Condition and Results of Operations--Liquidity and Capital Resources"
for a discussion of the Company's liquidity and capital plan.

   During the nine-month period ended September 30, 2002, the Company repaid
commercial paper borrowings and revolving credit facilities for Dynegy, DHI and
IP of approximately $500 million in the aggregate and borrowed an aggregate of
approximately $137 million under the Dynegy and DHI revolving credit

                                      32

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

facilities and $60 million under IP's revolving credit facility. Additionally,
during the nine months ended September 30, 2002, Dynegy and DHI issued an
aggregate of $651 million of letters of credit under their revolving credit
facilities. During the period from September 30, 2002 through the date of this
report, Dynegy repaid $84 million under the Dynegy revolving credit facility
that expired on November 2, 2002 and repaid $75 million under the DHI revolving
credit facility in order to allow for capacity to issue additional letters of
credit. Additionally, as described below, Dynegy used $250 million in proceeds
from sales of its United Kingdom natural gas storage facilities to repay an
interim financing that represented an advance on a portion of the proceeds from
such sales.

   Interim Financings.  In July 2002, the Company completed a $200 million
interim financing, bearing interest at LIBOR plus 1.38 percent. This loan
matures in January 2003 and is secured by interests in Dynegy's Renaissance and
Rolling Hills merchant power generation facilities.

   In June 2002, the Company completed a $250 million interim financing,
bearing interest at LIBOR plus 1.75 percent. This loan matures in June 2003 and
represents an advance on a portion of the proceeds from the sale of the
Company's United Kingdom natural gas storage facilities. In September 2002,
Dynegy sold the entity that owned the Hornsea storage facility and in October
2002 repaid approximately $189 million of this interim financing with the net
proceeds. On November 14, 2002, Dynegy sold the entities that owned the Rough
facilities and repaid the remaining balance of this financing with a portion of
the proceeds therefrom.

   Illinois Power.  On May 17, 2002, IP exercised the "term-out" provision
contained in its $300 million 364-day revolving credit facility, which was
scheduled to mature on May 20, 2002. In connection with this conversion, IP
borrowed the remaining $60 million available under this facility. The exercise
of the "term-out" provision converted the facility to a one-year term loan that
matures in May 2003. As such, the amounts outstanding under this loan are
classified as current. Borrowings of $300 million were outstanding under this
loan at September 30, 2002.

   DHI Revolvers.  On April 29, 2002, DHI closed a $900 million unsecured
revolving credit agreement with a syndicate of commercial banks. This facility
matures on April 28, 2003. Generally, borrowings under the credit agreement
bear interest at a Eurodollar rate plus a margin that is determined based on
designated unsecured debt ratings of Dynegy. Facility fees are payable on the
full amount of the facility and are determined based on designated unsecured
debt ratings. As of September 30, 2002, amounts outstanding under this facility
included $203 million of borrowings and $517 million in letters of credit.
During October 2002, Dynegy repaid $75 million of outstanding borrowings under
this facility in order to allow for capacity to issue additional letters of
credit. As of November 13, 2002, amounts outstanding under this facility
included $128 million of borrowings and $661 million in letters of credit.

   Financial covenants under the DHI $900 million revolver include a
debt-to-capitalization test (which takes into account certain lease and similar
commitments of DHI and its subsidiaries) and a 3.5 times EBITDA-to-interest
test. The permissible threshold for the debt-to-capitalization is 60%. Other
covenants in the facility include subordination of certain intercompany debt
owed to Dynegy and its subsidiaries (other than DHI and its subsidiaries),
restrictions on liens and limitations prohibiting subsidiary debt at Dynegy
Marketing & Trade, Dynegy Power Marketing, Inc. and Dynegy Midstream Services,
Limited Partnership. Default provisions include cross-payment default of
Dynegy, DHI or any principal subsidiary with respect to debt or other similar
obligations that exceed $100 million, cross acceleration of Dynegy, DHI or any
principal subsidiary under any instrument covering debt or similar obligations
that exceed $100 million and bankruptcy or receivership of

                                      33

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

Dynegy, DHI or any principal subsidiary. The facility does not contain any
defaults relating to material adverse changes in the condition of Dynegy or DHI
after the closing date or to changes in Dynegy's or DHI's credit ratings. The
facility also does not contain a "term-out" provision that would permit Dynegy
to extend the maturity for borrowings under the facility beyond the facility's
April 28, 2003 maturity date. As such, the amounts outstanding under this
facility are classified as current.

   Dynegy was in compliance with the covenants contained in its revolving
credit agreements and other debt instruments at September 30, 2002. Dynegy's
recent operating losses and any further operating losses will make it more
difficult for Dynegy to continue to satisfy the financial covenants in its
revolving credit agreements, particularly the EBITDA-to-interest covenants.
Management will continue to analyze these covenants relative to its results of
operations. The Company is required to deliver a certificate to the lenders
under its revolving credit facilities attesting to its compliance with the
financial covenants under these facilities on a quarterly basis. Any failure to
satisfy one or more of these covenants would constitute a breach giving rise to
a default under the applicable debt instrument and would permit the lenders
under such debt instrument to accelerate the maturity of Dynegy's outstanding
obligations thereunder. Depending upon the particular debt instrument, such a
breach or any action by the lenders to accelerate the maturity of amounts owing
would result in a default under or trigger cross-acceleration provisions in a
significant portion of the Company's other outstanding debt instruments. In the
event of non-compliance, Dynegy would seek waivers from the lenders under these
debt instruments or attempt to repay or refinance the affected debt
instruments. The Company cannot provide any assurance that it could repay,
obtain waivers with respect to or refinance such debt instruments in the event
of any such default.

   ABG Gas Supply Credit Agreement.  On April 10, 2001, ABG entered into a
credit agreement with a consortium of lenders in order to provide financing
associated with Project Alpha (the "ABG Credit Agreement"). Advances under the
agreement allowed ABG to purchase NYMEX natural gas contracts with the
underlying physical gas supply to be sold to Dynegy Marketing and Trade under
an existing natural gas purchases and sales agreement. The ABG Credit Agreement
requires ABG to repay the advances in monthly installments commencing February
2002 through December 2004 from funds received from Dynegy Marketing and Trade
under the natural gas purchases and sales agreement. The advances bear interest
at a Eurodollar rate plus a margin as defined in the agreement. Advances of
$272 million and $282 million were outstanding under this agreement at
September 30, 2002 and December 31, 2001, respectively.

   DHI Senior Notes.  On February 21, 2002, DHI issued $500 million of 8.75%
senior notes due 2012. Interest on the notes is due on February 15 and
August 15 of each year, beginning August 15, 2002. The notes are unsecured and
are not subject to a sinking fund.

   Generation Facility Capital Lease.  In response to the initiatives underway
at the FASB, on June 28, 2002, we unilaterally undertook certain actions, the
effect of which altered the accounting for one of our existing lease
obligations. These actions included the delivery of a guarantee of the lessor
debt in the lease of a power generation facility. As a result of these actions,
the lease is now accounted for as a capital lease and approximately $165
million of generation assets and the associated debt were brought on-balance
sheet. The assets under capital lease are included in property, plant and
equipment and are amortized over the useful life of the asset, which
approximates 35 years. We have the option to purchase the related assets at
lease maturity in 2005. This obligation bears interest at a rate of LIBOR plus
1.5% to 2.75%, depending on the tranche.

   This non-cash action resulted in an increase to property, plant and
equipment and a corresponding increase in long-term debt on the Company's
condensed consolidated balance sheets. This obligation was previously

                                      34

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

disclosed as a lease obligation in the footnotes to the Company's financial
statements and in the Commercial Financial Obligations and Contingent Financial
Commitments tables in the 2001 Form 10-K.

   The following is a schedule of future minimum lease payments under capital
leases together with the present value of the net minimum lease payments as of
September 30, 2002 ($ in millions):

<TABLE>
               <S>                                         <C>
               Three months ending December 31, 2002...... $  3
               Year ending December 31:
                  2003....................................    5
                  2004....................................    7
                  2005....................................  176
                                                           ----
               Total minimum lease payments...............  191
               Less: Amount representing interest.........  (26)
                                                           ----
               Present value of net minimum lease payments $165
                                                           ----
</TABLE>

   Other.  Dynegy completed an amendment to the Catlin Associates, LLC minority
interest transaction (also referred to as "Black Thunder") in June 2002, which
permanently removed a $270 million obligation which could have been triggered
by declines in Dynegy's credit ratings. The amended agreement requires a
subsidiary of Dynegy to make periodic payments totaling $275 million over the
remaining three years of the transaction. The subsidiary has already paid
approximately $73 million of this total. Quarterly maturities are approximately
$20 million through the first quarter 2005. In addition, Dynegy agreed to grant
mortgages on the midwest generation assets covered by the transaction, post a
letter of credit to secure a contingent obligation expiring December 31, 2002
and make certain structural changes to enhance the security of the third-party
lenders involved in the transaction. As a result of this amendment, $796
million related to Catlin Associates, LLC was reclassified from Minority
Interest to debt on Dynegy's Condensed Consolidated Balance Sheet.

   Also in June 2002, West Coast Power, LLC ("West Coast Power"), a joint
venture owned equally by Dynegy and NRG Energy with generation assets in
California, repaid a non-recourse project financing with cash on hand within
the joint venture entity. This payment eliminated a $31 million obligation
which could have been triggered by declines in Dynegy's credit ratings.
Concurrent with the retirement of the project financing, West Coast Power
entered into an amended $120 million bank facility consisting of a $100 million
letter of credit facility that will be used to collateralize West Coast Power's
obligations, a $10 million term loan and a $10 million working capital
facility. The facility has resulted in the release of approximately $100
million in letters of credit previously posted by Dynegy on behalf of West
Coast Power. Please see "Note 6--Unconsolidated Investments" for a discussion
of recent developments involving NRG Energy.

   Dynegy incurred upfront fees aggregating approximately $19 million in
connection with the interim financings, Black Thunder amendment and West Coast
Power transactions described above. Such amounts are capitalized and amortized
over the terms of the respective financing transactions.

Note 8--Related Party Transactions

   ChevronTexaco Commercial Arrangements.  In March 2002, Dynegy and
ChevronTexaco agreed to expand their commercial relationships to include
substantially all of the natural gas and domestic mixed NGLs and NGL products
produced or controlled by the former Texaco.

                                      35

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   In August 2002, Dynegy and ChevronTexaco executed an agreement pursuant to
which the parties amended the existing gas purchase agreement, security
agreement, netting agreement and certain related agreements. Under this new
agreement, Dynegy agreed to accelerate payment to the month of delivery for a
portion of the natural gas it purchases from ChevronTexaco, with the amount of
the accelerated payment generally being equal to 75 percent of the value of the
prior month's gas deliveries, after reduction pursuant to a netting agreement
between Dynegy and ChevronTexaco. This payment arrangement was effective upon
the closing of the sale of Northern Natural described in Note 3--Acquisitions
and Dispositions above. The accelerated payment totaled $152 million at
September 30, 2002.

   In connection with Dynegy's announced exit from third party risk management
aspects of the marketing and trading business. Dynegy and ChevronTexaco have
been negotiating to terminate the natural gas purchase agreement between the
parties and to provide for an orderly transition of responsibility for
marketing ChevronTexaco's domestic natural gas production. These discussions
will not affect Dynegy's current contractual agreements with ChevronTexaco
relative to ChevronTexaco's U.S. natural gas processing and the marketing of
ChevronTexaco's domestic NGLs.

   Also in August 2002, in partial satisfaction of certain of its obligations
to ChevronTexaco under these agreements, Dynegy sold to ChevronTexaco its 39.2%
ownership interest in WTLPS, which is the owner of West Texas LPG Pipeline.
ChevronTexaco was already the owner of the largest interest in WTLPS and the
operator of the pipeline. The interest sold to ChevronTexaco was valued at $45
million. This non-cash transaction reduced accounts payable to affiliates and
unconsolidated investments by $45 million.

   Dan Dienstbier Contract.  Dynegy entered into a services agreement with
Daniel L. Dienstbier effective as of May 28, 2002, the date on which Mr.
Dienstbier assumed the position of interim Chief Executive Officer. Mr.
Dienstbier served as Dynegy's interim Chief Executive Officer from such date
until October 23, 2002. Mr. Dienstbier continues to serve as non-executive
Chairman of the Board of Directors. Pursuant to the terms of the agreement,
Dynegy agreed to pay Mr. Dienstbier $1 million per year, to be paid ratably
once per month, in the form of cash or common stock as the parties shall agree.
Upon termination of the agreement, Mr. Dienstbier is eligible to receive a
bonus payment and a common stock grant, in each case at Dynegy's discretion.
The agreement contains customary indemnification, confidentiality and
non-compete provisions relating to Mr. Dienstbier's provision of services. Mr.
Dienstbier is continuing to be compensated under this agreement.

   Short-Term Executive Stock Purchase Loan Program.  In July 2001, Dynegy
established the Dynegy Inc. Short-Term Executive Stock Purchase Loan Program
pursuant to which eligible employees were loaned funds to acquire Class A
common stock through market purchases. Dynegy ceased making new loans under the
program at June 30, 2002. Outstanding loans bear interest at the greater of
five percent or the applicable federal rate as of the loan date, are full
recourse to the participants and mature on December 19, 2004. At September 30,
2002 and December 31, 2001, approximately $12 million and $13 million,
respectively, which included accrued and unpaid interest, was owed to the
Company under this program. The loans are accounted for as Subscriptions
Receivable within Stockholders' Equity on the Condensed Consolidated Balance
Sheet.

   In connection with the Company's organizational restructuring, the Company
offered to immediately forgive 50 percent of the outstanding balance under each
loan established through this program to non-executive officers. In order to
provide incentives to those employees with outstanding loans under this program
to remain with the Company post-restructuring, the Company has agreed to
forgive one-half of the remaining balance of each of their loans on October 1,
2003 and to forgive the then remaining balance under each such loan on

                                      36

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

October 1, 2004, subject to achievement of specified employment objectives. For
employees terminated as part of the restructuring, the remaining balance
outstanding under each loan matures and is due and payable on December 19,
2004. Interest rates charged under these loans remain unchanged. An accounting
charge of approximately $3 million is expected to be recognized in the fourth
quarter 2002 related to the forgiveness of these loans.

   December 2001 Equity Purchases.  In December 2001, certain executive
officers purchased Class A common stock from Dynegy in a private placement
pursuant to Section 4(2) of the Securities Act of 1933. These executives
received loans from Dynegy to purchase the common stock at a price of $19.75
per share. The purchase price equaled the net proceeds per share to Dynegy from
a concurrent public offering (after a $1.00 per share underwriting discount).
The loans bear interest at 3.25 percent per annum.

   During the quarter ended September 30, 2002, three executive officers with
loans then outstanding for December 2001 equity purchases and under the
Short-Term Executive Stock Purchase Loan Program resigned from their positions
with the Company. Two of these former executive officers paid an aggregate of
approximately $1.5 million to retire their outstanding December 2001 loans as
part of their severance arrangements. These former executive officers'
outstanding loans under the Short-Term Executive Stock Purchase Loan Program,
which aggregated approximately $2 million, were then extended to September
2007. The severance arrangement with the third former executive officer
included a similar pay down of 50 percent of an outstanding December 2001 loan
and an extension of the maturity date for the $512,000 remaining outstanding
under that loan, from September 15, 2002 to September 30, 2007. The extended
loans bear interest at the same interest rate as the initial loans.

   Two other executive officers with loans outstanding under each program
repaid an aggregate of $1 million to retire their December 2001 Equity Purchase
loans during the third quarter. These executive officers used proceeds from a
special bonus payment paid by the Company as part of their re-negotiated
employment contracts to make these loan payments. These executive officers'
outstanding loans under the Short-Term Executive Stock Purchase Loan Program,
which aggregate approximately $861,000 as of September 30, 2002, remain
outstanding and mature on December 19, 2004.

   Other.  At September 30, 2002, the Company had several financing
arrangements under which it was owed approximately $12 million from one of its
equity investees, Nicor Energy. The interest rate varies from zero to prime
plus two percent. The repayment terms for $4 million are over the next fifteen
months, while the remaining $8 million is due when Nicor Energy is sold.

Note 9--Earnings Per Share

   Basic earnings (loss) per share represents the amount of earnings (loss) for
the period available to each share of common stock outstanding during the
period. Diluted earnings (loss) per share represents the amount of earnings
(loss) for the period available to each share of common stock outstanding
during the period plus each share that would have been outstanding assuming the
issuance of common shares for all dilutive potential common shares outstanding
during the period. In-the-money outstanding options contribute to the
differences between basic and diluted shares outstanding in all periods. The
diluted shares in the 2002 periods do not include the effect of the assumed
conversion to Class A common stock of the Series B Mandatorily Convertible
Redeemable Preferred Securities held by ChevronTexaco as it would be
anti-dilutive.

                                      37

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   When an entity has a net loss from continuing operations, Statement of
Financial Accounting Standards No. 128, "Earnings per Share," prohibits the
inclusion of dilutive potential common shares in the computation of diluted
per-share amounts. Accordingly, the Company has utilized the basic shares
outstanding amount to calculate both basic and diluted loss per share for the
three and nine months ended September 30, 2002.

Note 10--Capital Stock

   Chevron U.S.A. Inc., a ChevronTexaco subsidiary, purchased approximately
10.4 million shares of Class B common stock in January 2002, pursuant to its
pre-emptive right under its shareholder agreement with Dynegy. Proceeds from
this sale were approximately $205 million and were held in cash to enhance
short-term liquidity.

   Dynegy's Board of Directors elected not to pay a dividend on Dynegy's Class
A or Class B common stock for the third quarter 2002.

Note 11--Commitments And Contingencies

   PLEASE NOTE THAT INFORMATION CONTAINED IN THIS NOTE 11, WHICH WAS PRESENTED
IN THE COMPANY'S THIRD QUARTER 2002 FORM 10-Q ORIGINALLY FILED WITH THE SEC ON
NOVEMBER 14, 2002 IN ORDER TO REFLECT MATERIAL CHANGES IN OR UPDATES TO THE
COMPANY'S MATERIAL LEGAL PROCEEDINGS SINCE THE ORIGINAL FILING OF ITS 2001 FORM
10-K AND ITS FIRST AND SECOND QUARTER 2002 FORMS 10-Q, DOES NOT REFLECT EVENTS
OCCURRING AFTER NOVEMBER 14, 2002. FOR A DESCRIPTION OF THESE EVENTS, INCLUDING
MATERIAL CHANGES IN OR UPDATES TO THE COMPANY'S MATERIAL LEGAL PROCEEDINGS,
PLEASE READ ITS EXCHANGE ACT REPORTS FILED SINCE NOVEMBER 14, 2002, INCLUDING
ITS ANNUAL REPORT ON FORM 10-K FOR THE FISCAL YEAR ENDED DECEMBER 31, 2002. SEE
NOTE 15--SUBSEQUENT EVENTS FOR FURTHER DISCUSSION.

   Please see Note 11, "Commitments and Contingencies," in the 2001 Form 10-K
and Notes 9 and 12, "Commitments and Contingencies," in the Company's Forms
10-Q for the quarters ended March 31, 2002 and June 30, 2002 (the "Forms 10-Q")
for a description of the Company's material legal proceedings. Set forth below
is a description of any material developments that occurred with respect to
such proceedings since the Company's original filing of the Form 10-Q for the
second quarter 2002 and a description of any new matters that have arisen
during the quarter.

   In addition to the matters described below, the Company is party to legal
proceedings arising in the ordinary course of business. In the opinion of
management, the disposition of these ordinary course matters will not have a
material adverse effect on the Company's financial condition, results of
operations or cash flows.

   The Company recognizes reserves for estimated losses from contingencies when
information available indicates that a loss is probable and the amount of the
loss is reasonably estimable in accordance with SFAS No. 5, "Accounting for
Contingencies." For environmental matters, we record liabilities when
environmental assessment indicates that remedial efforts are probable and the
costs can be reasonably estimated. Please read Note 2--Accounting Policies in
the 2001 Form 10-K.

   With respect to several of the items listed below, Dynegy has determined
that a loss is not probable or that any such loss, to the extent probable, is
not reasonably estimable. Notwithstanding the foregoing, Dynegy's

                                      38

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

management has assessed the matters described below based on currently
available information and made an informed judgment concerning the potential
outcome of such matters, giving due consideration to the nature of the claim,
the amount and nature of damages sought and the possibility of success.
Management's judgment may, as a result of facts arising prior to resolution of
these matters or other factors, prove inaccurate and investors should be aware
that such judgment is made subject to the known uncertainty of litigation.

   Baldwin Station Litigation.  IP and Dynegy Midwest Generation, Inc.
(collectively, the "Defendants") are the subject of a Notice of Violation
("NOV") from the Environmental Protection Agency (the "EPA") and a complaint
filed by the EPA and the Department of Justice alleging violations of the Clean
Air Act (the "Act") and the regulations promulgated under the Act. Similar
notices and complaints have been filed against a number of other utilities.
Both the NOV and the complaint allege that certain equipment repairs,
replacements and maintenance activities at the Defendants' three Baldwin
Station generating units constituted "major modifications" under the Prevention
of Significant Deterioration and/or the New Source Performance Standards
regulations. When activities that meet the definition of "major modifications"
occur and they are not otherwise exempt, the Act and related regulations
generally require that generating facilities meet more stringent emissions
standards, which may entail the installation of potentially costly pollution
control equipment. The Defendants filed an answer denying all claims and
asserting various specific defenses, and a trial date of June 3, 2003 has been
set.

   The Company believes that it has meritorious defenses to the EPA allegations
and will vigorously defend against these claims. The Company has undertaken
activities to significantly reduce emissions at the Baldwin Station since the
complaint was filed in 1999. In 2000, the Baldwin Station was converted from
high to low sulfur coal resulting in sulfur dioxide emission reductions of over
90% from 1999 levels. Furthermore, selective catalytic reduction equipment has
been installed at two of the three units at Baldwin Station, resulting in
significant emission reductions of nitrogen oxides. However, the EPA may seek
to require the installation of the "best available control technology," or the
equivalent, at the Baldwin Station. Independent experts hired by Dynegy
originally estimated that capital expenditures of up to $380 million if the
installation of best available control technology is required. Current
estimates suggest that such capital expenditures could be as much as $410
million. The EPA also has the authority to seek penalties for the alleged
violations in question at the rate of up to $27,500 per day for each violation.
The Company has filed a motion for summary judgment based on the five-year
statute of limitations, which could affect the EPA's ability to collect
penalties. The Company has recorded a reserve for penalties that could be
imposed if the EPA were to successfully prosecute its claims.

   None of the Defendants' other facilities are covered in the complaint and
NOV, but the EPA has officially requested information concerning activities at
the Defendants' Vermilion, Wood River, and Hennepin Plants as well as the
Danskammer and Roseton Plants operated by other Dynegy subsidiaries. It is
possible that the EPA will eventually commence enforcement actions based on
activities at those plants as well.

   On June 13, 2002, the EPA announced its intention to implement several
reforms to its regulations governing new source review. These reforms, if made,
would clarify the routine maintenance, repair and replacement exclusion,
provide more certainty in evaluating permit requirements and increase
operational flexibility for affected facilities.

   California Market Litigation.  Six class action lawsuits were filed in
2000-2001 against various Dynegy entities based on the events occurring in the
California power market. The complaints allege violations of California's
Business and Professions Code, Unfair Trade Practices Act and various other
statutes. The plaintiffs

                                      39

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

allege that the defendants, including the owners of in-state generation and
various power marketers, conspired to manipulate the California wholesale power
market to the detriment of California consumers. Included among the acts
forming the basis of the plaintiffs' claims are the alleged improper sharing of
generation outage data, improper withholding of generation capacity and the
manipulation of power market bid practices. The plaintiffs seek unspecified
treble damages.

   All six lawsuits were consolidated before Judge Sammartino, Superior Court
Judge for the County of San Diego. Subsequent to the consolidation, two
defendants filed cross complaints against a number of corporations and
governmental agencies that sold power in California's wholesale energy markets.
Four cross defendants removed the six cases to the United States District Court
for the Southern District of California (San Diego). Following removal, certain
cross defendants filed motions to dismiss the cross complaints, which motions
are pending. The original plaintiffs in the six consolidated complaints have
filed motions to remand the consolidated cases back to state court, which
motions are pending. The defendants in the six consolidated cases have filed
motions to dismiss the complaints based on the filed rate doctrine and
preemption defense. The motion to remand and the cross defendants' motion to
dismiss were heard by the Court and taken under submission by Federal Judge
Whaley on September 19, 2002. If the Court decides that it has jurisdiction
over the claims, the defendants' motion to dismiss will be heard as soon as
possible thereafter.

   On March 11, 2002, the California Attorney General filed, on behalf of the
People of the State of California, complaints in San Francisco Superior Court
against several owners of power generation facilities, including subsidiaries
of West Coast Power. The complaints allege that since June 1998, these power
generators sold power in the open market that should have been held in
emergency reserve for the State. In the aggregate, the complaints seek more
than $150 million in penalties, restitution and return of profits from the
generators. These lawsuits were subsequently removed to the United States
District Court for the Northern District of California. The California Attorney
General filed motions to remand the cases back to state court. By Order issued
on August 6, 2002, Judge Walker denied the motions to remand, thus keeping the
cases in federal court. The defendants have filed motions to dismiss, which
were argued and taken under submission by Judge Walker.

   In addition to the six consolidated lawsuits discussed above, eight new
putative class actions were filed on behalf of business and residential
electricity consumers, including consumers residing in the state of Washington.
The lawsuits were filed in various state courts in Northern California, and in
respect to the lawsuit on behalf of consumers in the state of Washington, in
the United States District Court for the Northern District of California. Named
as defendants are various power generators and marketers, including Dynegy and
some of its affiliates. The complaints allege unfair, unlawful and deceptive
practices in violation of the California Unfair Business Practices Act and seek
to enjoin illegal conduct, restitution and unspecified damages. While some of
the allegations in these lawsuits are similar to the allegations in the other
six lawsuits, these lawsuits include additional allegations based on events
occurring subsequent to the filing of the other six lawsuits. These additional
allegations include allegations similar to those made by the California
Attorney General in the March 11, 2002 lawsuit described above as well as
allegations that contracts between these power generators and the California
Department of Water Resources (the "DWR") constitute unfair business practices
resulting from market manipulation. The lawsuits filed in state court were
removed to federal courts in the Northern and Eastern Districts of California.
Certain defendants have filed a petition with the Judicial Panel For
Multidistrict Litigation seeking to consolidate the new cases with the six
cases consolidated in the United States District Court for the Southern
District of California. By order dated October 11, 2002, the Judicial Panel for
Multidistrict Litigation ordered the new cases consolidated with the original
six cases in the United States District Court for the Southern District of
California.

                                      40

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   Dynegy believes that it has meritorious defenses to these claims and intends
to vigorously defend against them. Dynegy is unable to estimate the range of
possible loss that could be incurred with respect to these lawsuits. However,
an adverse result in any of these proceedings could have a material adverse
effect on Dynegy's financial condition and results of operations.

   Enron Litigation.  Dynegy and DHI were sued on December 2, 2001 by Enron and
Enron Transportation Services Co. in the United States Bankruptcy Court for the
Southern District of New York, Adversary Proceeding No. 01-03626 (AJG). Enron
claimed that Dynegy materially breached the Merger Agreement dated November 9,
2001 between Enron and Dynegy and related entities by wrongfully terminating
that Agreement on November 28, 2001. Enron also claimed that DHI wrongfully
exercised its option to take ownership of Northern Natural under an Option
Agreement dated November 9, 2001. Enron sought damages in excess of $10 billion
and declaratory relief against Dynegy for breach of the Merger Agreement. Enron
also sought unspecified damages against Dynegy and DHI for breach of the Option
Agreement. Dynegy filed an answer on February 4, 2002, denying all material
allegations. On April 12, 2002, the Bankruptcy Court granted Dynegy's motion to
transfer venue in the proceeding to the United States District Court for the
Southern District of Texas (Houston Division).

   On August 15, 2002, Dynegy and Enron entered into an agreement to settle
this lawsuit. Under the terms of the settlement agreement, Dynegy agreed to pay
Enron $25 million, $10 million of which was paid to Enron upon approval of the
settlement agreement by the Bankruptcy Court, with the remaining $15 million
escrowed until approval of the settlement becomes final. In addition, Dynegy
and Enron agreed to exchange mutual releases of any and all claims related to
the terminated merger and to dismiss such litigation. Dynegy also agreed not to
pursue any claims for working capital adjustments relating to its acquisition
of Northern Natural. The terms of the settlement were approved by the
Bankruptcy Court on August 29, 2002. On September 6, 2002, an appeal of the
Bankruptcy Court's approval was filed by the plaintiffs who had filed the class
action lawsuits described below, and such appeal remains pending. The effect of
the appeal is to delay the effective date of the settlement, the release of the
remaining $15 million to Enron and the dismissal of the pending Enron lawsuit.

   Dynegy previously described a suit filed against Dynegy and DHI by Ann C.
Pearl and Joel Getzler in the United States District Court for the Southern
District of New York. Plaintiffs filed the lawsuit as a purported class action
on behalf of all persons or entities who owned Enron common stock as of
November 28, 2001. A similar suit was filed by Bernard D. Shapiro and Peter
Strub in the 129th Judicial District Court for Harris County, Texas. Plaintiffs
in each case alleged that they are intended third-party beneficiaries of the
Merger Agreement dated November 9, 2001 among Enron, Dynegy and related
entities. Plaintiffs claimed that Dynegy materially breached the Merger
Agreement by, among other things, wrongfully terminating that agreement.
Plaintiffs also claimed that Dynegy breached the implied covenant of good faith
and fair dealing. Plaintiffs sought unspecified damages and other relief. Enron
moved for an order of the Bankruptcy Court in the Southern District of New York
directing that the Pearl and Shapiro plaintiffs be enjoined from prosecuting
their actions and that their actions be immediately dismissed. The Bankruptcy
Court held that the claims asserted by the Pearl and Shapiro plaintiffs were
the exclusive property of the Enron bankruptcy estate and that the plaintiffs
lacked standing to sue as third-party beneficiaries of the Merger Agreement.
Accordingly, by an order entered on April 19, 2002, the Bankruptcy Court
granted Enron's motion, enjoined the prosecution of both actions and directed
that they be dismissed. The Pearl and Shapiro plaintiffs thereafter complied
with that order, but filed an appeal to the United States District Court for
the Southern District of New York. On October 22, 2002, the District Court
reversed the Bankruptcy Court's determination, holding that the Pearl and
Shapiro plaintiffs do have standing to sue as third-party beneficiaries, and
that their claims are not the exclusive property of the estate. That ruling is
subject to further review by the United States Court of Appeals for the Second
Circuit, should Enron elect to file

                                      41

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

an appeal. Shortly after this ruling, certain Enron shareholders filed an
action against Dynegy for wrongful termination of the Merger Agreement in the
United States District Court for the Southern District of New York.

   On October 28, 2002, Dynegy and DHI filed a declaratory action in Harris
County Judicial District Court relating to the Shapiro action. The action seeks
to reinstate the Shapiro action in the 129th Judicial District Court that is no
longer stayed. The action also seeks affirmative declarations to the effect
that Dynegy did not wrongfully terminate the Merger Agreement, that the
termination did not breach any duty owed to the Shapiro plaintiffs or to
Enron's shareholders generally and that neither the Shapiro plaintiffs nor
Enron's shareholders generally have a right to enforce or to make claims under
the Merger Agreement.

   Dynegy believes that it has meritorious defenses against these claims and
intends to vigorously defend against them. Dynegy is unable to estimate the
range of possible loss that could be incurred with respect to these lawsuits.
However, an adverse result in any of these proceedings could have a material
adverse effect on its financial position and results of operations.

   As a result of Enron's bankruptcy filing, Dynegy recognized in its fourth
quarter 2001 financial statements a pre-tax charge related to the Company's net
exposure for commercial transactions with Enron. As of September 30, 2002, the
Company's net exposure to Enron, inclusive of certain liquidated damages and
other amounts relating to the termination of the transactions, was
approximately $84 million and was calculated by setting off approximately $230
million owed from various Dynegy entities to various Enron entities against
approximately $314 million owed from various Enron entities to various Dynegy
entities. The master netting agreement between Dynegy and Enron and the
valuation of the commercial transactions covered by the agreement, which
valuation is based principally on the parties' assessment of market prices for
such period, remain subject to dispute by Enron with respect to which there
have been negotiations between the parties. These negotiations have focused on
the scope of the transactions covered by the master netting agreement and the
parties' valuations of those transactions. If any disputes cannot be resolved
by the parties, the agreements call for arbitration. Dynegy has instituted
arbitration proceedings against those Enron parties not in bankruptcy and has
filed a motion with the Bankruptcy Court requesting that it be allowed to
proceed to arbitration against those Enron parties that are in bankruptcy. If
the setoff rights were modified or disallowed, either by agreement or
otherwise, the amount available for Dynegy entities to set off against sums
that might be due Enron entities could be reduced materially.

   Shareholder Litigation.  Since April 2002, a number of class action lawsuits
have been filed on behalf of purchasers of publicly traded securities of Dynegy
generally during the period between April 2001 and April 2002. These lawsuits
principally assert that Dynegy and certain of its executive officers violated
the federal securities laws in connection with its accounting treatment and
disclosure of Project Alpha. These lawsuits have been consolidated in the
United States District Court for the Southern District of Texas. On October 28,
2002, the court in which the cases have been consolidated appointed the Regents
of the University of California as lead plaintiff and the law firm of Milberg
Weiss as class counsel. Plaintiffs were given 60 days to file a consolidated
amended complaint, which may differ materially from the complaints presently on
file. Dynegy intends to vigorously defend against these lawsuits. It is not
possible to predict with certainty whether Dynegy will incur any liability or
to estimate the damages, if any, that might be incurred in connection with
these lawsuits. An adverse result could have a material adverse effect on the
Company's financial condition and results of operations.

                                      42

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


   In addition, five derivative lawsuits have been filed in which the Company
is a nominal defendant. Three of these lawsuits relate to Project Alpha,
round-trip trades and alleged manipulation of the California power market. The
fourth lawsuit relates solely to Project Alpha and the fifth lawsuit relates to
severance for the Company's former Chief Executive Officer. All five lawsuits
seek recovery on behalf of the Company from various present and former officers
and directors. The Company continues to analyze these claims and does not
expect to incur any material liability with respect to these derivative claims.

   On August 15, 2002, a purported class action complaint was filed against
Dynegy in the United States District Court for the Southern District of Texas
(Houston Division) alleging violations of the Employee Retirement Income
Securities Act. The lawsuit concerns the Dynegy Inc. 401(k) Savings Plan and
claims that the Company's Board of Directors and certain former and current
officers involved in the administration of the 401(k) Plan breached their
fiduciary duties to the Plan's participants and beneficiaries in connection
with the Plan's holdings of Dynegy common stock. The lawsuit seeks unspecified
damages for the losses to the Plan resulting from the alleged breaches of
fiduciary duties, as well as attorney's fees and certain other costs. Dynegy is
analyzing these claims and intends to defend against them vigorously. As with
the shareholder class action lawsuits described above, it is not possible to
predict with certainty whether Dynegy will incur any liability or to estimate
the damages, if any, that might be incurred in connection with this lawsuit.
However, an adverse outcome could have a material adverse effect on the
Company's financial condition and results of operations.

   Farnsworth Litigation.  On August 2, 2002, Bradley Farnsworth filed a
lawsuit against Dynegy in Texas state district court claiming breach of
contract and that he was demoted and ultimately fired from the position of
Controller for refusing to participate in illegal activities. Specifically, Mr.
Farnsworth alleges, in the words of his complaint, that certain former
executive officers requested that he "shave or reduce for accounting purposes"
the forward price curves associated with the natural gas business in the United
Kingdom for the period of October 1, 2000 through March 31, 2001, in order to
indicate a reduction in the Company's mark-to-market losses. Mr. Farnsworth,
who seeks unspecified actual and exemplary damages and other compensation, also
alleges that he is entitled to a termination payment under his employment
agreement equal to 2.99 times the greater of his average base salary and
incentive compensation for the highest three calendar years preceding
termination or his base salary and target bonus amount for the year of
termination (estimated at a range of approximately $700,000 to $1,200,000). The
parties have commenced discovery in this lawsuit. Dynegy believes that it has
meritorious defenses against these claims and intends to vigorously defend
against them. Dynegy does not believe that any liability it might incur as a
result of this litigation would have a material adverse effect on its financial
condition or results of operations.

   SEC Settlement.  On September 24, 2002, Dynegy announced a settlement with
the SEC of allegations made against the Company in connection with the
previously disclosed investigation relating to Project Alpha and round-trip
electricity trades with CMS Energy. In the settlement, the SEC found that
Dynegy engaged in securities fraud in connection with its disclosures and
accounting for Project Alpha, and negligently included materially misleading
information about the round-trip energy trades with CMS Energy in two press
releases it issued in early 2002. In settlement of the SEC's enforcement
action, Dynegy, without admitting or denying the SEC's findings, agreed to the
entry of a cease-and-desist order and to pay a $3 million penalty in a related
civil suit filed in the United States District Court in Houston, Texas. Dynegy
is continuing to cooperate with the SEC's ongoing investigation of others
related to Project Alpha.

   CFTC Investigation.  The U.S. Commodity Futures Trading Commission ("CFTC")
commenced an investigation in June 2002 relating to the Company's trading
activities. The investigation covers Dynegydirect

                                      43

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

and round-trip trading and was recently expanded to cover Dynegy's practices
with respect to furnishing information regarding natural gas trades to various
energy industry publications that compile and report index prices. The Company
previously announced that, during an internal review of its trading activities
that is being conducted in connection with the CFTC investigation, it
discovered that certain employees in its trading business had furnished
inaccurate information to various industry publications. The Company is one of
many energy industry participants who routinely provide trade data to the
publications; consequently, it cannot determine whether the inaccurate data had
any impact on the published indices. In response to these findings, Dynegy now
requires that all price information provided to industry publications be
verified by the office of its Chief Risk Officer. In addition, in October 2002,
Dynegy dismissed six employees and disciplined seven others in its natural gas
trading business as a result of an investigation conducted by its Audit and
Compliance Committee and in collaboration with independent counsel. The Company
has produced documents in connection with the CFTC's investigation. The Company
has assured the Staff of the CFTC that it intends to cooperate with this
investigation. The Company cannot predict the ultimate outcome of this matter.

   U.S. Attorney Investigations.  The U.S. Attorney's office in Houston has
commenced an investigation of the Company relating to Project Alpha, roundtrip
trades with CMS Energy and Dynegy's gas trade reporting practices. The Company
produced documents and witnesses for interviews in connection with this
investigation. The Company is cooperating fully with the U.S. Attorney's office
in its investigation of these matters and cannot predict the ultimate outcome
of this investigation.

   Additionally, the U.S. Attorney's office in the Northern District of
California has issued a subpoena to the Company requesting information related
to the California energy markets. The Company intends to cooperate fully with
the U.S. Attorney's office in its investigation of these matters. The Company
cannot predict the ultimate outcome of this investigation.

   FERC and Related Regulatory Investigations.

   Requests for Refunds. On July 25, 2002, the FERC initiated a hearing to
establish refunds to electricity customers, or offsets against amounts owed to
electricity suppliers, during the period of October 2, 2000 through June 19,
2001. In particular, the FERC established a methodology to calculate mitigated
market clearing prices in the California Independent System Operator (the
"ISO") and the California Power Exchange (the "PX") markets. During March 2002
and August 2002, hearings on this matter were held before an administrative law
judge. The administrative law judge has stated that his findings of fact will
be issued before the end of 2002. Such findings will then be forwarded to the
FERC Commissioners for final determination.

   In August 2002, the FERC requested comments on a proposal made by the FERC
staff to change the method for determining natural gas prices for purposes of
computing the mitigated market-clearing price that it intends to utilize in
calculating refunds for sales of power in California power markets during the
period from October 2, 2000 to June 19, 2001. As drafted, the proposal would
replace the gas prices used in the computation, thus reducing the mitigated
market clearing price for power and increasing calculated refunds, subject to a
provision that generally would provide full recoverability of gas costs paid by
the generators to unaffiliated third parties. If adopted, this methodology
could have a material effect on any refunds or offsets that the FERC might
order from Dynegy or West Coast Power pursuant to its investigation of the
California power markets.

   Alleged California Market Manipulation and Round-Trip Trades.  On February
13, 2002, the FERC initiated an investigation of possible manipulation of
natural gas and power prices in the western United States

                                      44

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

during the period from January 2001 through the present. On May 8, 2002, in
response to three memoranda (authored by individuals employed by or previously
employed by Enron) discovered by the FERC allegedly containing evidence of
market manipulation by Enron in California, the FERC issued requests for
information to all sellers in the ISO and the PX markets during 2000 and 2001
seeking information with respect to whether those sellers engaged in trading
strategies described in the three Enron memoranda. Dynegy has responded to
these requests, indicating that it did not engage in any of the trading
strategies described in the three Enron memoranda. In August 2002, the FERC
staff issued its preliminary report on its investigation into trading practices
in the three Enron memoranda.

   On May 21, 2002, the FERC issued requests for information to all sellers of
wholesale electricity or ancillary services in the Western Electricity
Coordinating Council (the "WSCC") and, on May 22, 2002, the FERC issued
requests for information to all sellers of natural gas in the WSCC or Texas,
seeking information with respect to whether those sellers engaged in "wash,"
"round-trip" or "sale/buyback" transactions during 2000-2001. Requests for
similar information with respect to electric power trading activities in the
Electric Reliability Council of Texas were received from the Texas Public
Utility Commission in June 2002.

   Dynegy responded to each of these requests. Based on its investigation to
date, Dynegy believes that its trading practices are consistent with applicable
law and tariffs. In addition, Dynegy's investigations concluded that it did not
engage in "wash," "round-trip" or "sale/buyback" transactions in the WSCC, for
electricity or ancillary services, and the WSCC or Texas for natural gas
transactions. Neither the California State Senate committee nor the Texas
Public Utility Commission has issued its preliminary findings on its
investigation, and Dynegy cannot predict with certainty how such allegations
will ultimately be resolved. Dynegy will continue to cooperate fully with these
investigations.

   On August 13, 2002, the FERC staff issued its preliminary report on its
investigation into the Enron memoranda and "wash," "round-trip" or
"sale/buyback" transactions. The FERC has stated that a final staff report will
not be issued before March 2003.

   On September 17, 2002, California Public Utilities Commission President
Loretta Lynch released a report indicating that Dynegy and five other energy
firms did not produce all available power on days in which the State of
California experienced power service interruptions between November 1, 2000 and
May 31, 2001. No mention is made of prosecuting the named firms in the report.
However, the SEC and FERC staffs requested additional information and comment
with respect to the report. Dynegy disputes the report's findings and is
cooperating with the SEC and the FERC in connection with their requests.

   Trade Press.  In September 2002, the FERC staff issued requests for
information on issues related to reporting of information on natural gas trades
and electricity to energy industry publications that compile and report index
prices. Dynegy has responded to many of these requests and is cooperating with
the FERC staff in connection with this matter.

   Western Long-Term Contract Complaints.  On February 25, 2002 the California
Public Utilities Commission and the California Electricity Oversight Board
filed complaints with the FERC asking that it void or reform power supply
contracts between the DWR and, among others, West Coast Power. The complaints
allege that prices under the contracts exceed just and reasonable prices
permitted under the Federal Power Act. The FERC set these complaints for
evidentiary hearing. While West Coast Power continues in good faith
negotiations with the State of California on reforming the terms of its DWR
contract, settlement ultimately may not be

                                      45

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

possible. An administrative law judge has been directed to issue an order by
February 14, 2003 as to whether West Coast Power's or other contacts with the
DWR must be reformed. While the Company believes the terms of its contracts are
just and reasonable and do not reflect alleged market manipulation, it cannot
predict the outcome of this matter.

   In a related complaint, The Kroger Co. filed a complaint with the FERC in
August 2002 asking that the four wholesale contracts between Dynegy Power
Marketing, Inc. and AES New Energy, Inc., which provides retail service to The
Kroger Co., be declared void for their remaining terms, and that the FERC set
just and reasonable rates for prior periods. Alternatively, The Kroger Co. asks
that the FERC allow for an annual review procedure to reset the contract
prices. The complaint alleges that but for the dysfunctional California
electricity markets, it would not have entered into the contracts for delivery
of energy through December 2006. Dynegy believes it has meritorious defenses
against these claims and intends to vigorously defend against them.

   West Coast Power.  Through its interest in West Coast Power, Dynegy has
credit exposure for past transactions to certain state agencies ("ISO" and
"PX"), which primarily relied on cash payments from California utilities to pay
their bills. West Coast Power sells directly to the DWR pursuant to a long-term
sales agreement. Please see "Western Long-Term Contracts Complaints" above for
discussion of the actions taken by various parties with respect to this
agreement.

   At September 30, 2002, Dynegy's portion of the receivables owed to West
Coast Power by the ISO and PX approximated $205 million. Management is
continually assessing our exposure, as well as its exposure through West Coast
Power, relative to Dynegy's California receivables and establishes reserves for
contingent liabilities where the amount of potential loss is determined to be
probable and estimable. During the three-month periods ended September 30, 2002
and 2001, Dynegy's pre-tax share of reserves taken by West Coast Power totaled
$(1.3) million and $8.5 million, respectively. During the nine-month periods
ended September 30, 2002 and 2001, Dynegy's pre-tax share of reserves taken by
West Coast Power totaled $(1.3) million and $108.2 million, respectively.
Dynegy's share of the total reserve at September 30, 2002 and December 31, 2001
was $150.5 million and $151.8 million, respectively.

   Telstra Litigation.  On January 25, 2002, Telstra Corporation, Ltd. and
Telstra Wholesale Inc. (collectively, "Telstra") filed suit in Delaware
Chancery Court against DynegyConnect, L.P. ("DynegyConnect"), a limited
partnership in which Dynegy acquired a combined 80% interest, as well as some
of its other affiliates. DynegyConnect is a vehicle established by Dynegy to
participate in the U.S. telecommunications business. Telstra Wholesale
originally acquired the remaining 20% interest in DynegyConnect pursuant to a
limited partnership agreement that was executed in October 2000 and details the
partners' rights and obligations. Under the agreement, Telstra Wholesale was
granted a put option permitting it to require Dynegy or its designee, at any
time on or before September 20, 2002, to purchase its 20% partnership interest
for a purchase price equal to the value of Telstra Wholesale's capital account
in DynegyConnect, subject to certain adjustments. The plaintiffs brought this
action in connection with Telstra Wholesale's attempted exercise of this put
option. The plaintiffs allege breach of contract and bad faith, among other
things, in connection with the valuation of Telstra Wholesale's capital account
and, as a result, the put option purchase price, as well as the administration
of the partnership. The plaintiffs seek approximately $50 million plus interest
in damages together with fees and other litigation expenses. Minority Interest
on Dynegy's condensed consolidated balance sheets includes amounts relating to
Telstra Wholesale's investment in DynegyConnect. A March 2003 trial date has
been set for this lawsuit.

                                      46

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


Note 12--Regulatory Issues

   The Company is subject to regulation by various federal, state, local and
foreign agencies, including extensive rules and regulations governing
transportation, transmission and sale of energy commodities as well as the
discharge of materials into the environment or otherwise relating to
environmental protection. Compliance with these regulations requires general
and administrative, capital and operating expenditures including those related
to monitoring, pollution control equipment, emission fees and permitting at
various operating facilities and remediation obligations. In addition, the U.S.
Congress has before it a number of bills that could impact regulations or
impose new regulations applicable to Dynegy and its subsidiaries. The Company
cannot predict the outcome of these bills or other regulatory developments or
the effects that they might have on its business. For a more detailed
description of regulatory issues affecting the Company's business, please refer
to "Item 1. Business--Regulation" in the 2001 Form 10-K.

Note 13--Pension Plan Assets

   As a result of general declines in financial markets, the actual return on
pension plan assets was a negative 14 percent for the nine months ended
September 30, 2002. These negative returns have reduced plan assets during 2002
to levels that will likely fall below projected plan obligations at year end.
If any of Dynegy's pension plans are underfunded at year end, the Company has
two alternatives. The first alternative is to contribute cash to the plan in an
amount equal to the underfunded amount. The second alternative is to establish
a liability equal to the underfunded amount with the offset being an after-tax
reduction in shareholders' equity. Determination of any underfunded amount will
be made at year end 2002 and will be dependent on the actual return on pension
plan assets for 2002, the discount rate assumptions, which depend on year-end
interest rates and actual participant numbers.

Note 14--Segment Information

   Dynegy's operations are divided into four reportable segments: WEN, Dynegy
Midstream Services ("DMS"), Transmission and Distribution ("T&D") and Dynegy
Global Communications ("DGC"). WEN is engaged in a broad array of businesses,
including physical supply of, and risk-management activities around, wholesale
natural gas, power, coal and other similar products. This segment is focused on
optimizing the Company's and its customers' global portfolio of energy assets
and contracts, as well as direct commercial and industrial sales and retail
marketing alliances. DMS consists of the Company's North American midstream gas
processing, NGL marketing businesses and worldwide NGLs marketing and
transportation operations. Dynegy's T&D segment includes the operations of IP
and Northern Natural. IP is an energy-delivery company engaged in the
transmission, distribution and sale of electricity and natural gas to customers
across a 15,000-square-mile area of Illinois. As described in Note 3, the
Company sold Northern Natural in August 2002. Northern Natural's results are
included within the Company's consolidated results in the Discontinued
Operation section of the Statements of Operations. DGC is engaged in the
telecommunications business through its global long-haul fiber optic network
and metropolitan network located in the United States and Europe. Dynegy
accounts for intercompany transactions at prevailing market rates. Unaudited
operating segment information for the three- and nine-month periods ended
September 30, 2002 and 2001 is presented below. See Note 3 for an explanation
of anticipated changes impacting segment disclosures in the third quarter 2002
and beyond. See the Explanatory Note for a discussion of the restatements made
to the financial information included herein.

                                      47

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001

        Dynegy's Segment Data For The Quarter Ended September 30, 2002
                                ($ in millions)

<TABLE>
<CAPTION>
                                                 WEN      DMS     T&D    DGC  Eliminations  Total
                                               -------  ------  ------  ----  ------------ -------
<S>                                            <C>      <C>     <C>     <C>   <C>          <C>
Unaffiliated revenues:
   Domestic................................... $   299  $  574  $  396  $  6     $  --     $ 1,275
   Canadian...................................      --     130      --    --        --         130
   European and other.........................      --     175      --     2        --         177
                                               -------  ------  ------  ----     -----     -------
                                                   299     879     396     8        --       1,582
Intersegment revenues:
   Domestic...................................     186      33      11    --      (230)         --
                                               -------  ------  ------  ----     -----     -------
       Total revenues.........................     485     912     407     8      (230)      1,582
                                               -------  ------  ------  ----     -----     -------
Depreciation and amortization.................     (56)    (22)    (39)   --        --        (117)
Goodwill impairment...........................    (897)     --      --    --        --        (897)
Impairment and other charges..................     (25)     --      --    (4)       --         (29)
Operating income (loss).......................  (1,019)     29      72   (35)       --        (953)
Interest expense..............................     (59)    (13)    (25)   (6)       --        (103)
Other income (expense)........................     (26)    (10)     (3)   (1)       --         (40)
Earnings (losses) from unconsolidated
  investments.................................    (122)      4      (1)   (1)       --        (120)
Income tax provision (benefit)................    (113)      7      11   (25)       --        (120)
Income (loss) from continuing operations......  (1,113)      3      32   (18)       --      (1,096)
Discontinued operations (Note 3):
   Income (loss) from discontinued operations
     (including loss on disposal of Northern
     Natural of $586 million).................      17      --    (586)   --        --        (569)
   Income tax provision (benefit).............       6      --     (20)   --        --         (14)
                                               -------  ------  ------  ----     -----     -------
Income (loss) on discontinued operations......      11      --    (566)   --        --        (555)
Net income (loss)............................. $(1,102) $    3  $ (534) $(18)    $  --     $(1,651)
Identifiable assets:
   Domestic................................... $14,911  $1,955  $3,593  $ 68     $  --     $20,527
   Canadian...................................     468      25      --    --        --         493
   European and other.........................   2,668      --      --    32        --       2,700
Unconsolidated investments....................     600     116      --    --        --         716
Capital expenditures and unconsolidated
  investments.................................     (71)    (31)    (52)   (7)       --        (161)
</TABLE>

                                      48

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


        Dynegy's Segment Data For The Quarter Ended September 30, 2001
                                ($ in millions)

<TABLE>
<CAPTION>
                                           WEN      DMS     T&D    DGC   Eliminations  Total
                                         -------  ------  ------  -----  ------------ -------
<S>                                      <C>      <C>     <C>     <C>    <C>          <C>
Unaffiliated revenues:
   Domestic............................. $   634  $  792  $  395  $   3     $  --     $ 1,824
   Canadian.............................      --     448      --     --        --         448
   European and other...................      --     165      --      5        --         170
                                         -------  ------  ------  -----     -----     -------
                                             634   1,405     395      8        --       2,442
Intersegment revenues:
   Domestic.............................     149      45       6     --      (200)         --
                                         -------  ------  ------  -----     -----     -------
       Total revenues...................     783   1,450     401      8      (200)      2,442
                                         -------  ------  ------  -----     -----     -------
Depreciation and amortization...........     (47)    (21)    (42)    (5)       --        (115)
Operating income (loss).................     316      27      68    (31)       --         380
Interest expense........................     (23)    (12)    (27)    (3)       --         (65)
Other income (expense)..................     (21)     --      (1)     7        --         (15)
Earnings from unconsolidated investments      77       3      --      5        --          85
Income tax provision (benefit)..........     131       8      16     (8)       --         147
Net income (loss)....................... $   218  $   10  $   24  $ (14)    $  --     $   238
Identifiable assets:
   Domestic............................. $16,464  $1,880  $3,550  $ 825     $  --     $22,719
   Canadian.............................     441     342      --     --        --         783
   European and other...................   1,447      --      --    188        --       1,635
Unconsolidated investments..............     803     160      --     25        --         988
Capital expenditures and unconsolidated
  investments...........................    (125)    (25)    (30)  (308)       --        (488)
</TABLE>

                                      49

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


      Dynegy's Segment Data For The Nine Months Ended September 30, 2002
                                ($ in millions)

<TABLE>
<CAPTION>
                                                 WEN      DMS     T&D    DGC   Eliminations  Total
                                               -------  ------  ------  -----  ------------ -------
<S>                                            <C>      <C>     <C>     <C>    <C>          <C>
Unaffiliated revenues:
   Domestic................................... $   416  $1,804  $1,119  $  12     $  --     $ 3,351
   Canadian...................................     141     722      --     --        --         863
   European and other.........................      16     568      --      6        --         590
                                               -------  ------  ------  -----     -----     -------
                                                   573   3,094   1,119     18        --       4,804
Intersegment revenues:
   Domestic...................................     500     107      26     --      (633)         --
                                               -------  ------  ------  -----     -----     -------
       Total revenues.........................   1,073   3,201   1,145     18      (633)      4,804
                                               -------  ------  ------  -----     -----     -------
Depreciation and amortization.................    (141)    (63)   (110)   (33)       --        (347)
Goodwill impairment...........................    (897)     --      --     --        --        (897)
Impairment and other charges..................     (56)     (5)     (7)  (627)       --        (695)
Operating income (loss).......................  (1,238)     79     169   (753)       --      (1,743)
Interest expense..............................    (125)    (36)    (77)   (17)       --        (255)
Other income (expense)........................     (44)    (22)     (3)     4        --         (65)
Earnings (losses) from unconsolidated
  investments.................................     (77)     12      (2)   (49)       --        (116)
Income tax provision (benefit)................    (226)     14      31   (290)       --        (471)
Income (loss) from continuing operations......  (1,258)     19      56   (525)       --      (1,708)
Discontinued operations (Note 3):
   Income (loss) from discontinued operations
     (including loss on disposal of Northern
     Natural of $586 million).................      37      --    (548)    --        --        (511)
   Income tax provision (benefit).............      11      --      (5)    --        --           6
                                               -------  ------  ------  -----     -----     -------
Income (loss) on discontinued operations......      26      --    (543)    --        --        (517)
Cumulative effect of change in accounting
  principle...................................      --      --      --   (234)       --        (234)
Net income (loss)............................. $(1,232) $   19  $ (487) $(759)    $  --     $(2,459)
Identifiable assets:
   Domestic................................... $14,911  $1,955  $3,593  $  68     $  --     $20,527
   Canadian...................................     468      25      --     --        --         493
   European and other.........................   2,668      --      --     32        --       2,700
Unconsolidated investments....................     600     116      --     --        --         716
Capital expenditures and unconsolidated
  investments.................................    (501)    (84)   (124)  (101)       --        (810)
</TABLE>

                                      50

<PAGE>

                                  DYNEGY INC.

       NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS--(Continued)

                           (UNAUDITED AND RESTATED)

           For the Interim Periods Ended September 30, 2002 and 2001


      Dynegy's Segment Data For The Nine Months Ended September 30, 2001
                                ($ in millions)

<TABLE>
<CAPTION>
                                            WEN      DMS     T&D    DGC   Eliminations  Total
                                          -------  ------  ------  -----  ------------ -------
<S>                                       <C>      <C>     <C>     <C>    <C>          <C>
Unaffiliated revenues:
   Domestic.............................. $ 1,532  $3,204  $1,255  $   8     $  --     $ 5,999
   Canadian..............................      --   1,128      --     --        --       1,128
   European and other....................      20     514      --      8        --         542
                                          -------  ------  ------  -----     -----     -------
                                            1,552   4,846   1,255     16        --       7,669
Intersegment revenues:
   Domestic..............................     449     221      20     --      (690)         --
                                          -------  ------  ------  -----     -----     -------
       Total revenues....................   2,001   5,067   1,275     16      (690)      7,669
                                          -------  ------  ------  -----     -----     -------
Depreciation and amortization............    (136)    (61)   (125)   (15)       --        (337)
Operating income (loss)..................     614     115     184   (100)       --         813
Interest expense.........................     (66)    (40)    (87)    (6)       --        (199)
Other income (expense)...................    (100)    (11)     (2)    17        --         (96)
Earnings from unconsolidated investments.     167       9      --     19        --         195
Income tax provision (benefit)...........     241      26      43    (27)       --         283
Income (loss) from operations............     374      47      52    (43)       --         430
Cumulative effect of change in accounting
  principle..............................       2      --      --     --        --           2
Net income (loss)........................ $   376  $   47  $   52  $ (43)    $  --     $   432
Identifiable assets:
   Domestic.............................. $16,464  $1,880  $3,550  $ 825     $  --     $22,719
   Canadian..............................     441     342      --     --        --         783
   European and other....................   1,447      --      --    188        --       1,635
Unconsolidated investments...............     803     160      --     25        --         988
Capital expenditures and unconsolidated
  investments............................  (1,378)    (83)    (95)  (645)       --      (2,201)
</TABLE>

Note 15--Subsequent Events

   On October 23, 2002, Dynegy announced that Bruce A. Williamson had been
elected as its President and Chief Executive Officer. Effective as of such
date, Dynegy executed an agreement with Mr. Williamson pursuant to which Mr.
Williamson agreed to serve in such positions for an initial term of three
years, subject to extension. Under the terms of the agreement, Mr. Williamson
received a signing bonus of $2.25 million and a grant of options to purchase 2
million shares of common stock at an exercise price of $0.88. Mr. Williamson's
employment agreement entitles him to an annual base salary of $1 million,
subject to increase at the discretion of the Board of Directors, and the annual
opportunity to earn additional bonus amounts, dependent upon certain financial
or performance objectives, as a participant in Dynegy's Incentive Compensation
Plan. The agreement also provides that Mr. Williamson is entitled to receive
stock option grants each year during the term of the agreement. The agreement
contains non-compete and severance provisions relating to the termination of
Mr. Williamson's employment.

   THE COMPANY HAS EXPERIENCED A NUMBER OF MATERIAL DEVELOPMENTS SINCE THE
ORIGINAL FILING OF ITS THIRD QUARTER 2002 FORM 10-Q ON NOVEMBER 14, 2002. FOR
FURTHER DISCUSSION OF THE EVENTS THAT HAVE AFFECTED THE COMPANY SINCE NOVEMBER
14, 2002, PLEASE READ ITS EXCHANGE ACT REPORTS FILED SINCE SUCH DATE, INCLUDING
ITS ANNUAL REPORT ON FORM 10-K FOR THE FISCAL YEAR ENDED DECEMBER 31, 2002,
WHICH DISCUSSION IS INCORPORATED HEREIN BY THIS REFERENCE.

                                      51

<PAGE>

                                  DYNEGY INC.

          MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
                           AND RESULTS OF OPERATIONS
           For the Interim Periods Ended September 30, 2002 and 2001

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

   The following discussion and analysis should be read in conjunction with the
unaudited condensed consolidated financial statements of Dynegy Inc. ("Dynegy"
or the "Company") and the notes thereto included elsewhere herein and with the
Company's Annual Report on Form 10-K for the fiscal year ended December 31,
2001, as filed with the SEC. As discussed in the Introductory Note in this Form
10-Q/A, the financial information contained in this report has been revised to
reflect the restatement items described in the Explanatory Note to the
accompanying unaudited Condensed Consolidated Financial Statements. Dynegy has
also amended its 2001 Form 10-K, most recently with Amendment No. 2 thereto
filed with the SEC on April 11, 2003. The restatements to the Company's 2001
financial statements and related information are further described therein, and
this Form 10-Q/A should be read together with such Amendment No. 2.

   PLEASE NOTE THAT THE INFORMATION CONTAINED IN THIS FORM 10-Q/A, INCLUDING
THE FINANCIAL STATEMENTS AND THE NOTES THERETO, DOES NOT REFLECT EVENTS
OCCURRING AFTER NOVEMBER 14, 2002 (THE DATE ON WHICH DYNEGY ORIGINALLY FILED
ITS THIRD QUARTER 2002 FORM 10-Q). FOR A DESCRIPTION OF THESE EVENTS, PLEASE
READ THE COMPANY'S EXCHANGE ACT REPORTS FILED SINCE NOVEMBER 14, 2002,
INCLUDING ITS ANNUAL REPORT ON FORM 10-K FOR THE FISCAL YEAR ENDED DECEMBER 31,
2002. SEE NOTE 15--SUBSEQUENT EVENTS FOR FURTHER DISCUSSION.

                              RECENT DEVELOPMENTS

   A number of significant developments have occurred with respect to Dynegy
since the filing of its second quarter 2002 Form 10-Q. On October 16, 2002,
Dynegy announced an organizational restructuring plan designed to improve
operational efficiencies and performance across its asset-based lines of
business. The plan provides for the adoption of a decentralized business
structure consisting of a streamlined corporate center and operating units in
power generation, natural gas liquids, regulated energy delivery and
communications.

   Also on October 16th, Dynegy announced that it would exit third party risk
management aspects of the marketing and trading business. As a result of its
organizational restructuring and exit from third party risk management aspects
of the marketing and trading business, Dynegy announced a workforce reduction
affecting approximately 780 employees and the resignation of President and
Chief Operating Officer Steve Bergstrom.

   Several events affecting Dynegy precipitated the above actions. These events
include, among others, contraction in the trading markets, downgrades in the
Company's credit ratings, increased collateralization requirements and a weak
commodity price environment for power, as well as various legal proceedings and
investigations involving Project Alpha, Dynegy's trading practices and its
failed merger with Enron Corp. These events have had a severely negative effect
on Dynegy's operating results, liquidity, confidence in Dynegy's ability to
meet its debt and other obligations and its long-term business strategy, all of
which is reflected in continued declines in the market price for Dynegy's debt
and equity securities. These events, affecting Dynegy and the industry in
general, contributed to lower operating results in the third quarter 2002 and
have significantly affected the Company's business and operating capabilities.

   Dynegy has been and remains committed to addressing these issues. Since the
filing of its second quarter 2002 Form 10-Q, Dynegy continued to execute on the
elements of its capital and liquidity plan. In particular, the sale of Northern
Natural Gas Company ("Northern Natural") to MidAmerican Energy Holdings Company

                                      52

<PAGE>

("MidAmerican") in August enabled the Company to meet the sharp increase in
collateral obligations and to improve its liquidity position. This liquidity
position also was improved by the sale of the Company's United Kingdom natural
gas storage assets. The Company's decision to exit third party risk management
aspects of the marketing and trading business is intended to add to the capital
plan by freeing up material amounts of letters of credit and cash collateral
otherwise committed to customers in this business.
   On October 23, 2002, Dynegy announced the selection of Bruce Williamson as
the Company's new President and Chief Executive Officer. Under Mr. Williamson's
leadership, the Company intends to continue to execute the remaining elements
of the capital plan now enhanced by the exit from third party risk management
aspects of the marketing and trading business and additional general and
administrative expense reductions. On November 14, 2002, Dynegy completed the
sale of the Rough storage facility and certain related assets in the United
Kingdom as described below.

   The goal of Dynegy's enhanced capital plan is to enable the Company to meet
its debt obligations as they mature through 2003 and thereafter. Dynegy's
success and its future financial condition will depend on the management of its
exit from third party risk management aspects of the marketing and trading
business and execution of the remaining elements of its capital plan, each of
which is subject to the risks described in this quarterly report. Please read
"Liquidity and Capital Resources" for further details with respect to these
risks and "Uncertainty of Forward-Looking Statements and Information" for
additional factors that could impact Dynegy's future operating results and
financial condition.

                        LIQUIDITY AND CAPITAL RESOURCES

Capital Plan

   In June 2002, Dynegy announced a $2 billion capital plan designed to improve
liquidity and reduce debt. As part of the capital plan, on June 27, 2002,
Dynegy completed an amendment to the Catlin Associates, LLC minority interest
transaction (also referred to as "Black Thunder"), which permanently removed a
$270 million obligation that could have been triggered by declines in Dynegy's
credit ratings. Dynegy subsequently completed a $250 million interim financing
as an advance on a portion of the proceeds from the expected sale of certain of
its United Kingdom natural gas storage facilities and a $200 million interim
financing secured by interests in its Renaissance and Rolling Hills merchant
power generation facilities.

   During the third quarter 2002, Dynegy continued to execute on elements of
its capital plan. On August 16, 2002, Dynegy completed the sale of Northern
Natural to MidAmerican for $928 million in cash, subject to adjustment for
changes in working capital. The sale eliminated approximately $890 million of
Northern Natural debt. In September 2002, DHI sold $90 million in 6.875 percent
Northern Natural senior notes due May 2005 for approximately $96 million in
cash. DHI had acquired the notes at par value in April 2002 in order to obtain
a bondholder consent in connection with the acquisition of Northern Natural.

   In September 2002, Dynegy sold all of the shares of Dynegy Hornsea Limited,
a subsidiary that owned and operated a portion of its natural gas storage
facilities in the United Kingdom, to SSE Energy Supply Limited, a subsidiary of
Scottish and Southern Energy plc. SSE paid approximately $200 million (130
million (Pounds)). The net proceeds from the sale of approximately $189 million
were used to pay down a portion of the related $250 million interim financing
during October 2002.

   In October 2002, Dynegy's Illinois Power subsidiary ("IP") announced that it
agreed to sell its high-voltage electric transmission system to Trans-Elect,
Inc., an independent transmission company, for $239 million. The sale
represents the culmination of IP's long-term strategic initiatives relative to
its transmission assets and affirms the strategic direction established by IP
over two years ago. The sale is expected to close in the first half of 2003 and
is subject to customary closing conditions, including required approvals from
the SEC under the Public Utility Holding Company Act of 1935, as amended, the
Federal Trade Commission, the Illinois

                                      53

<PAGE>

Commerce Commission and the FERC. With respect to the FERC, the sale is
conditioned on its approving the levelized rates application to be filed by
Trans-Elect seeking a 13% return on equity. If the FERC does not approve
levelized rates in substantially the form sought by Trans-Elect, then
Trans-Elect is not obligated to close on the sale. The purchase price also is
subject to adjustment with respect to certain items, including a final
determination of the transmission assets to be sold, any variance in the
assumed amount of inventory on hand and the amount of accounts payable at
closing. A change in interest rates from those estimated by Trans-Elect in
contemplating its financing for the sale also could cause an adjustment to the
purchase price or postponement of the closing, at IP's option.

   During the second and third quarters of 2002, Dynegy took a number of steps
to reduce general and administrative expenses to more appropriately align the
Company's corporate structure with industry conditions and the decline in
commercial activity. Included among these measures are the June 2002 and
October 2002 workforce reductions affecting approximately 325 employees and 780
employees, respectively.

   On November 14, 2002, Dynegy sold all of the shares of two subsidiaries that
own and operate the Rough storage facility and certain related assets in the
United Kingdom to a subsidiary of Centrica plc for approximately $500 million.
The Company repaid the approximately $60 million remaining balance of the
related $250 million interim financing with proceeds from the sale.

   At the end of the third quarter, the following items in Dynegy's capital
plan remain to be completed:

  .   Closing of the pending sale of IP's transmission assets; and

  .   Issuance of IP mortgage bonds to repay or refinance IP obligations
      maturing in 2003.

Additionally, the capital plan has been enhanced by the Company's decision to
exit third party risk management aspects of the marketing and trading business
and certain other actions that are expected to result in reduced collateral
requirements, which actions are further described below.

   The remaining elements of the capital plan are subject to a number of risks,
including market conditions for asset sales, the timeliness and ability to
obtain required regulatory approvals for asset sales and the negative effects
of Dynegy's current financial condition, weak operating results and ongoing
investigations and litigation. Dynegy does not expect to pursue the initial
public offering of Dynegy Energy Partners L.P. Dynegy cannot guarantee that any
of the remaining transactions will be successfully completed or that, if
completed, they will occur on terms that the Company anticipates.

Available Credit Capacity, Liquidity and Debt Maturities

   Sources of Liquidity.  Dynegy's liquidity position has improved since the
filing of its second quarter 2002 Form 10-Q, primarily from the cash proceeds
received from the sale of Northern Natural in August 2002 and the sale of its
United Kingdom natural gas storage assets in September 2002 and November 2002.
Dynegy has relied on these cash proceeds, together with cash proceeds from the
other capital plan initiatives described above, cash from operations and
limited borrowings available under its revolving credit facilities, to satisfy
its capital requirements. Given its current non-investment grade credit
ratings, the re-audit of its 1999-2001 financial statements and its limited
access to the capital markets, Dynegy expects to continue to rely primarily on
cash on hand, cash from operations and proceeds from its capital plan
initiatives to fund its near-term obligations.

                                      54

<PAGE>

   The following table summarizes Dynegy's consolidated credit capacity and
liquidity position at September 30, 2002 ($ in millions):

<TABLE>
                     <S>                           <C>
                     Total Credit Capacity........ $ 1,940
                     Outstanding Loans............    (626)
                     Outstanding Letters of Credit  (1,028)
                                                   -------
                     Unused Borrowing Capacity....     286
                     Cash(1)......................   1,070
                     Liquid Inventory(2)..........     332
                                                   -------
                     Total Available Liquidity.... $ 1,688
                                                   =======
</TABLE>
--------
(1) Includes $189 million in net cash proceeds from the sale of the Hornsea
    storage facility, which is included in Restricted cash on the Condensed
    Consolidated Balance Sheet. These proceeds were used to pay down the
    principal on the related interim financing in early October 2002.
(2) Consists principally of natural gas inventories that the Company expects to
    monetize over the next six months in connection with the exit of third
    party risk management aspects of the marketing and trading business. The
    value presented is based on spot market prices at September 30, 2002.

   Uses of Liquidity and Current Liquidity Position.  During the third quarter
2002, significant uses of liquidity included the following:

  .   Retirement of $96 million in IP mortgage bonds which matured on July 15,
      2002.

  .   Retirement of $200 million in DHI senior notes which matured on July 15,
      2002.

  .   Funding of a $19 million quarterly payment under the Black Thunder
      financing.

  .   Funding of a $22 million quarterly payment on IP's transitional funding
      trust notes.

  .   Funding of a $17 million payment under the ABG Gas Supply financing.

  .   Issuance of approximately $455 million of cash collateral and letters of
      credit relating to the Company's marketing and trading business and other
      commercial obligations.

   On November 1, 2002, in connection with the expiration of the Dynegy Inc.
$300 million revolving credit facility, the Company repaid all of the $84
million of borrowings outstanding under the facility. Additionally, since
September 30, 2002, Dynegy has repaid the $250 million interim financing
relating to the sale of the UK storage facilities, $20 million in maturing
Illinova Corporation senior notes and the $19 million fourth quarter payment
under the Black Thunder financing.

   After giving effect to the Rough sale and expiration of the Dynegy Inc. $300
million revolving credit facility and repayment on the $250 million interim
financing, together with the above-described uses of liquidity, the Company's
total available liquidity as of the date of this report was approximately
$1,497 million, including approximately $974 million in cash, $129 million in
available borrowing capacity and $394 million in highly liquid inventory.

                                      55

<PAGE>

   Debt Maturities.  As of the date of this report, the Company's debt
maturities and related obligations through December 31, 2003 were approximately
as follows:

<TABLE>
<CAPTION>
                                                                     Amount
       Date                            Type                     Outstanding/Owed
------------------- ------------------------------------------- ----------------
<S>                 <C>                                         <C>
Fourth Quarter 2002 Canadian Credit Facility                     $40 million
                    IP Transitional Funding Trust Notes (1)      $21.6 million
                    ABG Gas Supply (2)                           $11.7 million
First Quarter 2003  Renaissance/Rolling Hills Interim Financing  $200 million
                    IP Transitional Funding Trust Notes (1)      $21.6 million
                    Black Thunder Financing (3)                  $18.9 million
                    ABG Gas Supply (2)                           $17.8 million
Second Quarter 2003 DHI $900 Million Revolving Credit Facility   $789 million (4)
                    DHI $400 Million Revolving Credit Facility   $382 million (5)
                    IP Bank Credit Facility                      $300 million
                    IP Transitional Funding Trust Notes (1)      $21.6 million
                    Black Thunder Financing (3)                  $21.6 million
                    ABG Gas Supply (2)                           $18.1 million
Third Quarter 2003  IP Mortgage Bonds                            $190 million
                    IP Transitional Funding Trust Notes (1)      $21.6 million
                    Black Thunder Financing (3)                  $21.6 million
                    ABG Gas Supply (2)                           $18.4 million
Fourth Quarter 2003 IP Transitional Funding Trust Notes (1)      $21.6 million
                    Black Thunder Financing (3)                  $21.6 million
                    ABG Gas Supply (2)                           $18.7 million
</TABLE>
--------
(1) Reflects required quarterly payments which are made with cash set aside
    from IP customer billings.
(2) Reflects required payments associated with Project Alpha as further
    described in the Explanatory Note to the accompanying financial statements.
(3) Reflects required quarterly payments under Dynegy's Black Thunder financing
    as further described in Note 7 to the accompanying financial statements.
(4) Reflects amounts outstanding under the DHI $900 million revolving credit
    facility, including $661 million in outstanding letters of credit.
(5) Reflects amounts outstanding under the DHI $400 million revolving credit
    facility, including $382 million in outstanding letters of credit.

   As indicated above, Dynegy has significant revolver maturities in the second
quarter 2003. Dynegy has begun discussions with its lenders with respect to the
refinancing of all or a portion of these revolving credit facilities. If Dynegy
is successful in entering into one or more new revolving credit facilities, it
expects such facilities would likely be smaller and would have higher pricing
and more restrictive terms than the current facilities. However, the Company
and its lenders may be unable to reach mutually agreeable terms for one or more
new revolving credit facilities. Dynegy faces significant risks relating to the
satisfaction or refinancing of the obligations under these facilities. Please
read "Conclusion" below for discussion of Dynegy's plans with respect to these
obligations and the covenant compliance and other execution risks inherent
therein.

Financing Trigger Events

   Dynegy's debt instruments and other financial obligations include routine
provisions, which, if not met, could require early payment, additional
collateral support or similar actions. For Dynegy, these trigger events include
leverage ratios, insolvency events, defaults on scheduled principal or interest
payments, acceleration of other financial obligations and change of control
provisions. Dynegy does not have any trigger events tied to specified credit
ratings or stock price in its debt instruments and has not executed any
transactions that require it to issue equity based on credit rating or other
trigger events. Please read "Conclusion" for a discussion of the Company's
compliance with other covenants contained in its debt instruments.

                                      56

<PAGE>

Collateral Obligations

   As a result of Dynegy's non-investment grade credit ratings and
counterparties' reduced confidence in its ability to satisfy its obligations,
the Company has received numerous requests from counterparties to provide
collateral support for its marketing and trading and other commercial
obligations, including obligations to support DMS and IP. These requests
generally are made under the Uniform Commercial Code, which allows for demands
of adequate assurance of performance when reasonable grounds for insecurity
exist, or contracts containing "adequate assurance" provisions or specific
ratings triggers that address collateral posting requirements. Specific ratings
triggers generally give counterparties the right to request collateral or, if
collateral is not provided, suspend or terminate credit if the Company's credit
ratings fall below investment grade; "adequate assurance" provisions permit a
counterparty to request adequate assurance (which is generally not specified in
the agreement) of continued performance. In most instances, Dynegy has
responded by posting cash or letters of credit to collateralize substantially
all of its marketing and trading obligations and a large portion of its other
commercial obligations. Outstanding letters of credit and cash collateral
totaled approximately $1.36 billion as of November 13, 2002.

   The obligations against which Dynegy has posted collateral include those
relating to certain of its long-term tolling agreements and other related
contracts. The Company is working with various counterparties to determine and
provide mutually acceptable collateral or other adequate assurance under these
contracts. The Company has yet to reach agreement with Sithe/Independence
Funding and Quachita Power LLC regarding a mutually acceptable amount of
collateral. Although the Company is current on all payments, it has received a
notice of default from each of these counterparties with regard to collateral
assurance and is continuing to negotiate these issues. The Company's annual net
payments under the Sithe/Independence and Quachita Power arrangements
approximate $66 million and $55 million, respectively, and the contracts extend
through 2014 and 2012, respectively.

   In response to the ongoing reductions in the liquidity of the trading
markets and the actions of counterparties either requiring additional
collateral or refusing to trade with the Company, Dynegy continued to scale
back the level of its customer and risk-management business activities during
the third quarter 2002. On October 16, 2002, Dynegy announced its decision to
exit third party risk management aspects of the marketing and trading business.
This announcement has no impact on the commercial activities of Dynegy's power
generation or midstream businesses. The power generation business will continue
to manage commodity price risk existing in its physical asset positions through
optimizing fuel procurement and the marketing of power from these assets.
Further, the midstream business will continue to manage commodity price risk
associated with its operations related to fuel procurement and the marketing of
natural gas and natural gas liquids in the markets where it operates.

   In connection with the Company's decision to exit third party risk
management aspects of the marketing and trading business, it subsequently
announced that it entered into a letter of intent to sell a significant portion
of its Canadian natural gas business to The Seminole Group, Inc. Dynegy also
agreed to sell to Seminole its 50 percent ownership in Tidal Energy Marketing,
Inc., a wholesale crude oil marketing company. The transactions, which are
subject to the negotiation and execution of definitive documentation,
regulatory approval and other customary conditions, are expected to close in
November 2002.

   The Company's decision to exit third party risk management aspects of the
marketing and trading business is expected to reduce significantly its
collateral requirements and overall corporate expenses.

Credit Rating Discussion

   Credit ratings impact the Company's ability to obtain short- and long-term
financing, the cost of such financing and the execution of its commercial
strategies. In determining the Company's credit ratings, the rating agencies
consider a number of factors. Quantitative factors that management believes are
given significant weight include, among other things, EBITDA; operating cash
flow; total debt outstanding; off balance sheet obligations and other
commitments; fixed charges such as interest expense, rent or lease payments;
payments to preferred stockholders; liquidity needs and availability and
various ratios calculated from these factors.

                                      57

<PAGE>

Qualitative factors include, among other things, predictability of cash flows,
business strategy, industry position, litigation, regulatory investigations and
other contingencies. Although these factors are among those considered by the
rating agencies, each agency may calculate and weigh each factor differently.

   Since the Company filed its second quarter 2002 Form 10-Q on August 14,
2002, Moody's Investors Service again lowered its ratings on Dynegy and its
subsidiaries. The senior unsecured debt ratings of Dynegy and DHI were lowered
from "Ba3" to "B2" and "B1" to "B3," respectively. Moody's also downgraded IP's
mortgage bonds from "Ba2" to "B1," stating that the ratings outlook for all of
Dynegy's ratings remained negative. Moody's stated that these ratings actions
were based on continuing concerns due to, among other things, increased amounts
of secured debt and the expectation that future renewals of existing bank debt
will likely be done on a secured basis, effectively subordinating DHI's senior
unsecured lenders.

   As of November 13, 2002, Dynegy's credit ratings were as set forth in the
table below. All three major credit rating agencies maintained a negative
outlook with respect to their ratings.

<TABLE>
<CAPTION>
                                            Standard
                    Rated Enterprises       & Poor's Moody's Fitch
                    -----------------       -------- ------- -----
              <S>                           <C>      <C>     <C>
              Senior Unsecured Debt Rating:
                 Dynegy Inc.(1)............    B-      B2      B
                 Dynegy Holdings Inc.(2)...    B-      B3      B
                 Illinois Power(3).........     *      B2      B
                 Illinova Corporation(4)...    B-      B3      B
              Senior Secured Debt Rating:
                 Illinois Power............    B+      B1     BB-
</TABLE>
--------
*  Not rated.
(1) Dynegy Inc. is the parent holding company. This entity generally provides
    financing to the enterprise through issuance of capital stock.
(2) Dynegy Holdings Inc. is the primary debt financing entity for the
    enterprise. This entity is a subsidiary of Dynegy Inc. and is a holding
    company that includes substantially all of the operations of the WEN and
    DMS business segments.
(3) This entity includes the Company's regulated transmission and distribution
    business in Illinois.
(4) Illinova Corporation is the holding company for Illinois Power.

IP Liquidity

   As described above in "Available Credit Capacity, Liquidity and Debt
Maturities," IP has significant debt maturities through December 31, 2003.
These maturities include the May 2003 maturity of its $300 million bank credit
facility, the August 2003 and September 2003 mortgage bond maturities of $100
million and $90 million, respectively, and quarterly payments of approximately
$22 million on IP's transitional funding trust notes. IP is required to make
these same quarterly payments of approximately $22 million on its transitional
funding trust notes into 2008, and has a payment of up to $81 million due on
its Tilton lease financing in the third quarter of 2004. IP's plans to satisfy
its significant near-term debt maturities and to improve its liquidity position
include the successful execution of capital-raising transactions, including its
previously terminated mortgage bond offering, and the closing of the previously
announced sale of its transmission assets. IP also plans to seek to refinance
its $300 million bank credit facility with another facility of equal or lesser
size. Such a facility would provide IP with additional liquidity to support its
ongoing capital requirements.

   IP's ability to successfully execute these initiatives is subject to a
number of risks including factors beyond its control. These factors include,
among others, the timeliness and ability to obtain required regulatory
approvals, further credit rating downgrades, the receptiveness of the capital
markets to the IP bond offering and

                                      58

<PAGE>

the continued negative effects of its relationship with Dynegy. If IP is unable
to successfully execute these initiatives, it could require additional
liquidity support from Dynegy, to the extent available and subject to receipt
of any required regulatory approvals, in order to satisfy its debt maturities
and other obligations as they become due.

   On October 23, 2002, the Illinois Commerce Commission (the "ICC") issued an
order approving a petition submitted by IP to enter into an agreement with
Dynegy and its affiliates that would allow for the netting of certain payments
due to Dynegy under the services and facilities agreement pursuant to which
Dynegy affiliates exchange certain corporate services and share facility space
with IP. Under the ICC's order, payments due to Dynegy from IP under this
agreement can be netted against certain intercompany payments due to IP from
Dynegy should Dynegy or its affiliates fail to make those payments on or before
their due dates. The agreement also allows Dynegy to net payments in the event
IP fails to make its required payments to Dynegy. Additionally, IP will not be
permitted to pay any common dividend to Dynegy or its affiliates until IP's
mortgage bonds are rated investment grade by Moody's and S&P and specific
approval is obtained from the ICC. The ICC also made certain provisions for the
advancement of funds necessary to fund payments on Illinova Corporation's
outstanding senior notes.

ChevronTexaco Preferred Stock

   In November 2001 in connection with entering into its merger agreement with
Enron, Dynegy issued $1.5 billion of Series B preferred stock to ChevronTexaco.
Dynegy used the proceeds from this preferred stock issuance to purchase $1.5
billion of preferred stock in Northern Natural. The resolutions establishing
the Series B preferred stock provide that all of the outstanding shares of the
series will be redeemed on November 9, 2003.

   The Company believes that there are restrictions under applicable state law
that prevent the Company from redeeming the preferred stock if it would render
the Company insolvent. If such redemption is restricted under applicable law,
the Company believes that the redemption obligation will remain outstanding
until such time as the law would permit such redemption and such redemption
obligation is satisfied. The failure to redeem the Series B preferred stock on
the redemption date as described above is not an event of default under any of
the Company's bank borrowings, secured debt, senior notes or other debt
obligations. The shares of Series B preferred stock are not entitled to a
dividend in cash or in kind or Board representation either before or after the
redemption date.

Generation Facility Capital Lease

   In response to the initiatives underway at the FASB, on June 28, 2002, the
Company unilaterally undertook certain actions, the effect of which altered the
accounting for one of its existing lease obligations. These actions included
the delivery of a guarantee of the lessor debt in the lease of a power
generation facility. As a result of these actions, the lease is now accounted
for as a capital lease and approximately $165 million of generation assets and
the associated debt were brought on-balance sheet. Dynegy has the option to
purchase the related assets at lease maturity in 2005. This obligation bears
interest at a rate of LIBOR plus 1.5% to 2.75%, depending on the tranche.

   This non-cash action resulted in an increase to property, plant and
equipment and a corresponding increase in long-term debt on the Company's
condensed consolidated balance sheets. This obligation was previously disclosed
as a lease obligation in the footnotes to Dynegy's financial statements and in
the Commercial Financial Obligations and Contingent Financial Commitments
tables in the 2001 Form 10-K.

Capital Expenditures

   Capital spending for the three- and nine-month periods ended September 30,
2002 totaled $165 million and $796 million, respectively, and related primarily
to the WEN and T&D operating segments. For the anticipated

                                      59

<PAGE>

future, the Company intends to limit its capital expenditures primarily to
required maintenance capital expenditures. The Company expects that its
required maintenance capital expenditures will total approximately $75 million
for the fourth quarter 2002 and approximately $285 million for 2003.

Dividend Policy

   In further support of the Company's capital and liquidity plan, its Board of
Directors elected not to pay a dividend on Dynegy's Class A or Class B common
stock for the third quarter 2002. Dynegy does not anticipate reinstating the
dividend for the foreseeable future. During the nine-month periods ended
September 30, 2002 and 2001, the Company paid approximately $55 million and $74
million in cash dividends, respectively, on its common stock.

Conclusion

   Dynegy believes its current liquidity position should be sufficient to
permit us to meet its debt maturities and other obligations through the first
quarter 2003. The sufficiency of the Company's liquidity will depend upon:

  .   Dynegy's continued compliance with the covenants in its bank credit and
      other debt instruments or its ability to negotiate waivers in the event
      of a covenant default;

  .   Dynegy's ability to repay or refinance the DHI and IP credit facilities
      that mature in the second quarter 2003;

  .   Dynegy's ability to manage its exit from third party risk management
      aspects of the marketing and trading business and the timing of the
      expected cash flows and reduction in collateral from this exit;

  .   the level of earnings and cash flow from Dynegy's assets and businesses,
      which is subject to the effect of changes in commodity prices,
      particularly natural gas and power;

  .   Dynegy's non-investment grade credit ratings, the effect of these ratings
      on Dynegy's ability to access capital markets and to conduct normal
      commercial operations and the effect of any further downgrade in these
      credit ratings on refinancings;

  .   ongoing investigations and litigation relating to Project Alpha, Dynegy's
      trading practices and its activities in the California power markets;

  .   confidence in Dynegy's financial reporting in light of the previously
      announced restatements and the re-audit of its 1999-2001 financial
      statements; and

  .   Dynegy's ability to eliminate or further reduce net cash outflows
      associated with its telecommunications business.

   Dynegy's liquidity may be significantly adversely affected if it is unable
to refinance the DHI and IP credit facilities that mature in the second quarter
2003. Dynegy also faces the risk of a covenant default on these facilities or
other debt instruments prior to maturity. The DHI and IP credit facilities and
the Company's telecommunications lease financing contain various covenants,
including EBITDA-to-interest and debt-to-capitalization financial covenants.
The Company was in compliance with the covenants in its credit facilities and
other debt instruments at September 30, 2002. While many of the charges
incurred by the Company during 2002 are excluded from the compliance
calculations, continued weakness in the Company's operating results compared
with results in 2001 will make it more difficult for the Company to continue to
comply with certain of its financial covenants. Compliance with these financial
covenants is measured on a quarterly basis.

   Any failure to satisfy one or more of these covenants would constitute a
breach giving rise to a default under the applicable debt instrument and would
permit the lenders under such debt instrument to accelerate the maturity of
Dynegy's outstanding obligations thereunder. Depending upon the particular debt
instrument, such a breach or

                                      60

<PAGE>

any action by the lenders to accelerate the maturity of amounts owing would
result in a default under or trigger cross-acceleration provisions in a
significant portion of the Company's other outstanding debt instruments. In the
event of non-compliance, Dynegy would seek waivers from the lenders under these
debt instruments or attempt to repay or refinance the affected debt
instruments. The Company cannot provide any assurance that it could repay,
obtain waivers with respect to or refinance such debt instruments in the event
of any such default.

   Dynegy has executed on the principal elements of its capital plan in order
to meet its current obligations as they mature and provide the necessary
collateral to support its commercial operations. Dynegy believes that the
combination of its liquidity initiatives and the roll off of collateral and
cash flow from its exit from third party risk management aspects of the
marketing and trading business should enable the Company to refinance all or a
sufficient portion of its second quarter 2003 maturities. However, the Company
faces significant risks related to its ongoing operations and other matters
discussed above. Dynegy also faces the risk that it may not be able to reach
agreement with its lenders on mutually acceptable terms. If Dynegy fails to
execute the remaining elements of its strategy, it may be forced to consider
other strategic alternatives including a possible reorganization under the
protection of federal bankruptcy laws.

                       RECENT ACCOUNTING PRONOUNCEMENTS

   See Note 1 to the accompanying financial statements for a discussion of
recently issued accounting pronouncements affecting the Company. Specifically,
Dynegy adopted the net presentation provisions of Emerging Issues Task Force
Issue No. 02-3 in the third quarter 2002. Please see Note 1 for the impact such
adoption had on the Company's Condensed Consolidated Statements of Operations.

                            ACCOUNTING METHODOLOGY

   The Company has identified three critical accounting policies that require a
significant amount of judgment and are considered to be the most important to
the portrayal of Dynegy's financial position and results of operations: the
accounting for long-lived assets, the evaluation of counterparty credit and
other similar risks and revenue recognition. See Note 3 to the financial
statements included in the 2001 Form 10-K for a discussion of the process
surrounding the evaluation of counterparty credit and other similar risks. For
disclosure on the Company's accounting for long-lived assets and revenue
recognition, refer to Note 2 to the financial statements included in the 2001
Form 10-K. Accounting methodology and application of accounting methodologies
are more fully described in the 2001 Form 10-K.

             ENTERPRISE RISK MANAGEMENT, VALUATION AND MONITORING

   Market Risk.  The Company is exposed to commodity price risk related to its
natural gas, NGLs, electricity and coal businesses. In addition, fuel
requirements at its power generation, gas processing and fractionation
facilities represent additional commodity price risks to the Company. In order
to manage these commodity price risks, Dynegy has routinely utilized certain
types of fixed-price forward purchase and sales contracts, futures and option
contracts traded on the New York Mercantile Exchange and swaps and options
traded in the over-the-counter financial markets to:

  .   Manage and hedge its fixed-price purchase and sales commitments;

  .   Provide fixed-price commitments as a service to its customers and
      suppliers;

  .   Reduce its exposure to the volatility of cash market prices;

  .   Protect its investment in storage inventories; and

  .   Hedge fuel requirements.

                                      61

<PAGE>

   The potential for changes in the market value of Dynegy's commodity,
interest rate and currency portfolios is referred to as "market risk." A
description of each market risk category is set forth below:

  .   Commodity price risks result from exposures to changes in spot rates,
      forward prices and volatilities in commodities, such as electricity,
      natural gas, coal, NGLs, and other similar products;

  .   Interest rate risks primarily result from exposures to changes in the
      level, slope and curvature of the yield curve and the volatility of
      interest rates; and

  .   Currency rate risks result from exposures to changes in spot rates,
      forward rates and volatilities in currency rates.

   Dynegy seeks to manage these market risks through diversification,
controlling position sizes and executing hedging strategies. The ability to
manage an exposure may, however, be limited by adverse changes in market
liquidity or other factors.

   In October 2002, the Company announced it would exit aspects of the
marketing and trading business relating to third party or customer risk
management for natural gas and power. The Company expects to complete a
significant portion of the exit from this business over the next three to six
months. The Company will maintain the resources and make the necessary
arrangements to meet its customer commitments, including retaining personnel
and risk management capabilities.

   Valuation Criteria and Management Estimates.  As more fully described in the
2001 Form 10-K, Dynegy utilizes a fair value accounting model for certain
aspects of its operations as required by generally accepted accounting
principles. The net gains or losses resulting from the revaluation of these
contracts during the period are recognized currently in the Company's results
of operations. For financial reporting purposes, assets and liabilities
associated with these transactions are reflected on the Company's balance sheet
as risk management assets and liabilities, classified as short- or long-term
pursuant to each contract's individual tenor. Net unrealized gains and losses
from these contracts are classified as revenue in the accompanying statement of
operations. As a result of EITF 02-3, the Company recorded realized and settled
amounts net in the income statement and has restated prior periods herein for
comparative purposes.

   As more fully described in the Explanatory Note to the accompanying
unaudited Condensed Consolidated Financial Statements, the Company corrected
the forward power curve methodology it used to estimate the fair market value
of its U.S. power marketing and trading portfolio. Further, the Company
restated its financial statements, beginning with the third quarter 2001, to
reflect the revised methodology.

   Risk-Management Asset and Liability Disclosures.  The following tables
depict the mark-to-market value and cash flow components of the Company's net
risk-management assets and liabilities at September 30, 2002 and December 31,
2001:

             Mark-to-Market Value of Net Risk-Management Asset(1)

<TABLE>
<CAPTION>
                           Total  2002(2) 2003 2004 2005 2006  Thereafter
                           -----  ------- ---- ---- ---- ----  ----------
                                          (in millions)
       <S>                 <C>    <C>     <C>  <C>  <C>  <C>   <C>
       September 30, 2002. $ 480   $ (27) $190 $113 $41  $ 17     $146
       December 31, 2001..   901     576   113   70  21    30       91
                           -----   -----  ---- ---- ---  ----     ----
       Increase (Decrease) $(421)  $(603) $ 77 $ 43 $20  $(13)    $ 55
                           =====   =====  ==== ==== ===  ====     ====
</TABLE>
--------
(1) The table reflects the fair value of Dynegy's risk-management asset
    position after deduction of time value, credit, price and other reserves
    necessary to determine fair value. These amounts exclude the fair value
    associated with certain derivative instruments designated as hedges. The
    net risk-management assets at September 30 of $482 million on the Condensed
    Consolidated Balance Sheet include the $480 million herein as well as
    emission allowance credits, hedging instruments and other non-trading
    amounts.
(2) Amounts represent October 1 to December 31, 2002 values in the September
    30, 2002 row and January 1 to December 31, 2002 values in the December 31,
    2001 row.

                                      62

<PAGE>

   The increases (decreases) in the Net Risk-Management Asset and Liabilities
were impacted by the following:

  .   The realization of approximately $638 million of cash related to
      contracts settled during the first three quarters of 2002;

  .   A net deferral of the anticipated timing of cash inflows totaling $95
      million from the 2002 through 2004 time periods to beyond 2006 related to
      long-term natural gas storage transactions. The change in the timing of
      cash inflows on these transactions resulted from the decision to extend
      the term of the contract through 2007; and

  .   The recognition of other net mark-to-market gains, change in reserves,
      changes in interest rates and changes in foreign exchange rates and their
      related impact on the discounted value of the portfolio and related
      annual cash flow amounts.

               Cash Flow Components of Net Risk-Management Asset

<TABLE>
<CAPTION>
                       Nine Months  Three Month
                          Ended        Ended
                      September 30, December 31, Total
                          2002          2002     2002  2003 2004 2005 2006  Thereafter
                      ------------- ------------ ----- ---- ---- ---- ----  ----------
                                               (in millions)
<S>                   <C>           <C>          <C>   <C>  <C>  <C>  <C>   <C>
September 30, 2002(1)     $638          $(16)    $622  $208 $128 $53  $ 25     $327
December 31, 2001....                             646   154  112  53    58      281
                                                 ----  ---- ---- ---  ----     ----
Increase (Decrease)..                            $(24) $ 54 $ 16 $--  $(33)    $ 46
                                                 ----  ---- ---- ---  ----     ----
</TABLE>
--------
(1) The cash flow values at September 30, 2002 reflect realized cash flows for
    the nine months ended September 30, 2002 and anticipated undiscounted cash
    inflows and outflows by contract based on tenor of individual contract
    position for the remaining periods. These anticipated undiscounted cash
    flows have not been adjusted for counterparty credit or other reserves.
    These amounts exclude the cash flows associated with certain derivative
    instruments designated as hedges as well as emission allowance credits and
    other non-trading amounts.

                                      63

<PAGE>

   The following table provides a reconciliation of the risk-management data on
the balance sheet, statement of operations and statement of cash flows (in
millions):

<TABLE>
<CAPTION>
                                                                                    As Of And For
                                                                                   The Nine Months
                                                                                        Ended
                                                                                    September 30,
                                                                                        2002
                                                                                   ---------------
<S>                                                                                <C>
Balance Sheet Risk--Management Accounts
Fair value of portfolio at January 1, 2002........................................    $     935
Risk-management gains recognized through the income statement in the period, net..          167
Cash received related to contracts settled in the period, net(1)..................         (638)
Changes in fair value as a result of a change in valuation technique(2)...........           --
Non-cash adjustments and other(3).................................................           18
                                                                                      ---------
Fair value of portfolio at September 30, 2002.....................................    $     482
                                                                                      ---------
Income Statement Reconciliation
Risk-management gains recognized through the income statement in the period, net..    $     167
Physical business recognized through the income statement in the period, net......           23
Non-cash adjustments and other(4).................................................          (34)
                                                                                      ---------
Net recognized operating loss(5)..................................................    $     156
                                                                                      ---------
Cash Flow Statement
Cash received related to risk-management contracts settled in the period, net(2)..    $     638
Estimated cash paid related to physical business settled in the period, net.......           23
Timing and other, net(6)..........................................................           22
                                                                                      ---------
Cash received during the period...................................................    $     683
                                                                                      ---------
Risk Management cash flow adjustment for the nine-month period ended September 30,
  2002(7).........................................................................    $     527
                                                                                      ---------
</TABLE>
--------
(1) This amount includes cash settlements of hedging instruments, emission
    allowances and other non-trading amounts in addition to the cash settlement
    of trading contracts.
(2) Dynegy's modeling methodology has been consistently applied period over
    period.
(3) This amount consists primarily of changes in value and cash settlements
    associated with foreign currency and interest rate hedges.
(4) This amount consists primarily of changes in value of interest rate hedges.
(5) This amount consists primarily of the customer and risk-management portion
    of WEN's operating income before the deduction of Depreciation and
    Amortization, Impairment and Other Charges and General and Administrative
    Expenses.
(6) This amount represents cash received for sales of emission credits, cash
    received associated with the settlement of fuel hedges and cash payments
    associated with foreign currency hedges.
(7) This amount is calculated as "Cash received during the period" less "Net
    recognized operating loss."

                                      64

<PAGE>

   The following table provides an assessment of net contract values by year
based on the Company's valuation methodology described above.

                     Net Fair Value of Marketing Portfolio
                              September 30, 2002

<TABLE>
<CAPTION>
                                             Total 2002(1) 2003 2004 2005 2006 Thereafter
                                             ----- ------- ---- ---- ---- ---- ----------
                                                            (in millions)
<S>                                          <C>   <C>     <C>  <C>  <C>  <C>  <C>
Market Quotations(2)........................ $307   $(27)  $118 $ 36 $22  $ 7     $151
Other External Sources(3)...................  178     --     73   77  28   --       --
                                             ----   ----   ---- ---- ---  ---     ----
Market Quotations and Other External Sources  485    (27)   191  113  50    7      151
Prices Based on Models(4)...................   (5)    --     --   --  (9)   9       (5)
</TABLE>
--------
(1) Amount represents October 1 to December 31, 2002 values.
(2) Prices obtained from actively traded, liquid markets for commodities other
    than natural gas positions. All natural gas positions for all periods are
    contained in this line based on available market quotations.
(3) Mid-term prices validated against industry posted prices.
(4) See discussion of the Company's use of long-term models in the
    "Management's Discussion and Analysis of Financial Condition and Results of
    Operations" section in the 2001 Form 10-K.

   Value at Risk ("VaR").  In addition to applying business judgment, senior
management uses a number of quantitative tools to manage the Company's exposure
to market risk. These tools include:

  .   Risk limits based on a summary measure of market risk exposure, referred
      to as VaR; and

  .   Stress and scenario analyses performed daily that measure the potential
      effects of various market events, including substantial swings in
      volatility factors, absolute commodity price changes and the impact of
      interest rate and foreign exchange rate movements.

   The modeling of the risk characteristics of Dynegy's marketing portfolio
involves a number of assumptions and approximations. Dynegy estimates VaR using
a JP Morgan RiskMetrics(TM) approach assuming a one-day holding period. Inputs
for the VaR calculation are prices, positions, instrument valuations and a
variance-covariance matrix. While management believes that these assumptions
and approximations are reasonable, there is no uniform industry methodology for
estimating VaR, and different assumptions and/or approximations could produce
materially different VaR estimates.

   Dynegy uses historical data to estimate the Company's VaR and, to better
reflect current asset and liability volatilities, these historical data are
weighted to give greater importance to more recent observations. Given its
reliance on historical data, VaR is effective in estimating risk exposures in
markets in which there are not sudden fundamental changes or shifts in market
conditions. An inherent limitation of VaR is that past changes in market risk
factors, even when weighted toward more recent observations, may not produce
accurate predictions of future market risk. VaR should be evaluated in light of
this and the methodology's other limitations.

   VaR represents the potential loss in value of Dynegy's enterprise-wide
marketing portfolio due to adverse market movements over a defined time horizon
within a specified confidence level. For the VaR numbers reported below, a
one-day time horizon and a 95% confidence level were used. This means that
there is a one in 20 statistical chance that the daily portfolio value will
fall below the expected maximum potential reduction in portfolio value at least
as large as the reported VaR. Thus, a change in portfolio value greater than
the expected change in portfolio value on a single trading day would be
anticipated to occur, on average, about once a month. Gains or losses on a
single day can exceed reported VaR by significant amounts. Gains or losses can
also accumulate over a longer time horizon such as a number of consecutive
trading days.


                                      65

<PAGE>

   In addition, Dynegy has provided its VaR using a one-day time horizon and a
99% confidence level. The purpose of this disclosure is to provide an
indication of earnings volatility using a higher confidence level. Under this
presentation, there is one in 100 statistical chance that the daily portfolio
value will fall below the expected maximum potential reduction in portfolio
value at least as large as the reported VaR. Average VaR is not available for
the nine-month periods ended September 30, 2002 and the year ended December 31,
2001 due to the restatement of historical results. While VaR can be calculated
at a single point in time, it is not feasible to recalculate the historical
results necessary to calculate an average.

   The following table sets forth the aggregate daily VaR of Dynegy's marketing
portfolio:

                       Daily VaR For Marketing Portfolio

<TABLE>
<CAPTION>
                                            September 30, December 31,
                                                2002          2001
                                            ------------- ------------
                                                  (in millions)
          <S>                               <C>           <C>
          One Day VaR--95% Confidence Level      $13          $17
                                                 ---          ---
          One Day VaR--99% Confidence Level      $18          $24
                                                 ===          ===
</TABLE>

   The decrease in One Day VaR from December 31, 2001 is due primarily to the
reduction in exposure in the domestic power portfolio. The reduced exposure is
a result of less price volatility and less trading caused by the current market
conditions and the downgrades to Dynegy's credit ratings.

   Credit Risk.  Credit risk represents the loss that the Company would incur
if a counterparty fails to perform under its contractual obligations. To reduce
the Company's credit exposure, the Company seeks to enter into payment netting
agreements with counterparties that permit Dynegy to offset receivables and
payables with such counterparties. Dynegy attempts to further reduce credit
risk with certain counterparties by entering into agreements that enable the
Company to obtain collateral or to terminate or reset the terms of transactions
after specified time periods or upon the occurrence of credit-related events.
The Company may, at times, use credit derivatives or other structures and
techniques to provide for third-party guarantees of the Company's
counterparties' obligations.

   Dynegy's industry has historically operated under negotiated credit lines or
physical delivery contracts. Dynegy's Credit Department, based on guidelines
set by Dynegy's Credit Policy Committee, establishes Dynegy's counterparty
credit limits. For collateralized transactions, the Company also evaluates
potential exposure over a shorter collection period and gives effect to the
value of collateral received. The Company further seeks to measure credit
exposure through the use of scenario analyses and other quantitative tools.
Dynegy's credit management systems monitor current and potential credit
exposure to individual counterparties and on an aggregate basis to
counterparties and their affiliates. Recent events in the merchant energy
industry have affected historical credit activities in the industry. Please
read "Trade Credit and Other Collateral Obligations" above.

                                      66

<PAGE>

   The following table represents Dynegy's credit exposure at September 30,
2002 associated with its forward positions within the Company's risk-management
portfolio, netted by counterparty (in millions):

                            Credit Exposure Summary

                              September 30, 2002

<TABLE>
<CAPTION>
                                       Investment   Non-investment
                                      Grade Quality Grade Quality  Total
                                      ------------- -------------- ------
      <S>                             <C>           <C>            <C>
      Type of Business:
      Financial Institutions.........     $ 96           $ --      $   96
      Commercial/Industrial/End Users      571             78         649
      Utility and Power Generators...       61              5          66
      Oil and Gas Producers..........       27              1          28
      Other..........................      150             57         207
                                          ----           ----      ------
         Total.......................     $905           $141      $1,046
                                          ====           ====      ======
</TABLE>

   Interest Rate Risk.  Interest rate risk results from variable rate financial
obligations and from providing risk-management services to customers, since
changing interest rates impact the discounted value of future cash flows used
to value risk-management assets and liabilities. Management continually
monitors its exposure to fluctuations in interest rates and may execute swaps
or other financial instruments to hedge and mitigate this exposure.

   The following table sets forth the daily VaR associated with the interest
rate component of the marketing portfolio. Average VaR is not available for the
nine-month period ended September 30, 2002 and the year ended December 31, 2001
due to the restatement of historical results. While VaR can be calculated at a
single point in time, it is not feasible to recalculate the historical results
necessary to calculate an average. Dynegy seeks to manage its interest rate
exposure through application of various hedging strategies. Hedging instruments
executed to mitigate such interest rate exposure in the marketing portfolio are
included in the VaR as of September 30, 2002 and December 31, 2001 reflected in
the table below.

            Daily VaR on Interest Component of Marketing Portfolio

<TABLE>
<CAPTION>
                                            September 30, December 31,
                                                2002          2001
                                            ------------- ------------
                                                  (in millions)
          <S>                               <C>           <C>
          One Day VaR--95% Confidence Level     $2.3          $0.1
                                                ====          ====
</TABLE>

   The increase in One Day VaR is due to changes in the interest rate exposure
on the underlying risk-management marketing portfolio. Interest rate swaps
entered into to manage such exposure were not simultaneously adjusted,
resulting in net interest rate exposure to the Company.

   In addition to the marketing portfolio, the Company is exposed to
fluctuating interest rates as it relates to other variable rate financial
obligations. Based on sensitivity analysis as of September 30, 2002, it is
estimated that a one percentage point interest rate movement in the average
market interest rates (either higher or (lower)) over the twelve months ended
September 30, 2003 would decrease (increase) income before taxes by
approximately $21 million. Hedging instruments executed to mitigate such
interest rate exposure are included in the sensitivity analysis.

                                      67

<PAGE>

   Foreign Currency Exchange Rate Risk.  Foreign currency risk arises from the
Company's investments in affiliates and subsidiaries owned and operated in
foreign countries. Such risk is also a result of risk management transactions
with customers in countries outside the U.S. Management continually monitors
its exposure to fluctuations in foreign currency exchange rates. When possible,
contracts are denominated in or indexed to the U.S. dollar, or such risk may be
hedged through debt denominated in the foreign currency or through financial
contracts. At September 30, 2002, the Company's primary foreign currency
exchange rate exposures were the United Kingdom Pound, Canadian Dollar and
European Euro.

   The following table sets forth the daily and average foreign currency
exchange VaR. Hedging instruments executed to mitigate such foreign currency
exchange exposure are included in VaR as of September 30, 2002 and December 31,
2001 reflected in the table below.

                Daily and Average Foreign Currency Exchange VaR

<TABLE>
<CAPTION>
                                                              September 30, December 31,
                                                                  2002          2001
                                                              ------------- ------------
                                                                    (in millions)
<S>                                                           <C>           <C>
One Day VaR--95% Confidence Level............................     $4.6          $0.6
                                                                  ----          ----
Average VaR for the Year-to-Date Period--95% Confidence Level     $2.9          $1.1
                                                                  ----          ----
</TABLE>

   The increase in One Day and Average VaR is due to the removal of a United
Kingdom Pound currency hedge associated with the Company's net investment in
the United Kingdom natural gas storage business.

   Derivative Contracts.  The absolute notional financial contract amounts
associated with the Company's commodity risk-management, interest rate and
foreign currency exchange contracts were as follows at September 30, 2002 and
December 31, 2001, respectively:

                      Absolute Notional Contract Amounts

<TABLE>
<CAPTION>
                                                                            September 30, December 31,
                                                                                2002          2001
                                                                            ------------- ------------
<S>                                                                         <C>           <C>
Natural Gas (Trillion Cubic Feet)..........................................     11.259       12.044
Electricity (Million Megawatt Hours).......................................     37.679       79.931
Natural Gas Liquids (Million Barrels)......................................      1.705        5.655
Crude Oil (Million Barrels)................................................     11.665           --
Weather Derivatives (In thousands of $/Degree Day).........................    $    --      $   190
Coal (Millions of Tons)....................................................        9.5         18.5
Variable Rate Financial Obligation Interest Rate Swaps (In Millions of U.S.
  Dollars).................................................................    $ 1,696      $    --
Weighted Average Fixed Interest Rate Paid (Percent)........................      2.796           --
Fair Value Hedge Interest Rate Swaps (In Millions of U.S. Dollars).........    $   601      $   206
   Fixed Interest Rate Received on Swaps (Percent).........................      5.616        5.284
Cash Flow Hedge Interest Rate Swaps (in Millions of U.S. Dollars)..........    $    --      $   100
   Fixed Interest Rate Paid on Swaps (Percent).............................         --        4.397
Interest Rate Risk-Management Contract.....................................    $   890      $   503
   Fixed Interest Rate Paid (Percent)......................................      5.995        6.150
Interest Rate Risk-Management Contract (In Millions of U.S. Dollars).......    $    --      $   100
   Fixed Interest Rate Received (Percent)..................................         --        4.370
U.K. Pound Sterling (In Millions of U.S. Dollars)..........................    $   207      $   906
Average U.K. Pound Sterling Contract Rate (In U.S. Dollars)................    $ 1.547      $ 1.423
Euro (In Millions of U.S. Dollars).........................................    $    10      $    18
Average Euro Contract Rate (In U.S. Dollars)...............................    $ 0.978      $0.8863
Canadian Dollar (In Millions of U.S. Dollars)..............................    $   617      $ 1,395
Average Canadian Dollar Contract Rate (In U.S. Dollars)....................    $ 0.637      $0.6435
</TABLE>

                                      68

<PAGE>

                             RESULTS OF OPERATIONS

   On October 16, 2002, Dynegy announced a restructuring plan designed to
improve operational efficiencies and performance across its lines of business.
The plan provides for the adoption of a decentralized business structure
consisting of a streamlined corporate center and operating units in power
generation, natural gas liquids, regulated energy delivery and communications.
Dynegy's operations are reported in four segments: Wholesale Energy Network
("WEN"), Dynegy Midstream Services ("DMS"), Transmission and Distribution
("T&D") and Dynegy Global Communications ("DGC").

   Provided below are a narrative and tabular presentation of certain operating
and financial data and statistics for the Company's businesses for the three-
and nine-month periods ended September 30, 2002 and 2001. The comparative
financial information contained herein has been revised to reflect the
restatement items described in the Explanatory Note to the accompanying
unaudited Condensed Consolidated Financial Statements. Please read this
Explanatory Note for further discussion of these restatement items. For segment
reporting purposes, all general and administrative expenses incurred by Dynegy
on behalf of its subsidiaries are charged to the applicable subsidiary as
incurred. Dynegy allocates indirect general and administrative expenses to its
subsidiaries using a two-step formula that considers both payroll expense and
the net book value of property, plant and equipment. Interest expense incurred
by Dynegy on behalf of its subsidiaries is allocated based on the subsidiaries'
debt to equity relationship. Other income (expense) items incurred by Dynegy on
behalf of its subsidiaries are allocated equally among sub-components of the
four segments.

   Net income (loss) and EPS include the following charges (in millions, except
per share data):

<TABLE>
<CAPTION>
                                         Three Months               Nine Months
                                             Ended                     Ended
                                         September 30,             September 30,
                                    ----------------------- --------------------------
                                        2002        2001        2002          2001
                                    ------------ ---------- ------------ -------------
                                    Charge  EPS  Charge EPS Charge  EPS  Income   EPS
                                    ------ ----- ------ --- ------ ----- ------ ------
<S>                                 <C>    <C>   <C>    <C> <C>    <C>   <C>    <C>
Impairment of goodwill(1)..........  $897  $2.44  $--   $--  $897  $2.46  $ --  $   --
Loss on sale of Northern Natural(2)   566   1.54   --    --   566   1.55    --      --
Cumulative effect of change in
  accounting principle(3)..........    --     --   --    --   234   0.64   (2)   (0.01)
Impairment of communications
  assets(4)........................     3   0.01   --    --   414   1.13    --      --
Impairment of generation
  investments(5)...................    94   0.26   --    --    94   0.26    --      --
Impairment of technology
  investments(6)...................     8   0.02   --    --    53   0.15    --      --
Severance(7).......................    --     --   --    --    21   0.06    --      --
Enron settlement(8)................    16   0.04   --    --    16   0.04    --      --
Other(9)...........................    16   0.04   --    --    27   0.07    --      --
</TABLE>
--------
(1) The Company recognized an after-tax charge of $897 million associated with
    the impairment of goodwill in the WEN segment. There was no tax basis in
    this intangible asset resulting in a pre-tax charge equal to the after-tax
    amount. This third quarter charge is included in Goodwill impairment in the
    accompanying Condensed Consolidated Statement of Operations.
(2) Dynegy incurred an after-tax loss of $566 million ($586 million pre-tax) on
    the sale of Northern Natural to MidAmerican during the third quarter 2002.
    (See Note 3 to the accompanying financial statements.) This loss is
    included in Discontinued Operations in the accompanying Condensed
    Consolidated Statement of Operations.
(3) Effective January 1, 2002, the Company adopted Statement of Financial
    Accounting Standards No. 142, "Goodwill and Other Intangible Assets,"
    realizing an after-tax cumulative effect loss of approximately $234 million
    relating to its telecommunications business. Effective January 1, 2001, the
    Company adopted

                                      69

<PAGE>

   Statement of Financial Accounting Standards No. 133, "Accounting for
   Derivative Instruments and Hedging Activities," as amended, realizing an
   after-tax cumulative effect gain of approximately $2 million.
(4) The Company recognized an after-tax charge of $414 million ($635 million
    pre-tax) associated with the write-down of certain telecommunications
    assets primarily in the second quarter 2002. The pre-tax charge is included
    in Cost of Sales, Impairment and Other Charges and Other Expenses in the
    accompanying Condensed Consolidated Statement of Operations.
(5) The Company recognized an after-tax charge of approximately $94 million
    ($144 million pre-tax) for the impairment of investments in generation
    assets in the third quarter 2002. The charge is included in Earnings
    (Losses) From Unconsolidated Investments in the accompanying Condensed
    Consolidated Statement of Operations.
(6) The Company recognized an after-tax charge of approximately $8 million ($12
    million pre-tax) for the impairment of technology investments in the third
    quarter 2002. For the nine-month period ended September 30, 2002, the
    Company recognized a cumulative after-tax charge of approximately $53
    million ($80 million pre-tax) for the impairment of technology investments.
    These charges are included in Earnings (Losses) from Investments in
    Unconsolidated Investments in the accompanying Condensed Consolidated
    Statement of Operations.
(7) The Company recognized an after-tax charge of approximately $21 million
    ($33 million pre-tax) for severance benefits for approximately 325
    employees, including the Company's former Chief Executive Officer and Chief
    Financial Officer in the second quarter. The charge is included in
    Impairment and Other Charges in the accompanying Condensed Consolidated
    Statement of Operations. The additional severance charge of $3 million
    after-tax ($4 million pre-tax) was allocated to Northern Natural, which is
    included in Discontinued Operations.
(8) The Company recognized an after-tax charge of approximately $16 million
    ($25 million pre-tax) in the third quarter 2002 associated with the
    settlement of the Enron litigation. The charge is included in Other
    Expenses in the accompanying Condensed Consolidated Statement of Operations.
(9) The amount represents $4 million after-tax ($6 million pre-tax) of fees
    related to a voluntary action that the Company took in the second quarter
    2002 that altered the accounting for certain lease obligations.
    Additionally, the Company had $4 million after-tax ($6 million pre-tax) of
    write-offs in the second quarter 2002 related to information technology
    equipment. In the third quarter 2002, in conjunction with the Company's
    decision to exit certain aspects of the marketing and trading business
    relating to third party or customer risk management for natural gas and
    power, the Company's investment in Dynegydirect was written off. This
    resulted in an after-tax charge of $16 million ($25 million pre-tax). These
    amounts are included in Impairment and Other Charges in the accompanying
    Condensed Consolidated Statement of Operations.

Three-month Periods Ended September 30, 2002 and 2001

   For the quarter ended September 30, 2002, Dynegy recorded a net loss of
$1,651 million or $4.71 per share, compared with third quarter 2001 net income
of $238 million or $0.71 per diluted share. Charges recognized in the third
quarter 2002, as more fully described in the footnotes to the table above,
included after-tax charges for an $897 million goodwill impairment, a $566
million loss on the sale of Northern Natural, a $94 million impairment of
generation investments, a $16 million after-tax charge related to the write-off
of Dynegydirect, a $16 million after-tax charge related to the Enron litigation
settlement and an $8 million after-tax impairment of technology investments.

   Dynegy announced in early October 2002 an organizational restructuring and
its intent to exit third party risk management aspects of the marketing and
trading business. The Company also announced a work force reduction affecting
approximately 780 employees. The Company estimates that it will recognize
pre-tax charges associated with severance of $50 million ($33 million
after-tax) in the fourth quarter 2002 and $6 million ($4 million after-tax) in
the first quarter 2003.

   Operating income decreased approximately $1,333 million quarter-to-quarter
due primarily to the negative impact of the goodwill impairment, as well as
reduced margins from operating units. General and administrative

                                      70

<PAGE>

expenses were lower period-to-period principally as a result of significantly
lower variable compensation costs in the 2002 period, which were partially
offset by higher legal and audit fees.

   Dynegy's losses from unconsolidated investments were approximately $120
million in the 2002 period compared to earnings of $85 million in 2001.
Variances period-to-period in these results primarily reflect the impact of the
$144 million impairment of generation investments, the $12 million impairment
of technology investments and a $75 million decrease in earnings related to
West Coast Power due to lower delivered power volumes.

   Interest expense totaled $103 million for the three-month period ended
September 30, 2002, compared to $65 million for the 2001 period. The variance
is primarily attributable to higher average principal balances in the 2002
period compared to the 2001 period, partially offset by lower average interest
rates on borrowings.

   Other income and expenses, net (including minority interest expense and
accumulated distributions associated with trust preferred securities) totaled
$40 million in expense in the quarter ended September 30, 2002. Combined other
income and other expenses totaled $15 million in expense in 2001. The 2002
quarter includes the $25 million pre-tax charge related to the Enron litigation
settlement.

   The Company reported an income tax benefit of $120 million for the quarter
ended September 30, 2002, compared to an income tax provision of $147 million
for the 2001 period. The effective tax rates approximated 10 percent and 38
percent in 2002 and 2001, respectively. The 2002 tax benefit was reduced from
statutory rates as a result of book-tax basis differences (principally
impacting the goodwill impairment), the effect of foreign equity investments,
the amortization of intangibles, state income taxes and valuation allowances
recognized in the period relative to the realizability of certain capital loss
carryforwards arising from the sale of Northern Natural and foreign tax credit
carryforwards. The tax provision in the 2001 period varied from the statutory
tax rate of 35 percent principally as a result of book-tax basis differentials
related to the amortization of certain intangibles, other book-tax basis
differences and the effect of foreign equity investments and state income taxes.

Nine-month Periods Ended September 30, 2002 and 2001

   For the nine months ended September 30, 2002, Dynegy recorded a net loss of
$2,459 million or $7.42 per share, compared with net income of $432 million or
$1.28 per diluted share in the same 2001 period. The nine-month period ended
September 30, 2002 included charges related to the items described above for
the three-month period plus the impairment of communications assets and
technology investments, a severance charge and the cumulative effect of a
change in accounting principle related to goodwill.

   In addition to these charges, 2002 net income decreased period-to-period due
primarily to market events that negatively affected the gas and power marketing
and trading industry in 2002 and the resulting negative impact these events had
on Dynegy's liquidity and creditworthiness, which in turn reduced the
effectiveness and profitability of the Company's marketing and trading,
generation and NGL businesses. Further, principally as a result of continued
depressed values in the telecommunications sector, the Company has to date been
unable to execute a managed exit from its telecommunications business thus
increasing financial losses period over period as well as reducing available
cash flow.

   Operating income decreased $2,556 million period over period primarily due
to the reasons described in the previous paragraph as well as the
aforementioned goodwill charge recorded in the third quarter 2002 and the
impairment and other charges taken during the previous two quarters in 2002
that are more fully described in Note 5 to the accompanying financial
statements.

   Dynegy's earnings (losses) from unconsolidated investments were
approximately $116 million of losses and $195 million of earnings in the 2002
and 2001 periods, respectively. Variances period-to-period in these results
primarily reflect the impact of the impairment of $114 million of generation
investments, the impairment of $80

                                      71

<PAGE>

million of technology investments resulting from unfavorable market conditions
and a $108 million decrease in earnings related to West Coast Power due to a
decrease in realized prices as well as an overall decline in demand.

   Interest expense totaled $255 million for the nine-month period ended
September 30, 2002, compared to $199 million for the equivalent 2001 period.
The variance is primarily attributed to higher average principal balances in
the 2002 period compared to the 2001 period, partially offset by lower average
interest rates on borrowings.

   Other income and expenses, net (including minority interest expense and
accumulated distributions associated with trust preferred securities) totaled
$65 million in expense in the nine-month period ended September 30, 2002
compared with $96 million in expense in the same 2001 period. Variances
period-to-period in these results primarily reflect higher minority interest
expense in the 2001 period.

   The Company reported an income tax benefit of $471 million for the
nine-month period ended September 30, 2002, compared to an income tax provision
of $283 million for the 2001 period. The effective tax rates approximated 22
percent and 40 percent in 2002 and 2001, respectively. The difference from the
effective tax rates and the statutory tax rate of 35 percent result from the
same factors impacting the third quarter periods.

   Effect of Accounting for Goodwill.  As described in Note 1 to the
accompanying financial statements, the Company adopted Statement of Financial
Accounting Standards No. 142, "Goodwill and Other Intangible Assets"
("Statement No. 142"), effective January 1, 2002. Had Statement No. 142 been in
effect in 2001, the Company's net income and earnings per share for the three
months ended September 30, 2001 would have been $249 million or $0.74 per
diluted share compared to actual net income reported of $238 million or $0.71
per diluted share. For the nine-months ended September 30, 2001, net income
would have been $467 million or $1.39 per diluted share compared to actual net
income reported of $432 million or $1.28 per diluted share.

                                      72

<PAGE>

Segment Disclosures

                           WHOLESALE ENERGY NETWORK

<TABLE>
<CAPTION>
                                                      Three Months          Nine Months
                                                         Ended                 Ended
                                                     September 30,         September 30,
                                                    -------------------  --------------------
                                                      2002      2001       2002       2001
                                                     -------    ------    -------    -------
                                                    (in millions, except operating statistics)
<S>                                                 <C>        <C>       <C>        <C>
Operating Income (loss):
   Customer and Risk-Management Activities......... $  (178)   $  127    $  (509)   $   285
   Asset Businesses................................      52       189        164        329
   Goodwill Impairment.............................    (893)       --       (893)        --
                                                     -------    ------    -------    -------
          Total Operating Income (Loss)............  (1,019)      316     (1,238)       614
Earnings (Losses) from Unconsolidated Investments..    (122)       77        (77)       167
Other Items........................................     (26)      (21)       (44)      (100)
                                                     -------    ------    -------    -------
   Earnings (Loss) Before Interest and Taxes.......  (1,167)      372     (1,359)       681
Interest Expense...................................     (59)      (23)      (125)       (66)
                                                     -------    ------    -------    -------
   Pre-tax Earnings (Loss).........................  (1,226)      349     (1,484)       615
Income Tax Provision (Benefit).....................    (113)      131       (226)       241
                                                     -------    ------    -------    -------
   Income (Loss) From Continuing Operations........  (1,113)      218     (1,258)       374
Discontinued operations (1):
   Income from discontinued operations.............      17        --         37         --
   Income tax provision............................       6        --         11         --
                                                     -------    ------    -------    -------
   Income on discontinued operations...............      11        --         26         --
Cumulative Effect of Change in Accounting Principle      --        --         --          2
                                                     -------    ------    -------    -------
       Net Income (Loss)........................... $(1,102)   $  218    $(1,232)   $   376
                                                     -------    ------    -------    -------
Operating Statistics:
   Natural Gas Marketing (Bcf/d)--
       Domestic Marketing Volumes..................     6.4       8.1        8.2        8.2
       Canadian Marketing Volumes..................     2.1       2.9        2.7        2.6
       European Marketing Volumes..................     2.5       1.0        2.3        1.4
                                                     -------    ------    -------    -------
          Total Marketing Volumes..................    11.0      12.0       13.2       12.2
                                                     -------    ------    -------    -------
Million Megawatt Hours Generated--Gross............    13.0      11.5       32.5       31.7
Million Megawatt Hours Generated--Net..............    11.8      10.1       29.4       26.9
North American Physical Million Megawatt Hours Sold    31.1      90.5      263.0      212.6
European Physical Million Megawatt Hours Sold......    21.2      34.6      116.7       69.4
                                                     -------    ------    -------    -------
   Total Physical Million Megawatt Hours Sold......    52.3     125.1      379.7      282.0
                                                     -------    ------    -------    -------
Coal Marketing Volumes (Millions of Tons)..........    10.5      11.2       27.8       29.7
Average Natural Gas Price--Henry Hub ($/MMbtu)..... $  3.16    $ 2.92    $  2.96    $  4.87
Average On-Peak Market Power Prices................
   Cinergy......................................... $ 33.47    $37.02    $ 27.48    $ 39.24
   TVA.............................................   32.69     35.72      27.67      38.99
   PJM.............................................   46.04     48.82      35.77      45.23
   New York--Zone G................................   55.57     57.04      44.90      58.05
   Platts SP 15....................................   35.73     45.02      32.25     147.26
</TABLE>
--------
   (1) See Note 3 to the accompanying financial statements.

                                      73

<PAGE>

Three-month Periods Ended September 30, 2002 and 2001

   WEN reported a net loss of $1,102 million for the three-month period ended
September 30, 2002, compared with net income of $218 million in the 2001
quarter. The results reflect an overall decline in market liquidity principally
caused by increasing credit concerns in the merchant energy sector,
counterparty concerns over Dynegy's non investment grade credit ratings and a
reduction in the spread between natural gas and power prices. The segment
results generally reflect lower returns from its generation portfolio as a
result of lower power prices and excess generation capacity in the market. As
previously discussed, the Company recognized an after-tax charge of $897
million associated with the impairment of goodwill. There was no tax basis in
this intangible asset resulting in a pre-tax charge equal to the after-tax
amount. The reported earnings were also negatively impacted by the third
quarter 2002 impairment of equity investments, the write-down of Dynegydirect
and an allocation of the Enron litigation settlement. Additionally, there was a
$75 million decline in earnings from the equity investment in West Coast Power
due to a decrease in delivered volumes period-over-period. Interest expense was
higher in the third quarter 2002 due to higher average borrowings, partially
offset by lower average interest rates.

   Total physical MW hours sold in the third quarter 2002 decreased to 52.3
million MW hours as compared to 125.1 million MW hours in the third quarter
2001. Total natural gas volumes sold in the third quarter 2002 decreased to
11.0 billion cubic feet per day as compared to 12.0 billion cubic feet per day
during last year's third quarter. The decrease in power and gas volumes is due
primarily to the decline in market liquidity resulting from increasing credit
concerns related to Dynegy and in the merchant energy sector generally.

Nine-month Periods Ended September 30, 2002 and 2001

   WEN reported a net loss of $1,232 million for the nine-month period ended
September 30, 2002, compared with net income of $376 million in the same 2001
period. Absent the charges discussed above, the decrease in operating results
generally reflect the significant downturn in profitability in the marketing
and trading business period-over-period resulting from credit, liquidity and
market concerns as well as significantly lower price realization in the
generation business in 2002. In addition to the items described above for the
third quarter comparisons, Dynegy's customer and risk-management business'
operating income for the nine-month period included significant customer
origination during the first quarter 2002 in both the wholesale and commercial
and industrial businesses. The increased origination resulted from new
contracts for the acquisition of long-term power supply at competitive prices
and incremental natural gas storage contracts. The segment's 2002 results
include a $109 million decline in earnings from the equity investment in West
Coast Power due to a decrease in realized power prices period-over-period as
well as an overall decline in demand and impairment of technology investments.
The results also include an allocated charge of $19 million associated with
severance and related costs recorded in the second quarter 2002.

   Total physical MW hours sold in the nine-month period ended September 30,
2002 increased to 379.7 million MW hours compared to 282.0 million MW hours in
the same period in 2001 due primarily to increased physical MW hours sold in
Europe and greater customer origination in the first quarter of 2002. Total
natural gas volumes sold in the nine months ended September 30, 2002 increased
to 13.2 billion cubic feet per day as compared to 12.2 billion cubic feet per
day during the same period last year due to the inclusion of incremental
ChevronTexaco volumes associated with former Texaco equity production and
increases in gas volumes sold in Europe.

WEN Outlook

   The weak power price environment has continued into the fourth quarter 2002.
Increased collateralization requirements resulting from credit concerns have
also continued, resulting in higher interest expense and other capital costs in
order to satisfy counterparties' credit concerns. Going forward, Dynegy expects
that its managed exit from third party risk management aspects of the marketing
and trading business will significantly reduce this

                                      74

<PAGE>

segment's collateral requirements and general and administrative expenses.
During this period, which the Company expects will take up to six months,
Dynegy will make appropriate arrangements regarding its long-term contractual
obligations, including retaining personnel and risk-management capabilities and
continuing capacity to support its customers. The Company's ability to
successfully manage this exit, which is dependent on a number of factors, some
of which are outside of the Company's control, will effect the amount of cash
that is ultimately realized from its marketing and trading portfolio.

   Following the exit from third party risk management aspects of the marketing
and trading business, Dynegy's WEN segment will consist primarily of its
generation assets (as well as any remaining risk management positions that
remain pending a roll off over the contract term). The results of operations
for Dynegy's generation assets will reflect a sensitivity to natural gas and
power prices as well as terms of contracts for contracted generation. The
Company expects that this business will continue its efforts to manage this
price risk through the optimization of fuel procurement and the marketing of
power generated from its owned and controlled assets. Dynegy's sensitivity to
prices and its ability to manage this sensitivity, however, is subject to a
number of factors, including general market liquidity, Dynegy's liquidity
position and the willingness of counterparties to transact business with Dynegy
given its non-investment grade credit ratings. Other factors that could affect
the prices at which transactions can be consummated and this segment's results
of operations include governmental actions or excess generation capacity in the
markets it serves.

                           DYNEGY MIDSTREAM SERVICES

<TABLE>
<CAPTION>
                                                      Three Months Ended Nine Months Ended
                                                       September 30,      September 30,
                                                      -----------------  ----------------
                                                       2002      2001     2002     2001
                                                       ------   ------   ------   ------
                                                          ($ in millions, except
                                                           operating statistics)
<S>                                                   <C>       <C>      <C>      <C>
Operating Income:
    Upstream......................................... $   12    $   16   $   31   $   76
    Downstream.......................................     17        11       48       39
                                                       ------   ------   ------   ------
          Total Operating Income.....................     29        27       79      115
Earnings from Unconsolidated Investments.............      4         3       12        9
Other Items..........................................    (10)       --      (22)     (11)
                                                       ------   ------   ------   ------
          Earnings Before Interest and Taxes.........     23        30       69      113
Interest Expense.....................................    (13)      (12)     (36)     (40)
                                                       ------   ------   ------   ------
          Pre-tax Earnings...........................     10        18       33       73
Income Tax Provision.................................      7         8       14       26
                                                       ------   ------   ------   ------
       Net Income.................................... $    3    $   10   $   19   $   47
                                                       ------   ------   ------   ------
Operating Statistics:
    Natural Gas Processing Volumes (MBbls/d):
       Field Plants..................................   56.3      56.3     55.0     56.0
       Straddle Plants...............................   35.3      26.1     36.5     25.5
                                                       ------   ------   ------   ------
       Total Natural Gas Processing Volumes..........   91.6      82.4     91.5     81.5
                                                       ------   ------   ------   ------
    Fractionation Volumes (MBbls/d)..................  224.8     241.6    223.7    230.4
    Natural Gas Liquids Sold (MBbls/d)...............  481.9     550.4    519.6    562.0
    Average Commodity Prices:
       Natural Gas--Henry Hub ($/MMBtu).............. $ 3.16    $ 2.92   $ 2.96   $ 4.87
       Crude Oil--Cushing ($/Bbl)....................  28.40     26.64    24.78    27.85
       Natural Gas Liquids ($/Gal)...................   0.41      0.39     0.37     0.50
       Fractionation Spread ($/MMBtu)................   1.40      1.51     1.24     0.80
</TABLE>

                                      75

<PAGE>

Three-month Periods Ended September 30, 2002 and 2001

   DMS reported net income of $3 million in the third quarter 2002 compared
with net income of $10 million in the third quarter 2001. The segment's results
of operations during the third quarter 2002 were impacted by lower
fractionation spreads and lower realized prices as compared to higher
fractionation spreads and higher realized prices during the third quarter 2001
as a result of the Company's hedging program and forward selling products at a
higher price than the prevailing market price during such quarter. In addition,
as a result of slow economic recovery, high industry-wide inventory levels,
reduced NGL liquidity and Dynegy specific credit limitations, the segment
experienced a decline in domestic and foreign marketing volumes and margins.
DMS' quarterly results were negatively impacted by $4 million, net of tax, due
to allocated charges related to the Enron settlement and the impairment of
technology investments as more fully discussed in Note 4 to the Condensed
Consolidated Financial Statements. There were no such charges recorded in the
third quarter 2001.

   Aggregate domestic NGL processing volumes totaled 91.6 thousand gross
barrels per day in the third quarter 2002 compared to 82.4 thousand gross
barrels per day during the same period in 2001. A small percentage of this
volume increase resulted from the inclusion of incremental ChevronTexaco
volumes associated with former Texaco equity production. The majority of the
volume growth is related to the Louisiana straddle plants and is the direct
result of an increasing need to process Gulf of Mexico natural gas production
to meet third party pipeline dew point specification limits.

   The average fractionation spread was $1.40 for the three months ended
September 30, 2002, compared to $1.51 for the comparable 2001 period.
Traditional keep-whole processing is only marginally economical at this level.
Historically, the Louisiana straddle plants would not have operated in this
pricing environment.

Nine-month Periods Ended September 30, 2002 and 2001

   DMS reported net income of $19 million in the nine months ended September
30, 2002 compared with net income of $47 million in the nine months ended
September 30, 2001. In addition to the items described above for the second
quarter comparisons, warmer winter temperatures influenced results of
operations period-to-period. DMS' results for the nine-months ended September
30, 2002 were negatively impacted by $8 million, net of tax, due to allocated
charges related to the Enron settlement, severance costs and the impairment of
technology investments as more fully discussed in Note 4 to the Condensed
Consolidated Financial Statements. There were no such charges recorded in the
nine-month period in 2001.

   Aggregate domestic NGL volumes from processing totaled 91.5 thousand gross
barrels per day in the nine months ended September 30, 2002 compared to 81.5
thousand gross barrels per day during the same period in 2001. A small
percentage of this volume resulted from the inclusion of incremental
ChevronTexaco volumes associated with former Texaco equity production. The
majority of the volume growth related to the Company's Louisiana straddle
plants and is the direct result of an increasing need to process Gulf of Mexico
natural gas production to meet third party pipeline dew point specification
limits.

   The average fractionation spread was $1.24 for the nine months ended
September 30, 2002, compared to $0.80 for the comparable 2001 period. Despite
the year-over-year increase in this spread, traditional keep-whole processing
is only marginally economical at this level. Historically, the Louisiana
straddle plants would not have operated in this pricing environment.

DMS Outlook

   The weak fractionation spread environment has continued into the fourth
quarter 2002. Increased collateralization requirements resulting from credit
concerns have also continued, particularly with respect to the global liquids
business. The Company is exploring alternatives for the global liquids business
to reduce its collateral commitments or to otherwise align it with Dynegy's
current liquidity position, which may include a sale. Going forward, Dynegy
expects that its DMS segment will incur higher interest expenses and other
capital

                                      76

<PAGE>

costs in order to satisfy counterparties' credit concerns. Credit concerns have
also made it more difficult for DMS to execute new long-term commercial
agreements or to renew expiring commercial agreements in the ordinary course of
business, potentially resulting in reduced results of operation.

   DMS' sensitivity to commodity prices can be expected to continue and is
impacted by a number of factors, including:

  .   The correlation between the price of crude oil and NGLs;

  .   The absolute price of natural gas;

  .   The spread between the price of natural gas and the price of NGLs;

  .   The relative impact of all of these factors based on DMS' mix of
      processing contracts; and

  .   The resulting volumes of NGLs available for DMS' fee-driven downstream
      business.

Sensitivity to commodity prices varies at any point in time based on the
relative combination of the above factors. DMS intends to manage its commodity
price exposure by hedging its natural gas and NGL production within the limits
of market liquidity and credit availability. Typically, this hedging strategy
primarily focuses on the forward twelve months.

   In addition, DMS' business is dependent on producer drilling activity in the
producing regions that its gathering systems serve. At current natural gas
price levels, producers are actively drilling new wells and DMS' new connect
gas volumes for processing are growing enough to offset the natural decline in
production. The producers supplying DMS' facilities are primarily independent
producers who, as a group, react quickly to changes in gas prices. As natural
gas prices decline significantly from current levels, these producers have
historically reduced their drilling investment. If this occurs going forward,
DMS could experience difficulty in acquiring enough volumes to offset natural
declines. Conversely, as gas prices strengthen from current levels, producers
have historically invested more heavily in drilling and development.

                                      77

<PAGE>

                         TRANSMISSION AND DISTRIBUTION

<TABLE>
<CAPTION>
                                                                 Three Months Ended Nine Months Ended
                                                                  September 30,       September 30,
                                                                 -----------------  ----------------
                                                                  2002      2001      2002     2001
                                                                  ------   ------   -------  -------
                                                                          ($ in millions)
<S>                                                              <C>       <C>      <C>      <C>
   Operating Income............................................. $   72    $   68   $   169  $   184
Losses from Unconsolidated Investments..........................     (1)       --        (2)      --
Other Items.....................................................     (3)       (1)       (3)      (2)
                                                                  ------   ------   -------  -------
   Earnings Before Interest and Taxes...........................     68        67       164      182
Interest Expense................................................    (25)      (27)      (77)     (87)
                                                                  ------   ------   -------  -------
   Pre-tax Earnings.............................................     43        40        87       95
Income Tax Provision............................................     11        16        31       43
                                                                  ------   ------   -------  -------
Income from continuing operations...............................     32        24        56       52
Discontinued operation (1):
Loss from discontinued operations (including loss on disposal of
  $586 million).................................................   (586)       --      (548)      --
   Income tax benefit...........................................    (20)       --        (5)      --
                                                                  ------   ------   -------  -------
   Loss on discontinued operations..............................   (566)       --      (543)      --
                                                                  ------   ------   -------  -------
   Net Income (Loss)............................................ $ (534)   $   24   $  (487) $    52
                                                                  ------   ------   -------  -------
Illinois Power:
Electric Sales in kWh (Millions)
   Residential..................................................  1,832     1,681     4,342    4,160
   Commercial...................................................  1,231     1,194     3,334    3,308
   Commercial distribution......................................      1         5         2       39
   Industrial...................................................  1,667     1,645     4,719    4,754
   Industrial distribution......................................    621       677     1,921    1,937
   Other........................................................     98        97       283      287
                                                                  ------   ------   -------  -------
       Total Electric Sales.....................................  5,450     5,299    14,601   14,485
                                                                  ------   ------   -------  -------
Gas Sales in Therms (Millions)
   Residential..................................................     18        20       214      225
   Commercial...................................................     11        12        90       99
   Industrial...................................................     24        24        61       69
   Transportation of Customer-Owned Gas.........................     47        49       180      185
                                                                  ------   ------   -------  -------
       Total Gas Delivered......................................    100       105       545      578
                                                                  ------   ------   -------  -------
   Heating Degree Days..........................................     29        89     3,024    3,146
                                                                  ------   ------   -------  -------
   Cooling Degree Days..........................................  1,006       847     1,432    1,291
                                                                  ------   ------   -------  -------
</TABLE>
--------
(1) See Note 3 to the accompanying financial statements.

Three-month Periods Ended September 30, 2002 and 2001

   The T&D segment reported a net loss of $534 million in the third quarter
2002 compared to $24 million net income in the third quarter 2001. Net income
for the three months ended September 30, 2002 includes a $566 million after-tax
($586 million pre-tax) loss on the sale of Northern Natural. (See Note 3 for
further details.) Illinois Power ("IP") experienced favorable results from
operations period-to-period that were influenced by increased electricity usage
from commercial and residential customers due to favorable weather conditions.
These results were partially offset by a mandated five percent residential rate
reduction effective May 1, 2002, the election of some commercial and industrial
customers to pay for power at market-based prices, rather than

                                      78

<PAGE>

under bundled tariffs, and a decrease in industrial customer demand due to a
weakened economy in IP's principal market areas.

Nine-month Periods Ended September 30, 2002 and 2001

   The T&D segment reported a net loss of $487 million in the nine months ended
September 30, 2002 compared to $52 million in the same 2001 period. Net income
for the nine months ended September 30, 2002 includes the loss on the sale of
Northern Natural. IP experienced slightly favorable results period-to-period.
In addition to the items described above for the third quarter comparisons, the
nine-month results were influenced by decreased demand from commercial and
residential customers due to unfavorable weather conditions experienced during
the first quarter 2002.

IP Outlook

   Future results of operations for IP may be affected, either positively or
negatively, by regulatory actions, general economic conditions, overall
economic growth, the demand for power and natural gas in IP's service area and
interest rates. In addition, Dynegy's financial condition may impact IP's
business, as well as its capitalization structure and ability to access the
capital markets. The transmission sale, if approved, is expected to decrease
annual operating margin by approximately $42 million, offset by a $28 million
reduction in regulatory asset amortization. The change in annual free cash flow
is expected to be relatively neutral.

   Please read "IP Liquidity" above for further discussion regarding IP's
significant near-term debt maturities and IP's plans to satisfy these
maturities.

                         DYNEGY GLOBAL COMMUNICATIONS

<TABLE>
<CAPTION>
                                                     Three Months Ended Nine Months Ended
                                                     September 30,      September 30,
                                                     -----------------  ----------------
                                                     2002      2001      2002     2001
                                                     ----      ----      -----    -----
                                                          ($ in millions)
 <S>                                                 <C>       <C>      <C>      <C>
 Operating Loss..................................... $(35)     $(31)    $(753)   $(100)
 Earnings (Losses) from Unconsolidated Investments..   (1)        5       (49)      19
 Other Items........................................   (1)        7         4       17
                                                       ----     ----     -----    -----
 Loss Before Interest and Taxes.....................  (37)      (19)     (798)     (64)
 Interest Expense...................................   (6)       (3)      (17)      (6)
                                                       ----     ----     -----    -----
 Pre-tax Loss.......................................  (43)      (22)     (815)     (70)
 Income Tax Benefit.................................  (25)       (8)     (290)     (27)
                                                       ----     ----     -----    -----
 Net Loss from Operations...........................  (18)      (14)     (525)     (43)
 Cumulative Effect of Change in Accounting Principle   --        --      (234)      --
                                                       ----     ----     -----    -----
 Net Loss........................................... $(18)     $(14)     (759)   $ (43)
                                                       ----     ----     -----    -----
</TABLE>

Three-month Periods Ended September 30, 2002 and 2001

   The telecommunications segment continues to experience severely depressed
industry conditions as evidenced by an increased number of bankruptcies,
continued devaluation of equity securities, lack of financing sources in the
sector and further pricing pressures resulting from challenges faced by major
industry players. During the period, management continued to take measures to
reduce losses in the business by limiting capital spending and reducing
operating and administrative expenses. Capital expenditures for the third
quarter 2002 were $7 million compared to $87 million in the third quarter 2001,
$28 million in the first quarter 2002 and $13 million in the second quarter
2002. Based on ongoing analysis pursuant to Statement No. 144, the Company is
expensing capital investment in the segment as incurred (see Note 4 of the
accompanying financial statements).

                                      79

<PAGE>

   DGC reported a net loss of $18 million for the third quarter 2002 compared
to a net loss of $14 million in the third quarter 2001. Results for 2002
include non-cash expenses to cover DGC's accrual of costs for the lease
obligation on its domestic network assets and the cost to purchase a lease
obligation associated with the European network. (See Note 4 of the
accompanying financial statements for further discussion.) Period-to-period
operating results were negatively impacted by higher operating costs
attributable to the domestic fiber optic network becoming operational in the
fourth quarter 2001, partially offset by efforts to reduce operating and
administrative expenses in 2002.

Nine-month Periods Ended September 30, 2002 and 2001

   DGC reported a $759 million net loss in the nine-month period ended
September 30, 2002. This compares to a $43 million net loss in the nine-month
period ended September 30, 2001. Segment results for 2002 include a $234
million charge for the impairment of goodwill upon adoption of Statement No.
142 and a pre-tax charge of $635 million ($414 million after tax) associated
with the impairment of assets pursuant to the application of Statement No. 144
(see Note 4 of the accompanying financial statements for further discussion of
these two charges). These results were adversely impacted by higher operating
costs associated with a fully operational domestic network, non-cash expenses
to cover DGC's anticipated loss for a lease obligation on the domestic network,
the purchase of a lease obligation associated with the European network and a
decrease in equity earnings related to technology investments. These results
were partially offset by lower depreciation expense resulting from the 2002
impairment of assets and aggressive efforts this year to lower administrative
expenses.

DGC Outlook

   The outlook for telecommunications services remains depressed in the near
term. Management anticipates the segment will continue to negatively impact the
Company's cash flows and earnings for the remainder of 2002. Thus, management
is pursuing efforts to reduce costs, limit capital spending, and obtain new
revenue while seeking mutually beneficial resolution of longer-term
commitments. Dynegy is also pursuing partnership and sale opportunities for
this business, although no formal plans are in place and no assurance can be
provided as to the timing or structure of any such transaction. In addition, as
of September 30, 2002, Dynegy has approximately $185 million, or approximately
$100 million on a discounted basis, in long-term operating commitments relating
to its global telecommunications business.

                                      80

<PAGE>

Cash Flow Disclosures

   The following table is a condensed version of the operating section of the
Condensed Consolidated Statements of Cash Flows (in millions):

<TABLE>
<CAPTION>
                                            For The Nine Months Ended September 30, 2002
                                       -----------------------------------------------------
                                                                    Corporate &
                                         WEN     DMS   T&D    DGC   Eliminations Consolidated
                                       -------  ----  -----  -----  ------------ ------------
<S>                                    <C>      <C>   <C>    <C>    <C>          <C>
Net Income (Loss)..................... $(1,232) $ 19  $(487) $(759)     $ --       $(2,459)
Net Non-Cash Items Included in Net
  Income..............................   1,663    63    797    633         5         3,161
                                       -------  ----  -----  -----      ----       -------
Operating Cash Flows Before Changes in
  Working Capital.....................     431    82    310   (126)        5           702
Changes in Working Capital............    (281)  (19)   (52)   (57)      (31)         (440)
                                       -------  ----  -----  -----      ----       -------
Net Cash Provided by (Used in)
  Operating Activities................ $   150  $ 63  $ 258  $(183)     $(26)      $   262
                                       -------  ----  -----  -----      ----       -------

                                            For The Nine Months Ended September 30, 2001
                                       -----------------------------------------------------
                                                                    Corporate &
                                         WEN     DMS   T&D    DGC   Eliminations Consolidated
                                       -------  ----  -----  -----  ------------ ------------
Net Income (Loss)..................... $   376  $ 47  $  52  $ (43)     $ --       $   432
Net Non-Cash Items Included in Net
  Income..............................      15    92    170      6        --           283
                                       -------  ----  -----  -----      ----       -------
Operating Cash Flows Before Changes in
  Working Capital.....................     391   139    222    (37)       --           715
Changes in Working Capital............    (114)   10   (144)   (28)       19          (257)
                                       -------  ----  -----  -----      ----       -------
Net Cash Provided by (Used in)
  Operating Activities................ $   277  $149  $  78  $ (65)     $ 19       $   458
                                       -------  ----  -----  -----      ----       -------
</TABLE>

   Operating Cash Flow.  Cash flow from operating activities totaled $262
million for the nine-month period ended September 30, 2002 compared to $458
million reported in the same 2001 period. Non-cash add-backs were greater in
the 2002 period, primarily due to the following charges, which are further
described in Notes 3 and 4 to the accompanying financial statements:

  .   The $897 million goodwill impairment associated with the WEN segment;

  .   The $586 million loss on the sale of Northern Natural;

  .   The $234 million impairment of goodwill for DGC related to the adoption
      of Statement No. 142 as previously disclosed in the first quarter 2002
      and $635 million of additional pre-tax impairment charges for DGC
      primarily during the second quarter 2002;

  .   Write-offs within Earnings (Losses) from Unconsolidated Investments in
      the first three quarters of 2002 of $80 million representing technology
      investment impairments based on the Company's change in business strategy
      and continued downturn in the technology sector. Of the total write-offs,
      $26 million related to WEN and $50 million related to DGC, with the
      remaining amounts allocated to DMS and T&D. Additionally, the Company
      wrote off $144 million of generation investments in the third quarter
      2002, all of which was associated with the WEN segment.

   Other changes in non-cash items include the following:

  .   Depreciation and amortization expense increased by $78 million primarily
      due to the inclusion of Northern Natural from February through July 2002
      and the United Kingdom natural gas storage facilities beginning in
      November 2001 offset by the discontinued amortization of goodwill in 2002;

                                      81

<PAGE>

  .   A reduction in Earnings (Losses) from Unconsolidated Investments of
      approximately $108 million related to West Coast Power;

  .   Deferred income taxes are a $414 million benefit position for the nine
      months ended September 30, 2002, compared to an expense of $203 million
      in the same 2001 period, producing a $617 million decreased add-back; and

  .   Risk Management activity produced a $527 million add-back, compared to a
      deduction of $104 million in the 2001 period. The add-backs represent
      cash realized for settled contracts in excess of gains recognized
      combined with non-cash losses realized in the period in excess of cash
      settlements.

   Changes in working capital had a negative impact on cash flow from
operations for the nine-month period ended September 30, 2002 primarily due to
the following:

  .   Increased cash collateral requirements resulting from the Company's below
      investment grade credit rating;

  .   Settlement of foreign exchange swaps; and

  .   Amortization of liabilities associated with previous acquisitions.

   Capital Expenditures and Investing Activities.  Cash provided by investing
activities during the nine-month period ended September 30, 2002 totaled $350
million. Capital spending and investments in unconsolidated investments totaled
$810 million and relate primarily to generation asset additions and
improvements, environmental compliance and first quarter investments in
technology infrastructure. Cash spent for the acquisition of Northern Natural
totaled $20 million, net of cash acquired. These cash outflows were offset by
$1,105 million in proceeds primarily from the sales of Northern Natural and the
Hornsea UK storage facility. Other Investing activities include proceeds from
the sale of the Northern Natural bonds.

   Financing Activities.  Cash provided by financing activities during the
nine-month period ended September 30, 2002 totaled $101 million. The Company
received $205 million in cash proceeds relative to ChevronTexaco's purchase of
approximately 10.4 million shares of Class B common stock in January 2002.
Additional capital stock proceeds include $24 million in cash from members of
senior management associated with the December 2001 private equity placement.
Dividends declared and paid to holders of Class A and Class B common stock
totaled $40 million and $15 million, respectively, for the nine-month period
ended September 30, 2002.

   In March 2002, Illinova Corporation, a wholly owned subsidiary of Dynegy and
the parent company of IP, paid $28 million in cash for shares of IP's preferred
stock through a tender offer.

   Long-term debt proceeds, net of issuance costs, for the nine-months ended
September 30, 2002 consisted of $496 million from the issuance of 8.75 percent
senior notes due February 2012, $42 million from the construction of generation
facilities and the U.S. fiber optic network and $36 million from ABG.
Repayments of long-term debt totaled $570 million for the nine-months ended
September 30, 2002 and consisted of the following:

  .   $66 million in quarterly payments of IP Transitional Funding Trust Notes;

  .   $90 million relating to the April 2002 purchase of Northern Natural's
      senior unsecured notes due 2005;

  .   $73 million in principle payments related to the Black Thunder financing;

  .   $200 million relating to the July 2002 DHI 6.785% senior note repayment;
      and

  .   $96 million relating to the July 2002 IP mortgage bond repayment; and

  .   $45 million relating to ABG.

                                      82

<PAGE>

   Net proceeds from short-term financing consisted of a $245 million net cash
advance for the anticipated sale of United Kingdom gas storage assets as well
as $192 million in financings secured by interests in two of the Company's
generating facilities. Additionally, during the nine months ended September 30,
2002, Dynegy repaid $500 million in commercial paper and borrowings under
revolving credit lines for DHI and IP in the aggregate and borrowed $60 million
under IP's term loan and drew upon $137 million under the Company's revolvers.

   Finally, other financing cash payments totaled $14 million for the
nine-months ended September 30, 2002, which primarily consisted of $13 million
in minority interest associated with Black Thunder prior to the June 2002
restructuring (see Note 7 to the accompanying financial statements for more
information).

           UNCERTAINTY OF FORWARD-LOOKING STATEMENTS AND INFORMATION

   This Quarterly Report on Form 10-Q includes statements reflecting
assumptions, expectations, projections, intentions or beliefs about future
events that are intended as "forward-looking statements" under the Private
Securities Litigation Reform Act of 1995. You can identify these statements by
the fact that they do not relate strictly to historical or current facts. They
use words such as "anticipate," "estimate," "project," "forecast," "may,"
"will," "should," "expect" and other words of similar meaning. In particular,
these include, but are not limited to, statements relating to the following:

  .   Projected operating or financial results;

  .   Expectations regarding capital expenditures and other payments;

  .   Expectations regarding transaction volume and liquidity in wholesale
      energy markets in North America and Europe;

  .   The Company's beliefs and assumptions relating to its liquidity position,
      including its ability to satisfy or refinance its obligations as they
      come due;

  .   The Company's ability to execute additional capital-raising transactions
      or refinancings to enhance its liquidity position;

  .   The Company's ability to effectively compete for market share with
      industry participants;

  .   Beliefs about the outcome of legal and administrative proceedings,
      including matters involving Enron, the California power market,
      shareholder class action lawsuits and environmental matters as well as
      the investigations primarily relating to Project Alpha and the Company's
      trading practices;

  .   The Company's ability to manage its exit from third party risk management
      aspects of the marketing and trading business and the timing of the
      expected cash flow and collateral rolloff related to this exit; and

  .   The Company's strategic plans in communications, including the Company's
      ability to eliminate or further reduce net cash outflows associated with
      this segment.

   Any or all of Dynegy's forward-looking statements may turn out to be wrong.
They can be affected by inaccurate assumptions or by known or unknown risks and
uncertainties, including the following:

  .   The timing and consummation of asset sales or refinancings;

  .   The timing and extent of changes in commodity prices for energy,
      particularly natural gas, electricity and NGLs;

  .   The extent and timing of the entry of additional competition in the
      Company's lines of business;

  .   The condition of the capital markets generally, which will be affected by
      interest rates, foreign currency fluctuations and general economic
      conditions, and Dynegy's financial condition, including its ability to
      refinance or repay its significant debt maturities and to maintain its
      credit ratings;

                                      83

<PAGE>

  .   Developments in the California power markets, including, but not limited
      to, governmental intervention, deterioration in the financial condition
      of Dynegy's counterparties, default on receivables due and adverse
      results in current or future investigations or litigation;

  .   The effectiveness of Dynegy's risk-management policies and procedures and
      the ability of Dynegy's counterparties to satisfy their financial
      commitments;

  .   The liquidity and competitiveness of wholesale trading markets for energy
      commodities, particularly natural gas, electricity and NGLs;

  .   Operational factors affecting the start up or ongoing commercial
      operations of Dynegy's power generation or midstream natural gas
      facilities, including catastrophic weather related damage, regulatory
      approval of permit issues, unscheduled outages or repairs, unanticipated
      changes in fuel costs or availability of fuel emission credits, the
      unavailability of gas transportation, the unavailability of electric
      transmission service or workforce issues;

  .   The cost of borrowing, availability of trade credit and other factor's
      affecting Dynegy's financing activities, including the effect of issues
      described in this Form 10-Q;

  .   Dynegy's ability to successfully execute the remaining elements of its
      capital plan and to generate sustainable earnings and cash flow from its
      assets and businesses;

  .   The direct or indirect effects on Dynegy's business of further downgrades
      in its credit ratings (or actions Dynegy may take in response to changing
      credit ratings criteria), including refusal by counterparties to enter
      into transactions with the Company and its inability to obtain credit or
      capital in amounts or on terms that are considered favorable;

  .   Cost and other effects of legal and administrative proceedings,
      settlements, investigations and claims, including legal proceedings
      related to the terminated merger with Enron, the California power market,
      shareholder claims and environmental liabilities that may not be covered
      by indemnity or insurance, as well as the SEC, FERC, CFTC and other
      similar investigations primarily surrounding Project Alpha and the
      Company's trading practices;

  .   Other North American regulatory or legislative developments that affect
      the regulation of the electric utility industry, the demand for energy
      generally, increase the environmental compliance cost for Dynegy's power
      generation or midstream gas facilities or impose liabilities on the
      owners of such facilities; and

  .   General political conditions and developments in the United States and in
      foreign countries whose affairs affect Dynegy's lines of business,
      including any extended period of war or conflict.

   Many of these factors will be important in determining Dynegy's actual
future results. Consequently, no forward-looking statement can be guaranteed.
Dynegy's actual future results may vary materially from those expressed or
implied in any forward-looking statements.

   All of Dynegy's forward-looking statements, whether written or oral, are
expressly qualified by these cautionary statements and any other cautionary
statements that may accompany such forward-looking statements. In addition,
Dynegy disclaims any obligation to update any forward-looking statements to
reflect events or circumstances after the date of this report.

Item 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

   The Quantitative and Qualitative Disclosures About Market Risk are set forth
in "Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations" herein.

                                      84

<PAGE>

Item 4.  CONTROLS AND PROCEDURES

   Within the 90-day period immediately preceding the filing of this report, an
evaluation was carried out under the supervision and with the participation of
Dynegy's management, including its Chief Executive Officer and its Chief
Accounting Officer (as Dynegy's responsible financial officer), of the
effectiveness of the design and operation of its disclosure controls and
procedures (as defined in Rule 13a-14(c) under the Exchange Act). Based upon
that evaluation, the Chief Executive Officer and Chief Accounting Officer
concluded that the design and operation of these disclosure controls and
procedures were effective. No significant changes were made to Dynegy's
internal controls or in other factors that could significantly affect these
controls subsequent to the date of this evaluation.

                                  DYNEGY INC.

                          PART II.  OTHER INFORMATION

Item 1.  LEGAL PROCEEDINGS

   See Note 12 to the accompanying financial statements for discussion of
material recent developments in the Company's material legal proceedings.

Item 5.  OTHER INFORMATION

   Our Chief Executive Officer and Chief Financial Officer have provided the
required certifications of this Amendment No. 1 pursuant to Sections 302 and
906 of the Sarbanes-Oxley Act of 2002. Please read Item 14. Controls and
Procedures beginning on page 87 of the 2002 Form 10-K for a discussion of our
disclosure controls and procedures and the material weaknesses identified in
our internal controls for the preparation of our consolidated financial
statements in connection with the preparation of the 2002 Form 10-K.

Item 6.  EXHIBITS AND REPORTS ON FORM 8-K

   (a)  The following instruments and documents are included as exhibits to
this Form 10-Q/A:

<TABLE>
<C>   <S>
10.1* Employment Agreement, effective as of September 16, 2002, between R. Blake Young and Dynegy
      Inc.
10.2* Employment Agreement, effective as of September 16, 2002, between Hugh A. Tarpley and Dynegy
      Inc.
10.3* Employment Agreement, effective as of October 1, 2002, between Michael R. Mott and Dynegy Inc.
10.4* Employment Agreement, effective as of October 23, 2002, between Bruce A. Williamson and Dynegy
      Inc.
99.1+ Certification pursuant to 18 United States Code Section 1350, as adopted pursuant to Section 906 of
      the Sarbanes-Oxley Act of 2002.
99.2+ Certification pursuant to 18 United States Code Section 1350, as adopted pursuant to Section 906 of
      the Sarbanes-Oxley Act of 2002.
</TABLE>
--------
*  Previously filed.
+  Pursuant to Securities and Exchange Commission Release No. 33-8212, this
   certification will be treated as "accompanying" this Amendment No. 1 and not
   "filed" as part of such report for purposes of Section 18 of the Securities
   Exchange Act of 1934, as amended, or the Exchange Act, or otherwise subject
   to the liability of Section 18 of the Exchange Act and this certification
   will not be deemed to be incorporated by reference into any filing under the
   securities Act of 1933, as amended, or the Exchange Act.

   (b)  Reports on Form 8-K of Dynegy Inc. for the third quarter 2002.

    1.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated July 15, 2002. Items 5 and 7 were reported and
no financial statements were filed.

    2.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated July 23, 2002. Items 7 and 9 were reported and
no financial statements were filed.

                                      85

<PAGE>

    3.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated July 30, 2002. Items 5 and 7 were reported and
no financial statements were filed.

    4.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated August 9, 2002. Items 5 and 7 were reported
and no financial statements were filed.

    5.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated August 14, 2002. Items 7 and 9 were reported
and no financial statements were filed.

    6.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated August 16, 2002. Items 5, 7 and 9 were
reported and no financial statements were filed.

    7.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated August 30, 2002. Items 5, 7 and 9 were
reported and no financial statements were filed.

    8.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated September 6, 2002. Items 5 and 7 were reported
and no financial statements were filed.

    9.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated September 23, 2002. Items 5 and 7 were
reported and no financial statements were filed.

   10.  During the quarter ended September 30, 2002, the Company filed a
Current Report on Form 8-K dated September 25, 2002. Items 5 and 7 were
reported and no financial statements were filed.


                                      86

<PAGE>

                                  DYNEGY INC.

                                  SIGNATURES

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

<TABLE>
<C>                                                                          <C> <S>
                                                                                          DYNEGY INC.

Date: May 14, 2003                                                           By:        /s/  NICK J. CARUSO
                                                                                 ----------------------------------
                                                                                           Nick J. Caruso
                                                                                 Executive Vice President and Chief
                                                                                         Financial Officer
</TABLE>

                                      87

<PAGE>

                           SECTION 302 CERTIFICATION

   I, Bruce A. Williamson , certify that:

   1.  I have reviewed this Amendment No. 1 to Quarterly Report on Form 10-Q/A
of Dynegy Inc. (the "Amendment No. 1");

   2.  Based on my knowledge, this Amendment No. 1 does not contain any untrue
statement of a material fact or omit to state a material fact necessary to make
the statements made, in light of the circumstances under which such statements
were made, not misleading with respect to the periods covered by this Amendment
No. 1;

   3.  Based on my knowledge, the financial statements, and other financial
information included in this Amendment No. 1, fairly present in all material
respects the financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this Amendment No. 1;

   4.  The registrant's other certifying officer and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined in
Exchange Act Rules 13a-14 and 15d-14) for the registrant and have:

      (a)  designed such disclosure controls and procedures to ensure that
   material information relating to the registrant, including its consolidated
   subsidiaries, is made known to us by others within those entities,
   particularly during the period in which this Amendment No. 1 is being
   prepared;

      (b)  evaluated the effectiveness of the registrant's disclosure controls
   and procedures as of a date within 90 days prior to the filing date of this
   Amendment No. 1 (the "Evaluation Date"); and

      (c)  presented in this Amendment No. 1 our conclusions about the
   effectiveness of the disclosure controls and procedures based on our
   evaluation as of the Evaluation Date;

   5.  The registrant's other certifying officer and I have disclosed, based on
our most recent evaluation, to the registrant's auditors and the audit
committee of the registrant's board of directors (or persons performing the
equivalent functions):

      (a)  all significant deficiencies in the design or operation of internal
   controls which could adversely affect the registrant's ability to record,
   process, summarize and report financial data and have identified for the
   registrant's auditors any material weaknesses in internal controls; and

      (b)  any fraud, whether or not material, that involves management or
   other employees who have a significant role in the registrant's internal
   controls; and

   6.  The registrant's other certifying officer and I have indicated in this
quarterly report whether there were significant changes in internal controls or
in other factors that could significantly affect internal controls subsequent
to the date of our most recent evaluation, including any corrective actions
with regard to significant deficiencies and material weaknesses.

<TABLE>
<C>                                                                          <C> <S>

Date: May 14, 2003                                                           By:      /s/  BRUCE A. WILLIAMSON
                                                                                 ----------------------------------
                                                                                        Bruce A. Williamson
                                                                                      Chief Executive Officer
</TABLE>

                                      88

<PAGE>

                           SECTION 302 CERTIFICATION

   I, Nick J. Caruso, certify that:

   1.  I have reviewed this Amendment No. 1 to Quarterly Report on Form 10-Q/A
of Dynegy Inc. (the "Amendment No. 1");

   2.  Based on my knowledge, this Amendment No. 1 does not contain any untrue
statement of a material fact or omit to state a material fact necessary to make
the statements made, in light of the circumstances under which such statements
were made, not misleading with respect to the period covered by this Amendment
No. 1;

   3.  Based on my knowledge, the financial statements, and other financial
information included in this Amendment No. 1, fairly present in all material
respects the financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this Amendment No. 1;

   4.  The registrant's other certifying officer and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined in
Exchange Act Rules 13a-14 and 15d-14) for the registrant and have:

      (a)  designed such disclosure controls and procedures to ensure that
   material information relating to the registrant, including its consolidated
   subsidiaries, is made known to us by others within those entities,
   particularly during the period in which this Amendment No. 1 is being
   prepared;

      (b)  evaluated the effectiveness of the registrant's disclosure controls
   and procedures as of a date within 90 days prior to the filing date of this
   Amendment No. 1 (the "Evaluation Date"); and

      (c)  presented in this Amendment No. 1 our conclusions about the
   effectiveness of the disclosure controls and procedures based on our
   evaluation as of the Evaluation Date;

   5.  The registrant's other certifying officer and I have disclosed, based on
our most recent evaluation, to the registrant's auditors and the audit
committee of the registrant's board of directors (or persons performing the
equivalent functions):

      (a)  all significant deficiencies in the design or operation of internal
   controls which could adversely affect the registrant's ability to record,
   process, summarize and report financial data and have identified for the
   registrant's auditors any material weaknesses in internal controls; and

      (b)  any fraud, whether or not material, that involves management or
   other employees who have a significant role in the registrant's internal
   controls; and

   6.  The registrant's other certifying officer and I have indicated in this
quarterly report whether there were significant changes in internal controls or
in other factors that could significantly affect internal controls subsequent
to the date of our most recent evaluation, including any corrective actions
with regard to significant deficiencies and material weaknesses.

<TABLE>
<C>                                                                          <C> <S>

Date: May 14, 2003                                                           By:        /s/  NICK J. CARUSO
                                                                                 ----------------------------------
                                                                                           Nick J. Caruso
                                                                                      Chief Financial Officer
</TABLE>

                                      89