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

FORM 10-Q

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

For quarterly period ended September 30, 2001

[ ] 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 1-16739

VECTREN UTILITY HOLDINGS, INC.
---------------------------------
(Exact name of registrant as specified in its charter)

INDIANA 35-2104850
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)

20 N.W. Fourth Street, Evansville, Indiana 47741
------------------------------------------------
(Address of principal executive offices and Zip Code)

(812) 491-4000
-------------------------------------
(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 [ ]

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

Common Stock -Without par value 10 November 10, 2001
- -------------------------------- ---------------- -----------------------
Class Number of shares Date

TABLE OF CONTENTS

Item Page
Number Number
PART I. FINANCIAL INFORMATION
1 Financial Statements (Unaudited)
Vectren Utility Holdings, Inc. and Subsidiary Companies
Condensed Consolidated Balance Sheets 3 - 4
Condensed Consolidated Statements of Operations 5
Condensed Consolidated Statements of Cash Flows 6
Notes to Unaudited Condensed Consolidated Unaudited
Financial Statements 7 - 19
2 Management's Discussion and Analysis of Results of
Operations and Financial Condition 20 - 28
3 Quantitative and Qualitative Disclosure About Market Risk 29 - 30

PART II. OTHER INFORMATION
1 Legal Proceedings 31
6 Exhibits and Reports on Form 8-K 31
Signatures 32

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)

VECTREN UTILITY HOLDINGS, INC. AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited - Thousands)

September 30, December 31,
ASSETS 2001 2000
------ ---------- ----------

Utility Plant at original cost:
Electric $1,174,362 $1,175,552
Gas 1,527,431 1,552,825
---------- ----------
2,701,793 2,728,377
Less: accumulated depreciation and amortization 1,285,148 1,233,033
---------- ----------
1,416,645 1,495,344
Construction work in progress 150,149 60,417
---------- ----------
Net utility plant 1,566,794 1,555,761
---------- ----------

Current Assets:
Cash and cash equivalents 2,443 2,202
Accounts receivable, less reserves of $5,924 and
$5,602, respectively 95,035 173,300
Accounts receivable from affiliated company 32,872 34,278
Accrued unbilled revenues 17,689 143,365
Inventories 98,621 93,294
Prepaid gas delivery service 47,304 34,849
Recoverable fuel and natural gas costs 78,990 96,084
Other current assets 52,579 36,086
---------- ----------
Total current assets 425,533 613,458
---------- ----------

Other Investments and Property:
Nonutility property and other, net 2,331 4,916
Other investments 5,049 1,056
---------- ----------
Total other investments and property 7,380 5,972
---------- ----------

Other Assets:

Deferred charges, net 21,760 19,985
Goodwill, net 194,321 197,977
Regulatory assets 52,860 52,246
---------- ----------
Total other assets 268,941 270,208
---------- ----------

TOTAL ASSETS $2,268,648 $2,445,399
========== ==========

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

VECTREN UTILITY HOLDINGS, INC. AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited - Thousands)

September 30, December 31,
LIABILITIES AND SHAREHOLDER'S EQUITY 2001 2000
------------------------------------ ----------- -----------

Capitalization:
Common stock $ 350,674 $ 221,254
Retained earnings 318,845 350,537
Accumulated comprehensive income (3,998) -
----------- -----------
Total common shareholder's equity 665,521 571,791
Cumulative nonredeemable preferred stock of subsidiary - 8,890
Cumulative redeemable preferred stock of subsidiary - 7,500
Cumulative special preferred stock of subsidiary 460 575
Long-term debt, net of current maturities 565,439 572,609
Short-term borrowings, refinanced - 129,420
----------- -----------
Total capitalization, net of current maturities 1,231,420 1,290,785
----------- -----------

Commitments and Contingencies (Notes 10 through 13 )

Current Liabilities:
Short-term borrowings, net of amounts refinanced 580,162 524,032
Notes payable to affiliated company - 6,901
Accounts payable to affiliated company 62,821 25,425
Accounts payable 65,229 239,257
Dividends payable - 144
Accrued taxes 23,799 41,382
Accrued interest 7,802 9,790
Refunds to customers 17,688 15,343
Deferred income taxes 6,723 16,531
Other accrued liabilities 14,939 31,812
----------- -----------
Total current liabilities 779,163 910,617
----------- -----------

Deferred Credits and Other Liabilities:
Deferred income taxes 173,369 167,420
Unamortized investment tax credits 21,456 23,165
Accrued postretirement benefits other than pensions 47,949 43,993
Other 15,291 9,419
----------- -----------
Total deferred credits and other liabilities 258,065 243,997
----------- -----------

TOTAL SHAREHOLDER'S EQUITY AND LIABILITIES $ 2,268,648 $ 2,445,399
=========== ===========

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

VECTREN UTILITY HOLDINGS, INC. AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited - Thousands)

Three Months Nine Months
Ended September 30, Ended September 30,
------------------------ -----------------------
2001 2000 2001 2000
---------- ---------- ---------- ----------

OPERATING REVENUES:
Gas revenues $ 97,578 $ 90,156 $ 774,265 $ 391,486
Electric revenues 104,335 97,936 287,564 249,215
---------- ---------- ---------- ----------
Total operating revenues 201,913 188,092 1,061,829 640,701
---------- ---------- ---------- ----------
COST OF OPERATING REVENUES:
Cost of gas 51,147 54,948 550,019 229,373
Cost of fuel and purchased power 43,576 32,603 126,231 80,704
---------- ---------- ---------- ----------
Total cost of operating revenues 94,723 87,551 676,250 310,077
---------- ---------- ---------- ----------

Total margin 107,190 100,541 385,579 330,624

OPERATING EXPENSES:
Operations and maintenance 55,071 49,653 177,919 147,408
Merger and integration costs 1,366 864 2,075 29,918
Restructuring costs 1,233 - 12,038 -
Depreciation and amortization 24,604 19,813 74,132 60,164
Income taxes 794 5,254 11,269 19,438
Taxes other than income taxes 8,633 5,768 38,384 20,752
---------- ---------- ---------- ----------
Total operating expenses 91,701 81,352 315,817 277,680
---------- ---------- ---------- ----------

OPERATING INCOME 15,489 19,189 69,762 52,944

OTHER INCOME-NET (189) 1,711 1,614 4,014

INTEREST EXPENSE 15,542 10,426 52,278 30,063

PREFERRED DIVIDEND REQUIREMENT
OF SUBSIDIARY 268 241 748 776
---------- ---------- ---------- ----------

INCOME (LOSS) BEFORE CUMULATIVE EFFECT
OF CHANGE IN ACCOUNTING PRINCIPLE (510) 10,233 18,350 26,119

CUMULATIVE EFFECT OF CHANGE IN
ACCOUNTING PRINCIPLE- NET OF TAX - - 3,938 -
---------- ---------- ---------- ----------

NET INCOME (LOSS) $ (510) $ 10,233 $ 22,288 $ 26,119
========== ========== ========== ==========

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

VECTREN UTILITY HOLDINGS, INC. AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited - Thousands)

Nine Months
Ended September 30,
----------------------
2001 2000
--------- ---------

CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 22,288 $ 26,119
--------- ---------
Adjustments to reconcile net income to cash provided
from operating activities -
Depreciation and amortization 74,132 60,164
Preferred dividend requirement of subsidiary 748 776
Deferred income taxes and investment tax credits (3,197) (16,917)
Allowance for funds used during construction (1,409) (436)
Cumulative effect of change in accounting principle - net of tax (3,938) -
Unrealized loss on derivatives 3,264 -
Other non-cash income and expenses 152 (1,574)
Changes in assets and liabilities -
Receivables - net 205,347 37,952
Inventories (5,327) 7,729
Prepaid gas delivery service (12,455) (25,851)
Recoverable fuel and natural gas costs 17,094 (25,095)
Other current assets (16,416) (9,667)
Regulatory assets (614) 5,136
Accounts payable, refunds to customers,
other current liabilities (157,708) 16,402
Accrued taxes and interest (19,571) (14,740)
Accrued post-retirement benefits other than pensions 3,956 4,765
Other assets and liabilities 4,802 5,955
--------- ---------
Total adjustments 88,860 44,599
--------- ---------
Net cash flows from operating activities 111,148 70,718
--------- ---------
CASH FLOWS FROM (REQUIRED FOR) FINANCING ACTIVITIES
Issuance of common stock 129,420 -
Retirement of and dividends on preferred stock (18,424) (2,776)
Retirement of long-term debt and other obligations (7,322) (1,109)
Net change in short-term borrowings (80,191) 62,483
Dividends paid on common stock (46,652) (41,589)
--------- ---------
Net cash flows from (required for) financing activities (23,169) 17,009
--------- ---------
CASH FLOWS (REQUIRED FOR) INVESTING ACTIVITIES
Capital expenditures (85,828) (81,807)
Proceeds from sale of assets 1,119 -
Other investments (3,029) (999)
--------- ---------
Net cash flows (required for) investing activities (87,738) (82,806)
--------- ---------

Net increase in cash 241 4,921

Cash and cash equivalents at beginning of period 2,202 802
--------- ---------

Cash and cash equivalents at end of period $ 2,443 $ 5,723
========= =========

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

VECTREN UTILITY HOLDINGS, INC. AND SUBSIDIARY COMPANIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

1. Organization and Nature of Operations

Vectren Utility Holdings, Inc. (VUHI or the Company), an Indiana corporation,
was formed on March 31, 2000 to serve as the intermediate holding company for
Vectren Corporation's (Vectren) three operating public utilities, Indiana Gas
Company, Inc. (Indiana Gas), formerly a wholly owned subsidiary of Indiana
Energy, Inc. (Indiana Energy), Southern Indiana Gas and Electric Company
(SIGECO), formerly a wholly owned subsidiary of SIGCORP, Inc. (SIGCORP), and the
Ohio operations (defined hereafter).

Vectren is an Indiana corporation that was organized on June 10, 1999, solely
for the purpose of effecting the merger of Indiana Energy and SIGCORP. On March
31, 2000, the merger of Indiana Energy with SIGCORP and into Vectren was
consummated with a tax-free exchange of shares and has been accounted for as a
pooling-of-interests. Therefore, the reorganization of Indiana Gas and SIGECO
into subsidiaries of VUHI has been accounted for as a combination of entities
under common control. These transactions did not affect the preferred stock and
debt securities of Indiana Gas and SIGECO.

On October 31, 2000, Vectren acquired the natural gas distribution assets of The
Dayton Power and Light Company for approximately $465 million. The acquisition
has been accounted for as a purchase transaction in accordance with Accounting
Principles Board (APB) Opinion No. 16 and accordingly, the results of operations
of the acquired assets are included in the accompanying financial statements
since the date of acquisition.

Vectren acquired the natural gas distribution assets as a tenancy in common
through two separate wholly owned subsidiaries. Vectren Energy Delivery of Ohio,
Inc. (VEDO), a wholly owned subsidiary, holds a 53% undivided ownership interest
in the assets and Indiana Gas holds a 47% undivided ownership interest. VEDO is
the operator of the assets, operations of which are referred to as "the Ohio
operations."

The Company's regulated subsidiaries serve approximately one million customers.
Indiana Gas provides natural gas distribution and transportation services to a
diversified base of customers in 311 communities in 49 of Indiana's 92 counties.
SIGECO provides generation, transmission, distribution and sale of electric
power to Evansville, Indiana, and 74 other communities in 8 counties in
southwestern Indiana, and the distribution and sale of natural gas to
Evansville, Indiana, and 64 communities in 10 counties in southwestern Indiana.
The Ohio operations provide natural gas distribution and transportation services
to Dayton, Ohio and 16 counties in west central Ohio.

2. Basis of Presentation

The interim condensed financial statements included in this report have been
prepared by the Company, without audit, as provided in the rules and regulations
of the Securities and Exchange Commission. Certain information and footnote
disclosures normally included in financial statements prepared in accordance
with accounting principles generally accepted in the United States have been
omitted as provided in such rules and regulations. The Company believes that the
information in this report reflects all adjustments necessary to fairly state
the results of the interim periods reported. These condensed consolidated
financial statements and related notes should be read in conjunction with the
Company's audited annual consolidated financial statements for the year ended
December 31, 2000 filed in Amendment 3 to the Company's Registration Statement
on Form 10. Because of the seasonal nature of the Company's operations, the
results shown on a quarterly basis are not necessarily indicative of annual
results.

The preparation of financial statements in conformity with accounting principles
generally accepted in the United States requires management to make estimates

and assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the statements
and the reported amounts of revenues and expenses during the reporting periods.
Actual results could differ from those estimates.

The Company's results of operations are presented prior to certain
reclassifications necessary to conform to the financial statement presentation
of Vectren.

3. Merger and Integration Costs

Since March 31, 2000, $34.8 million has been expensed associated with merger and
integration activities. Accruals were established at March 31, 2000 totaling
$19.3 million. Of this amount, $5.5 million related to employee and executive
severance costs, $11.7 million related to transaction costs and regulatory
filing fees incurred prior to the closing of the merger, and the remaining $2.1
million related to employee relocations that occurred prior to or coincident
with the merger closing. At September 30, 2001, the accrual remaining for such
costs totaled $1.8 million, all related to severance costs. Of the $34.8 million
expensed, the remaining $15.5 million was expensed through September 30, 2001
($13.4 million in 2000 and $2.1 million in 2001) for accounting fees resulting
from merger related filing requirements, consulting fees related to integration
activities such as organization structure, employee travel between company
locations as part of integration activities, internal labor of employees
assigned to integration teams, investor relations communications activities, and
certain benefit costs.

The integration activities experienced by the Company included such things as
information system consolidation, process review and definition, organization
design and consolidation, and knowledge sharing.

As a result of merger integration activities, management has identified certain
information systems that are expected to be retired in 2001. Accordingly, the
useful lives of these assets have been shortened to reflect this decision. These
information system assets are owned by a wholly owned subsidiary of Vectren and
the fees allocated by the subsidiary for the use of these systems by the
Company's subsidiaries are reflected in operation and maintenance expenses in
the accompanying condensed consolidated financial statements. As a result of the
shortened useful lives, additional fees were incurred by the Company, resulting
in additional operation and maintenance expense of $2.7 million ($1.7 million
after tax) and $8.2 million ($5.1 million after tax) for the three and nine
months ended September 30, 2001, respectively, and $3.3 million ($2.0 million
after tax) and $6.7 million ($4.1 million after tax) for the three and nine
months ended September 30, 2000, respectively.

4. Restructuring Costs

In June 2001, the management and board of directors of Vectren approved a plan
to restructure primarily, its regulated operations. The restructuring plan
involves the elimination of administrative and supervisory positions in its
utility operations, corporate office, and certain non-regulated businesses.
Charges of $10.8 million were expensed in June 2001 as a direct result of the
restructuring plan. Additional charges incurred during the third quarter totaled
$1.2 million. In total, the Company has incurred restructuring charges of $12.0
million. These charges were comprised of $7.0 million for severance, related
benefits and other employee related costs, $2.0 million for lease termination
fees related to duplicate facilities, and $3.0 million for consulting fees
incurred as of September 30, 2001.

Components of restructuring expense incurred through September 30, 2001 are as
follows:

Incurred Expenses
Accrual for Cash ---------------------- Total
In millions Payments Paid in Cash Non-Cash Expense
-------- ------------ -------- -------
Severance and related costs $ 0.9 $ 5.3 $ 0.8 $ 7.0
Lease termination fees 2.0 - - 2.0
Consulting fees - 3.0 - 3.0
-------- ------------ -------- -------
Total $ 2.9 $ 8.3 $ 0.8 $ 12.0
======== ============ ======== =======

The $7.0 million expensed for employee severance and related costs is associated
with approximately 90 employees. Employee separation benefits include severance,
healthcare and outplacement services. As of September 30, 2001, approximately 60
employees have exited the business. The accrual for severance and related cots,
lease termination costs and consulting fees, when first established, totaled
$7.0 million, $2.0 million and $1.8 million, respectively. With the exception of
cash payments, there have been no modifications to the restructuring accrual
since it was established. The restructuring program will be completed during
2001.

5. Preferred Stock of Subsidiary

In September 2001, SIGECO notified holders of its 4.80%, 4.75% and 6.50%
preferred stock of its intention to redeem the shares. The 4.80% preferred stock
was redeemed at $110.00 per share, plus $1.3464 in accrued and unpaid dividends.
Prior to the redemption, there were 85,519 shares outstanding. The 4.75%
preferred stock was redeemed at $101.00 per share, plus $0.9694 in accrued and
unpaid dividends. Prior to the redemption, there were 3,000 shares outstanding.
The 6.50% preferred stock was redeemed at $104.23 per share, plus $0.7339 in
accrued and unpaid dividends. Prior to the redemption, there were 75,000 shares
outstanding.

6. Shareholder's Equity

Vectren At-Risk Compensation Plan
At Vectren's annual shareholders meeting on April 25, 2001, shareholders
approved Vectren's At-Risk Compensation Plan. On May 1, 2001, per the terms of
the plan, 4,000,000 shares of Vectren common stock were reserved for issuance in
the form of stock options, restricted stock, and other awards. Approximately
785,000 stock options have been granted to employees of the Company.

7. Long - Term Debt

In September 2001, the Company filed a shelf registration statement for $350.0
million aggregate principal amount of unsecured senior notes. When issued, these
unsecured notes are to be guaranteed by the three operating utility companies:
SIGECO, Indiana Gas, and VEDO. The Company has no significant independent assets
or operations other than the assets and operations of these subsidiary
guarantors. These guarantees of the Company's debt are full and unconditional
and joint and several.

In October 2001, the Company issued guaranteed senior unsecured notes priced
with an aggregate principal amount of $100.0 million and an interest rate of
7.25%. The net proceeds from the sale of the senior notes were used to reduce
existing debt outstanding under the Company's short-term borrowing arrangements.
The senior notes have no sinking fund requirement and are due October 2031.
However, the senior notes may be called, in whole or in part, at any time after
October, 2006 at 100% of the principal amount plus any accrued interest thereon.

liabilities. Effective March 1, 2001, the bonds were reset for a five-year
period and have been classified as long-term debt. Resulting from the reset, the
interest rate on the $31.5 million Series A bonds increased from 4.30% to 4.75%,
and the interest rate on the $22.2 million Series C bonds increased from 4.45%
to 5.00%.

8. Short - Term Borrowings

The Company's credit facility was renewed in June 2001 and extended though June
2002. As part of the renewal, the capacity of the facility was decreased from
$435.0 million to $350.0 million. As of December 31, 2000 the Company had
classified $129.4 million of commercial paper as short-term borrowings,
refinanced in capitalization in the Condensed Consolidated Balance Sheets. In
February 2001, the Company repaid $129.4 million of commercial paper with
proceeds received from an equity contribution by Vectren. Vectren funded the
contribution with the proceeds from an offering of its common stock.

9. Comprehensive Income

The difference between the Company's net income (loss) and other comprehensive
income results principally from the market value fluctuation of the interest
rate swaps designated as cash flow hedges.

Comprehensive income consists of the following:

Three Months Nine Months
Ended September 30, Ended September 30,
-------------------- --------------------
In thousands 2001 2000 2001 2000
--------- -------- -------- --------

Net income (loss) $ (510) $ 10,233 $ 22,288 $ 26,119
Interest rate swaps and other, net of tax (3,016) - (3,998) -
-------- -------- -------- --------
Total comprehensive income (loss) $ (3,526) $ 10,233 $ 18,290 $ 26,119
======== ======== ======== ========

10. Contingencies

The Company is party to various legal proceedings arising in the normal course
of business. In the opinion of management, there are no legal proceedings
pending against the Company that are likely to have a material adverse effect on
its financial position or results of operations. See Note 11 regarding the
Culley Generating Station Investigation Matter and Note 13 regarding ProLiance
Energy, LLC.

11. Environmental Matters

Clean Air Act
NOx SIP Call Matter. On October 27, 1998, the United States Environmental
Protection Agency (USEPA) issued a final rule "Finding of Significant
Contribution and Rulemaking for Certain States in the Ozone Transport Assessment
Group Region for Purposes of Reducing Regional Transport of Ozone," (63 Fed.
Reg. 57355) that required uniform nitrogen oxide (NOx) emissions reduction of
85% by utilities and other large sources in certain Midwestern states and the
District of Columbia. These emission levels are below those already imposed by
Phase I and Phase II of the Clean Air Act Amendments of 1990 (the Act).

In their state implementation plans (SIPs), the USEPA encouraged states to
target utility coal-fired boilers for the majority of the reductions required,
especially NOx emissions. Northeastern states have claimed that ozone transport
from Midwestern states (including Indiana) is the primary reason for their ozone
concentration problems. Although this premise is challenged by others based on
various air quality modeling studies, including studies commissioned by the
USEPA, the USEPA intends to incorporate a regional control strategy to reduce
ozone transport.

The NOx emissions budget for Indiana stipulated in the USEPA's final ruling
requires a 31% reduction in total NOx emissions from Indiana. Indiana's
implementation plan requires SIGECO to lower its system-wide NOx emissions to
.14/mmbtu. Based on the level of system-wide emissions reductions required and
the control technology utilized to achieve the reductions, the current estimated
construction cost of the control equipment ranges from $175.0 million to $200.0
million and is expected to be expended during the 2001-2004 period. Related
additional annual operation and maintenance expenses are estimated to be $8.0
million to $10.0 million. Through September 30, 2001, approximately $10.8
million has been expended. The Company's system-wide compliance is required by
May 31, 2004 (the compliance date).

In April 2001, the Company initiated steps toward compliance with the revised
regulations. These steps include upgrading Culley Generating Station Unit 3
(Culley), Warrick Generating Station Unit 4 (Warrick), and A.B. Brown Generating
Station Unit 2 (A.B. Brown) with selective catalytic reduction (SCR) systems.
SCR systems reduce flue gas NOx emissions to atmospheric nitrogen and water
using ammonia in chemical reaction. This technology is known to be the most
effective method of reducing NOx emissions where high removal efficiencies are
required. The Company expects the Culley, Warrick and A.B. Brown SCR systems to
be operational by the compliance date. Modifications to these stations are
expected to reduce the Company's overall NOx emissions to levels compliant with
Indiana's NOx emissions budget allotted by the USEPA. No accrual has been
recorded by the Company related to the NOx SIP Call matter. The rules governing
NOx emissions are to be applied prospectively.

In August 2001, the Indiana Utility Regulatory Commission (IURC) issued an order
that (1) approves the Company's proposed project to achieve environmental
compliance by investing in clean coal technology, (2) approves the Company's
project cost estimate for the construction, subject to periodic review of actual
costs incurred, and (3) approves a mechanism for recovery of construction work
in progress on an ongoing basis so that prior to an electric base rate case, the
Company may recover its capital costs for the project, at its overall cost of
capital, including a return on equity.

Culley Generating Station Investigation Matter. The USEPA initiated an
investigation under Section 114 of the Act of SIGECO's coal-fired electric
generating units in commercial operation by 1977 to determine compliance with
environmental permitting requirements related to repairs, maintenance,
modifications and operations changes. The focus of the investigation was to
determine whether new source performance standards should be applied to the
modifications and whether the best available control technology was, or should
have been, used. Numerous other electric utilities were, and are currently,
being investigated by the USEPA under an industry-wide review for similar
compliance. SIGECO responded to all of the USEPA's data requests during the
investigation. In July 1999, SIGECO received a letter from the Office of
Enforcement and Compliance Assurance of the USEPA discussing the industry-wide
investigation, vaguely referring to the investigation of SIGECO and inviting
SIGECO to participate in a discussion of the issues. No specifics were noted;
furthermore, the letter stated that the communication was not intended to serve
as a notice of violation. Subsequent meetings were conducted in September and
October 1999 with the USEPA and targeted utilities, including SIGECO, regarding
potential remedies to the USEPA's general allegations.

On November 3, 1999, the USEPA filed a lawsuit against seven utilities,
including SIGECO. The USEPA alleges that, beginning in 1992, SIGECO violated the
Act by: (i) making modifications to its Culley Generating Station in Yankeetown,
Indiana without obtaining required permits; (ii) making major modifications to
the Culley Generating Station without installing the best available emission
control technology; and (iii) failing to notify the USEPA of the modifications.
In addition, the lawsuit alleges that the modifications to the Culley Generating
Station required SIGECO to begin complying with federal new source performance
standards.

SIGECO believes it performed only maintenance, repair and replacement activities
at the Culley Generating Station, as allowed under the Act. Because proper
maintenance does not require permits, application of the best available emission
control technology, notice to the USEPA, or compliance with new source
performance standards, SIGECO believes that the lawsuit is without merit, and
intends to vigorously defend the lawsuit.

The lawsuit seeks fines against SIGECO in the amount of $27,500 per day per
violation. The lawsuit does not specify the number of days or violations the
USEPA believes occurred. The lawsuit also seeks a court order requiring SIGECO
to install the best available emissions technology at the Culley Generating
Station. If the USEPA is successful in obtaining an order, SIGECO estimates that
it would incur capital costs of approximately $40.0 million to $50.0 million
complying with the order. As a result of the NOx SIP call issue, the majority of
the $40.0 million to $50.0 million for best available emissions technology at
Culley Generating Station would be included in the $175.0 million to $200.0
million cost range previously discussed.

The USEPA has also issued an administrative notice of violation to SIGECO making
the same allegations, but alleging that violations began in 1977.

While it is possible that SIGECO could be subjected to criminal penalties if the
Culley Generating Station continues to operate without complying with the new
source performance standards and the allegations are determined by a court to be
valid, SIGECO believes such penalties are unlikely as the USEPA and the electric
utility industry have a bonafide dispute over the proper interpretation of the
Act. Accordingly, the Company has recorded no accrual and the plant continues to
operate while the matter is being decided.

Information Request. On January 23, 2001, SIGECO received an information request
from the USEPA under Section 114(a) of the Act for historical operational
information on the Warrick and A.B. Brown generating stations. SIGECO has
provided all information requested, and no further action has occurred.

Manufactured Gas Plants
In the past, Indiana Gas and others operated facilities for the manufacture of
gas. Given the availability of natural gas transported by pipelines, these
facilities have not been operated for many years. Under currently applicable
environmental laws and regulations, Indiana Gas and others may now be required
to take remedial action if certain byproducts are found above the regulatory
thresholds at these sites.

Indiana Gas has identified the existence, location and certain general
characteristics of 26 gas manufacturing and storage sites for which it may have
some remedial responsibility. Indiana Gas has completed a remedial
investigation/feasibility study (RI/FS) at one of the sites under an agreed
order between Indiana Gas and the Indiana Department of Environmental Management
(IDEM), and a Record of Decision was issued by the IDEM in January 2000.
Although Indiana Gas has not begun an RI/FS at additional sites, Indiana Gas has
submitted several of the sites to IDEM's Voluntary Remediation Program and is
currently conducting some level of remedial activities including groundwater
monitoring at certain sites where deemed appropriate and will continue remedial
activities at the sites as appropriate and necessary.

In conjunction with data compiled by expert consultants, Indiana Gas has accrued
the estimated costs for further investigation, remediation, groundwater
monitoring and related costs for the sites. While the total costs that may be
incurred in connection with addressing these sites cannot be determined at this
time, Indiana Gas has accrued costs that it reasonably expects to incur totaling
approximately $20.3 million.

The estimated accrued costs are limited to Indiana Gas' proportionate share of
the remediation efforts. Indiana Gas has arrangements in place for 19 of the 26
sites with other potentially responsible parties, which serve to limit Indiana
Gas' share of response costs at these 19 sites to between 20 and 50%.

With respect to insurance coverage, as of December 31, 2000, Indiana Gas has
received and recorded settlements from all known insurance carriers in an
aggregate amount approximating its $20.3 million accrual.

Environmental matters related to manufactured gas plants have had no material
impact on earnings since costs recorded to date approximate PRP and insurance

settlement recoveries. While Indiana Gas has recorded all costs which it
presently expects to incur in connection with activities at these sites, it is
possible that future events may require some level of additional remedial
activities which are not presently foreseen.

12. Rate and Regulatory Matters

Gas Costs Proceedings
Commodity prices for natural gas purchases were significantly higher during the
2000 - 2001 heating season, primarily due to a colder temperatures, increased
demand and tighter supplies. Subject to compliance with applicable state laws,
the Company's utility subsidiaries are allowed full recovery of such changes in
purchased gas costs from their retail customers through commission-approved gas
cost adjustment (GCA) mechanisms.

In March 2001, Vectren, Indiana Gas and SIGECO reached agreement with the
Indiana Office of Utility Consumer Counselor (OUCC) and the Citizens Action
Coalition of Indiana, Inc. (CAC) regarding the IURC Order that disallowed $3.8
million of Indiana Gas' gas procurement costs for the 2000 - 2001 heating
season, which was recognized in 2000. As part of the agreement, among other
things, the companies agreed to contribute an additional $1.9 million to the
State of Indiana's Low Income Heating Assistance Program in 2001 and to credit
$3.3 million of the $3.8 million disallowed amount to Indiana Gas customers'
April 2001 utility bills in exchange for both the OUCC and the CAC dropping
their appeals of the IURC Order. In April 2001, the IURC issued an order
approving the settlement. The contributions to Indiana's Low Income Heating
Assistance Program totaling $1.9 million were made in 2001 and were charged to
other income, net in 2001. There was no impact to 2000 results of operations as
a result of these contributions.

Purchased Power Costs
As a result of an appeal of a generic order issued by the IURC in August 1999
regarding guidelines for the recovery of purchased power costs, SIGECO entered
into a settlement agreement with the OUCC that provides certain terms with
respect to the recoverability of such costs. The settlement, originally approved
by the IURC on August 9, 2000, has been extended by agreement through March
2002. Under the settlement, SIGECO can recover the entire cost of purchased
power up to an established benchmark, and during forced outages, SIGECO will
bear a limited share of its purchased power costs regardless of the market costs
at that time. Based on this agreement, SIGECO believes it has limited its
exposure to unrecoverable purchased power costs.

13. Affiliate Transactions

Vectren and certain subsidiaries of Vectren have provided corporate, general and
administrative services to the Company including legal, finance, tax, risk
management and human resources. The costs have been allocated to the Company
using various allocators, primarily number of employees, number of customers
and/or revenues. Allocations are based on cost. Management believes that the
allocation methodology is reasonable and approximates the costs that would have
been incurred had the Company secured those services on a stand alone basis. For
the three months ended September 30, 2001 and 2000, amounts billed by other
wholly owned subsidiaries of Vectren to the Company were $16.2 million and $23.6
million, respectively. For the nine months ended September 30, 2001 and 2000,
amounts billed by other wholly owned subsidiaries of Vectren to the Company were
$88.9 million and $55.1 million, respectively.

Vectren Fuels, Inc., a wholly owned subsidiary of Vectren, owns and operates
coal mines from which SIGECO purchases fuel used for electric generation.
Amounts paid for such purchases for the three months ended September 30, 2001
and 2000 were $7.3 million and $4.2 million respectively. Amounts paid for such
purchases for the nine months ended September 30, 2001 and 2000 were $28.2
million and $14.3 million, respectively. Amounts charged by Vectren Fuels, Inc.
are market based.

The Company also participates in a centralized cash management program with its
parent, affiliated companies and banks, which permits funding of checks as they
are presented.

ProLiance Energy Services, LLC (ProLiance), a non-regulated, energy marketing
affiliate of Vectren, provides natural gas supply and related services to
certain wholly owned subsidiaries of the Company. Purchases from ProLiance for
resale and for injections into storage for the three months ended September 30,
2001 and 2000 totaled $89.3 million and $81.2 million, respectively; and for the
nine months ended September 30, 2001 and 2000 totaled $503.7 million and $217.5
million, respectively. Amounts charged by ProLiance are market based.

ProLiance began providing natural gas and related services to Indiana Gas,
Citizens Gas and Coke Utility (Citizens Gas) and others effective April 1, 1996.
In March 2001, ProLiance began providing services to the Ohio operations. The
sale of gas and provision of other services to Indiana Gas by ProLiance is
subject to regulatory review through the quarterly GCA process administered by
the IURC.

On September 12, 1997, the IURC issued a decision finding the gas supply and
portfolio administration agreements between ProLiance and Indiana Gas and
ProLiance and Citizens Gas to be consistent with the public interest and that
ProLiance is not subject to regulations by the IURC as a public utility. The
IURC's decision reflected the significant gas cost savings to customers obtained
through ProLiance's services and suggested that all material provisions of the
agreements between ProLiance and the utilities are reasonable. Nevertheless,
with respect to the pricing of gas commodity purchased from ProLiance, the
pricing of fees paid by ProLiance to the utilities for the prospect of using
pipeline entitlements if and when they are not required to serve the utilities'
firm customers, and the pricing of fees paid by the utilities to ProLiance for
portfolio administration services, the IURC concluded that additional review in
the GCA process would be appropriate and directed that these matters be
considered further in the pending, consolidated GCA proceeding involving Indiana
Gas and Citizens Gas.

As a result of an appeal of the IURC's order, on September 22, 2000, the Indiana
Supreme Court issued a decision affirming the IURC's decision with respect to
Indiana Gas' and Citizens Gas' agreements with ProLiance in all respects. The
IURC has recently commenced the processing of the further GCA proceeding
regarding the issues. The IURC has indicated that it will also consider the
prospective relationship of ProLiance with the utilities in this proceeding.
Discovery is ongoing in the further proceeding and an evidentiary hearing is
scheduled for 2002.

In August 1998, Indiana Gas, Citizens Gas and ProLiance each received a Civil
Investigative Demand (CID) from the United States Department of Justice
requesting information relating to Indiana Gas' and Citizens Gas' relationship
with and the activities of ProLiance. The Department of Justice issued the CID
to gather information regarding ProLiance's formation and operations, and to
determine if trade or commerce has been restrained. In October 2001, the
Antitrust Division of the Department of Justice informed the Company that it
closed its investigation without further action.

Indiana Gas continues to record gas costs in accordance with the terms of the
ProLiance contract.

CIGMA, LLC (CIGMA), owned jointly and equally by a wholly owned subsidiary of
Vectren and a third party, provides materials acquisition and related services
that are used by certain wholly owned subsidiaries of the Company. Purchases of
these services for the three months ended September 30, 2001 and 2000 totaled
$1.9 million and $0.7 million, respectively, and for the nine months ended
September 30, 2001 and 2000 totaled $5.8 million and $2.2 million, respectively.
Amounts charged by CIGMA are market based.

Amounts owed to wholly owned subsidiaries of Vectren totaled $62.8 million and
$32.3 million at September 30, 2001 and December 31, 2000, respectively, and are
included in payables to affiliated company in the Condensed Consolidated Balance
Sheets. Amounts due from wholly owned subsidiaries of Vectren totaled $32.9
million and $34.3 million at September 30, 2001 and December 31, 2000,
respectively, and are included in accounts receivable from affiliated company in
the Condensed Consolidated Balance Sheets.

Amounts owed to unconsolidated affiliates of Vectren totaled $25.1 million and
$97.9 million at September 30, 2001 and December 31, 2000, respectively, and are
included in accounts payable in the Condensed Consolidated Balance Sheets.
Amounts due from unconsolidated affiliates of Vectren totaled $0.2 million at
December 31, 2000 and are included in accounts receivable in the Condensed
Consolidated Balance Sheets.

14. Risk Management, Derivatives and New Accounting Principle

Risk Management
The Company is exposed to market risks associated with commodity prices,
interest rates, and counterparty credit. These financial exposures are monitored
and managed by the Company as an integral part of its overall risk management
program.

Commodity Price Risk. The operations of the Company's regulated subsidiaries
have limited exposure to commodity price risk for purchases and sales of natural
gas and electric energy for its retail customers due to current Indiana and Ohio
regulations, which subject to compliance with applicable state regulations,
allow for recovery of such purchases through natural gas and fuel cost
adjustment mechanisms. (See Note 12 Rate and Regulatory Matters.)

The Company does engage in limited, wholesale power marketing activities that
may expose the Company to commodity price risk associated with fluctuating
electric power prices. These power marketing activities manage the utilization
of its available electric generating capacity. Power marketing operations enter
into forward contracts that commit the Company to purchase and sell electric
power in the future.

Commodity price risk results from forward sales contracts that commit the
Company to deliver electric power on specified future dates. Power marketing
uses planned unutilized generation capability and forward purchase contracts to
protect certain sales transactions from unanticipated fluctuations in the price
of electric power, and periodically, will use derivative financial instruments
to protect its interests from unplanned outages and shifts in demand.

Open positions in terms of price, volume and specified delivery points may occur
to a limited extent and are managed using methods described above and frequent
management reporting.

Interest Rate Risk. The Company is exposed to interest rate risk associated with
its short-term borrowings and adjustable rate long term debt. Its risk
management program seeks to reduce the potentially adverse effects that market
volatility may have on operations.

Under normal circumstances, the Company tries to limit the amount of short-term
debt and adjustable rate long-term debt outstanding to a maximum of 25% of total
debt. However, there are times when this targeted level of interest rate
exposure may be exceeded. To manage this exposure, the Company may periodically
use derivative financial instruments to reduce earnings fluctuations caused by
interest rate volatility.

Other Risks. By using forward purchase contracts and derivative financial
instruments to manage risk, the Company exposes itself to counterparty credit
risk and market risk. The Company manages this exposure to counterparty credit
risk by entering into contracts with financially sound companies that can be
expected to fully perform under the terms of the contract. The Company manages
exposure to market risk associated with commodity contracts and interest rates
by establishing and monitoring parameters that limit the types and degree of
market risk that may be undertaken.

Accounting for Forward Contracts and Other Financial Instruments
Commodity Contracts. At origination all contracts to buy and sell electric power
are designated as "physical," "other-than-trading" or "trading."

Power marketing contracts are designated as "physical" when there is intent and
ability to physically deliver power from its unutilized generating capacity.
Power marketing contracts are designated as "other-than-trading" when there is
intent to receive power to manage base and peak load capacity. Both contract
designations generally require settlement by physical delivery of electricity.
However, certain of these contracts may be net settled in accordance with
industry standards when unplanned outages, favorable pricing movements, and
shifts in demand occur.

Prior to the adoption of Statement of Financial Accounting Standard No. 133
"Accounting for Derivative Instruments and Hedging Activities" (SFAS 133),
contracts in the "physical" and "other-than-trading" portfolios received
accounting recognition on settlement with revenues recorded in electric utility
revenues and costs recorded in fuel for electric generation for those contracts
fulfilled through generation and in purchased electric energy for contracts
purchased in the wholesale energy market. Subsequent to the adoption of SFAS
133, certain contracts that are periodically settled net are recorded at market
value.

The Company may occasionally enter into forward purchase and sale contracts
designated as "trading" that attempt to take advantage of short-term movement in
commodity prices. Commodity contracts designated as "trading" are generally
settled net in accordance with industry trading standards. These contracts are
accounted for at market value. As of September 30, 2001, the Company has no
contracts designated as "trading."

Contracts recorded at market value are recorded as assets or liabilities in the
Condensed Consolidated Balance Sheets as deferred charges, net, other current
assets, other accrued liabilities and other liabilities, as appropriate, and
changes in market value are recorded in the Condensed Consolidated Statements of
Operations as purchased electric energy. Market value is determined using quoted
market prices from independent sources.

Financial Contracts. In September 2001, the Company entered into several forward
starting interest rate swaps with a total notional amount of $200.0 million in
anticipation of a public offering of long-term debt. The swaps fixed the
interest rate at a level considered by management to be favorable. Upon issuance
of the debt, the swaps will be settled, and the value at settlement will be
amortized over the life of the debt, using the interest method. In December
2000, the Company entered into an interest rate swap used to hedge interest rate
risk associated with variable rate short-term notes payable totaling $150.0
million. The swap was entered into concurrently with the issuance of the
floating rate notes on December 28, 2000 and swaps the debt's variable interest
rate of three-month LIBOR plus 0.75% for a fixed rate of 6.64%. The swap expires
on December 27, 2001, the date that the debt agreement expires.

Prior to the adoption of SFAS 133, instruments hedging interest rate risk were
accounted for upon settlement in interest expense. After adoption of SFAS 133,
hedging instruments are carried at market value in deferred charges, net or
other accrued liabilities, as appropriate, and changes in market value are
recorded in accumulated other comprehensive income and recorded to interest
expense as settled.

Impact of New Accounting Principle
In June 1998, the Financial Accounting Standards Board (FASB) issued SFAS 133,
which requires that every derivative instrument be recorded on the balance sheet
as an asset or liability measured at its market value and that changes in the
derivative's market value be recognized currently in earnings unless specific
hedge accounting criteria are met.

SFAS 133, as amended, requires that as of the date of initial adoption, the
difference between the market value of derivative instruments recorded on the
balance sheet and the previous carrying amount of those derivatives be reported
in net income or other comprehensive income, as appropriate, as the cumulative
effect of a change in accounting principle in accordance with APB Opinion No.
20, "Accounting Changes."

on settlement. The cumulative impact of the adoption of SFAS 133 resulting from
marking these contracts to market on January 1, 2001 was an earnings gain of
approximately $6.3 million ($3.9 million net of tax) recorded as a cumulative
effect of accounting change in the Condensed Consolidated Statements of
Operations. SFAS 133 did not impact other commodity contracts because they were
normal purchases and sales that are specifically excluded.

As of September 30, 2001, the Company has derivative assets resulting from its
power marketing operations of $6.9 million classified in other current assets as
well as derivative liabilities of $3.8 million classified in other current
liabilities. Unrealized losses totaling $3.3 million arising from the difference
between the current market value and the market value on the date of adoption is
included in purchased electric energy in the Condensed Consolidated Statements
of Operations for the nine months ended September 30, 2001. Unrealized losses
for the three months ended September 30, 2001 were $0.9 million.

Vectren has documented the hedging relationship between its interest rate swaps
and underlying risks as well as its risk management objectives and anticipated
effectiveness. The Company expects its hedges to be effective at hedging the
cash flow related to the interest payments. Accordingly, the swaps have been
designated as cash flow hedges. The adoption of SFAS 133 had no impact as the
market value of the Company's cash flow hedges was zero.

As of September 30, 2001, the market value of the Company's interest rate swaps
is $6.4 million and is included in other accrued liabilities on the Condensed
Consolidated Balance Sheets. The difference between the current market value and
the market value on the date of adoption of 6.4 million ($4.0 million after tax)
is included in accumulated other comprehensive income in the Condensed
Consolidated Balance Sheets. Of that amount, assuming current market conditions,
$0.8 million after tax will be reclassified to interest expense by December 31,
2001.

15. Segment Reporting

Operating segments are defined as components of an enterprise for which separate
financial information is available and evaluated regularly by the chief
operating decision makers in deciding how to allocate resources and in the
assessment of performance.

There were two operating segments of the Company during the reported periods:
(1) Gas Utility Services and (2) Electric Utility Services. The Gas Utility
Services segment distributes, transports and sells natural gas in southwest and
central Indiana and west central Ohio and is comprised of the operations of
Indiana Gas, the Ohio operations and SIGECO's natural gas business. The Electric
Utility Services segment generates, transmits, distributes and sells electricity
within primarily southwestern Indiana and in periods of under utilized capacity,
sells excess electricity to other wholesale customers. This segment is comprised
of SIGECO's electric business.

Certain information relating to the Company's business segments is presented
below:

Three Months Nine Months
Ended September 30, Ended September 30,
-------------------------- --------------------------
In thousands 2001 2000 2001 2000
----------- ----------- ----------- -----------

Operating Revenues:
Gas Utility Services $ 97,578 $ 90,156 $ 774,265 $ 391,486
Electric Utility Services 104,335 97,936 287,564 249,215
----------- ----------- ----------- -----------
Total operating revenues $ 201,913 $ 188,092 $ 1,061,829 $ 640,701
=========== =========== =========== ===========
Net Income (Loss):
Gas Utility Services $ (12,960) $ (7,337) $ (10,303) $ 66
Electric Utility Services 12,450 17,570 32,591 26,053
----------- ----------- ----------- -----------
Net income (loss) $ (510) $ 10,233 $ 22,288 $ 26,119
=========== =========== =========== ===========

September 30, December 31,
2001 2000
------------- ------------
Identifiable Assets:
Gas Utility Services $1,498,086 $1,646,295
Electric Utility Services 770,562 799,104
------------- -------------
Total identifiable assets $2,268,648 $2,445,399
============= =============

16. Impact of Recently Issued Accounting Guidance

The FASB issued two new statements of financial accounting standards in July
2001: SFAS No. 141 "Business Combinations" (SFAS 141), and SFAS No. 142
"Goodwill and Other Intangible Assets" (SFAS 142). These interrelated standards
change the accounting for business combinations and goodwill in two significant
ways:

SFAS 141 requires that the purchase method of accounting be used for
all business combinations initiated after June 30, 2001. Use of the
pooling-of-interests method is prohibited. This change does not affect
the pooling-of-interest transaction forming Vectren.

SFAS 142 changes the accounting for goodwill from an amortization
approach to an impairment-only approach. Thus, amortization of goodwill
not included as an allowable cost for ratemaking purposes will cease
upon adoption of the statement. This includes goodwill recorded in past
business combinations, such as the Company's acquisition of the Ohio
operations. Goodwill is to be tested for impairment at a reporting unit
level at least annually.

SFAS 142 also requires the initial impairment review of all goodwill and other
intangible assets within six months of the adoption date, which is January 1,
2002 for the Company. The impairment review consists of a comparison of the fair
value of a reporting unit to its carrying amount. If the fair value of a
reporting unit is less than its carrying amount, an impairment loss would be
recognized. Results of the initial impairment review are to be treated as a
change in accounting principle in accordance with APB Opinion No. 20 "Accounting
Changes." An impairment loss recognized as a result of an impairment test
occurring after the initial impairment review is to be reported as a part of
operations.

SFAS 142 also changes certain aspects of accounting for intangible assets;
however, the Company does not have any significant intangible assets.

The adoption of SFAS 141 will not materially impact operations. As required by
SFAS 142, amortization of goodwill relating to the acquisition of the Ohio
operations, which approximates $5.0 million per year, will cease on January 1,
2002. The Company has not determined the potential impact of initial impairment
reviews to be performed within six months of adoption of SFAS 142.

SFAS 143

In July 2001, the FASB issued SFAS No. 143 "Accounting for Asset Retirement
Obligations" (SFAS 143). SFAS 143 requires entities to record the fair value of
a liability for an asset retirement obligation in the period in which it is
incurred. When the liability is initially recorded, the entity capitalizes a
cost by increasing the carrying amount of the related long-lived asset. Over
time, the liability is accreted to its present value, and the capitalized cost
is depreciated over the useful life of the related asset. Upon settlement of the
liability, an entity either settles the obligation for its recorded amount or
incurs a gain or loss upon settlement. SFAS 143 is effective for fiscal years
beginning after June 15, 2002, with earlier application encouraged. The Company
is currently evaluating the impact that SFAS 143 will have on its operations.

SFAS 144

In October 2001, the FASB issued SFAS No. 144 "Accounting for the Impairment or
Disposal of Long-Lived Assets" (SFAS 144). SFAS 144 develops one accounting
model for all impaired long-lived assets and long-lived assets to be disposed
of. SFAS 144 replaces existing the authoritative guidance in FASB Statement No.
121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived
Assets to Be Disposed Of" and ABP Opinion No. 30, "Reporting Results of
Operations- Reporting the Effects of Disposal of a Segment of a Business."

This new accounting model retains the framework of SFAS 121 and requires that
those impaired long-lived assets and long-lived assets to be disposed of be
measured at the lower of carrying amount or fair value less cost to sell,
whether reported in continuing operations or in discontinued operations.
Therefore, discontinued operations will no longer be measured at net realizable
value or include amounts for operating losses that have not yet occurred.

SFAS 144 also broadens the reporting of discontinued operations to include all
components of an entity with operations that can be distinguished from the rest
of the entity and that will be eliminated from the ongoing operations of the
entity in a disposal transaction.

SFAS 144 is effective for fiscal years beginning after December 15, 2001, with
earlier application encouraged. The Company is currently evaluating the impact
that SFAS 144 will have on its operations.

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

VECTREN UTILITY HOLDINGS, INC AND SUBSIDIARY COMPANIES

Description of the Business

Vectren is an Indiana corporation that was organized on June 10, 1999, solely
for the purpose of effecting the merger of Indiana Energy and SIGCORP. On March
31, 2000, the merger of Indiana Energy with SIGCORP and into Vectren was
consummated with a tax-free exchange of shares and has been accounted for as a
pooling-of-interests. Therefore, the reorganization of Indiana Gas and SIGECO
into subsidiaries of the Company has been accounted for as a combination of
entities under common control. These transactions did not affect the preferred
stock and debt securities of Indiana Gas and SIGECO.

The Company's regulated subsidiaries serve approximately one million customers.
Indiana Gas provides natural gas distribution and transportation services to a
diversified base of customers in 311 communities in 49 of Indiana's 92 counties.
SIGECO provides generation, transmission, distribution and the sale of electric
power to Evansville, Indiana, and 74 other communities in 8 counties in
southwestern Indiana, and the distribution and sale of natural gas to
Evansville, Indiana, and 64 communities in 10 counties in southwestern Indiana.
The Ohio operations provide natural gas distribution and transportation services
to Dayton, Ohio and 16 counties in west central Ohio.

Results of Operations

Net Income

For the three months ended September 30, 2001, the Company incurred a
consolidated net loss of $0.5 million. Before nonrecurring charges such as
merger and integration and restructuring costs, net income was $2.8 million,
compared to the net income before merger and integration costs for the third
quarter of 2000 of $12.8 million.

For the nine months ended September 30, 2001, consolidated net income was $22.3
million. Before nonrecurring charges such as merger and integration and
restructuring costs, net income was $36.1 million, compared to net income before
merger and integration costs for the nine months ended September 30, 2000 of
$53.1 million. The Company's results for the nine months ended September 30,
2001 reflect the results of the Ohio operations.

See discussion of merger and integration costs and restructuring costs that
follow.

Merger and Integration Costs

Merger and integration costs incurred for the three and nine months ended
September 30, 2001 were $1.4 million and $2.1 million, respectively, and for the
three and nine months ended September 30, 2000 total $0.9 million and $29.9
million, respectively. Vectren expects to realize net merger savings of nearly
$200.0 million over the next ten years from the elimination of duplicate
corporate and administrative programs and greater efficiencies in operations,
business processes and purchasing encompassed in operations. The continued
merger integration activities, which will contribute to the merger savings, will
be completed in 2001. Merger costs are reflected in the financial statements of
the operating subsidiaries in which merger savings are expected to be realized.

As a result of merger integration activities, management has identified certain
information systems that are expected to be retired in 2001. Accordingly, the
useful lives of these assets have been shortened to reflect this decision. These
information system assets are owned by a wholly owned subsidiary of Vectren and
the fees allocated by the subsidiary for the use of these systems by the
Company's subsidiaries are reflected in operation and maintenance expenses in
the accompanying condensed consolidated financial statements. As a result of the
shortened useful lives, additional fees were incurred by the Company, resulting
in additional operation and maintenance expense of $2.7 million and $8.2 million
for the three and nine months ended September 30, 2001, respectively, and $3.3
million and $6.7 million for the three and nine months ended September 30, 2000,
respectively.

In total, for the three months ended September 30, 2001, merger and integration
costs totaled $4.1 million ($2.5 million after tax), compared to $4.2 million
($2.6 million after tax) for the same period in 2000.

In total, for the nine months ended September 30, 2001, merger and integration
costs totaled $10.3 million ($6.4 million after tax), compared to $36.6 million
($27.0 million after tax) for the same period in 2000.

Restructuring Costs

In June 2001, the management and board of directors of Vectren approved a plan
to restructure primarily, its regulated operations. The restructuring plan
involves the elimination of administrative and supervisory positions in its
utility operations and corporate office. Charges of $10.8 million ($6.7 million
after tax), were expensed in June 2001 as a direct result of the restructuring
plan. Additional charges incurred during the third quarter relating primarily to
consulting fees and employee relocation totaled $1.2 million ($0.8 million after
tax). In total, the Company has incurred restructuring charges of $12.0 million
($7.4 million after tax). These charges were comprised of $7.0 million for
severance, related benefits and other employee related costs, $2.0 million for
lease termination

fees related to duplicate facilities, and $3.0 million for consulting fees
incurred as of September 30, 2001.

New Accounting Principle

In June 1998, the Financial Accounting Standards Board (FASB) issued Statement
of Financial Accounting Standard No. 133 "Accounting for Derivative Instruments
and Hedging Activities" (SFAS 133), which requires that every derivative
instrument be recorded on the balance sheet as an asset or liability measured at
its market value and that changes in the derivative's market value be recognized
currently in earnings unless specific hedge accounting criteria are met.

Resulting from the adoption of SFAS 133, certain contracts in the Company's
power marketing operations that are periodically settled net were required to be
recorded at market value. Previously, the Company accounted for these contracts
on settlement. The cumulative impact of the adoption of SFAS 133 resulting from
marking these contracts to market on January 1, 2001 was an earnings gain of
approximately $6.3 million ($3.9 million after tax) recorded as a cumulative
effect of accounting change in the Condensed Consolidated Statements of
Operations. SFAS 133 did not impact other commodity contracts because they were
normal purchases and sales that are specifically excluded.

As of September 30, 2001, the Company has derivative assets resulting from its
power marketing operations of $6.9 million classified in other current assets as
well as derivative liabilities of $3.8 million classified in other current
liabilities. Unrealized losses totaling $3.3 million ($2.0 million after tax)
arising from the difference between the current market value and the market
value on the date of adoption is included in purchased electric energy in the
Condensed Consolidated Statements of Operations for the nine months ended
September 30, 2001. Unrealized losses for the three months ended September 30,
2001 were $0.9 million ($0.6 million after tax).

As of September 30, 2001, the market value of the Company's interest rate swaps
is $6.4 million and is included in other accrued liabilities on the Condensed
Consolidated Balance Sheets. The difference between the current market value and
the market value on the date of adoption of $6.4 million ($4.0 million after
tax) is included in accumulated other comprehensive income in the Condensed
Consolidated Balance Sheets. Of that amount, assuming current market conditions,
$0.8 million after tax will be reclassified to interest expense by December 31,
2001.

Utility Margin (Operating Revenues Less Cost of Gas and Cost of Fuel and
Purchased Power)

Gas Utility Margin
Gas Utility margin for the three months ended September 30, 2001 of $46.4
million increased $11.2 million, or 32%, compared to 2000. Excluding $10.6
million related to the Ohio operations, margin was comparable to the prior year.

Total cost of gas sold was $51.1 million for the three months ended September
30, 2001 and $54.9 million in 2000. Excluding $17.8 million related to the Ohio
operations, total cost of gas sold decreased $21.6 million, or 39%, during 2001
compared to 2000. The decrease is primarily due to decreased gas costs in
addition to a 10% decrease in volumes sold to residential and commercial
customers in 2001. The total average cost per dekatherm of gas purchased by
Indiana Gas and SIGECO for the three months ended September 30, 2001 was $4.70
compared to $6.53 for the same period in 2000.

Gas Utility margin for the nine months ended September 30, 2001 of $224.2
million increased $62.1 million, or 38%, compared to 2000. The Ohio operations
represent $58.5 million of the increase. The remaining increase of $3.6 million
related to Indiana Gas and SIGECO is due to a 3% increase in volumes sold to
residential and commercial customers resulting primarily from weather 7% colder
than the previous year and a 1% increase in their combined residential customer
base. These favorable impacts on gas margin were partially offset by reduced
consumption, the cost of unaccounted for gas, and a 9% decrease in transported
volumes for the benefit of contract customers, all primarily due to the effects
of increased gas costs.

Total cost of gas sold was $550.0 million for the nine months ended September
30, 2001 and $229.4 million in 2000. Excluding $204.2 million related to the
Ohio operations, total cost of gas sold increased $116.4 million, or 51%, during
2001 compared to 2000, and is primarily due to significantly higher per unit
purchased gas costs. The total average cost per dekatherm of gas purchased by
Indiana Gas and SIGECO for the nine months ended September 30, 2001 was $6.16
compared to $4.77 for the same period in 2000.

Commodity prices for natural gas purchases were significantly higher during the
2000 - 2001 heating season, primarily due to colder temperatures, increased
demand and tighter supplies. However, in 2001 the Company's subsidiaries have
experienced and may continue to experience higher working capital requirements,
increased expenses, including unrecoverable interest costs, uncollectibles and
unaccounted for gas, and some level of price sensitive reduction in volumes
sold. (See Note 12 of the Company's unaudited condensed consolidated financial
statements in Part I, Item 1 Financial Statements.)

Electric Utility Margin
Electric Utility margin for the three months ended September 30, 2001 of $60.8
million, decreased $4.5 million, or 7%, compared to 2000 due to decreased margin
on wholesale energy sales and a reduction in margin recorded to reflect certain
wholesale power marketing purchase and sale contracts at current market values
as required by SFAS 133. The decrease in wholesale margin is attributable to
changes in wholesale electric prices. This overall decrease was partially offset
by an increase in residential and commercial activity. Retail megawatt hours
sold to residential and commercial customers increased 7% for the quarter. This
retail increase results from weather 11% warmer than the previous year and
combined residential and commercial customer growth of 2%.

Electric Utility margin for the nine months ended September 30, 2001 of $161.3
million, decreased $7.2 million, or 4%, compared to 2000 primarily due to
decreased margin on wholesale energy sales and a reduction in margin recorded to
reflect certain wholesale power marketing purchase and sale contracts at current
market values as required by SFAS 133. The decrease in wholesale margin is
attributable to changes in wholesale electric prices. This overall decrease was
partially offset by a $6.2 million increase in residential and commercial
margin. Retail megawatt hours sold to residential and commercial customers
increased 7% for the nine month period. This retail increase results from
weather 12% warmer than the previous year and combined residential and
commercial customer growth of 3%.

The cost of fuel and purchased power was $43.6 million and $126.2 million for
the three and nine months ended September 30, 2001, respectively, and $32.6
million and $80.7 million for the three and nine months ended September 30,
2000, respectively. The increases of $11.0 million, or 34%, for the three months
period and $45.5 million, or 56% for the nine month period are due primarily to
increased purchased power related to greater sales to other utilities and power
marketers as well as the reductions in margin recorded as a result of SFAS 133.

Operating Expenses

Operations and Maintenance
Excluding $9.4 million in expenses related to the Ohio operations, operations
and maintenance expense for the three months ended September 30, 2001 decreased
$4.0 million, and excluding $29.8 million in expenses related to the Ohio
operations, slightly increased for the nine months ended September 30, 2001. The
decreases reflect merger synergies causing less general and administrative
expenses. For the nine month period, these merger synergies were offset by
increased fees allocated from a wholly owned subsidiary of Vectren to reflect
the shortened useful lives of certain information systems in use by the
Company's subsidiaries (see merger and integration costs above) and increased
bad debt expense as a result of higher gas costs.

Depreciation and Amortization
Depreciation and amortization increased $4.8 million and $14.0 million,
respectively, for the three and nine months ended September 30, 2001 compared to
the prior year due primarily to the inclusion of the Ohio operations.
Depreciation and amortization related to the Ohio operations was $3.9 million
and $11.7 million for the three and nine months ended September 30, 2001,
respectively. The remaining increases are attributable to depreciation of
additions to utility plant.

Income Taxes
Federal and state income taxes decreased $4.5 million and $8.2 million for the
three and nine months ended September 30, 2001, respectively, compared to the
prior year due primarily to lower pre-tax earnings and normal effective tax
rates in 2001. The effective tax rate in 2000 was higher as a result of the
non-deductibility of certain merger and integration costs.

Taxes Other Than Income Taxes
Taxes other than income taxes increased $2.9 million and $17.6 million,
respectively, for the three and nine month periods ended September 30, 2001. The
three and nine month periods include $2.6 million and $15.8 million,
respectively, of primarily Ohio state excise tax related to the Ohio operations.
The remaining increases result from increases in gross receipts taxes.

Other Income-Net

Other income-net decreased $1.9 million and $2.4 million for the three and nine
month periods ended September 30, 2001, compared to 2000. The three month
decrease is attributable to the inclusion of the Ohio operations. In addition to
the inclusion of the Ohio operations, the nine month period reflects additional
Low Income Heating Assistance Program contributions. (See Note 12 of the
Company's condensed consolidated financial statements in Part I, Item 1
Financial Statements.)

Interest Expense

Interest expense increased $5.1 million and $22.2 million, respectively, for the
three and nine months ended September 30, 2001, when compared to the prior year.
The increases were due primarily to interest related to the financing of the
acquisition of the Ohio operations and increased working capital requirements
resulting from higher natural gas prices.

Financial Condition

Liquidity and Capital Resources

The Company's equity capitalization objective is 40-55% of total capitalization.
This objective may have varied, and will vary, from time to time, depending on
particular business opportunities and seasonal factors that affect the Company's
operation. The Company's common equity component was 54% and 49% of total
capitalization, including current maturities of long-term debt and adjustable
rate bonds subject to tender, at September 30, 2001, and December 31, 2000,
respectively. The common equity component of 54% at September 30, 2001 is
expected to be reduced in 2001 upon the refinancing of approximately $350.0
million of the short-term debt issued for the acquisition of the Ohio operations
with long-term debt. Subsequent to September 30, 2001, the Company issued $100.0
million of senior unsecured notes and plans to issue an additional $250.0
million of long term debt by year end 2001. Including both the completed and
planned issues, the Company's pro forma equity component would have been 42% at
September 30, 2001.

Short-term cash working capital is required primarily to finance customer
accounts receivable, unbilled utility revenues resulting from cycle billing, gas
in underground storage, prepaid gas delivery services, capital expenditures and
investments until permanently financed. Short-term borrowings tend to be
greatest during the summer when accounts receivable and unbilled utility
revenues related to electricity are highest and gas storage facilities are being
refilled. However, working capital requirements have been significantly higher
throughout 2001 due to the higher natural gas costs and the acquisition of the
Ohio operations initially financed with short term borrowings.

Cash Flow from Operations
The Company's primary source of liquidity to fund working capital requirements
has been cash generated from operations, which totaled approximately $111.1
million and $70.7 million for the nine months ended September 30, 2001 and 2000,
respectively.

Cash flow from operations increased during the nine months ended September 30,
2001 compared to 2000 by $40.4 million due to higher earnings after considering
non-cash charges such as depreciation and deferred income taxes, and favorable
changes in working capital accounts.

The Company expects the majority of its capital expenditures and debt security
redemptions to be funded by internally generated funds.

Financing Activities
Cash flow required for financing activities of $23.2 million for the nine months
ended September 30, 2001 includes $87.5 million of reductions in net borrowings,
$46.7 million of common stock dividends paid to Vectren, and $18.4 million paid
for the retirement of preferred stock and preferred stock dividends, offset by
the issuance of $129.4 million of common stock. This is an increase in cash
required for financing activities of $40.2 million when compared to the nine
months ended September 30, 2000. The increase in cash requirements is primarily
due to decreased draws against short term borrowing arrangements, increased
dividend payments, and the retirement of principally all of the outstanding
preferred stock.

Purchase of the Ohio Operations.
On October 31, 2000, the acquisition of the Ohio operations was completed for a
purchase price of approximately $465.0 million. Commercial paper was issued to
fund the purchase. Since the purchase, the Company has issued $129.4 million in
equity, $100.0 million in long-term debt and plans to issue an additional $250.0
million in long term debt by year end 2001 to refinance the purchase with
permanent financing. These completed equity and debt transactions are more fully
described below.

In September 2001, the Company filed a shelf registration statement for $350.0
million aggregate principal amount of unsecured senior notes. When issued, these

unsecured notes are to be guaranteed by the three public utility companies:
SIGECO, Indiana Gas, and VEDO. The Company has no significant independent assets
or operations other than the assets and operations of these subsidiary
guarantors. These guarantees of the Company's debt are full and unconditional
and joint and several.

As of December 31, 2000 the Company had classified $129.4 million of commercial
paper as short-term borrowings, refinanced in capitalization in the Condensed
Consolidated Balance Sheets. In February 2001, the Company repaid $129.4 million
of commercial paper with proceeds received from an equity contribution by
Vectren. Vectren funded the contribution with the proceeds from an offering of
its common stock.

Other Financing Transactions and Activity
In September 2001, the Company notified holders of SIGECO's 4.80%, 4.75% and
6.50% preferred stock of its intention to redeem the shares. The 4.80% preferred
stock was redeemed at $110.00 per share, plus $1.3464 in accrued and unpaid
dividends. Prior to the redemption, there were 85,519 shares outstanding. The
4.75% preferred stock was redeemed at $101.00 per share, plus $0.9694 in accrued
and unpaid dividends. Prior to the redemption, there were 3,000 shares
outstanding. The 6.50% preferred stock was redeemed at $104.23 per share, plus
$0.7339 in accrued and unpaid dividends. Prior to the redemption, there were
75,000 shares outstanding.

SIGECO has $53.7 million of adjustable rate pollution control series first
mortgage bonds which could, at the election of the bondholder, be tendered to
SIGECO when the interest rates are reset. Prior to the latest reset on March 1,
2001, the interest rates were reset annually, and the bonds subject to tender
were presented as current liabilities. Effective March 1, 2001, the bonds were
reset for a five-year period and have been classified as long-term debt at both
September 30, 2001 and December 31, 2000. Resulting from the reset, the interest
rate on the $31.5 million Series A bonds increased from 4.30% to 4.75%, and the
interest rate on the $22.2 million Series C bonds increased from 4.45% to 5.00%.

At September 30, 2001, the Company has approximately $679.0 million of
short-term borrowing capacity. Approximately $98.8 million is available for its
operations. Included is the Company's credit facility, which was renewed in June
2001 and extended though June 2002. As part of the renewal, the facility's
capacity was decreased from $435.0 million to $350.0 million.

Indiana Gas' and SIGECO's credit ratings on outstanding debt at September 30,
2001 were A/A2 and A/A1, respectively. The Company's commercial paper related to
the October 2000 Ohio operations acquisition had a credit rating of A-1/P-1.
Indiana Gas' commercial paper retains an A-1/P-1 rating. Subsequent to September
30, 2001, Standard & Poor's lowered its above ratings by one level. The rating
A-/A2 was assigned to the Company's $100.0 million senior unsecured notes issued
in October 2001.

Capital Expenditures and Other Investment Activities
Cash required for investing activities of $87.7 million for the nine months
ended September 30, 2001 includes $85.8 million of capital expenditures.
Investing activities for the nine months ended September 30, 2000 were $82.8
million. The increase from the prior period results from increased capital
expenditures in 2001, principally for NOx compliance.

New construction, normal system maintenance and improvements, and information
technology investments needed to provide service to a growing customer base will
continue to require substantial expenditures. Capital expenditures investments

for the remainder of 2001 are estimated at $48.0 million and are expected to
approximate $165.7 million in 2002.

Environmental and Regulatory Matters

See Notes 11, 12, and 13 in the Company's condensed consolidated financial
statements in Part I, Item 1 regarding matters affecting operations including
the Culley Generating Station Investigation Matter compliance (Note 11),
purchased power cost recovery (Note 12), and transactions with ProLiance Energy,
LLC (Note 13).

Impact of Recently Issued Accounting Guidance

See Note 16 of the condensed consolidated financial statements in Part I, Item 1
regarding recently issued accounting standards.

Forward-Looking Information

A "safe harbor" for forward-looking statements is provided by the Private
Securities Litigation Reform Act of 1995 (Reform Act of 1995). The Reform Act of
1995 was adopted to encourage such forward-looking statements without the threat
of litigation, provided those statements are identified as forward-looking and
are accompanied by meaningful cautionary statements identifying important
factors that could cause the actual results to differ materially from those
projected in the statement. Certain matters described in Management's Discussion
and Analysis of Results of Operations and Financial Condition, including, but
not limited to Vectren's realization of net merger savings, are forward-looking
statements. Such statements are based on management's beliefs, as well as
assumptions made by and information currently available to management. When used
in this filing, the words "believe," "anticipate," "endeavor," "estimate,"
"expect," "objective," "projection," "forecast," "goal," and similar expressions
are intended to identify forward-looking statements. In addition to any
assumptions and other factors referred to specifically in connection with such
forward-looking statements, factors that could cause Vectren Utility Holdings,
Inc. and subsidiary companies' actual results to differ materially from those
contemplated in any forward-looking statements included, among others, the
following:

|X| Factors affecting utility operations such as unusual weather conditions;
catastrophic weather-related damage; unusual maintenance or repairs;
unanticipated changes to fossil fuel costs; unanticipated changes to gas
supply costs, or availability due to higher demand, shortages,
transportation problems or other developments; environmental or pipeline
incidents; transmission or distribution incidents; unanticipated changes to
electric energy supply costs, or availability due to higher demand,
shortages, transportation problems or other developments; environmental or
pipeline incidents; transmission or distribution incidents; unanticipated
changes to electric energy costs, or availability due to demand, shortages,
transmission problems or other developments; or electric transmission or
gas pipeline system constraints.

|X| Increased competition in the energy environment including effects of
industry restructuring and unbundling.

|X| Regulatory factors such as unanticipated changes in rate-setting policies
or procedures, recovery of investments and costs made under traditional
regulation, and the frequency and timing of rate increases.

|X| Financial or regulatory accounting principles or policies imposed by the
Financial Accounting Standards Board, the Securities and Exchange
Commission, the Federal Energy Regulatory Commission, state public utility
commissions, state entities which regulate natural gas transmission,
gathering and processing, and similar entities with regulatory oversight.

|X| Economic conditions including the effects of an economic downturn,
inflation rates, and monetary fluctuations.

|X| Changing market conditions and a variety of other factors associated with
physical energy and financial trading activities including, but not limited
to, price, basis, credit, liquidity, volatility, capacity, interest rate,
and warranty risks.

|X| Availability or cost of capital, resulting from changes in the Company,
including its security ratings, changes in interest rates, and/or changes
in market perceptions of the utility industry and other energy-related
industries.

|X| Employee workforce factors including changes in key executives, collective
bargaining agreements with union employees, or work stoppages.

|X| Legal and regulatory delays and other obstacles associated with mergers,
acquisitions, and investments in joint ventures.

|X| Costs and other effects of legal and administrative proceedings,
settlements, investigations, claims, and other matters, including, but not
limited to, those described in Management's Discussion and Analysis of
Results of Operations and Financial Condition.

|X| Changes in federal, state or local legislature requirements, such as
changes in tax laws or rates, environmental laws and regulations.

The Company undertakes no obligation to publicly update or revise any
forward-looking statements, whether as a result of changes in actual results,
changes in assumptions, or other factors affecting such statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company does engage in limited, wholesale power marketing activities that
may expose it to commodity price risk associated with fluctuating electric power
prices. These power marketing activities manage the utilization of its available
electric generating capacity. Power marketing operations enter into forward
contracts that commit the Company to purchase and sell electric power in the
future.

Open positions in terms of price, volume and specified delivery points may occur
to a limited extent and are managed using methods described above and frequent
management reporting.

Market risk is measured by management as the potential impact on pre tax
earnings resulting from a 10% adverse change in the forward price of electricity
on market sensitive financial instruments (all contracts not expected to be
settled by physical receipt or delivery). For the three and nine months ended
September 30, 2001, a 10% adverse change in the forward prices of electricity on
market sensitive financial instruments would have decreased pre tax earnings by
approximately $0.6 million and $2.0 million, respectively. Prior to the adoption
of SFAS 133 on January 1, 2001, the Company was not engaged in any market
sensitive financial instruments.

At September 30, 2001, VUHI's short-term debt, represented 51% of the Company's
total debt portfolio, due primarily to financing the approximate $465.0 million
acquisition of the Ohio operations initially with short-term debt and the
increased working capital requirements resulting from higher gas costs. The
short-term debt utilized for the Ohio operations acquisition is being replaced
over time with permanent financing (see Liquidity and Capital Resources). Upon
the refinancing of $350.0 million of short term debt with long term debt,
short-term debt would represent 20% of the Company's total debt.

Management measures market risk as the potential impact resulting from
fluctuations in interest rates on short-term borrowings, including bank notes,

lines of credit, and commercial paper. These instruments have interest rates
indexed to short-term market interest rates. At September 30, 2001 and December
31, 2000, the combined borrowings under these facilities totaled $580.2 million
and $653.5 million, respectively. Based upon average borrowing rates under these
facilities during the three months ended September 30, 2001 and 2000, an
increase of 100 basis points (1%) in the rates would have increased interest
expense by $1.3 million and $0.4 million. For the nine months ended September
30, 2001 and 2000, an increase of 100 basis points in the rates would have
increased interest expense by $4.0 million and $0.8 million, respectively.
Approximately $0.4 million of the three month ended September 30, 2001 decrease
and $1.1 million of the nine months ended September 30, 2001 decrease would be
offset by changes in the Company's interest rate swaps.

VECTREN UTILITY HOLDINGS, INC.

PART II - OTHER ITEMS

ITEM 1. LEGAL PROCEEDINGS

ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K

Exhibits

EX - 12 Computation of Ratio of Earnings to Fixed Charges

Reports on Form 8-K

None.

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.

VECTREN UTILITY HOLDINGS, INC.
-------------------------------
Registrant

November 14, 2001 /s/Jerome A. Benkert, Jr.
-------------------------
Jerome A. Benkert, Jr.
Executive Vice President,
Chief Financial Officer, and Treasurer

/s/M. Susan Hardwick
------------------------
M. Susan Hardwick
Vice President and Controller