<PAGE>

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

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

                                   FORM 10-Q

(MARK ONE)

    [X]        QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
                     OF THE SECURITIES EXCHANGE ACT OF 1934

               FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2003

                                       OR

    [  ]       TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
                     OF THE SECURITIES EXCHANGE ACT OF 1934

             FOR THE TRANSITION PERIOD FROM           TO

                         COMMISSION FILE NUMBER 1-7320

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

                              ANR PIPELINE COMPANY
             (Exact Name of Registrant as Specified in its Charter)

<Table>
<S>                                                <C>
                  DELAWARE                                          38-1281775
        (State or Other Jurisdiction                             (I.R.S. Employer
     of Incorporation or Organization)                         Identification No.)

              EL PASO BUILDING
           1001 LOUISIANA STREET                                      77002
               HOUSTON, TEXAS                                       (Zip Code)
  (Address of Principal Executive Offices)
</Table>

                        Telephone Number: (713) 420-2600

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

     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 [ ]

     Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act).  Yes [ ]  No [X]

     Indicate the number of shares outstanding of each of the issuer's classes
of common stock, as of the latest practicable date.

     Common Stock, par value $1 per share. Shares outstanding on November 10,
2003: 1,000

     ANR PIPELINE COMPANY MEETS THE CONDITIONS OF GENERAL INSTRUCTION H(1)(a)
AND (b) OF FORM 10-Q AND IS THEREFORE FILING THIS REPORT WITH A REDUCED
DISCLOSURE FORMAT AS PERMITTED BY SUCH INSTRUCTION.
--------------------------------------------------------------------------------
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<PAGE>

                              ANR PIPELINE COMPANY

                               TABLE OF CONTENTS

<Table>
<Caption>
                                    CAPTION                             PAGE
                                    -------                             ----
<S>       <C>                                                           <C>
                        PART I -- Financial Information
Item 1.   Financial Statements........................................    1
Item 2.   Management's Discussion and Analysis of Financial Condition
            and Results of Operations.................................   11
          Cautionary Statement Regarding Forward-Looking Statements...   14
Item 3.   Quantitative and Qualitative Disclosures About Market
            Risk......................................................   14
Item 4.   Controls and Procedures.....................................   14

                          PART II -- Other Information
Item 1.   Legal Proceedings...........................................   16
Item 2.   Changes in Securities and Use of Proceeds...................   16
Item 3.   Defaults Upon Senior Securities.............................   16
Item 4.   Submission of Matters to a Vote of Security Holders.........   16
Item 5.   Other Information...........................................   16
Item 6.   Exhibits and Reports on Form 8-K............................   16
          Signatures..................................................   17
</Table>

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

     Below is a list of terms that are common to our industry and used
throughout this document:

<Table>
<Caption>

<S>       <C>                                                           <C>
/d        = per day
BBtu      = billion British thermal units
MMcf      = million cubic feet
</Table>

     When we refer to cubic feet measurements, all measurements are at a
pressure of 14.73 pounds per square inch.

                                        i
<PAGE>

                        PART I -- FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

                              ANR PIPELINE COMPANY

                  CONDENSED CONSOLIDATED STATEMENTS OF INCOME
                                 (IN MILLIONS)
                                  (UNAUDITED)

<Table>
<Caption>
                                                                               NINE MONTHS
                                                              QUARTER ENDED       ENDED
                                                              SEPTEMBER 30,   SEPTEMBER 30,
                                                              -------------   -------------
                                                              2003    2002    2003    2002
                                                              -----   -----   -----   -----
<S>                                                           <C>     <C>     <C>     <C>
Operating revenues..........................................  $117    $120    $428    $400
                                                              ----    ----    ----    ----
Operating expenses
  Operation and maintenance.................................    69      67     217     192
  Depreciation, depletion and amortization..................     9       9      27      27
  Taxes, other than income taxes............................     6       8      19      22
                                                              ----    ----    ----    ----
                                                                84      84     263     241
                                                              ----    ----    ----    ----
Operating income............................................    33      36     165     159
Earnings from unconsolidated affiliates.....................    11      13      42      49
Other income................................................    --      --      --       5
Interest and debt expense...................................   (18)    (11)    (48)    (31)
Affiliated interest income, net.............................     1       2       1       4
                                                              ----    ----    ----    ----
Income before income taxes..................................    27      40     160     186
Income taxes................................................     9      14      59      66
                                                              ----    ----    ----    ----
Net income..................................................  $ 18    $ 26    $101    $120
                                                              ====    ====    ====    ====
</Table>

                            See accompanying notes.

                                        1
<PAGE>

                              ANR PIPELINE COMPANY

                     CONDENSED CONSOLIDATED BALANCE SHEETS
                      (IN MILLIONS, EXCEPT SHARE AMOUNTS)
                                  (UNAUDITED)

<Table>
<Caption>
                                                              SEPTEMBER 30,   DECEMBER 31,
                                                                  2003            2002
                                                              -------------   ------------
<S>                                                           <C>             <C>
                                          ASSETS
Current assets
  Cash and cash equivalents.................................     $   25          $   --
  Accounts and notes receivable
     Customer, net of allowance of $3 in 2003 and $2 in
      2002..................................................         81              39
     Affiliates.............................................          6              14
     Other..................................................          3               5
  Materials and supplies....................................         22              23
  Other.....................................................         11               8
                                                                 ------          ------
          Total current assets..............................        148              89
                                                                 ------          ------
Property, plant and equipment, at cost......................      3,590           3,599
  Less accumulated depreciation, depletion and
     amortization...........................................      2,194           2,192
                                                                 ------          ------
          Total property, plant and equipment, net..........      1,396           1,407
                                                                 ------          ------
Other assets
  Investments in unconsolidated affiliates..................        325             312
  Notes receivable from affiliates..........................        401             560
  Other.....................................................         33              11
                                                                 ------          ------
                                                                    759             883
                                                                 ------          ------
          Total assets......................................     $2,303          $2,379
                                                                 ======          ======

                           LIABILITIES AND STOCKHOLDER'S EQUITY
Current liabilities
  Accounts payable
     Trade..................................................     $   22          $   28
     Affiliates.............................................         57              10
     Other..................................................         24              38
  Accrued interest..........................................         17               9
  Taxes payable.............................................         51              56
  Other payable to affiliate................................          8               8
  Other.....................................................         28              21
                                                                 ------          ------
          Total current liabilities.........................        207             170
                                                                 ------          ------
Long-term debt..............................................        807             511
                                                                 ------          ------
Other liabilities
  Deferred income taxes.....................................        300             267
  Payable to affiliates.....................................        192             196
  Other.....................................................         42              52
                                                                 ------          ------
                                                                    534             515
                                                                 ------          ------
Commitments and contingencies
Stockholder's equity
  Common stock, par value $1 per share; 1,000 shares
     authorized, issued and outstanding.....................         --              --
  Additional paid-in capital................................        598             599
  Retained earnings.........................................        157             584
                                                                 ------          ------
          Total stockholder's equity........................        755           1,183
                                                                 ------          ------
          Total liabilities and stockholder's equity........     $2,303          $2,379
                                                                 ======          ======
</Table>

                            See accompanying notes.

                                        2
<PAGE>

                              ANR PIPELINE COMPANY

                CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
                                 (IN MILLIONS)
                                  (UNAUDITED)

<Table>
<Caption>
                                                               NINE MONTHS
                                                                  ENDED
                                                              SEPTEMBER 30,
                                                              --------------
                                                               2003    2002
                                                              ------   -----
<S>                                                           <C>      <C>
Cash flows from operating activities
  Net income................................................  $ 101    $120
  Adjustments to reconcile net income to net cash from
     operating activities
     Depreciation, depletion and amortization...............     27      27
     Deferred income tax expense............................     32      19
     Undistributed earnings of unconsolidated affiliates....    (13)    (19)
     Other non-cash income items............................      2      --
     Working capital changes................................     35      90
     Non-working capital changes............................    (24)     (6)
                                                              -----    ----
       Net cash provided by operating activities............    160     231
                                                              -----    ----
Cash flows from investing activities
  Additions to property, plant and equipment................    (61)    (73)
  Proceeds from the sale of assets..........................      7       2
  Net change in affiliated advances receivable..............   (369)   (160)
                                                              -----    ----
       Net cash used in investing activities................   (423)   (231)
                                                              -----    ----
Cash flows from financing activities
  Net proceeds from the issuance of long-term debt..........    288      --
                                                              -----    ----
       Net cash provided by financing activities............    288      --
                                                              -----    ----
Increase in cash and cash equivalents.......................     25      --
Cash and cash equivalents
  Beginning of period.......................................     --      --
                                                              -----    ----
  End of period.............................................  $  25    $ --
                                                              =====    ====
Supplemental cash flow disclosures:
  Non-cash dividend to parent of affiliated receivables.....  $ 528    $ --
                                                              =====    ====
</Table>

                            See accompanying notes.

                                        3
<PAGE>

                              ANR PIPELINE COMPANY

              NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
                                  (UNAUDITED)

1. BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

     We are an indirect wholly owned subsidiary of El Paso Corporation (El
Paso). We prepared this Quarterly Report on Form 10-Q under the rules and
regulations of the United States Securities and Exchange Commission. These
financial statements are unaudited and, because this is an interim period filing
presented using a condensed format, do not include all of the disclosures
required by generally accepted accounting principles. You should read it along
with our Current Report on Form 8-K/A dated May 20, 2003, and our Current Report
on Form 8-K filed June 4, 2003 (our Combined Historical Financial Statements),
which include a summary of our significant accounting policies and our audited
combined financial statements and related footnotes as of December 31, 2002 and
2001 and for the three years ended December 31, 2002. As discussed below, our
historical financial information as of December 31, 2002, and for the quarter
and nine months ended September 30, 2002, has been restated to reflect the
contribution of El Paso Great Lakes, Inc. to us by El Paso. We derived the
balance sheet as of December 31, 2002, from our Combined Historical Financial
Statements. In our opinion, we have made all adjustments which are of a normal,
recurring nature to fairly present our interim period results. Due to the
seasonal nature of our business, information for interim periods may not be
indicative of our results of operations for the entire year. In addition, prior
period information presented in these financial statements includes
reclassifications which were made to conform to the current period presentation.
These reclassifications had no effect on our previously reported net income or
stockholder's equity.

  Acquisition of El Paso Great Lakes

     In March 2003, American Natural Resources Company, an affiliate and
subsidiary of El Paso, contributed to us all of the common stock of its wholly
owned subsidiary, El Paso Great Lakes, Inc. El Paso Great Lakes had a net book
value at the time of its contribution of approximately $247 million. El Paso
Great Lakes' principal asset consists of its effective 50 percent interest in
Great Lakes Gas Transmission Limited Partnership, a Delaware limited
partnership, which is accounted for under the equity method. It held this
interest through a direct investment in the Great Lakes Gas Transmission Limited
Partnership and indirectly through its 50 percent ownership of Great Lakes Gas
Transmission Company. Since both El Paso Great Lakes and our common stock were
owned by El Paso at the time of the contribution, we were required to reflect
the contribution at its historical cost and its operating results in our
financial statements for all periods prior to its contribution. As a result, our
financial statements reflect the contribution of El Paso Great Lakes as though
it occurred on January 1, 2002 (the beginning of the earliest period presented
in these financial statements). Our historical and combined net income for the
quarter and nine months ended September 30, 2002 is presented below.

<Table>
<Caption>
                                                          QUARTER             NINE MONTHS
                                                           ENDED                 ENDED
                                                     SEPTEMBER 30, 2002    SEPTEMBER 30, 2002
                                                     ------------------    ------------------
                                                                  (IN MILLIONS)
<S>                                                  <C>                   <C>
Net income
  Historical.......................................         $17                   $ 87
  El Paso Great Lakes, Inc. .......................           9                     33
                                                            ---                   ----
     Combined net income...........................         $26                   $120
                                                            ===                   ====
</Table>

                                        4
<PAGE>

  Significant Accounting Policies

     Our accounting policies are consistent with those discussed in our Combined
Historical Financial Statements, except as discussed below:

     Accounting for Costs Associated with Exit or Disposal Activities.  As of
January 1, 2003, we adopted Statement of Financial Accounting Standards (SFAS)
No. 146, Accounting for Costs Associated with Exit or Disposal Activities. SFAS
No. 146 requires that we recognize costs associated with exit or disposal
activities when they are incurred rather than when we commit to an exit or
disposal plan. There was no initial financial statement impact of adopting this
standard.

     Accounting for Guarantees.  On January 1, 2003, we adopted Financial
Accounting Standards Board Interpretation (FIN) No. 45, Guarantor's Accounting
and Disclosure Requirements for Guarantees, Including Indirect Guarantees of
Indebtedness of Others. FIN No. 45 requires that we record a liability for all
guarantees, including financial performance and fair value guarantees, issued
after December 31, 2002, at fair value when they are issued. There was no
initial financial statement impact of adopting this standard.

     Accounting for Regulated Operations.  Our natural gas systems and storage
operations are subject to the jurisdiction of the Federal Energy Regulatory
Commission (FERC) in accordance with the Natural Gas Act of 1938 and Natural Gas
Policy Act of 1978. In 1996, we discontinued the application of SFAS No. 71,
Accounting for the Effects of Certain Types of Regulation. The accounting
required by SFAS No. 71 differs from the accounting required for businesses that
do not apply its provisions. Transactions that are generally recorded
differently as a result of applying regulatory accounting requirements include
the capitalization of an equity return component on regulated capital projects,
post retirement employee benefit plans, and other costs included in, or expected
to be included in, future rates.

     As a result of recent changes in our competitive environment and operating
cost structure, we continue to assess the applicability of the provisions of
SFAS No. 71 to our financial statements. The outcome of this evaluation could
result in the restoration of our application of this accounting. We expect to
complete our current evaluation of the applicability of SFAS No. 71 by the end
of this year.

2. DEBT AND OTHER CREDIT FACILITIES

  Debt

     In March 2003, we issued $300 million of senior unsecured notes with an
annual interest rate of 8.875%. The notes mature in 2010. Net proceeds of $288
million were used to pay off intercompany payables of $263 million. The
remaining net proceeds of $25 million were retained for future capital
expenditure requirements.

  Credit Facilities

     In April 2003, El Paso entered into a new $3 billion revolving credit
facility, with a $1.5 billion letter of credit sublimit, which matures on June
30, 2005. The $3 billion revolving credit facility has a borrowing cost of LIBOR
plus 350 basis points, letter of credit fees of 350 basis points and a
commitment fee of 75 basis points on the unused portion of the facility. This
facility replaces El Paso's previous $3 billion revolving credit facility.
Approximately $1 billion of other El Paso financing arrangements (including
leases, letters of credit and other facilities) were also amended to conform El
Paso's obligations to the new $3 billion revolving credit facility. We, along
with El Paso and our affiliates, Tennessee Gas Pipeline Company and El Paso
Natural Gas Company (EPNG), are borrowers under the $3 billion revolving credit
facility, and El Paso's equity in several of its subsidiaries, including its
equity in us, collateralizes the $3 billion revolving credit facility and the
other financing arrangements. We are only liable for amounts we directly borrow
under the $3 billion revolving credit facility. As of September 30, 2003, $1.3
billion was outstanding and $1 billion in letters of credit were issued under
the $3 billion revolving credit facility, none of which were borrowed by or
issued on behalf of us.

     Under the $3 billion revolving credit facility and other indentures, we are
subject to a number of restrictions and covenants. The most restrictive of these
include (i) limitations on the incurrence of additional debt, based on a ratio
of debt to EBITDA (as defined in the agreements); (ii) limitations on the use of
                                        5
<PAGE>

proceeds from borrowings; (iii) limitations, in some cases, on transactions with
our affiliates; (iv) limitations on the incurrence of liens; (v) potential
limitations on our ability to declare and pay dividends; and (vi) potential
limitations on our ability to participate in the El Paso cash management program
discussed in Note 4. For the nine months ended September 30, 2003, we were in
compliance with these covenants.

3. COMMITMENTS AND CONTINGENCIES

  Legal Proceedings

     Grynberg.  In 1997, we and a number of our affiliates were named defendants
in actions brought by Jack Grynberg on behalf of the U.S. Government under the
False Claims Act. Generally, these complaints allege an industry-wide conspiracy
to underreport the heating value as well as the volumes of the natural gas
produced from federal and Native American lands, which deprived the U.S.
Government of royalties. The plaintiff in this case seeks royalties that he
contends the government should have received had the volume and heating value of
natural gas produced from royalty properties been differently measured,
analyzed, calculated and reported, together with interest, treble damages, civil
penalties, expenses and future injunctive relief to require the defendants to
adopt allegedly appropriate gas measurement practices. No monetary relief has
been specified in this case. These matters have been consolidated for pretrial
purposes (In re: Natural Gas Royalties Qui Tam Litigation, U.S. District Court
for the District of Wyoming, filed June 1997). In May 2001, the court denied the
defendants' motions to dismiss. Discovery is proceeding. Our costs and legal
exposure related to these lawsuits and claims are not currently determinable.

     Will Price (formerly Quinque).  We and a number of our affiliates were
named defendants in Quinque Operating Company, et al. v. Gas Pipelines and Their
Predecessors, et al., filed in 1999 in the District Court of Stevens County,
Kansas. Quinque has been dropped as a plaintiff and Will Price has been added.
This class action complaint alleges that the defendants mismeasured natural gas
volumes and heating content of natural gas on non-federal and non-Native
American lands. The plaintiff in this case seeks certification of a nationwide
class of natural gas working interest owners and natural gas royalty owners to
recover royalties that the plaintiff contends these owners should have received
had the volume and heating value of natural gas produced from their properties
been differently measured, analyzed, calculated and reported, together with
prejudgment and postjudgment interest, punitive damages, treble damages,
attorneys' fees, costs and expenses, and future injunctive relief to require the
defendants to adopt allegedly appropriate gas measurement practices. No monetary
relief has been specified in this case. Plaintiffs' motion for class
certification was denied on April 10, 2003. Plaintiffs' motion to file another
amended petition to narrow the proposed class to royalty owners in wells in
Kansas, Wyoming and Colorado was granted on July 28, 2003. Our costs and legal
exposure related to these lawsuits and claims are not currently determinable.

     In addition to the above matters, we are also a named defendant in numerous
lawsuits and governmental proceedings that arise in the ordinary course of our
business.

     For each of our outstanding legal matters, we evaluate the merits of the
case, our exposure to the matter, possible legal or settlement strategies and
the likelihood of an unfavorable outcome. If we determine that an unfavorable
outcome is probable and can be estimated, we establish the necessary accruals.
As of September 30, 2003, we had no material accruals for our outstanding legal
matters.

  Environmental Matters

     We are subject to federal, state and local laws and regulations governing
environmental quality and pollution control. These laws and regulations require
us to remove or remedy the effect on the environment of the disposal or release
of specified substances at current and former operating sites. As of September
30, 2003, we had accrued approximately $26 million for expected remediation
costs and associated onsite, offsite and groundwater technical studies and for
related environmental legal costs, which we anticipate incurring through

                                        6
<PAGE>

2027. Our accrual at September 30, 2003 was based on the most likely outcome
that can be reasonably estimated. Below is a reconciliation of our accrued
liability as of September 30, 2003 (in millions):

<Table>
<S>                                                           <C>
Balance as of January 1, 2003...............................       $26
Additions/adjustments for remediation activities............         3
Payments for remediation activities.........................        (4)
Other changes, net..........................................         1
                                                                   ---
Balance as of September 30, 2003............................       $26
                                                                   ===
</Table>

     In addition, we expect to make capital expenditures for environmental
matters of approximately $28 million in the aggregate for the years 2003 through
2008. These expenditures primarily relate to compliance with clean air
regulations. For the remainder of 2003, we estimate that our total remediation
expenditures will be approximately $2 million. All of this amount is being
expended under government directed clean-up plans.

     CERCLA Matters.  We have received notice that we could be designated, or
have been asked for information to determine whether we could be designated, as
a Potentially Responsible Party (PRP) with respect to three active sites under
the Comprehensive Environmental Response, Compensation and Liability Act
(CERCLA) or state equivalents. We have sought to resolve our liability as a PRP
at these sites through indemnification by third parties and settlements which
provide for payment of our allocable share of remediation costs. As of September
30, 2003, we have estimated our share of the remediation costs at these sites to
be approximately $1 million. Since the clean-up costs are estimates and are
subject to revision as more information becomes available about the extent of
remediation required, and because in some cases we have asserted a defense to
any liability, our estimates could change. Moreover, liability under the federal
CERCLA statute is joint and several, meaning that we could be required to pay in
excess of our pro rata share of remediation costs. Our understanding of the
financial strength of other PRPs has been considered, where appropriate, in
estimating our liabilities. Reserves for these matters are included in the
environmental reserve discussed above.

     It is possible that new information or future developments could require us
to reassess our potential exposure related to environmental matters. We may
incur significant costs and liabilities in order to comply with existing
environmental laws and regulations. It is also possible that other developments,
such as increasingly strict environmental laws and regulations and claims for
damages to property, employees, other persons and the environment resulting from
our current or past operations, could result in substantial costs and
liabilities in the future. As this information becomes available, or other
relevant developments occur, we will adjust our accrual amounts accordingly.
While there are still uncertainties relating to the ultimate costs we may incur,
based upon our evaluation and experience to date, we believe our reserves are
adequate.

  Rates and Regulatory Matters

     Order No. 637.  In February 2000, the FERC issued Order No. 637. Order No.
637 impacts the way pipelines conduct their operational activities, including
how they release capacity, segment capacity, manage imbalance services, issue
operational flow orders, and impose pipeline penalties. We filed our compliance
proposal in June 2000, and subsequently filed an Offer of Settlement in July
2001. On December 2, 2002, we sought rehearing of an October 31, 2002 FERC order
responding to the United States Court of Appeals for the District of Columbia
Circuit's order remanding various aspects of order No. 637. In December 2001,
the FERC approved the Settlement subject to certain modifications and
conditions. Due to the modifications and conditions, and after meeting with
parties to our Order No. 637 proceeding, we submitted a modified Settlement for
approval by the FERC.

     On April 9, 2003, the FERC issued an order accepting the modified
Settlement, but required further changes and in particular rejected our proposed
limitations on the ability of certain Replacement Shippers to use segmenting to
reserve point capacity and, therefore, firm capacity on a primary firm basis. On
April 24, 2003, we advised the FERC that, due to the required changes, we were
unwilling to accept the

                                        7
<PAGE>

settlement as modified by its April 9 order. On May 8, 2003, we met with parties
to the proceedings to determine whether the settlement could be preserved
through further negotiations. On May 9, 2003, we filed for rehearing of the
April 9 order. As a result of our May 8 meeting with the parties, on May 28,
2003, we filed a further modified settlement with the FERC. On September 23,
2003, the FERC substantially granted the rehearing request and directed other
minor changes in the tariff language. We filed language to comply with this
directive on October 8, 2003. Meanwhile, we implemented Order No. 637 provisions
on October 1, 2003.

     Marketing Affiliate NOPR.  In September 2001, the FERC issued a Notice of
Proposed Rulemaking (NOPR) proposing to apply the standards of conduct governing
the relationship between interstate pipelines and marketing affiliates to all
energy affiliates. The proposed regulations, if adopted by the FERC, would
dictate how we conduct business and interact with our energy affiliates. We have
filed comments with the FERC addressing our concerns with the proposed rules,
participated in a public conference, and filed additional comments. At this
time, we cannot predict the outcome of the NOPR, but adoption of the regulations
in their proposed form would, at a minimum, place additional administrative and
operational burdens on us.

     Negotiated Rate Policy.  In July 2002, the FERC issued a Notice of Inquiry
(NOI) that sought comments regarding its 1996 policy of permitting pipelines to
enter into negotiated rate transactions. We have entered into those transactions
over the years, and the FERC is now reviewing whether negotiated rates should be
capped, whether or not the "recourse rate" (a cost-of-service based rate)
continues to safeguard against a pipeline exercising market power and other
issues related to negotiated rate programs. El Paso's pipelines and others filed
comments on the NOI.

     In July 2003, the FERC issued an order that prospectively prohibits
pipelines from negotiating rates based upon natural gas commodity price indices
and imposes certain new filing requirements to ensure the transparency of
negotiated rate transactions. Requests for rehearing were filed on August 25,
2003 and remain pending. We do not expect that the order on rehearing will have
a material effect on us.

     Cash Management Rule.  On October 23, 2003, the FERC approved a rule that
requires a FERC regulated entity to file its cash management agreement with the
FERC, maintain records of transactions involving its participation in the cash
management program, compute its proprietary capital ratio quarterly based on
criteria established by the FERC, and notify the FERC 45 days after the end of a
calendar quarter whether its proprietary capital ratio falls below 30 percent
and subsequently when its proprietary capital ratio returns to or exceeds 30
percent. In the rule, the FERC stated that the requirements imposed by the rule
are not in the nature of a regulation governing participation in cash management
programs and that the rule does not dictate the content or terms for
participating in a cash management program. Although the rule is subject to
rehearing, we do not believe an order on rehearing will have a material effect
on us.

     On September 10, 2003, the Office of Executive Director of Regulatory
Audits completed an industry-wide audit of the FERC Form 2 related to cash
management. The audit included our affiliates, EPNG and Mojave. The audit did
not identify any instances of non-compliance with the FERC's reporting and
recording requirements but recommended that EPNG and Mojave revise and update
their existing cash management agreements with El Paso. We are in the process of
reviewing and revising our cash management agreement pursuant to this
recommendation.

     Emergency Reconstruction of Interstate Natural Gas Facilities Rule.  On May
19, 2003, the FERC issued a rule that amends its regulations to enable natural
gas interstate pipeline companies, in emergency situations resulting in sudden,
unanticipated loss of natural gas or capacity, to replace facilities when
immediate action is required to restore service for the protection of life or
health or for the maintenance of physical property. Specifically, the rule
permits a pipeline to replace mainline facilities using a route other than an
existing right-of-way, to commence construction without being subject to a
45-day waiting period, and to undertake projects that exceed the existing
blanket cost constraints. It also requires that landowners be notified of
potential construction, but provides for a possible waiver of the 30-day waiting
period.

     Pipeline Safety Notice of Proposed Rulemaking.  In January 2003, the U.S.
Department of Transportation issued a NOPR proposing to establish a rule
requiring pipeline operators to develop integrity

                                        8
<PAGE>

management programs to comprehensively evaluate their pipelines, and take
measures to protect pipeline segments located in what the notice refers to as
"high consequence areas." The proposed rule resulted from the enactment of the
Pipeline Safety Improvement Act of 2002, a new bill signed into law in December
2002. Comments on the NOPR were filed on April 30, 2003. Although we cannot
predict the outcome of this rulemaking, we do not expect this order to have a
material effect on us.

     FERC Inquiry.  In February 2003, El Paso received a letter from the Office
of the Chief Accountant at the FERC requesting details of its announcement of
2003 asset sales and plans for Southern Natural Gas (an El Paso subsidiary) and
us to issue a combined $700 million of long-term notes. The letter requested
that El Paso explain how it intended to use the proceeds from the issuance of
the notes and if the notes were to be included in the two regulated companies'
capital structure for rate-setting purposes. Our response to the FERC was filed
on March 12, 2003. On April 2, 2003, we received an additional request for
information, to which we fully responded on April 15, 2003.

     ANR Cashout Proceeding.  On May 1, 2002, ANR made its annual filing to
reconcile the costs and revenues associated with operating its cashout program,
a program which involves the sale and purchase of natural gas to satisfy shipper
imbalances. On October 31, 2002, the FERC accepted the filing, and allowed ANR's
proposed cashout surcharge to go into effect. However, the FERC found that the
existing cashout mechanism, which it had previously approved, was no longer
"just and reasonable" under the NGA. That is because FERC found that the
existing mechanism produced wide variances in the surcharge amount from period
to period and that certain shippers did not have an adequate opportunity to
resolve their imbalances prior to being subjected to the surcharge. The FERC set
the case for hearing to establish a replacement mechanism. A group of shippers
who are interveners in the case have recently filed testimony proposing a
mechanism which would require ANR to credit to an imbalance account: (1) past
and possible future revenues associated with over-recovered fuel and lost and
unaccounted for gas; (2) past and possible future revenues associated with ANR's
Firm Storage Service Overrun Service; and (3) the estimated value of balancing
assets utilized by ANR to provide other transportation services. ANR opposes
this proposal on the grounds, among others, that it would require retroactive
refunds, which is contrary to Section 5 of the Natural Gas Act. A hearing is
scheduled for January 15, 2004. The outcome of this case is not presently
determinable but we do not believe that it will have an adverse material impact
on us.

     While the outcome of our outstanding legal matters, environmental matters
and rates and regulatory matters cannot be predicted with certainty, based on
current information and our existing accruals, we do not expect the ultimate
resolution of these matters to have a material adverse effect on our financial
position, operating results or cash flows. However, it is possible that new
information or future developments could require us to reassess our potential
exposure related to these matters. It is possible that the outcome of these
matters could impact our credit rating and that of our parent. Further, for
environmental matters, it is possible that other developments, such as
increasingly strict environmental laws and regulations and claims for damages to
property, employees, other persons and the environment resulting from our
current or past operations, could result in substantial costs and liabilities in
the future. As new information for our outstanding legal matters, environmental
matters and rates and regulatory matters becomes available, or relevant
developments occur, we will review our accruals and make any appropriate
adjustments. The impact of these changes may have a material effect on our
results of operations, our financial position, and on our cash flows in the
period the event occurs.

4. INVESTMENTS IN UNCONSOLIDATED AFFILIATES AND RELATED PARTY TRANSACTIONS

  Great Lakes

     In March 2003, American Natural Resources contributed the common stock of
its wholly owned subsidiary, El Paso Great Lakes, to us. El Paso Great Lakes'
principal asset consists of its effective 50 percent ownership interest in Great
Lakes Gas Transmission Limited Partnership. Great Lakes Gas Transmission owns
and operates a 2,115 mile interstate natural gas pipeline that transports gas to
customers in the midwestern and northeastern United States and Canada.

                                        9
<PAGE>

     Summarized financial information of our proportionate share of our
investment in Great Lakes Gas Transmission for the quarters and nine months
ended September 30, 2003 and 2002 are as follows:

<Table>
<Caption>
                                                                QUARTER       NINE MONTHS
                                                                 ENDED           ENDED
                                                             SEPTEMBER 30,   SEPTEMBER 30,
                                                             -------------   --------------
                                                             2003    2002    2003     2002
                                                             -----   -----   -----    -----
                                                                     (IN MILLIONS)
<S>                                                          <C>     <C>     <C>      <C>
Operating results data:
  Operating revenues.......................................   $31     $31     $96      $94
  Operating expenses.......................................    15      14      43       35
  Net income(1)............................................     7       9      27       33
</Table>

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

(1)Our proportionate share of net income includes our share of taxes payable by
   partners recorded by Great Lakes Gas Transmission.

  Transactions with Affiliates

     We participate in El Paso's cash management program which matches
short-term cash surpluses and needs of participating affiliates, thus minimizing
total borrowings from outside sources. In February 2003, we made non-cash
distributions of $528 million in outstanding affiliated receivables to our
parent, which were treated as a reduction of our stockholder's equity. As of
September 30, 2003 and December 31, 2002, we had advanced to El Paso $401
million and $560 million. The market rate of interest at September 30, 2003 and
December 31, 2002 was 3.5% and 1.5%. These receivables are due upon demand;
however, as of September 30, 2003 and December 31, 2002, we have classified
these amounts as non-current notes receivable from affiliates because we do not
anticipate settlement within the next twelve months.

     At September 30, 2003 and December 31, 2002, we had accounts receivable
from related parties of $6 million and $14 million. In addition, we had accounts
payable to related parties of $57 million and $10 million at September 30, 2003,
and December 31, 2002. These balances arose in the normal course of business.

     At September 30, 2003 and December 31, 2002, we had payables to an
affiliate of $200 million and $204 million for obligations related to a
non-cancelable lease on our former headquarters. Of this amount, $8 million was
classified as current at September 30, 2003 and December 31, 2002. This payable
resulted from the relocation of our headquarters from Detroit, Michigan to
Houston, Texas and the transfer of this lease to our affiliate from a third
party. The lease payments are due semi-annually.

     In the second quarter of 2003, we sold a non-pipeline asset and received
net proceeds of $6 million of which $3 million was from our parent, and no gain
or loss was recognized on this sale.

     The following table shows revenues and charges from our affiliates for the
quarters and nine months ended September 30, 2003 and 2002:

<Table>
<Caption>
                                                              QUARTER        NINE MONTHS
                                                               ENDED            ENDED
                                                           SEPTEMBER 30,    SEPTEMBER 30,
                                                           --------------   --------------
                                                           2003     2002    2003     2002
                                                           -----    -----   -----    -----
                                                                    (IN MILLIONS)
<S>                                                        <C>      <C>     <C>      <C>
Revenues from affiliates.................................   $ 3      $ 7     $14      $21
Operations and maintenance from affiliates...............    32       34      97       92
Reimbursements for operating expenses from affiliates....    --       --       1        1
</Table>

                                        10
<PAGE>

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

     The information contained in Item 2 updates, and should be read in
conjunction with, the information disclosed in our Combined Historical Financial
Statements and the financial statements and notes presented in Item 1 of this
Form 10-Q.

                             RESULTS OF OPERATIONS

     We use earnings before interest and income taxes (EBIT) to assess the
operating results and effectiveness of our business. We define EBIT as net
income adjusted for (i) items that do not impact our income from continuing
operations, such as the impact of accounting changes, (ii) income taxes, (iii)
interest and debt expense and (iv) affiliated interest income. Our business
consists of consolidated operations as well as investments in unconsolidated
affiliates. We believe EBIT, which includes the results of our consolidated and
unconsolidated operations, is useful to our investors because it allows them to
more effectively evaluate the operating performance of both our consolidated
business and our unconsolidated investments. In addition, this is the
measurement used by El Paso to evaluate the operating performance of its
business segments. We exclude interest and debt expense from this measure so
that investors may evaluate our operating results without regard to our
financing methods. EBIT may not be comparable to measurements used by other
companies and should not be used as a substitute for net income or other
performance measures such as operating income or operating cash flow. As
discussed in Item 1, Notes 1 and 4, in March 2003, El Paso Great Lakes was
contributed to us by our parent. Our historical financial statements have been
restated to reflect this transaction for the earliest period presented in this
filing. The following is a reconciliation of our operating results to our EBIT
and our EBIT to our net income for the periods ended September 30:

<Table>
<Caption>
                                                                                    NINE MONTHS
                                                               QUARTER ENDED           ENDED
                                                               SEPTEMBER 30,       SEPTEMBER 30,
                                                             -----------------   -----------------
                                                              2003      2002      2003      2002
                                                             -------   -------   -------   -------
                                                             (IN MILLIONS, EXCEPT VOLUME AMOUNTS)
<S>                                                          <C>       <C>       <C>       <C>
Operating revenues.........................................  $  117    $  120    $  428    $  400
Operating expenses.........................................     (84)      (84)     (263)     (241)
                                                             ------    ------    ------    ------
     Operating income......................................      33        36       165       159
                                                             ------    ------    ------    ------
Earnings from unconsolidated affiliates....................      11        13        42        49
Other income...............................................      --        --        --         5
                                                             ------    ------    ------    ------
     Other.................................................      11        13        42        54
                                                             ------    ------    ------    ------
       EBIT................................................      44        49       207       213
Interest and debt expense..................................     (18)      (11)      (48)      (31)
Affiliated interest income, net............................       1         2         1         4
Income taxes...............................................      (9)      (14)      (59)      (66)
                                                             ------    ------    ------    ------
     Net income............................................  $   18    $   26    $  101    $  120
                                                             ======    ======    ======    ======
Throughput volumes (BBtu/d)(1).............................   4,695     4,858     5,495     5,325
                                                             ======    ======    ======    ======
</Table>

----------

(1) Throughput includes volumes associated with our 50 percent equity investment
    in Great Lakes. Prior period volumes have been restated to reflect our
    current year presentation which includes billable transportation throughput
    volume for storage withdrawal.

  Third Quarter 2003 Compared to Third Quarter 2002

     Operating revenues for the quarter ended September 30, 2003, were $3
million lower than the same period in 2002. The decrease was primarily due to a
$3 million reduction of Dakota gasification facility purchased gas resales
following a FERC approved buyout of this contract effective August 1, 2003 and
lower transportation and storage revenues of $2 million due to contract changes
relating to our customer, We Energies. The decrease was partially offset by $2
million of sales of operational natural gas recoveries in 2003 that did not
occur in 2002.

     Operating expenses for the quarter ended September 30, 2003, were
consistent with the same period in 2002. There was a net increase of $3 million
related to the Dakota contract buyout offset by a $2 million

                                        11
<PAGE>

unfavorable property tax adjustment recorded in the third quarter of 2002 and
lower shared services costs of $1 million allocated to us in 2003.

     Other income for the quarter ended September 30, 2003, was $2 million lower
than the same period in 2002. The decrease was due to lower equity earnings from
our investment in Great Lakes primarily related to reorganization charges
incurred and recorded in 2003 by Great Lakes.

  Nine Months Ended 2003 Compared to Nine Months Ended 2002

     Operating revenues for the nine months ended September 30, 2003, were $28
million higher than the same period in 2002. The increase was primarily due to
sales of operational natural gas recoveries in 2003 of $19 million that did not
occur in 2002 and $17 million from higher realized prices in 2003 on the resale
of natural gas purchased from the Dakota gasification facility, partially offset
by lower gas resales of $5 million following the buyout of the Dakota gas
purchase contract. Also contributing to the increase were higher transportation
revenues of $4 million primarily due to colder winter weather in 2003. These
increases were partially offset by lower transportation and storage revenues of
$6 million due to contract changes relating to our customer We Energies and $3
million of lower storage revenues due to lower contracted volumes in 2003.

     Operating expenses for the nine months ended September 30, 2003, were $22
million higher than the same period in 2002. The increase was primarily due to
higher prices on natural gas purchased at the Dakota gasification facility of
$16 million along with the impact of the FERC approved contract buyout of $6
million, partially offset by lower gas purchases of $5 million following the
termination of the Dakota contract. Also contributing to the increase was $6
million from lower benefit costs in 2002, a favorable corporate overhead
allocation adjustment received in the second quarter of 2002 of $5 million, and
the reversal of a $3 million liability in the second quarter 2002 related to
facilities in Detroit that were no longer being used. These increases were
partially offset by additional accruals in the second quarter of 2002 of $10
million on estimated liabilities to assess and remediate our environmental
exposure due to an ongoing evaluation of the exposure at our facilities.

     Other income for the nine months ended September 30, 2003, was $12 million
lower than the same period in 2002. The decrease was a result of lower equity
earnings from our investment in Great Lakes of $7 million primarily due to a
favorable use tax settlement recorded by Great Lakes in the first quarter of
2002 and the favorable resolution of uncertainties associated with the sale of
our interest in the Iroquois pipeline system of $4 million in the second quarter
of 2002.

INTEREST AND DEBT EXPENSE

     Interest and debt expense for the quarter and nine months ended September
30, 2003, was $7 million and $17 million higher than the same periods in 2002
due to the issuance of $300 million senior unsecured notes with an annual
interest rate of 8.875% in March 2003.

AFFILIATED INTEREST INCOME, NET

  Third Quarter 2003 Compared to Third Quarter 2002

     Affiliated interest income, net for the quarter ended September 30, 2003,
was $1 million lower than the same period in 2002 due primarily to lower average
advances to El Paso under its cash management program in 2003, offset by higher
short-term interest rates in 2003. The average advance balance due from El Paso
of $274 million for the third quarter of 2002 decreased to $244 million during
the same period in 2003. The average short-term interest rates for the third
quarter increased from 1.8% in 2002 to 1.9% during the same period in 2003.

  Nine Months Ended 2003 Compared to Nine Months Ended 2002

     Affiliated interest income, net for the nine months ended September 30,
2003, was $3 million lower than the same period in 2002 due primarily to lower
average advances to El Paso under its cash management

                                        12
<PAGE>

program and lower short-term interest rates in 2003. The average advance balance
due from El Paso of $302 million for the first nine months of 2002 decreased to
$139 million during the same period in 2003. The average short-term interest
rates decreased from 1.9% in 2002 to 1.6% during the same period in 2003.

INCOME TAXES

<Table>
<Caption>
                                                                 QUARTER          NINE MONTHS
                                                                  ENDED              ENDED
                                                              SEPTEMBER 30,      SEPTEMBER 30,
                                                             ----------------   ---------------
                                                              2003      2002     2003     2002
                                                             ------    ------   ------   ------
                                                              (IN MILLIONS, EXCEPT FOR RATES)
<S>                                                          <C>       <C>      <C>      <C>
Income taxes...............................................   $ 9       $14      $59      $66
Effective tax rate.........................................    33%       35%      37%      35%
</Table>

     Our effective tax rates were different than the statutory rate of 35
percent primarily due to state income taxes and earnings from unconsolidated
affiliates where we anticipate receiving dividends.

OTHER

     WestLeg.  In June 2003, the FERC granted certificate authorization for our
proposed WestLeg project expansion. The WestLeg project will expand the capacity
of our system by approximately 218 MMcf/d by looping our Madison Lateral line,
located in Wisconsin's Walworth and Rock Counties and in Illinois' McHenry
County, and modifying our existing Beloit Lateral line in Rock County,
Wisconsin. The estimated cost of the project is approximately $45 million and
the anticipated in-service date of the project is November 2004. Total year to
date expenditures on the project have been approximately $2 million.

                         COMMITMENTS AND CONTINGENCIES

     See Item 1, Financial Statements, Note 3, which is incorporated herein by
reference.

                                        13
<PAGE>

CAUTIONARY STATEMENT FOR PURPOSES OF THE "SAFE HARBOR" PROVISIONS OF THE PRIVATE
                    SECURITIES LITIGATION REFORM ACT OF 1995

     This report contains or incorporates by reference forward-looking
statements within the meaning of the Private Securities Litigation Reform Act of
1995. Where any forward-looking statement includes a statement of the
assumptions or bases underlying the forward-looking statement, we caution that,
while we believe these assumptions or bases to be reasonable and to be made in
good faith, assumed facts or bases almost always vary from the actual results,
and the differences between assumed facts or bases and actual results can be
material, depending upon the circumstances. Where, in any forward-looking
statement, we or our management express an expectation or belief as to future
results, that expectation or belief is expressed in good faith and is believed
to have a reasonable basis. We cannot assure you, however, that the statement of
expectation or belief will result or be achieved or accomplished. The words
"believe," "expect," "estimate," "anticipate" and similar expressions will
generally identify forward-looking statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

     This information updates, and you should read it in conjunction with,
information disclosed in Part II, Item 7A in our Combined Historical Financial
Statements, in addition to the information presented in Items 1 and 2 of this
Quarterly Report on Form 10-Q.

     In March 2003, we issued $300 million of senior unsecured notes with an
annual interest rate of 8.875% due 2010. Other than this issuance, there were no
material changes in our quantitative and qualitative disclosures about market
risks from those as of December 31, 2002.

ITEM 4.  CONTROLS AND PROCEDURES

     Evaluation of Controls and Procedures.  Under the supervision and with the
participation of management, including our principal executive officer and
principal financial officer, we have evaluated the effectiveness of the design
and operation of our disclosure controls and procedures (Disclosure Controls)
and internal controls over financial reporting (Internal Controls) as of the end
of the period covered by this Quarterly Report pursuant to Rules 13a-15 and
15d-15 under the Securities Exchange Act of 1934 (Exchange Act).

     Definition of Disclosure Controls and Internal Controls.  Disclosure
Controls are our controls and other procedures that are designed to ensure that
information required to be disclosed by us in the reports that we file or submit
under the Exchange Act is recorded, processed, summarized and reported, within
the time periods specified under the Exchange Act. Disclosure Controls include,
without limitation, controls and procedures designed to ensure that information
required to be disclosed by us in the reports that we file under the Exchange
Act is accumulated and communicated to our management, including our principal
executive officer and principal financial officer, as appropriate to allow
timely decisions regarding required disclosure. Internal Controls are procedures
which are designed with the objective of providing reasonable assurance that (1)
our transactions are properly authorized; (2) our assets are safeguarded against
unauthorized or improper use; and (3) our transactions are properly recorded and
reported, all to permit the preparation of our financial statements in
conformity with generally accepted accounting principles.

     Limitations on the Effectiveness of Controls.  ANR Pipeline Company's
management, including the principal executive officer and principal financial
officer, does not expect that our Disclosure Controls and Internal Controls will
prevent all errors and all fraud. The design of a control system must reflect
the fact that there are resource constraints, and the benefits of controls must
be considered relative to their costs. Because of the inherent limitations in
all control systems, no evaluation of controls can provide absolute assurance
that all control issues and instances of fraud, if any, within the company have
been detected. These inherent limitations include the realities that judgments
in decision-making can be faulty, and that breakdowns can occur because of
simple errors or mistakes. Additionally, controls can be circumvented by the
individual acts of some persons, by collusion of two or more people, or by
management override of the controls. The design of any system of controls also
is based in part upon certain assumptions about the likelihood of future events.
Therefore, a control system, no matter how well conceived and operated, can
provide only reasonable, not
                                        14
<PAGE>

absolute, assurance that the objectives of the control system are met. Our
Disclosure Controls and Internal Controls are designed to provide such
reasonable assurances of achieving our desired control objectives, and our
principal executive officer and principal financial officer have concluded that
our Disclosure Controls and Internal Controls are effective in achieving that
level of reasonable assurance.

     No Significant Changes in Internal Controls.  We have sought to determine
whether there were any "significant deficiencies" or "material weaknesses" in
ANR Pipeline Company's Internal Controls, or whether the company had identified
any acts of fraud involving personnel who have a significant role in ANR
Pipeline Company's Internal Controls. This information was important both for
the controls evaluation generally and because the principal executive officer
and principal financial officer are required to disclose that information to our
Board's Audit Committee and our independent auditors and to report on related
matters in this section of the Quarterly Report. The principal executive officer
and principal financial officer note that there has not been any change in
Internal Controls that occurred during the most recent fiscal quarter that has
materially affected, or is reasonably likely to materially affect, Internal
Controls.

     Effectiveness of Disclosure Controls.  Based on the controls evaluation,
our principal executive officer and principal financial officer have concluded
that the Disclosure Controls are effective to ensure that material information
relating to ANR Pipeline Company and its consolidated subsidiaries is made known
to management, including the principal executive officer and principal financial
officer, on a timely basis.

     Officer Certifications.  The certifications from the principal executive
officer and principal financial officer required under Sections 302 and 906 of
the Sarbanes-Oxley Act of 2002 have been included as Exhibits to this Quarterly
Report.

                                        15
<PAGE>

                          PART II -- OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

     See Part I, Item 1, Financial Statements, Note 3, which is incorporated
herein by reference.

ITEM 2. CHANGES IN SECURITIES AND USE OF PROCEEDS

     None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

     None.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

     None.

ITEM 5. OTHER INFORMATION

     None.

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

     a.  Exhibits

     Each exhibit identified below is filed as a part of this report. Exhibits
not incorporated by reference to a prior filing are designated by an "*"; all
exhibits not so designated are incorporated herein by reference to a prior
filing as indicated.

<Table>
<Caption>
EXHIBIT
NUMBER                            DESCRIPTION
-------                           -----------
<S>       <C>
 *31.A    Certification of Chief Executive Officer pursuant to
          sec. 302 of the Sarbanes-Oxley Act of 2002.
 *31.B    Certification of Chief Financial Officer pursuant to
          sec. 302 of the Sarbanes-Oxley Act of 2002.
 *32.A    Certification of Chief Executive Officer pursuant to 18
          U.S.C. sec. 1350 as adopted pursuant to sec. 906 of the
          Sarbanes-Oxley Act of 2002.
 *32.B    Certification of Chief Financial Officer pursuant to 18
          U.S.C. sec. 1350 as adopted pursuant to sec. 906 of the
          Sarbanes-Oxley Act of 2002.
</Table>

Undertaking

     We hereby undertake, pursuant to Regulation S-K, Item 601(b), paragraph
(4)(iii), to furnish to the U.S. Securities and Exchange Commission, upon
request, all constituent instruments defining the rights of holders of our
long-term debt not filed herewith for the reason that the total amount of
securities authorized under any of such instruments does not exceed 10 percent
of our total consolidated assets.

     b. Reports on Form 8-K

        None.

                                        16
<PAGE>

                                   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.

                                              ANR PIPELINE COMPANY

Date: November 10, 2003                         /s/ JOHN W. SOMERHALDER II
                                              ----------------------------------
                                                    John W. Somerhalder II
                                              Chairman of the Board and Director
                                                (Principal Executive Officer)

Date: November 10, 2003                             /s/ GREG G. GRUBER
                                              ----------------------------------
                                                        Greg G. Gruber
                                                    Senior Vice President,
                                              Chief Financial Officer, Treasurer
                                                         and Director
                                                   (Principal Financial and
                                                      Accounting Officer)

                                        17
<PAGE>

                                 EXHIBIT INDEX

     Each exhibit identified below is filed as a part of this report. Exhibits
not incorporated by reference to a prior filing are designated by an "*"; all
exhibits not so designated are incorporated herein by reference to a prior
filing as indicated.

<Table>
<Caption>
EXHIBIT
NUMBER                            DESCRIPTION
-------                           -----------
<S>       <C>
 *31.A    Certification of Chief Executive Officer pursuant to
          sec. 302 of the Sarbanes-Oxley Act of 2002.
 *31.B    Certification of Chief Financial Officer pursuant to
          sec. 302 of the Sarbanes-Oxley Act of 2002.
 *32.A    Certification of Chief Executive Officer pursuant to 18
          U.S.C. sec. 1350 as adopted pursuant to sec. 906 of the
          Sarbanes-Oxley Act of 2002.
 *32.B    Certification of Chief Financial Officer pursuant to 18
          U.S.C. sec. 1350 as adopted pursuant to sec. 906 of the
          Sarbanes-Oxley Act of 2002.
</Table>