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 June 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: 1-15467
VECTREN CORPORATION
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(Exact name of registrant as specified in its charter)
INDIANA 35-2086905
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(State or other jurisdiction of (IRS Employer
incorporation or organization) Identification No.)
20 N.W. 4th Street, Evansville, Indiana, 47708
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(Address of principal executive offices)
(Zip Code)
812-491-4000
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(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 by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act). 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 68,119,966 August 1, 2003
-------------------------------- ----------- --------------
Class Number of Shares Date
Table of Contents
Item Page
Number Number
PART I. FINANCIAL INFORMATION
1 Financial Statements (Unaudited)
Vectren Corporation and Subsidiary Companies
Consolidated Condensed Balance Sheets 1-2
Consolidated Condensed Statements of Income 3
Consolidated Condensed Statements of Cash Flows 4
Notes to Unaudited Consolidated Condensed Financial Statements 5-19
2 Management's Discussion and Analysis of Results of Operations
and Financial Condition 20-42
3 Quantitative and Qualitative Disclosures About Market Risk 42
4 Controls and Procedures 43
PART II. OTHER INFORMATION
1 Legal Proceedings 43
4 Submission of Matters to a Vote of Security Holders 44
6 Exhibits and Reports on Form 8-K 45
Signatures 46
Definitions
AFUDC: allowance for funds used during MMBTU: millions of British thermal
construction units
APB: Accounting Principles Board MW: megawatts
EITF: Emerging Issues Task Force MWh / GWh: megawatt hours / millions
of megawatt hours (gigawatt hours)
FASB: Financial Accounting Standards NOx: nitrogen oxide
Board
FERC: Federal Energy Regulatory OUCC: Indiana Office of the Utility
Commission Consumer Counselor
IDEM: Indiana Department of PUCO: Public Utilities Commission of
Environmental Management Ohio
IURC: Indiana Utility Regulatory SFAS: Statement of Financial
Commission Accounting Standards
MCF / BCF: millions / billions of USEPA: United States Environmental
cubic feet Protection Agency
MDth / MMDth: thousands / millions of Throughput: combined gas sales and
dekatherms gas transportation volumes
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
VECTREN CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED CONDENSED BALANCE SHEETS
(Unaudited - In millions)
June 30, December 31,
2003 2002
- ----------------------------------------------- --------- ------------
ASSETS
Current Assets
Cash & cash equivalents $ 16.4 $ 25.1
Accounts receivable-less reserves
of $3.4 & $5.5, respectively 110.5 154.4
Accrued unbilled revenues 40.6 116.1
Inventories 47.0 62.8
Recoverable fuel & natural gas costs 15.4 22.1
Prepayments & other current assets 84.9 93.0
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Total current assets 314.8 473.5
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Utility Plant
Original cost 3,132.8 3,037.1
Less: accumulated depreciation
& amortization 1,434.6 1,389.0
- -----------------------------------------------------------------------------
Net utility plant 1,698.2 1,648.1
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Investments in Unconsolidated Affiliates 164.8 153.3
Other Investments 112.7 124.3
Non-Utility Property-Net 219.3 228.0
Goodwill-Net 202.2 202.2
Regulatory Assets 85.4 75.2
Other Assets 22.8 21.9
- -----------------------------------------------------------------------------
TOTAL ASSETS $ 2,820.2 $ 2,926.5
=============================================================================
The accompanying notes are an integral part of these consolidated condensed
financial statements.
VECTREN CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED CONDENSED BALANCE SHEETS
(Unaudited - In millions)
June 30, December 31,
2003 2002
- ------------------------------------------------------- --------- ------------
LIABILITIES & SHAREHOLDERS' EQUITY
Current Liabilities
Accounts payable $ 45.7 $ 101.7
Accounts payable to affiliated companies 61.4 86.4
Accrued liabilities 101.7 119.9
Short-term borrowings 390.6 399.5
Current maturities of long-term debt - 39.8
Long-term debt subject to tender - 26.6
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Total current liabilities 599.4 773.9
- -------------------------------------------------------------------------------------
Long-term Debt-Net of Current Maturities &
Debt Subject to Tender 980.9 954.2
Deferred Income Taxes & Other Liabilities
Deferred income taxes 203.4 195.5
Deferred credits & other liabilities 137.0 130.8
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Total deferred credits & other liabilities 340.4 326.3
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Minority Interest in Subsidiary 0.3 1.9
Commitments & Contingencies (Notes 8, 9 & 10)
Cumulative, Redeemable Preferred Stock of a Subsidiary 0.2 0.3
Common Shareholders' Equity
Common stock (no par value) - issued & outstanding
68.1 and 67.9, respectively 354.5 350.0
Retained earnings 552.9 530.4
Accumulated other comprehensive income (8.4) (10.5)
- -------------------------------------------------------------------------------------
Total common shareholders' equity 899.0 869.9
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TOTAL LIABILITIES & SHAREHOLDERS' EQUITY $ 2,820.2 $ 2,926.5
=====================================================================================
The accompanying notes are an integral part of these consolidated condensed
financial statements.
VECTREN CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED CONDENSED STATEMENTS OF INCOME
(Unaudited - In millions, except per share data)
Three Months Six Months
Ended June 30, Ended June 30,
---------------- -----------------
2003 2002 2003 2002
- ---------------------------------------- ---------------- -----------------
As Restated, As Restated,
See Note 3 See Note 3
------------ ------------
OPERATING REVENUES
Gas utility $ 165.1 $ 140.1 $ 674.6 $ 498.2
Electric utility 90.2 158.9 209.6 285.7
Energy services & other 28.1 81.1 61.7 226.6
- --------------------------------------------------------------------------------
Total operating revenues 283.4 380.1 945.9 1,010.5
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OPERATING EXPENSES
Cost of gas sold 104.3 81.8 469.4 312.0
Fuel for electric generation 20.6 19.1 41.4 36.9
Purchased electric energy 18.8 86.8 59.2 146.5
Cost of energy services & other 19.1 72.0 44.6 206.8
Other operating 59.6 55.9 122.2 113.6
Depreciation & amortization 32.4 28.7 63.8 57.7
Taxes other than income taxes 11.1 10.2 33.1 28.5
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Total operating expenses 265.9 354.5 833.7 902.0
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OPERATING INCOME 17.5 25.6 112.2 108.5
OTHER INCOME (EXPENSE)
Equity in earnings (losses) of
unconsolidated affiliates (0.1) 3.7 8.7 6.8
Other - net (1.1) 3.1 (2.2) 5.3
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Total other income (expense) (1.2) 6.8 6.5 12.1
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Interest expense 18.2 19.5 37.1 39.3
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INCOME (LOSS) BEFORE INCOME TAXES (1.9) 12.9 81.6 81.3
- --------------------------------------------------------------------------------
Income taxes (5.9) 0.4 21.8 23.4
Minority interest in & preferred dividend
requirements of subsidiaries (0.1) - - (0.2)
- --------------------------------------------------------------------------------
NET INCOME $ 4.1 $ 12.5 $ 59.8 $ 58.1
================================================================================
COMMON SHARES OUTSTANDING:
BASIC 67.8 67.6 67.7 67.5
DILUTED 68.1 67.9 68.0 67.8
EARNINGS PER SHARE OF COMMON STOCK:
BASIC $ 0.06 $ 0.18 $ 0.88 $ 0.86
DILUTED 0.06 0.18 0.88 0.86
DIVIDENDS DECLARED PER SHARE
OF COMMON STOCK 0.28 0.27 0.55 0.53
The accompanying notes are an integral part of these consolidated condensed
financial statements.
VECTREN CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited - In millions)
Six Months Ended June 30,
-------------------------
2003 2002
- ------------------------------------------------------------------------------------------
As Restated,
See Note 3
------------
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 59.8 $ 58.1
Adjustments to reconcile net income to cash from operating
activities:
Depreciation & amortization 63.8 57.7
Deferred income taxes & investment tax credits 4.3 (0.4)
Equity in earnings of unconsolidated affiliates (8.7) (6.8)
Net unrealized (gain) loss on derivative instruments (0.8) 2.9
Pension and postretirement expense 7.0 6.6
Other non-cash charges- net 7.6 1.8
Changes in working capital accounts:
Accounts receivable & accrued unbilled revenue 112.2 98.4
Inventories 15.8 20.4
Recoverable fuel & natural gas costs 6.7 26.2
Prepayments & other current assets 0.3 34.4
Accounts payable, including to affiliated companies (81.0) (36.8)
Accrued liabilities (15.5) (2.1)
Changes in other noncurrent assets 0.6 (2.7)
Changes in other noncurrent liabilities (1.6) (3.5)
- --------------------------------------------------------------------------------------------
Net cash flows from operating activities 170.5 254.2
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CASH FLOWS REQUIRED FOR FINANCING ACTIVITIES
Proceeds from stock option exercises and other stock plans 3.6 1.4
Requirements for:
Retirement of long-term debt, including premiums paid (40.9) (6.3)
Dividends on common stock (37.3) (35.8)
Redemption of preferred stock of subsidiary (0.1) (0.2)
Net change in short-term borrowings (8.9) (116.3)
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Net cash flows required for financing activities (83.6) (157.2)
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CASH FLOWS REQUIRED FOR INVESTING ACTIVITIES
Proceeds from:
Notes receivable & other collections 9.4 3.7
Unconsolidated affiliate distributions 7.6 2.7
Requirements for:
Capital expenditures, excluding AFUDC-equity (99.9) (93.3)
Unconsolidated affiliate investments (8.6) (8.0)
Notes receivable & other investments (4.1) (8.1)
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Net cash flows required for investing activities (95.6) (103.0)
- --------------------------------------------------------------------------------------------
Net decrease in cash & cash equivalents (8.7) (6.0)
Cash & cash equivalents at beginning of period 25.1 25.0
- --------------------------------------------------------------------------------------------
Cash & cash equivalents at end of period $ 16.4 $ 19.0
============================================================================================
The accompanying notes are an integral part of these consolidated condensed
financial statements.
VECTREN CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS
(UNAUDITED)
1. Organization and Nature of Operations
Vectren Corporation (the Company or Vectren), an Indiana corporation, is an
energy and applied technology holding company headquartered in Evansville,
Indiana. The Company was organized on June 10, 1999 solely for the purpose of
effecting the merger of Indiana Energy, Inc. (Indiana Energy) and SIGCORP, Inc.
(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 in accordance with APB Opinion No. 16
"Business Combinations" (APB 16).
The Company's wholly owned subsidiary, Vectren Utility Holdings, Inc. (VUHI),
serves as the intermediate holding company for its three operating public
utilities: Indiana Gas Company, Inc. (Indiana Gas), formerly a wholly owned
subsidiary of Indiana Energy, Southern Indiana Gas and Electric Company
(SIGECO), formerly a wholly owned subsidiary of SIGCORP, and the Ohio
operations. VUHI also has other assets that provide information technology and
other services to the three utilities. Both Vectren and VUHI are exempt from
registration pursuant to Section 3(a) (1) and 3(c) of the Public Utility Holding
Company Act of 1935.
Indiana Gas provides natural gas distribution and transportation services to a
diversified customer base in 49 of Indiana's 92 counties. SIGECO provides
electric generation, transmission, and distribution services to 8 counties in
southwestern Indiana, including counties surrounding Evansville, and
participates in the wholesale power market. SIGECO also provides natural gas
distribution and transportation services to 10 counties in southwestern Indiana,
including counties surrounding Evansville. The Ohio operations, owned as a
tenancy in common by Vectren Energy Delivery of Ohio, Inc.(VEDO), a wholly owned
subsidiary, (53 % ownership) and Indiana Gas (47 % ownership), provide natural
gas distribution and transportation services to 17 counties in west central
Ohio, including counties surrounding Dayton.
The Company is also involved in nonregulated activities in four primary business
areas: Energy Marketing and Services, Coal Mining, Utility Infrastructure
Services, and Broadband. Energy Marketing and Services markets natural gas and
provides energy management services, including energy performance contracting
services. Coal Mining mines and sells coal to the Company's utility operations
and to other parties and generates IRS Code Section 29 investment tax credits
relating to the production of coal-based synthetic fuels. Utility Infrastructure
Services provides underground construction and repair, facilities locating, and
meter reading services. Broadband invests in broadband communication services
such as analog and digital cable television, high-speed Internet and data
services, and advanced local and long distance phone services. In addition, the
nonregulated group has other businesses that provide utility services, municipal
broadband consulting, and retail products and services and that invest in
energy-related opportunities, real estate, and leveraged leases.
2. Basis of Presentation
The interim consolidated 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
note 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 consolidated
condensed 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, 2002, filed on Form 10-K/A. Because of the seasonal nature of
the Company's utility 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.
3. Restatement of Previously Reported Information
Subsequent to the issuance of the Company's 2002 quarterly financial statements,
the Company's management determined that previously issued financial statements
should be restated. The restatement had the effect of decreasing net income for
both the three and six months ended June 30, 2002 by $1.8 million after tax, or
$0.03 on a basic earnings per share basis.
In the second quarter of 2002, the Company recorded $5.2 million ($3.2 million
after tax) of carrying costs for demand side management (DSM) programs pursuant
to existing IURC orders and based on an improved regulatory environment. During
the 2002 annual audit, management determined that the accrual of such carrying
costs was more appropriate in periods prior to 2000 when DSM program
expenditures were made. Therefore, such carrying costs originally reflected in
2002 quarterly results were reversed and reflected in common shareholders'
equity as of January 1, 2000. The Company also identified other adjustments for
various reconciliation errors and other errors related primarily to the
recording of estimates. These adjustments were not significant, either
individually or in the aggregate and increased previously reported pre-tax and
after tax earnings for the three months ended June 30, 2002 by approximately
$2.3 million and $1.4 million, respectively, and increased previously reported
pre-tax and after tax earnings for the six months ended June 30, 2002 by
approximately $2.6 million and $1.4 million (including a $0.2 million tax
adjustment), respectively.
In addition, the Company reduced previously reported energy services and other
revenues and cost of energy services and other by $7.1 million for the three
months ended June 30, 2002 and $12.9 million for the six months ended June 30,
2002, reflecting the adoption of EITF Issue No. 99-19 "Reporting Revenue Gross
as a Principal versus Net as an Agent."
Following is a summary of the effects of the restatement on previously reported
results of operations for the three months ended June 30, 2002.
In millions
- --------------------------------------------------------------------------------------
OPERATING REVENUES As reported Adjustments As Restated
----------- ----------- -----------
Gas utility $ 139.8 $ 0.3 $ 140.1
Electric utility 158.9 - 158.9
Energy services & other 88.2 (7.1) 81.1
- --------------------------------------------------------------------------------------
Total operating revenues 386.9 (6.8) 380.1
- --------------------------------------------------------------------------------------
OPERATING EXPENSES
Cost of gas sold 81.9 (0.1) 81.8
Fuel for electric generation 19.0 0.1 19.1
Purchased electric energy 87.0 (0.2) 86.8
Cost of energy services & other 79.1 (7.1) 72.0
Other operating 57.4 (1.5) 55.9
Depreciation & amortization 28.7 - 28.7
Taxes other than income taxes 10.2 - 10.2
- --------------------------------------------------------------------------------------
Total operating expenses 363.3 (8.8) 354.5
- --------------------------------------------------------------------------------------
OPERATING INCOME 23.6 2.0 25.6
OTHER INCOME
Equity in earnings of unconsolidated
affiliates 3.8 (0.1) 3.7
Other - net 7.7 (4.6) 3.1
- --------------------------------------------------------------------------------------
Total other income 11.5 (4.7) 6.8
- --------------------------------------------------------------------------------------
Interest expense 19.3 0.2 19.5
- --------------------------------------------------------------------------------------
INCOME BEFORE INCOME TAXES 15.8 (2.9) 12.9
- --------------------------------------------------------------------------------------
Income taxes 1.5 (1.1) 0.4
Minority interest in and preferred dividends
requirement of subsidiaries - - -
- --------------------------------------------------------------------------------------
NET INCOME $ 14.3 $ (1.8) $ 12.5
======================================================================================
Following is a summary of the effects of the restatement on previously reported
results of operations for the six months ended June 30, 2002.
In millions
- -------------------------------------------------------------------------------------
OPERATING REVENUES As reported Adjustments As Restated
----------- ----------- -----------
Gas utility $ 496.9 $ 1.3 $ 498.2
Electric utility 285.7 - 285.7
Energy services & other 239.5 (12.9) 226.6
- -------------------------------------------------------------------------------------
Total operating revenues 1,022.1 (11.6) 1,010.5
- -------------------------------------------------------------------------------------
OPERATING EXPENSES
Cost of gas sold 311.9 0.1 312.0
Fuel for electric generation 36.8 0.1 36.9
Purchased electric energy 146.8 (0.3) 146.5
Cost of energy services & other 218.5 (11.7) 206.8
Other operating 114.0 (0.4) 113.6
Depreciation & amortization 57.8 (0.1) 57.7
Taxes other than income taxes 28.5 - 28.5
- -------------------------------------------------------------------------------------
Total operating expenses 914.3 (12.3) 902.0
- -------------------------------------------------------------------------------------
OPERATING INCOME 107.8 0.7 108.5
OTHER INCOME
Equity in earnings of unconsolidated
affiliates 6.1 0.7 6.8
Other - net 9.1 (3.8) 5.3
- -------------------------------------------------------------------------------------
Total other income 15.2 (3.1) 12.1
- -------------------------------------------------------------------------------------
Interest expense 39.1 0.2 39.3
- -------------------------------------------------------------------------------------
INCOME BEFORE INCOME TAXES 83.9 (2.6) 81.3
- -------------------------------------------------------------------------------------
Income taxes 24.2 (0.8) 23.4
Minority interest in and preferred dividends
requirement of subsidiaries (0.2) - (0.2)
- -------------------------------------------------------------------------------------
NET INCOME $ 59.9 $ (1.8) $ 58.1
=====================================================================================
4. Stock-Based Compensation
The Company applies APB Opinion 25, "Accounting for Stock Issued to Employees"
(APB25) and related interpretations when measuring compensation expense for its
stock-based compensation plans.
Stock Option Plans
The exercise price of stock options awarded under the Company's stock option
plans is equal to the fair market value of the underlying common stock on the
date of grant. Accordingly, no compensation expense has been recognized for
stock option plans. In January 2003, 384,500 options to purchase shares of
common stock at an exercise price of $23.19 were issued to management. The grant
vests over three years.
Other Plans
In addition to its stock option plans, the Company also maintains restricted
stock and phantom stock plans for executives and non-employee directors. In
January 2003, 93,000 restricted shares with a fair value per share of $23.19
were issued to management. Those shares vest in 2006.
Compensation expense recognized in the consolidated financial statements
associated with these restricted stock and phantom stock plans for the three
months ended June 30, 2003 and 2002 was $0.7 million ($0.4 million after tax)
and $1.3 million ($0.8 million after tax), respectively, and for the six months
ended June 30, 2003 and 2002 was $1.4 million ($0.9 million after tax) and $1.9
million ($1.2 million after tax), respectively. The amount of expense is
consistent with the amount of expense that would have been recognized if the
Company used the fair value based method described in SFAS No. 123 "Accounting
for Stock Based Compensation" (SFAS 123), as amended, to value these awards.
Pro forma Information
Following is the effect on net income and earnings per share as if the fair
value based method described in SFAS 123 had been applied to the Company's
stock-based compensation plans:
Three Months Six Months
Ended June 30, Ended June 30,
--------------- ---------------
In millions, except per share amounts 2003 2002 2003 2002
- -------------------------------------- --------------- ---------------
Net Income:
As reported $ 4.1 $ 12.5 $ 59.8 $ 58.1
Add: Stock-based employee
compensation included in
reported net income- net of tax 0.4 0.8 0.9 1.2
Deduc: Total stock-based employee
compensation expense determined
under fair value based
method for all awards- net of tax 0.9 1.0 1.6 1.6
- ------------------------------------------------------------------------------
Pro forma $ 3.6 $ 12.3 $ 59.1 $ 57.7
==============================================================================
Basic Earnings Per Share:
As reported $ 0.06 $ 0.18 $ 0.88 $ 0.86
Pro forma 0.05 0.17 0.86 0.84
Diluted Earnings Per Share:
As reported $ 0.06 $ 0.18 $ 0.88 $ 0.86
Pro forma 0.05 0.17 0.86 0.84
5. Earnings Per Share
Basic earnings per share is computed by dividing net income available to common
shareholders by the weighted-average number of common shares outstanding for the
period. Diluted earnings per share assumes the conversion of stock options into
common shares and the lifting of restrictions on issued restricted shares using
the treasury stock method to the extent the effect would be dilutive. The
following tables illustrates the basic and dilutive earnings per share
calculations for the three and six months ended June 30, 2003 and 2002:
Three Months Ended June 30,
--------------------------------------------------------
2003 2002
-------------------------- --------------------------
Per Per
In millions, except Share Share
per share amounts Income Shares Amount Income Shares Amount
- --------------------- ------ ------ ------ ------ ------ ------
Basic EPS $ 4.1 67.8 $ 0.06 $12.5 67.6 $ 0.18
Effect of dilutive
stock equivalents 0.3 0.3
- -------------------------------------------------------------------------------
Diluted EPS $ 4.1 68.1 $ 0.06 $12.5 67.9 $ 0.18
===============================================================================
For the three months ended June 30, 2003 and 2002, options to purchase an
additional 87,963 and 4,200 common shares of the Company's common stock were
outstanding, but were not included in the computation of diluted earnings per
share because their effect would be antidilutive. Exercise prices for options
excluded from the computation ranged from $24.05 to $25.59 in 2003 and equaled
$25.59 in 2002.
Six Months Ended June 30,
--------------------------------------------------------
2003 2002
-------------------------- --------------------------
Per Per
In millions, except Share Share
per share amounts Income Shares Amount Income Shares Amount
- -------------------- ------ ------ ------ ------ ------ ------
Basic EPS $59.8 67.7 $ 0.88 $58.1 67.5 $ 0.86
Effect of dilutive
stock equivalents 0.3 0.3
- -------------------------------------------------------------------------------
Diluted EPS $59.8 68.0 $ 0.88 $58.1 67.8 $ 0.86
===============================================================================
For the six months ended June 30, 2003 and 2002, options to purchase an
additional 530,663 and 22,274 common shares of the Company's common stock were
outstanding, but were not included in the computation of diluted earnings per
share because their effect would be antidilutive. Exercise prices for options
excluded from the computation ranged from $23.19 to $25.59 in 2003 and from
$24.90 to $25.59 in 2002.
6. Comprehensive Income
Comprehensive income consists of the following:
Three Months Six Months
Ended June 30, Ended June 30,
--------------- -----------------
In millions 2003 2002 2003 2002
- --------------------------- ------ ------ ------ -------
Net income $ 4.1 $ 12.5 $ 59.8 $ 58.1
Other comprehensive income
(loss) of unconsolidated
affiliates- net of tax (5.2) 2.1 2.2 (0.2)
- -------------------------------------------------------------------------
Total comprehensive income (loss) $ (1.1) $ 14.6 $ 62.0 $ 57.9
=========================================================================
Other comprehensive income arising from unconsolidated affiliates is the
Company's portion of ProLiance Energy, LLC's and Reliant Services, LLC's
accumulated comprehensive income related to the use of cash flow hedges,
including commodity contracts and interest rate swaps, and the Company's portion
of Haddington Energy Partners, LP's accumulated comprehensive income related to
unrealized gains and losses of "available for sale securities."
7. Transactions with ProLiance Energy, LLC
ProLiance Energy, LLC (ProLiance), a nonregulated energy marketing affiliate of
Vectren and Citizens Gas and Coke Utility (Citizens Gas), provides natural gas
and related services to Indiana Gas, the Ohio operations and Citizens Gas and
also began providing services to SIGECO and Vectren Retail, LLC (the Company's
retail gas marketer) in 2002. ProLiance's primary businesses include gas
marketing, gas portfolio optimization, and other portfolio and energy management
services. ProLiance's primary customers are utilities and other large end use
customers. Vectren's ownership percentage of ProLiance is 61%. Governance and
voting rights remain at 50% for each member. Since governance of ProLiance
remains equal between the members, Vectren continues to account for its
investment in ProLiance using the equity method of accounting.
Purchases from ProLiance for resale and for injections into storage for the
three months ended June 30, 2003 and 2002 totaled $169.2 million and $108.5
million, respectively, and for the six months ended June 30, 2003 and 2002
totaled $434.9 million and $236.3 million, respectively. Amounts owed to
ProLiance at June 30, 2003 and December 31, 2002 for those purchases were $59.2
million and $84.6 million, respectively, and are included in accounts payable to
affiliated companies. Amounts charged by ProLiance for gas supply services are
established by supply agreements with each utility.
8. Commitments & Contingencies
Legal Proceedings
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 9 regarding
environmental matters.
United States Securities and Exchange Commission (SEC) Informal Inquiry
As more fully described in Note 3 to these consolidated condensed financial
statements and in Note 3 to the 2002 consolidated financial statements filed on
Form 10-K/A, the Company restated its consolidated financial statements for
2000, 2001, and quarterly results issued in 2002. The Company is cooperating
with the SEC in an informal inquiry with respect to this previously announced
restatement, has met with the staff of the SEC, and is providing information in
response to their requests.
IRS Section 29 Investment Tax Credit Recent Developments
Vectren's Coal Mining operations are comprised of Vectren Fuels, Inc. (Fuels),
which includes its coal mines and related operations and Vectren Synfuels, Inc.
(Synfuels). Synfuels holds one limited partnership unit (an 8.3% interest) in
Pace Carbon Synfuels Investors, LP (Pace Carbon), a Delaware limited partnership
formed to develop, own, and operate four projects to produce and sell coal-based
synthetic fuel utilizing Covol technology. Under Section 29 of the Internal
Revenue Code, manufacturers such as Pace Carbon, receive a tax credit for every
ton of synthetic fuel sold. To qualify for the credits, the synthetic fuel must
meet three primary conditions: 1) there must be a significant chemical change in
the coal feedstock, 2) the product must be sold to an unrelated person, and 3)
the production facility must have been placed in service before July 1, 1998.
In past rulings, the Internal Revenue Service (IRS) has concluded that the
synthetic fuel produced at the Pace Carbon facilities should qualify for Section
29 tax credits. The IRS issued a private letter ruling with respect to the four
projects on November 11, 1997, and subsequently issued an updated private letter
ruling on September 23, 2002.
As a partner in Pace Carbon, Vectren has reflected total tax credits under
Section 29 in its consolidated results through June 30, 2003 of approximately
$30 million. Vectren has been in a position to fully utilize the credits
generated and continues to project full utilization. In addition, Fuels receives
synfuel-related fees from synfuel producers unrelated to Pace Carbon for a
portion of its coal production.
On June 27, 2003, the IRS, in an industry-wide announcement, stated that it has
reason to question the scientific validity of certain test procedures and
results that have been presented to it by certain taxpayers with an interest in
synfuel operations. Accordingly, the IRS has suspended the issuance of new
private letter rulings. In addition, the IRS indicated that it may revoke
existing private letter rulings that relied on the procedures and results under
review if it determines that those test procedures and results do not
demonstrate that a significant chemical change has occurred. During June 2001,
the IRS began a tax audit of Pace Carbon for the 1998 tax year and later
expanded the audit to include tax years 1999 and 2000. The IRS has requested
numerous extensions to the statute of limitations for the years under audit. It
is expected that the issue of the existence of chemical change will be formally
raised in the Pace Carbon audit.
At this time, Vectren cannot predict the outcome of the IRS' review of the
industry-wide issues, when that review will be completed or the ultimate impact,
if any, of the audit of Pace Carbon relative to Vectren's investments in Pace
Carbon. Vectren believes that it is justified in its reliance on the private
letter rulings for the Pace Carbon facilities, that the test results that Pace
Carbon presented to the IRS in connection with its private letter rulings are
scientifically valid, and that Pace Carbon has operated its facilities in
compliance with its private letter rulings and Section 29 of the Internal
Revenue Code.
Guarantees and Product Warranties
Vectren Corporation issues guarantees to third parties on behalf of its
unconsolidated affiliates. Such guarantees allow those affiliates to execute
transactions on more favorable terms than the affiliate could obtain without
such a guarantee. Guarantees may include posted letters of credit, leasing
guarantees, and performance guarantees. As of June 30, 2003, guarantees issued
and outstanding on behalf of unconsolidated affiliates approximated $2 million.
The Company has also issued a guarantee approximating $4 million related to the
residual value of an operating lease that expires in 2006.
Vectren Corporation has accrued no liabilities for these guarantees as they
relate to guarantees issued among related parties or were executed prior to the
adoption of FASB Interpretation No. 45, "Guarantor's Accounting and Disclosure
Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of
Others" (FIN 45). As more fully described in Note 10, FIN 45 was adopted
prospectively and specifically excludes from its recognition and measurement
provisions guarantees issued among related parties.
Through June 30, 2003, the Company has not been called upon to satisfy any
obligations pursuant to its guarantees. Liabilities accrued for, and activity
related to, product warranties are not significant.
9. Environmental Matters
Clean Air Act
NOx SIP Call Matter
The Clean Air Act (the Act) requires each state to adopt a State Implementation
Plan (SIP) to attain and maintain National Ambient Air Quality Standards (NAAQS)
for a number of pollutants, including ozone. If the USEPA finds a state's SIP
inadequate to achieve the NAAQS, the USEPA can call upon the state to revise its
SIP (a SIP Call).
In October 1998, the 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). This ruling found that the SIP's of certain states, including
Indiana, were substantially inadequate since they allowed for nitrogen oxide
(NOx) emissions in amounts that contributed to non-attainment with the ozone
NAAQS in downwind states. The USEPA required each state to revise its SIP to
provide for further NOx emission reductions. The NOx emissions budget, as
stipulated in the USEPA's final ruling, requires a 31% reduction in total NOx
emissions from Indiana.
In June 2001, the Indiana Air Pollution Control Board adopted final rules to
achieve the NOx emission reductions required by the NOx SIP Call. Indiana's SIP
requires the Company to lower its system-wide NOx emissions to .14 lbs./MMBTU by
May 31, 2004 (the compliance date). This is a 65% reduction from emission levels
existing in 1999 and 1998.
The Company has initiated steps toward compliance with the revised regulations.
These steps include installing Selective Catalytic Reduction (SCR) systems at
Culley Generating Station Unit 3 (Culley), Warrick Generating Station Unit 4,
and A.B. Brown Generating Station Units 1 and 2. SCR systems reduce flue gas NOx
emissions to atmospheric nitrogen and water using ammonia in a chemical
reaction. This technology is known to be the most effective method of reducing
NOx emissions where high removal efficiencies are required.
The IURC has issued orders that approve:
o the Company's proposed project to achieve environmental compliance by
investing in clean coal technology;
o a total capital cost investment for this project up to $244 million
(excluding AFUDC), subject to periodic review of the actual costs incurred;
o a mechanism whereby, prior to an electric base rate case, the Company may
recover through a rider that is updated every six months an 8 percent
return on its capital costs for the project; and
o ongoing recovery of operating costs, including depreciation and purchased
emission allowances through a rider mechanism, related to the clean coal
technology once the facility is in service.
Based on the level of system-wide emissions reductions required and the control
technology utilized to achieve the reductions, the current estimated clean coal
technology construction cost is consistent with amounts approved in the IURC's
orders and is expected to be expended during the 2001-2006 period. Through June
30, 2003, $102.8 million has been expended. After the equipment is installed and
operational, related annual operating expenses, including depreciation expense,
are estimated to be between $24 million and $27 million. Such expenses are
expected to commence later in 2003 when the Culley SCR is operational. The 8
percent return on capital investment approximates the return authorized in the
Company's last electric rate case in 1995 and includes a return on equity.
The Company expects to achieve timely compliance as a result of the project.
Construction of the first SCR at Culley was completed on schedule, and
construction of the Warrick 4 and Brown SCR's is proceeding on schedule.
Installation of SCR technology as planned is expected to reduce the Company's
overall NOx emissions to levels compliant with Indiana's NOx emissions budget
allotted by the USEPA. Therefore, the Company has recorded no accrual for
potential penalties that may result from noncompliance.
Culley Generating Station Litigation
In the late 1990's, 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 review permitting
requirements were triggered by such plant modifications, and whether the best
available control technology was, or should have been used. Numerous electric
utilities were, and are currently, being investigated by the USEPA under an
industry-wide review for compliance. 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 an 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. SIGECO's suit was filed in the U.S. District Court for the
Southern District of Indiana. The USEPA alleged that, beginning in 1992, SIGECO
violated the Act by (1) making modifications to its Culley Generating Station in
Yankeetown, Indiana without obtaining required permits (2) making major
modifications to the Culley Generating Station without installing the best
available emission control technology and (3) failing to notify the USEPA of the
modifications. In addition, the lawsuit alleged that the modifications to the
Culley Generating Station required SIGECO to begin complying with federal new
source performance standards at its Culley Unit 3. The USEPA also issued an
administrative notice of violation to SIGECO making the same allegations, but
alleging that violations began in 1977.
On June 6, 2003, SIGECO, the Department of Justice (DOJ), and the USEPA
announced a proposed agreement that would resolve the lawsuit. The agreement was
embodied in a consent decree filed in U.S. District Court for the Southern
District of Indiana. The mandatory public comment period has expired, and no
comments were received. SIGECO anticipates that the Court will enter the consent
decree.
Under the terms of the proposed agreement, the DOJ and USEPA have agreed to drop
all challenges of past maintenance and repair activities at the Culley
coal-fired units. In reaching the proposed agreement, SIGECO did not admit to
any allegations alleged in the government's complaint, and SIGECO continues to
believe that it acted in accordance with applicable regulations and conducted
only routine maintenance on the units. SIGECO has entered into this proposed
agreement to further its continued commitment to improve air quality and avoid
the cost and uncertainties of litigation.
Under the proposed agreement, SIGECO has committed to:
o either repower Culley Unit 1 (50 MW) with natural gas, which would
significantly reduce air emissions from this unit, and equip it with SCR
control technology for further reduction of nitrogen oxides, or cease
operation of the unit by December of 2006;
o operate the existing SCR control technology recently installed on Culley
Unit 3 (287 MW) year round at a lower emission rate than that currently
required under the NOx SIP Call, resulting in further nitrogen oxide
reductions;
o enhance the efficiency of the existing scrubber at Culley Units 2 and 3 for
additional removal of sulphur dioxide emissions;
o install a baghouse for further particulate matter reductions at Culley Unit
3 by June of 2007;
o conduct a Sulphuric Acid Reduction Demonstration Project as an
environmental mitigation project designed to demonstrate an advance in
pollution control technology for the reduction of sulfate emissions; and
o pay a $600,000 civil penalty.
The Company anticipates that the proposed settlement would result in total
capital expenditures through 2007 in a range between $16 million and $28
million. Other than the $600,000 civil penalty, which was accrued in the second
quarter of 2003, the implementation of the proposed settlement, including these
capital expenditures and related operating expenses, are expected to be
recovered through rates.
Information Request
On January 23, 2001, SIGECO received an information request from the USEPA under
Section 114 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 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 the 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 environmental 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 recorded costs that it reasonably expects to incur
totaling approximately $20.4 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 (PRP), which serve to limit
Indiana Gas' share of response costs at these 19 sites to between 20% and 50%.
With respect to insurance coverage, Indiana Gas has received and recorded
settlements from all known insurance carriers in an aggregate amount
approximating $20.4 million.
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.
In October 2002, the Company received a formal information request letter from
the IDEM regarding five manufactured gas plants owned and/or operated by SIGECO
and not currently enrolled in the IDEM's Voluntary Remediation Program. In
response SIGECO submitted to the IDEM the results of preliminary site
investigations conducted in the mid-1990's. These site investigations confirmed
that based upon the conditions known at the time, the sites posed no risk to
human health or the environment. Follow up reviews have recently been initiated
by the Company to confirm that the sites continue to pose no such risk.
10. Rate and Regulatory Matters
The following is an update on two regulatory matters in Ohio. Each of the
discussed matters is currently pending before the PUCO.
The first matter relates to an application made to the PUCO by VEDO, together
with other regulated Ohio gas utilities, for authority to establish a tariff
mechanism to recover expenses related to uncollectible accounts pursuant to an
automatic adjustment procedure. The application is pending before the PUCO and,
if granted, will enable VEDO to better match revenues with costs associated with
fulfilling its obligation to serve customers who are unable to pay their bills.
Presently, the amount provided for in VEDO's base rates is not adequate to cover
the total expenses relating to uncollectible accounts. The actual positive
impact of the tariff mechanism will vary with the as-billed price of natural gas
and the number of customers who are unable to pay their bills. While the Company
believes there is a sound basis for the PUCO to grant the application to recover
actual expenses relating to uncollectible accounts, no assurance can be provided
with respect to the ultimate outcome of this proceeding.
The second matter concerns the requirement in Ohio that gas utilities, including
VEDO, undergo a biannual audit of their gas acquisition practices in connection
with the gas cost recovery (GCR) mechanism. In the case of VEDO, on or about
August 15, 2003, a third-party consulting firm engaged by the Staff of the PUCO,
is scheduled to conclude an audit report to be filed with the PUCO. The audit
report will provide the results of that firm's review of VEDO's gas acquisition
practices for the biannual period commencing November 1, 2000 (the first day of
operations by VEDO) through October 31, 2002. The audit will provide the initial
opportunity, in the context of a PUCO GCR proceeding, for a review of the
portfolio administration arrangement between VEDO and ProLiance Energy, LLC.
Similar arrangements for the Company's other utility subsidiaries, Indiana Gas
and SIGECO, were previously reviewed and approved by the IURC. VEDO's prior gas
acquisition practices may be challenged in the audit report, including VEDO's
relationship with ProLiance, and, as a result, a gas cost disallowance may be
recommended. Should such a challenge be made, then, by the first of September
2003, VEDO would file its response. If a hearing is necessary, the earliest it
could occur would be mid-September 2003. After that hearing, the PUCO would
consider all of the evidence on the matter and make a determination on the
merits. Throughout this process VEDO could, and likely would, endeavor to engage
in efforts with the participants in the proceeding to resolve disputed issues
outside of administrative litigation. The Company believes that VEDO's gas
acquisition practices that are the subject of the audit were reasonable. If a
challenge is made with respect to VEDO's gas acquisition practices during the
audit period and that challenge was adopted by the PUCO, the Company believes
that it would not be reasonably likely to have a material effect on the
Company's results or financial condition. However, the Company can provide no
assurance as to the ultimate outcome of this proceeding.
11. Impact of Recently Issued Accounting Guidance
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. The Company adopted this statement on
January 1, 2003. The adoption was not material to the Company's results of
operations or financial condition.
In accordance with regulatory treatment, the Company collects an estimated net
cost of removal of its utility plant in rates through normal depreciation. As of
June 30, 2003 and December 31, 2002 such removal costs approximated $385 million
of accumulated depreciation as presented in the condensed consolidated balance
sheets based upon the Company's latest depreciation studies.
SFAS 149
In April 2003, the FASB issued SFAS No. 149, "Amendment of Statement 133 on
Derivative Instruments and Hedging Activities" (SFAS 149). SFAS 149 amends and
clarifies the accounting guidance on (1) derivative instruments (including
certain derivative instruments embedded in other contracts) and (2) hedging
activities that fall within the scope of FASB Statement No. 133 (SFAS 133),
Accounting for Derivative Instruments and Hedging Activities. SFAS 149 amends
SFAS 133 to reflect decisions that were made (1) as part of the process
undertaken by the Derivatives Implementation Group (DIG), which necessitated
amending SFAS 133; (2) in connection with other projects dealing with financial
instruments; and (3) regarding implementation issues related to the application
of the definition of a derivative. SFAS 149 also amends certain other existing
pronouncements, which will result in more consistent reporting of contracts that
are derivatives in their entirety or that contain embedded derivatives that
warrant separate accounting. SFAS 149 is effective (1) for contracts entered
into or modified after June 30, 2003, with certain exceptions and (2) for
hedging relationships designated after June 30. The guidance is to be applied
prospectively. Although management is still evaluating the impact of SFAS 149 on
its financial position and results of operations, the adoption is not expected
to have a material effect.
SFAS 150
In May 2003, the FASB issued SFAS No. 150, "Accounting for Certain Financial
Instruments with Characteristics of Both Liabilities and Equity" (SFAS 150).
SFAS 150 requires issuers to classify as liabilities the following three types
of freestanding financial instruments: mandatorily redeemable financial
instruments; obligations to repurchase the issuer's equity shares by
transferring assets; and certain obligations to issue a variable number of
shares. SFAS 150 is effective immediately for all financial instruments entered
into or modified after May 31, 2003. For all other instruments, SFAS 150 applies
to the Company's third quarter of 2003. The Company has approximately $200,000
of outstanding preferred stock of a subsidiary that is redeemable on terms
outside the Company's control. However, the preferred stock is not redeemable on
a specified or determinable date or upon an event that is certain to occur.
Therefore, SFAS 150's adoption will not affect the Company's results of
operations or financial condition.
FIN 45
In November 2002, the FASB issued FIN 45. FIN 45 clarifies the requirements for
a guarantor's accounting for and disclosure of certain guarantees issued and
outstanding and that a guarantor is required to recognize, at the inception of a
guarantee, a liability for the fair value of the obligations it has undertaken.
The initial recognition and measurement provisions are applicable on a
prospective basis to guarantees issued or modified after December 31, 2002.
Since that date, the adoption has not had a material effect on the Company's
results of operations or financial condition. The incremental disclosure
requirements are included in these financial statements in Note 8.
FIN 46
In January 2003, the FASB issued Interpretation 46, "Consolidation of Variable
Interest Entities" (FIN 46). FIN 46 addresses consolidation by business
enterprises of variable interest entities and significantly changes the
consolidation requirements for those entities. FIN 46 is intended to achieve
more consistent application of consolidation policies to variable interest
entities and, thus improves comparability between enterprises engaged in similar
activities when those activities are conducted through variable interest
entities. FIN 46 applies to variable interest entities created after January 31,
2003 and to variable interest entities in which an enterprise obtains an
interest after that date. FIN 46 applies to the Company's third quarter of 2003
for variable interest entities in which the Company holds a variable interest
acquired before February 1, 2003. Although management is still evaluating the
impact of FIN 46 on its financial position and results of operations, the
adoption is not expected to have a material effect.
12. Segment Reporting
The Company has four operating segments: 1) Gas Utility Services, (2) Electric
Utility Services, (3) Nonregulated Operations, and (4) Corporate and Other. The
Gas Utility Services segment provides natural gas distribution and
transportation services in nearly two-thirds of Indiana and west central Ohio.
The Electric Utility Services segment includes the operations of SIGECO's
electric transmission and distribution services, which provides electricity
primarily to southwestern Indiana, and SIGECO's power generating and power
marketing operations. The Company collectively refers to its gas and electric
utility services segments as its Regulated Operations. Segments within the
Regulated Operations use operating income as a measure of profitability.
The Nonregulated Operations segment is comprised of various subsidiaries and
affiliates offering and investing in energy marketing and services, coal mining,
utility infrastructure services, and broadband communications among other
energy-related opportunities. The Corporate and Other segment, among other
activities, provides general and administrative support and assets, including
computer hardware and software, to the Company's other operating segments. The
Nonregulated Operations and Corporate and Other segments use net income as a
measure of profitability. The Company makes decisions on finance and dividends
at the corporate level.
Following is information regarding the Company's segments' operating data.
Three Months Six Months
Ended June 30, Ended June 30,
---------------------- ---------------------
In millions 2003 2002 2003 2002
- --------------------------------------- --------- --------- ------- ---------
Operating Revenues
Gas Utility Services $ 165.1 $ 140.1 $ 674.6 $ 498.2
Electric Utility Services 90.2 158.9 209.6 285.7
- -----------------------------------------------------------------------------------------
Total Regulated 255.3 299.0 884.2 783.9
- -----------------------------------------------------------------------------------------
Nonregulated Operations 47.7 97.0 100.9 256.5
Corporate & Other 6.8 5.6 13.7 11.4
Intersegment Eliminations (26.4) (21.5) (52.9) (41.3)
- -----------------------------------------------------------------------------------------
Total operating revenues $ 283.4 $ 380.1 $ 945.9 $ 1,010.5
=========================================================================================
Measure of Profitability
Operating Income
Gas Utility Services $ 0.2 $ 4.7 $ 69.5 $ 66.8
Electric Utility Services 15.3 18.4 39.2 34.8
- -----------------------------------------------------------------------------------------
Total Regulated operating income 15.5 23.1 108.7 101.6
- -----------------------------------------------------------------------------------------
Regulated other income (expense)-net 0.1 2.2 (1.0) 4.2
Regulated interest expense (15.4) (15.7) (30.9) (31.6)
Regulated income taxes (1.4) (2.5) (30.9) (25.9)
- -----------------------------------------------------------------------------------------
Regulated net income (loss) (1.2) 7.1 45.9 48.3
- -----------------------------------------------------------------------------------------
Nonregulated net income 3.4 4.4 11.9 8.8
Corporate & other net income 1.9 1.0 2.0 1.0
- -----------------------------------------------------------------------------------------
Net income $ 4.1 $ 12.5 $ 59.8 $ 58.1
=========================================================================================
Following is the Company's segments' identifiable assets.
June 30, December 31,
In millions 2003 2002
- ----------------------------------------------------- ----------
Identifiable Assets
Gas Utility Services $ 1,413.8 $ 1,570.1
Electric Utility Services 871.7 869.2
- ------------------------------------------------------------------
Total Regulated 2,285.5 2,439.3
- ------------------------------------------------------------------
Nonregulated Operations 404.4 419.6
Corporate & Other 373.0 393.3
Intersegment Eliminations (242.7) (325.7)
- ------------------------------------------------------------------
Total identifiable assets $ 2,820.2 $ 2,926.5
==================================================================
13. Subsequent Events
Equity Issuance
In August 2003, the Company completed a public offering of 6.5 million shares of
its common stock, which was priced at $22.81 per share to yield total gross
proceeds $148.3 million. The Company also has granted the underwriters a 30-day
option to purchase up to an additional 975,000 shares of the Company's common
stock at the public offering price to cover over-allotments, if any. The public
offering of the shares closed on August 13, 2003 with net proceeds of
approximately $143 million (excluding any proceeds from an over-allotment
option).
VUHI Debt Issuance
In July 2003, VUHI issued senior unsecured notes with an aggregate principal
amount of $200 million in two $100 million tranches. The first tranche are
10-year notes due August 2013, with an interest rate of 5.25% priced at 99.746%
to yield 5.28% to maturity (2013 Notes). The second tranche are 15-year notes
due August 2018 with an interest rate of 5.75% priced at 99.177% to yield 5.80%
to maturity (2018 Notes).
The notes are jointly and severally guaranteed by the Company's three public
utilities. In addition, they have no sinking fund requirements, and interest
payments are due semi-annually. The notes may be called by the Company, in whole
or in part, at any time for an amount equal to accrued and unpaid interest, plus
the greater of 100% of the principal amount or the sum of the present values of
the remaining scheduled payments of principal and interest, discounted to the
redemption date on a semi-annual basis at the Treasury Rate, as defined in the
indenture, plus 20 basis points for the 2013 Notes and 25 basis points for the
2018 Notes.
Shortly before these issues, the Company entered into several treasury locks
with a total notional amount of $150.0 million. Upon issuance of the debt, the
treasury locks were settled resulting in the Company receiving $5.7 million. The
value received will be amortized as a reduction of interest expense over the
life of the issues.
The net proceeds from the sale of the senior notes and settlement of related
hedging arrangements approximated $203 million.
SIGECO and Indiana Gas Debt Call
In August 2003, the Company initiated steps to call two first mortgage bonds
outstanding at SIGECO and a senior unsecured note outstanding at Indiana Gas.
The first SIGECO bond has a principal amount of $45.0 million, an interest rate
of 7.60%, was originally due in 2023, and may be redeemed at 103.745% of its
stated principal amount. The second SIGECO bond has a principal amount of $20.0
million, an interest rate of 7.625%, was originally due in 2025, and may be
redeemed at 103.763% of the stated principal amount. The Indiana Gas note has a
principal amount of $13.5 million, an interest rate of 6.75%, was originally due
in 2028, and may be redeemed at the principal amount. These transactions are
expected to take place in September 2003. Pursuant to regulatory authority, the
premium paid to retire the net carrying value of these notes will be deferred as
a regulatory asset.
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF OPERATIONS AND
FINANCIAL CONDITION
Description of the Business
Vectren Corporation (the Company or Vectren), an Indiana corporation, is an
energy and applied technology holding company headquartered in Evansville,
Indiana. The Company was organized on June 10, 1999 solely for the purpose of
effecting the merger of Indiana Energy, Inc. (Indiana Energy) and SIGCORP, Inc.
(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 in accordance with APB Opinion No. 16
"Business Combinations" (APB 16).
The Company's wholly owned subsidiary, Vectren Utility Holdings, Inc. (VUHI),
serves as the intermediate holding company for its three operating public
utilities: Indiana Gas Company, Inc. (Indiana Gas), formerly a wholly owned
subsidiary of Indiana Energy, Southern Indiana Gas and Electric Company
(SIGECO), formerly a wholly owned subsidiary of SIGCORP, and the Ohio
operations. VUHI also has other assets that provide information technology and
other services to the three utilities. Both Vectren and VUHI are exempt from
registration pursuant to Section 3(a)(1) and 3(c) of the Public Utility Holding
Company Act of 1935.
Indiana Gas provides natural gas distribution and transportation services to a
diversified customer base in 49 of Indiana's 92 counties. SIGECO provides
electric generation, transmission, and distribution services to 8 counties in
southwestern Indiana, including counties surrounding Evansville, and
participates in the wholesale power market. SIGECO also provides natural gas
distribution and transportation services to 10 counties in southwestern Indiana,
including counties surrounding Evansville. The Ohio operations, owned as a
tenancy in common by Vectren Energy Delivery of Ohio, Inc.(VEDO), a wholly owned
subsidiary, (53 % ownership) and Indiana Gas (47 % ownership), provide natural
gas distribution and transportation services to 17 counties in west central
Ohio, including counties surrounding Dayton.
The Company is also involved in nonregulated activities in four primary business
areas: Energy Marketing and Services, Coal Mining, Utility Infrastructure
Services, and Broadband. Energy Marketing and Services markets natural gas and
provides energy management services, including energy performance contracting
services. Coal Mining mines and sells coal to the Company's utility operations
and to other parties and generates IRS Code Section 29 investment tax credits
relating to the production of coal-based synthetic fuels. Utility Infrastructure
Services provides underground construction and repair, facilities locating, and
meter reading services. Broadband invests in broadband communication services
such as analog and digital cable television, high-speed Internet and data
services, and advanced local and long distance phone services. In addition, the
nonregulated group has other businesses that provide utility services, municipal
broadband consulting, and retail products and services and that invest in
energy-related opportunities, real estate, and leveraged leases.
Consolidated Results of Operations
The following discussion and analysis should be read in conjunction with the
unaudited condensed consolidated financial statements and notes thereto.
Subsequent to the issuance of the Company's 2002 quarterly financial statements,
the Company's management determined that previously issued financial statements
should be restated. The restatement had the effect of decreasing net income for
both the three and six months ended June 30, 2002 by $1.8 million after tax.
Note 3 to the consolidated condensed financial statements includes a summary of
the effects of the restatement. The Company's results of operations give effect
to the restatement.
Three Months Six Months
Ended June 30, Ended June 30,
---------------------- ---------------------
In millions, except
per share amounts 2003 2002 2003 2002
- -------------------------------- ---------------------- ---------------------
As Restated As Restated
----------- -----------
Net income $ 4.1 $ 12.5 $ 59.8 $ 58.1
Attributed to:
Utility Group $ 1.4 $ 8.7 $ 48.7 $ 50.7
Nonregulated Group 3.4 4.4 11.9 8.8
Corporate & Other Group (0.7) (0.6) (0.8) (1.4)
- ----------------------------------------------------------------------------
Basic earnings per share $ 0.06 $ 0.18 $ 0.88 $ 0.86
Attributed to:
Utility Group $ 0.02 $ 0.13 $ 0.72 $ 0.75
Nonregulated Group 0.05 0.06 0.18 0.13
Corporate & Other Group (0.01) (0.01) (0.02) (0.02)
Net Income
For the three months ended June 30, 2003, net income was $4.1 million, or $0.06
per share, compared to net income of $12.5 million, or $0.18 per share, for the
same period last year. For the six months ended June 30, 2003, reported earnings
were $59.8 million, or $0.88 per share, compared to $58.1 million, or $0.86 per
share, for the same period in 2002.
The 2003 second quarter results declined $0.10 per share as compared to the same
period in 2002 due to milder weather affecting both heating and cooling sales
and the write-off of two investments. Heating weather experienced in the second
quarter 2003 was 9% warmer than the same period last year and cooling sales were
reduced by weather 51% milder than the same period in 2002. The estimated
quarter over quarter impact of milder weather was $4.3 million after tax, or
$0.06 per share.
The 2003 results include the write-off of the Company's investment in BABB
International, Inc. (BABB), an entity that processes fly ash into building
materials. Charges of $1.9 million, pre-tax and $2.0 million, pre-tax were
recorded in the second and first quarters, respectively, of 2003. The second
quarter 2003 also includes the write-off of $2.0 million pre-tax of the
investment in First Mile Technologies (First Mile), a small broadband entity
located in Indianapolis, Indiana. The write-off of both investments reduced net
income for the second quarter by $2.3 million, or $0.04 per share, and the first
six months by $3.5 million, or nearly $0.06 per share.
Dividends
Dividends declared for the three months ended June 30, 2003 were $0.275 per
share compared to $0.265 per share for the same period in 2002. Dividends
declared for the six months ended June 30, 2003 were $0.550 per share compared
to $0.530 per share for the same period in 2002.
Detailed Discussion of Results of Operations
Following is a more detailed discussion of the results of operations of the
Company's Utility Group and Nonregulated Group. The detailed results of
operations for the Utility Group and Nonregulated Group are presented and
analyzed before the reclassification and elimination of certain intersegment
transactions necessary to consolidate those results into the Company's
Consolidated Condensed Statements of Income. The operations of the Corporate and
Other Group are not significant.
Results of Operations of the Utility Group
The Utility Group is comprised of Vectren Utility Holdings, Inc.'s operations,
which consist of the Company's regulated operations (the Gas Utility Services
and Electric Utility Services operating segments), and components of the
Corporate and Other operating segment. Gas Utility Services provides natural gas
distribution and transportation services in nearly two-thirds of Indiana and
west central Ohio. Electric Utility Services provides electricity primarily to
southwestern Indiana, and includes the Company's power generating and marketing
operations. Corporate and Other Operations provides information technology and
other support services to those utility operations. The results of operations of
the Utility Group before certain intersegment eliminations and reclassifications
for the three and six months ended June 30, 2003 and 2002 follow.
Three Months Six Months
Ended June 30, Ended June 30,
----------------- -----------------
In millions, except
per share amounts 2003 2002 2003 2002
- ------------------------------------ ------- ------- ------- -------
OPERATING REVENUES
Gas revenues $ 165.1 $ 140.1 $ 674.6 $ 498.2
Electric revenues 90.2 158.9 209.6 285.7
Other revenues 0.2 0.1 0.4 0.2
- -----------------------------------------------------------------------------
Total operating revenues 255.5 299.1 884.6 784.1
- -----------------------------------------------------------------------------
OPERATING EXPENSES
Cost of gas 104.3 82.1 469.4 312.6
Fuel for electric generation 20.6 19.1 41.4 36.9
Purchased electric energy 18.8 86.8 59.2 146.5
Other operating 53.9 48.8 110.5 100.1
Depreciation & amortization 29.6 26.3 58.4 53.1
Taxes other than income taxes 10.9 10.0 32.6 28.1
- -----------------------------------------------------------------------------
Total operating expenses 238.1 273.1 771.5 677.3
- -----------------------------------------------------------------------------
OPERATING INCOME 17.4 26.0 113.1 106.8
OTHER INCOME (EXPENSE) - NET
Equity in losses of unconsolidated
affiliates 0.1 (0.4) (0.4) (0.5)
Other - net 0.2 3.7 (1.3) 5.8
- -----------------------------------------------------------------------------
Total other income (expense) - net 0.3 3.3 (1.7) 5.3
- -----------------------------------------------------------------------------
Interest expense 15.9 17.3 32.4 34.9
- -----------------------------------------------------------------------------
INCOME BEFORE INCOME TAXES 1.8 12.0 79.0 77.2
- -----------------------------------------------------------------------------
Income taxes 0.4 3.3 30.3 26.5
- -----------------------------------------------------------------------------
NET INCOME $ 1.4 $ 8.7 $ 48.7 $ 50.7
=============================================================================
BASIC EARNINGS PER SHARE $ 0.02 $ 0.13 $ 0.72 $ 0.75
=============================================================================
Utility Group earnings for the second quarter 2003 were $1.4 million as compared
to $8.7 million for the same quarter last year. As noted previously, the primary
contributors to the decline are electric cooling weather that was significantly
below normal in the 2003 quarter and the write-off of the BABB investment.
Utility Group earnings for the six months ended June 30, 2003 were $48.7 million
as compared to $50.7 million for the same period in 2002. Earnings in 2003 were
primarily driven by weather that on the year was favorably impacted by an
estimated $5.4 million after tax compared to last year and increased wholesale
and other margins, offset by the BABB investment write-off of $2.3 million after
tax and increased other operating costs.
Significant Fluctuations
Utility Margin
Gas Utility Margin
Gas utility margin by customer type and separated between volumes sold and
transported follows:
Three Months Six Months
Ended June 30, Ended June 30,
---------------- -----------------
In millions 2003 2002 2003 2002
- ------------------------ ---------------- -----------------
Residential $ 38.7 $ 34.9 $ 132.5 $ 119.8
Commercial 10.0 13.7 42.5 40.6
Contract 8.8 8.6 24.4 23.6
Other 3.3 0.8 5.8 1.6
- ------------------------------------------------------------
Total gas margin $ 60.8 $ 58.0 $ 205.2 $ 185.6
============================================================
Volumes in MMDth
Sold 14.6 15.9 78.5 67.6
Transported 17.6 19.3 45.8 46.2
- ------------------------------------------------------------
Total throughput 32.2 35.2 124.3 113.8
============================================================
Gas margins were $60.8 million, an increase of $2.8 million over the same
quarter in 2002. The increase is primarily due to increased late payment
charges, an increase in Ohio's percent of income payment plan (PIPP) rate
recovery rider, recovery of Ohio customer choice implementation costs, recovery
of gross receipts and excise taxes on higher gas costs, and other items. The
increase was partially offset by heating weather which was normal and 9% warmer
than the prior year period. The estimated quarter over quarter impact of the
warmer weather on gas utility margins was a decrease of approximately $3.3
million. Weather and an overall decline in customer usage were the primary
factors resulting in the 8% decrease in throughput.
Gas margins were $205.2 million, an increase of $19.6 million over the first six
months of 2002. It is estimated that weather, 17% colder than the prior year and
7% colder than normal, contributed $12.0 million to the increased margin. The
remaining $7.6 million increase is primarily attributable to gross receipts and
excise taxes, increased late payment fees, and recovery of Ohio customer choice
implementation costs. The colder weather is the primary reason for the 9%
increase in throughput.
Higher gas costs and a slowly recovering economy have impacted customer usage.
The total average cost per dekatherm of gas purchased for the three and six
months ended June 30, 2003, was $6.48 and $6.51, respectively, compared to $4.46
for both periods in 2002.
Electric Utility Margin
Electric utility margin by customer type and non-firm wholesale margin separated
between realized margin and mark-to-market gains and losses follows:
Three Months Six Months
Ended June 30, Ended June 30,
--------------- ---------------
In millions 2003 2002 2003 2002
- ---------------------------- --------------- ---------------
Retail & firm wholesale $ 46.9 $ 51.0 $ 96.9 $ 99.2
Non-firm wholesale 3.9 2.0 12.1 3.1
- --------------------------------------------------------------------
Total electric margin $ 50.8 $ 53.0 $109.0 $102.3
====================================================================
Non-firm wholesale margin:
Realized margin $ 4.0 $ 2.0 $ 11.3 $ 6.0
Mark-to-market gains (losses) (0.1) - 0.8 (2.9)
Electric margins were $50.8 million, a decrease of $2.2 million compared to the
second quarter of 2002. The decrease in electric margin was due primarily to the
effect of milder cooling weather which was 43% cooler than normal and 51% cooler
than last year, offset by increased margins from wholesale power activities. The
estimated quarter over quarter decrease as a result of the milder weather on
electric utility margins was approximately $3.9 million. As a result of the mild
weather, volumes sold to retail and firm wholesale customers decreased 7% from
1.49 GWh in 2002 to 1.39 GWh in 2003. Non-firm wholesale electric utility
margins increased $1.9 million to $3.9 million in 2003 compared to 2002.
Electric margins were $109.0 million, an increase of $6.7 million over the first
six months of 2002 primarily due to increased non-firm wholesale power activity
resulting from price volatility, offset by lower retail sales due to milder
cooling weather. As a result of the mild weather which was 44% cooler than
normal and 51% cooler than last year, volumes sold to retail and firm wholesale
customers decreased 3% from 2.89 GWh in 2002 to 2.81 GWh in 2003 with an
estimated margin decrease of $2.9 million. Non-firm wholesale margins were $12.1
million, an increase of $9.0 million over 2002.
Periodically, generation capacity is in excess of that needed to serve retail
and firm wholesale customers. The Company markets this unutilized capacity to
optimize the return on its owned generation assets. The contracts entered into
are primarily short-term purchase and sale transactions that expose the Company
to limited market risk. For the three months ended June 30, 2003, volumes sold
into the wholesale market were 0.58 GWh compared to 3.17 GWh in 2002 while
volumes purchased from the wholesale market were 1.23 GWh in 2003 compared to
3.16 GWh in 2002. For the six months ended June 30, 2003 volumes sold into the
wholesale market were 2.02 GWh compared to 5.63 GWh in 2002 while volumes
purchased from the wholesale market were 2.48 GWh in 2003 compared to 5.49 GWh
in 2002. A portion of volumes purchased in the wholesale market is used to serve
retail and firm wholesale customers. In 2003, greater amounts of purchased power
have been required for native load due to scheduled outages and installation of
NOx equipment. While volumes both sold and purchased in the wholesale market
have decreased during 2003, which has resulted in decreased electric revenues
and purchased power, margins increased as noted above primarily from price
volatility.
Utility Group Operating Expenses
Other Operating
For the three and six months ended June 30, 2003, other operating expenses
increased $5.1 million and $10.4 million, respectively, compared to the same
periods in the prior year. The increased expenses were principally due to higher
uncollectible accounts expenses, the timing of electric plant maintenance
expenditures, and other costs such as PIPP and Ohio customer choice costs that
are recovered through margins. Year-to-date uncollectible accounts expense has
increased $2.7 million compared to the prior year.
Depreciation & Amortization
For the three and six months ended June 30, 2003, depreciation and amortization
increased $3.3 million and $5.3 million, respectively, due to additions to
utility plant. Since June 30, 2002, the Company has placed into service over
$100 million in utility plant including a new gas-fired peaker unit,
expenditures for implementing a choice program for Ohio gas customers, and other
upgrades to existing transmission and distribution facilities.
Taxes Other Than Income Taxes
For the three and six months ended June 30, 2003, taxes other than income taxes
increased $0.9 million and $4.5 million, respectively, compared to the prior
year. The increase results from higher utility receipts and excise taxes as a
result of higher gas prices and for the year to date period more volumes sold.
Utility Group Other Income (Expense)-Net
For the three and six months ended June 30, 2003, other income (expense)-net
decreased $3.0 million and $7.0 million, respectively, compared to the prior
year. The decreases are primarily the result of the write-off of the BABB
investment ($1.9 million for the quarter and $3.9 million for the year to date).
The remaining decreases result principally from sales of emission allowances and
other assets in the second quarter of 2002 totaling $1.8 million. Year to date
results are also affected by contributions of $1.2 million made in 2003 to low
income customer assistance programs resulting from the ProLiance settlement
previously approved by the IURC.
Utility Group Interest Expense
For the three and six months ended June 30, 2003, interest expense decreased
$1.4 million and $2.5 million, respectively, when compared to the same periods
last year. The decreases result primarily from lower interest rates. This was
partially offset by higher outstanding balances due primarily to funding of
capital expenditures and increased working capital requirements resulting from
the higher gas prices experienced during late 2002 and 2003.
Utility Group Income Tax
For the three months ended June 30, 2003, federal and state income taxes
decreased $2.9 million and for the six months ended June 30, 2003 increased $3.8
million when compared to 2002. The changes are primarily due to fluctuations in
pre-tax income. Year to date, the effective tax rate increased from 34.3% in
2002 to 38.4% in 2003 principally due to an increase in the Indiana state income
tax rate from 4.5 % to 8.5% that was effective January 1, 2003.
Environmental Matters
Clean Air Act
NOx SIP Call Matter
The Clean Air Act (the Act) requires each state to adopt a State Implementation
Plan (SIP) to attain and maintain National Ambient Air Quality Standards (NAAQS)
for a number of pollutants, including ozone. If the USEPA finds a state's SIP
inadequate to achieve the NAAQS, the USEPA can call upon the state to revise its
SIP (a SIP Call).
In October 1998, the 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). This ruling found that the SIP's of certain states, including
Indiana, were substantially inadequate since they allowed for nitrogen oxide
(NOx) emissions in amounts that contributed to non-attainment with the ozone
NAAQS in downwind states. The USEPA required each state to revise its SIP to
provide for further NOx emission reductions. The NOx emissions budget, as
stipulated in the USEPA's final ruling, requires a 31% reduction in total NOx
emissions from Indiana.
In June 2001, the Indiana Air Pollution Control Board adopted final rules to
achieve the NOx emission reductions required by the NOx SIP Call. Indiana's SIP
requires the Company to lower its system-wide NOx emissions to .14 lbs./MMBTU by
May 31, 2004 (the compliance date). This is a 65% reduction from emission levels
existing in 1999 and 1998.
The Company has initiated steps toward compliance with the revised regulations.
These steps include installing Selective Catalytic Reduction (SCR) systems at
Culley Generating Station Unit 3 (Culley), Warrick Generating Station Unit 4,
and A.B. Brown Generating Station Units 1 and 2. SCR systems reduce flue gas NOx
emissions to atmospheric nitrogen and water using ammonia in a chemical
reaction. This technology is known to be the most effective method of reducing
NOx emissions where high removal efficiencies are required.
The IURC has issued orders that approve:
o the Company's proposed project to achieve environmental compliance by
investing in clean coal technology;
o a total capital cost investment for this project up to $244 million
(excluding AFUDC), subject to periodic review of the actual costs incurred;
o a mechanism whereby, prior to an electric base rate case, the Company may
recover through a rider that is updated every six months an 8 percent
return on its capital costs for the project; and
o ongoing recovery of operating costs, including depreciation and purchased
emission allowances through a rider mechanism, related to the clean coal
technology once the facility is placed into service.
Based on the level of system-wide emissions reductions required and the control
technology utilized to achieve the reductions, the current estimated clean coal
technology construction cost is consistent with amounts approved in the IURC's
orders and is expected to be expended during the 2001-2006 period. Through June
30, 2003, $102.8 million has been expended. After the equipment is installed and
operational, related annual operating expenses, including depreciation expense,
are estimated to be between $24 million and $27 million. Such expenses are
expected to commence later in 2003 when the Culley SCR is operational. The 8
percent return on capital investment approximates the return authorized in the
Company's last electric rate case in 1995 and includes a return on equity.
The Company expects to achieve timely compliance as a result of the project.
Construction of the first SCR at Culley was completed on schedule, and
construction of the Warrick 4 and Brown SCRs is proceeding on schedule.
Installation of SCR technology as planned is expected to reduce the Company's
overall NOx emissions to levels compliant with Indiana's NOx emissions budget
allotted by the USEPA. Therefore, the Company has recorded no accrual for
potential penalties that may result from noncompliance.
Culley Generating Station Litigation
In the late 1990's, 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 review permitting
requirements were triggered by such plant modifications, and whether the best
available control technology was, or should have been used. Numerous electric
utilities were, and are currently, being investigated by the USEPA under an
industry-wide review for compliance. 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 an 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. SIGECO's suit was filed in the U.S. District Court for the
Southern District of Indiana. The USEPA alleged that, beginning in 1992, SIGECO
violated the Act by (1) making modifications to its Culley Generating Station in
Yankeetown, Indiana without obtaining required permits (2) making major
modifications to the Culley Generating Station without installing the best
available emission control technology and (3) failing to notify the USEPA of the
modifications. In addition, the lawsuit alleged that the modifications to the
Culley Generating Station required SIGECO to begin complying with federal new
source performance standards at its Culley Unit 3. The USEPA also issued an
administrative notice of violation to SIGECO making the same allegations, but
alleging that violations began in 1977.
On June 6, 2003, SIGECO, the Department of Justice (DOJ), and the USEPA
announced a proposed agreement that would resolve the lawsuit. The agreement was
embodied in a consent decree filed in U.S. District Court for the Southern
District of Indiana. The mandatory public comment period has expired, and no
comments were received. SIGECO anticipates that the Court will enter the consent
decree.
Under the terms of the proposed agreement, the DOJ and USEPA have agreed to drop
all challenges of past maintenance and repair activities at the Culley
coal-fired units. In reaching the proposed agreement, SIGECO did not admit to
any allegations alleged in the government's complaint, and SIGECO continues to
believe that it acted in accordance with applicable regulations and conducted
only routine maintenance on the units. SIGECO has entered into this proposed
agreement to further its continued commitment to improve air quality and avoid
the cost and uncertainties of litigation.
Under the proposed agreement, SIGECO has committed to:
o either repower Culley Unit 1 (50 MW) with natural gas, which would
significantly reduce air emissions from this unit, and equip it with SCR
control technology for further reduction of nitrogen oxides, or cease
operation of the unit by December of 2006;
o operate the existing SCR control technology recently installed on Culley
Unit 3 (287 MW) year round at a lower emission rate than that currently
required under the NOx SIP Call, resulting in further nitrogen oxide
reductions;
o enhance the efficiency of the existing scrubber at Culley Units 2 and 3 for
additional removal of sulphur dioxide emissions;
o install a baghouse for further particulate matter reductions at Culley Unit
3 by June of 2007; o conduct a Sulphuric Acid Reduction Demonstration
Project as an environmental mitigation project designed to demonstrate an
advance in pollution control technology for the reduction of sulfate
emissions; and
o pay a $600,000 civil penalty.
The Company anticipates that the proposed settlement would result in total
capital expenditures through 2007 in a range between $16 million and $28
million. Other than the $600,000 civil penalty, which was accrued in the second
quarter of 2003, the implementation of the proposed settlement, including these
capital expenditures and related operating expenses, are expected to be
recovered through rates.
Information Request
On January 23, 2001, SIGECO received an information request from the USEPA under
Section 114 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 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 the 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 environmental 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 recorded costs that it reasonably expects to incur
totaling approximately $20.4 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 (PRP), which serve to limit
Indiana Gas' share of response costs at these 19 sites to between 20% and 50%.
With respect to insurance coverage, Indiana Gas has received and recorded
settlements from all known insurance carriers in an aggregate amount
approximating $20.4 million.
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.
In October 2002, the Company received a formal information request letter from
the IDEM regarding five manufactured gas plants owned and/or operated by SIGECO
and not currently enrolled in the IDEM's Voluntary Remediation Program. In
response SIGECO submitted to the IDEM the results of preliminary site
investigations conducted in the mid-1990's. These site investigations confirmed
that based upon the conditions known at the time, the sites posed no risk to
human health or the environment. Follow-up reviews have recently been initiated
by the Company to confirm that the sites continue to pose no such risk.
Rate and Regulatory Matters
The following is an update on two regulatory matters in Ohio. Each of the
discussed matters is currently pending before the PUCO.
The first matter relates to an application made to the PUCO by VEDO, together
with other regulated Ohio gas utilities, for authority to establish a tariff
mechanism to recover expenses related to uncollectible accounts pursuant to an
automatic adjustment procedure. The application is pending before the PUCO and,
if granted, will enable VEDO to better match revenues with costs associated with
fulfilling its obligation to serve customers who are unable to pay their bills.
Presently, the amount provided for in VEDO's base rates is not adequate to cover
the total expenses relating to uncollectible accounts. The actual positive
impact of the tariff mechanism will vary with the as-billed price of natural gas
and the number of customers who are unable to pay their bills. While the Company
believes there is a sound basis for the PUCO to grant the application to recover
actual expenses relating to uncollectible accounts, no assurance can be provided
with respect to the ultimate outcome of this proceeding.
The second matter concerns the requirement in Ohio that gas utilities, including
VEDO, undergo a biannual audit of their gas acquisition practices in connection
with the gas cost recovery (GCR) mechanism. In the case of VEDO, on or about
August 15, 2003, a third-party consulting firm engaged by the Staff of the PUCO,
is scheduled to conclude an audit report to be filed with the PUCO. The audit
report will provide the results of that firm's review of VEDO's gas acquisition
practices for the biannual period commencing November 1, 2000 (the first day of
operations by VEDO) through October 31, 2002. The audit will provide the initial
opportunity, in the context of a PUCO GCR proceeding, for a review of the
portfolio administration arrangement between VEDO and ProLiance Energy, LLC.
Similar arrangements for the Company's other utility subsidiaries, Indiana Gas
and SIGECO, were previously reviewed and approved by the IURC. VEDO's prior gas
acquisition practices may be challenged in the audit report, including VEDO's
relationship with ProLiance, and, as a result, a gas cost disallowance may be
recommended. Should such a challenge be made, then, by the first of September
2003, VEDO would file its response. If a hearing is necessary, the earliest it
could occur would be mid-September 2003. After that hearing, the PUCO would
consider all of the evidence on the matter and make a determination on the
merits. Throughout this process VEDO could, and likely would, endeavor to engage
in efforts with the participants in the proceeding to resolve disputed issues
outside of administrative litigation. The Company believes that VEDO's gas
acquisition practices that are the subject of the audit were reasonable. If a
challenge is made with respect to VEDO's gas acquisition practices during the
audit period and that challenge was adopted by the PUCO, the Company believes
that it would not be reasonably likely to have a material effect on the
Company's results or financial condition. However, the Company can provide no
assurance as to the ultimate outcome of this proceeding.
Results of Operations of the Nonregulated Group
The Nonregulated Group is comprised of four primary business areas: Energy
Marketing and Services, Coal Mining, Utility Infrastructure Services, and
Broadband. Energy Marketing and Services markets natural gas and provides energy
management services, including energy performance contracting services. Coal
Mining mines and sells coal to the Company's utility operations and to other
parties and generates IRS Code Section 29 investment tax credits relating to the
production of coal-based synthetic fuels. Utility Infrastructure Services
provides underground construction and repair, facilities locating, and meter
reading services. Broadband invests in broadband communication services such as
analog and digital cable television, high-speed Internet and data services, and
advanced local and long distance phone services. In addition, the Nonregulated
Group has other businesses that provide utility services, municipal broadband
consulting, and retail products and services and that invest in energy-related
opportunities, real estate, and leveraged leases. The results of operations of
the Nonregulated Group before certain intersegment eliminations and
reclassifications for the three and six months ended June 30, 2003 and 2002
follow:
Three Months Six Months
Ended June 30, Ended June 30,
---------------- -----------------
In millions, except per share amounts 2003 2002 2003 2002
- -------------------------------------- ------ ------ ------- -------
Energy services & other revenues $ 47.7 $ 97.0 $ 100.9 $ 256.5
Operating expenses:
Cost of energy services & other
revenues 38.2 87.1 82.9 235.1
Operating expenses 9.3 9.3 18.4 18.4
- ----------------------------------------------------------------------------
Total expenses 47.5 96.4 101.3 253.5
- ----------------------------------------------------------------------------
OPERATING INCOME (LOSS) 0.2 0.6 (0.4) 3.0
Other income (expense):
Equity in earnings of
unconsolidated affiliates (0.2) 4.1 9.1 7.3
Other - net (1.1) (0.5) - 0.5
- ----------------------------------------------------------------------------
Total other income (expense) (1.3) 3.6 9.1 7.8
- ----------------------------------------------------------------------------
Interest expense 2.4 2.2 4.8 4.5
- ----------------------------------------------------------------------------
INCOME BEFORE TAXES (3.5) 2.0 3.9 6.3
Income tax (6.9) (2.4) (8.1) (2.3)
Minority interest in
consolidated subsidiaries - - 0.1 (0.2)
- ----------------------------------------------------------------------------
NET INCOME $ 3.4 $ 4.4 $ 11.9 $ 8.8
============================================================================
BASIC EARNINGS PER SHARE $ 0.05 $ 0.06 $ 0.18 $ 0.13
============================================================================
NET INCOME ATTRIBUTED TO:
Energy Marketing & Services $ 2.1 $ 3.6 $ 10.5 $ 8.2
Coal Mining 4.7 2.9 7.2 4.9
Utility Infrastructure (0.2) - (1.2) (0.5)
Broadband (1.2) 0.1 (1.1) 0.2
Other Businesses (2.0) (2.2) (3.5) (4.0)
Nonregulated earnings for the second quarter 2003 decreased to $3.4 million as
compared to $4.4 million for the same period last year due to the impact of the
write-off of First Mile, a small broadband investment.
Nonregulated earnings for the six months ended June 30, 2003 were $11.9 million
in 2003 as compared to $8.8 million for the same period in 2002. The $3.1
million increase results primarily from increased earnings generated by the
Company's investments in ProLiance Energy, LLC (ProLiance) and Pace Carbon
Synfuels, LP (Pace Carbon), offset somewhat by the current quarter write-off of
the First Mile investment. ProLiance is a component of the Energy Marketing and
Services Group and Pace Carbon is a component of the Coal Mining Group.
Energy Marketing & Services
Energy Marketing and Services includes the Company's gas marketing operations.
These gas marketing operations are performed through the Company's investment in
ProLiance, a nonregulated energy marketing affiliate of Vectren and Citizens Gas
and Coke Utility (Citizens Gas). ProLiance provides natural gas and related
services to Indiana Gas, the Ohio operations, and Citizens Gas and also began
providing services to SIGECO and Vectren Retail, LLC (the Company's retail gas
marketer) in 2002. ProLiance's primary businesses include gas marketing, gas
portfolio optimization, and other portfolio and energy management services.
ProLiance's primary customers are utilities and other large end use customers.
In June 2002, the integration of Vectren's wholly owned gas marketing
subsidiary, SIGCORP Energy Services, LLC (SES), with ProLiance was completed.
SES provided natural gas and related services to SIGECO and others prior to the
integration. In exchange for the contribution of SES' net assets, Vectren's
allocable share of ProLiance's profits and losses increased from 52.5% to 61%,
consistent with Vectren's new ownership percentage. Governance and voting rights
remain at 50% for each member. Since governance of ProLiance remains equal
between the members, Vectren continues to account for its investment in
ProLiance using the equity method of accounting.
Prior to June 1, 2002, SES' operating results were consolidated. Subsequent to
June 1, 2002, SES' operating results, now part of ProLiance, are reflected in
equity in earnings of unconsolidated affiliates. SES' revenues and expenses were
the primary component of nonregulated revenues and cost of revenues. Therefore,
the integration significantly decreased revenues, cost of revenues, and
operating expenses. For the three months ended June 30, 2003, revenues, cost of
revenues, and operating expenses decreased $61.0 million, $58.6 million, and
$1.8 million, respectively, compared to 2002. And, for the six months ended June
30, 2003, revenues, cost of revenues, and operating expenses decreased $186.3
million, $178.7 million, and $4.1 million, respectively, compared to 2002. The
transfer of net assets was accounted for at book value consistent with joint
venture accounting and did not result in any gain or loss.
For the Company's portion of ProLiance's operations, $2.7 million and $5.4
million, respectively, is included in equity in earnings of unconsolidated
affiliates for the three months ended June 30, 2003 and 2002. For the six months
ended June 30, 2003 and 2002, such amounts included in equity in earnings of
unconsolidated affiliates are $17.0 million and $10.8 million, respectively.
For the quarter, gas marketing's contribution was down $2.2 million period over
period primarily due to the timing of costs and optimization benefits related to
pipeline contracts. For the year to date period, gas marketing's contribution
increased $1.2 million period over period due to continued realization of
benefits from the integration of its two gas marketing companies in 2002 and
from opportunities provided by gas price volatility in the first quarter.
In addition to gas marketing, Energy Marketing and Services includes the
operations of Energy Systems Group, LLC (ESG), which provides energy performance
contracting and facility upgrades through its design and installation of
energy-efficient equipment. Prior to April 2003, ESG was a consolidated venture
between the Company and Citizens Gas with the Company owning two-thirds. In
April 2003, the Company purchased the remaining interest in ESG for
approximately $4 million. For the three and six months ended June 30, 2003
earnings from ESG were $0.6 million compared to a loss for the quarter of $0.1
million and $0.3 million for the year to date period in 2002. The $0.7 million
increase for the quarter and $0.9 million increase year to date are due
primarily to success in obtaining higher margins and working from a higher
construction backlog at the end of 2002. ESG's results also reflect 100% Vectren
ownership during the quarter versus 67% Vectren ownership in 2002. For the
quarter, ESG produced operating income of approximately $1.1 million on sales of
$12.3 million compared to an operating loss of $0.2 million on sales of $7.8
million in the prior year. And for the six months ended June 30, 2003, ESG
produced operating income of approximately $1.1 million on sales of $21.2
million compared to an operating loss of $0.5 million on sales of $13.4 million
in the prior year.
Coal Mining
Coal Mining generates IRS Code Section 29 investment tax credits relating to the
production of coal-based synthetic fuels through its 8.3% ownership interest in
Pace Carbon. Pace Carbon is a Delaware limited partnership formed to develop,
own, and operate four projects to produce and sell coal-based synthetic fuel
(synfuel) utilizing Covol technology. Vectren accounts for is investment in Pace
Carbon using the equity method. The group also mines and sells coal to the
Company's utility operations and to other third parties through its wholly owned
subsidiary Vectren Fuels, Inc. (Fuels). In addition, Fuels receives
synfuel-related fees from synfuel producers unrelated to Pace Carbon for a
portion of its coal production.
For the three months ended June 30, 2003 and 2002, the investment in Pace Carbon
resulted in losses reflected in equity in earnings of unconsolidated affiliates
of $2.9 million and $2.4 million, respectively. For the six months ended June
30, 2003 and 2002, the investment in Pace Carbon resulted in losses reflected in
equity in earnings of unconsolidated affiliates of $6.4 million and $3.3
million, respectively. Losses have increased as a result of increased production
of synthetic fuels and higher production costs. The production of synfuel
generates IRS Code Section 29 investment tax credits that are reflected in
income taxes. These credits have also increased consistent with increased
synfuel production. Net income, including the losses, tax benefits, and tax
credits, generated from the investment in Pace Carbon totaled $3.2 million and
$1.3 million for the three months ended June 30, 2003 and 2002, respectively,
and totaled $4.8 million and $2.1 million for the six months ended June 30, 2003
and 2002, respectively.
For the three months ended June 30, 2003, earnings from Fuels were $1.5 million,
compared to earnings of $1.6 million in 2002. For the six months ended June 30,
2003, earnings from Fuels were $2.4 million, compared to earnings of $2.8
million in 2002. During both the quarter and year to date period, net income and
operating income decreased as a result of lower market prices on third party
coal sales, a lower yield per ton mined, and increased depreciation of mine
development costs, offset by increased synfuel-related fees. For the quarter,
Fuels produced operating income of approximately $2.5 million on sales of $29.6
million compared to operating income of $3.3 million on sales of $26.2 million
in the prior year. And for the six months ended June 30, 2003, Fuels produced
operating income of approximately $4.0 million on sales of $56.8 million
compared to operating income of $5.1 million on sales of $51.4 million in the
prior year.
For the three months ended June 30, 2003 and 2002, total synfuel-related
results, which reflect earnings from the investment in Pace Carbon and Fuel's
synfuel-related fees, were $4.3 million and $2.0 million, respectively. For the
six months ended June 30, 2003 and 2002, synfuel-related results were $6.6
million and $3.5 million, respectively.
IRS Section 29 Investment Tax Credit Recent Developments
Under Section 29 of the Internal Revenue Code, manufacturers such as Pace
Carbon, receive a tax credit for every ton of synthetic fuel sold. To qualify
for the credits, the synthetic fuel must meet three primary conditions: 1) there
must be a significant chemical change in the coal feedstock, 2) the product must
be sold to an unrelated person, and 3) the production facility must have been
placed in service before July 1, 1998.
In past rulings, the Internal Revenue Service (IRS) has concluded that the
synthetic fuel produced at the Pace Carbon facilities should qualify for Section
29 tax credits. The IRS issued a private letter ruling with respect to the four
projects on November 11, 1997, and subsequently issued an updated private letter
ruling on September 23, 2002.
As a partner in Pace Carbon, Vectren has reflected total tax credits under
Section 29 in its consolidated results through June 30, 2003 of approximately
$30 million. Vectren has been in a position to fully utilize the credits
generated and continues to project full utilization.
On June 27, 2003, the IRS, in an industry-wide announcement, stated that it has
reason to question the scientific validity of certain test procedures and
results that have been presented to it by certain taxpayers with an interest in
synfuel operations. Accordingly, the IRS has suspended the issuance of new
private letter rulings. In addition, the IRS indicated that it may revoke
existing private letter rulings that relied on the procedures and results under
review if it determines that those test procedures and results do not
demonstrate that a significant chemical change has occurred. During June 2001,
the IRS began a tax audit of Pace Carbon for the 1998 tax year and later
expanded the audit to include tax years 1999 and 2000. The IRS has requested
numerous extensions to the statute of limitations for the years under audit. It
is expected that the issue of the existence of chemical change will be formally
raised in the Pace Carbon audit.
At this time, Vectren cannot predict the outcome of the IRS' review of the
industry-wide issues, when that review will be completed or the ultimate impact,
if any, of the audit of Pace Carbon relative to Vectren's investments in Pace
Carbon. Vectren believes that it is justified in its reliance on the private
letter rulings for the Pace Carbon facilities, that the test results that Pace
Carbon presented to the IRS in connection with its private letter rulings are
scientifically valid, and that Pace Carbon has operated its facilities in
compliance with its private letter rulings and Section 29 of the Internal
Revenue Code.
Utility Infrastructure Services
Utility Infrastructure Services provides underground construction and repair of
utility infrastructure services to the Company and to other gas, water,
electric, and telecommunications companies as well as facilities locating and
meter reading services through its investment in Reliant Services, LLC
(Reliant). Reliant is a 50% owned strategic alliance with an affiliate of
Cinergy Corp. and is accounted for using the equity method of accounting.
Reliant's losses have increased in 2003 primarily due to continued cutbacks of
underground construction and repair projects from gas distribution utility
customers, which began in the later part of 2002.
Broadband
Broadband invests in broadband communication services such as cable television,
high-speed Internet, and advanced local and long distance phone services. The
Company has an approximate 1% equity interest and a convertible subordinated
debt investment in Utilicom Networks, LLC (Utilicom) that if converted bring the
Company's ownership interest up to 12%. Utilicom is a provider of bundled
communication services focusing on last mile delivery to residential and
commercial customers. The Company also has an 18.9% equity interest in SIGECOM
Holdings, Inc. (Holdings), which was formed by Utilicom to hold interests in
SIGECOM, LLC (SIGECOM). SIGECOM provides broadband services to the greater
Evansville, Indiana, area.
The equity investments in Utilicom and Holdings are accounted for using the cost
method of accounting. As a result, for the three and six months ended June 30,
2003 and 2002, these investments had no significant impact on the Company's
operating results.
Utilicom also plans to provide broadband services to the greater Indianapolis,
Indiana, and Dayton, Ohio, markets. However, the funding of these projects has
been delayed due to the continued difficult environment within the
telecommunication capital markets, which has prevented Utilicom from obtaining
debt financing on terms it considers acceptable. While the existing investors
remain interested in the Indianapolis and Dayton projects, the Company is not
required to make further investments and does not intend to proceed unless
commitments are obtained to fully fund these projects. Franchising agreements
have been extended in both locations.
In addition to its Utilicom-related investment, the Company also had an
investment in First Mile, a small broadband entity located in Indianapolis,
Indiana. During the three months ended June 30, 2003, the Company disposed of
its First Mile investment at a loss recorded in other-net totaling $2.0 million
($1.2 after tax).
Other Businesses
The Other Businesses Group includes a variety of wholly owned operations and
investments. The significant activities that affected the nonregulated results
of operations during the three and six months ended June 30, 2003 compared to
2002 are the wholly owned operations of Vectren Retail, LLC (Vectren Retail),
Vectren Communication Services, Inc. (VCS), and Southern Indiana Properties,
Inc. (SIPI), and the Haddington Partnerships investments.
Vectren Retail provides natural gas and other related products and services
primarily in Ohio, serving customers opting for choice among energy providers.
Vectren Retail began operations in 2001 and continues to incur startup costs.
During the three and six months ended June 30, 2003, these start up costs have
increased operating expenses approximately $0.7 million and $1.8 million,
respectively, compared to the same periods in 2002. For the three months ended
June 30, 2003, Vectren Retail incurred an operating loss of approximately $1.4
million on sales of $4.7 million compared to an operating loss of $1.0 million
on sales of $0.6 million in the prior year. And for the six months ended June
30, 2003, Vectren Retail incurred an operating loss of approximately $1.5
million on sales of $20.6 million compared to an operating loss of $1.8 million
on sales of $2.2 million in the prior year. The net loss incurred by Vectren
Retail for the quarter was $0.9 million in 2003 and $0.6 million in 2002. Year
to date, the net loss incurred was $1.0 million in 2003 and $1.1 million in
2002.
VCS is a wholly owned broadband consulting company. For the three and six months
ended June 30, 2003, operating income contributed by VCS increased $0.8 million
and $0.7 million, respectively, when compared to the prior year. The increase is
primarily due to charges incurred in 2002 related to the settlement of
construction contracts and the reorganization of its operations, allowing it to
focus on consulting services. For the three months ended June 30, 2003 and 2002,
net losses incurred by VCS were $0.5 million and $1.0 million, respectively. For
the six months ended June 30, 2003 and 2002, net losses incurred by VCS were
$1.0 million and $1.7 million, respectively.
SIPI is a wholly owned company with various investments in leveraged leases,
notes receivable, and unconsolidated affiliates. For both the three and six
months ended June 30, 2003, the net loss incurred by SIPI decreased $0.7
million. The decrease is primarily due to charges to income tax expense incurred
in 2002 related to a change in Indiana corporate income tax laws. The tax law
change, which effectively increased Vectren's state income tax rate from 4.5% to
8.5%, required the recalculation of SIPI's deferred tax obligations and earnings
from leveraged lease investments at the date of enactment of the law.
The Haddington Partnerships are equity method investments that invest in
energy-related opportunities. The 2002 results include earnings of $1.3 million
($0.8 million after tax). The earnings resulted from allocating proceeds
generated from the sale of investments. Such earnings are included in equity in
earnings of unconsolidated affiliates, and have not recurred in 2003.
Other Nonregulated Transactions
In early August, 2003, the Company disposed of its interest in two nonregulated
businesses. These actions were in furtherance of the Company's objective to
narrow the scope of its nonregulated businesses. Proceeds realized from these
dispositions will be used to reduce outstanding debt at the Company's
nonregulated business.
The first disposition was closed as of August 1, 2003, when the Company
consummated the sale of its investment in Genscape, Inc., a supplier of
real-time power plant output and transmission information, to GFI Energy
Ventures, LLC. The after-tax gain realized by the Company was approximately $2.6
million.
The second disposition was closed on August 4, 2003, and involved CIGMA, LLC
(CIGMA), a joint venture between the Company and a subsidiary of Citizens Gas.
In that transaction, substantially all of CIGMA's assets were sold to McJunkin
Corporation. CIGMA had been engaged in utility materials management for the
Company's utility subsidiaries, Citizens Gas & Coke Utility, and others. As a
result of the transaction, the Company realized a small after-tax gain, and
received a cash dividend from CIGMA of $4 million.
United States Securities and Exchange Commission (SEC) Informal Inquiry
As more fully described in Note 3 to these consolidated condensed financial
statements and in Note 3 to the 2002 consolidated financial statements filed on
Form 10-K/A, the Company restated its consolidated financial statements for
2000, 2001, and quarterly results issued in 2002.. The Company is cooperating
with the SEC in an informal inquiry with respect to this previously announced
restatement, has met with the staff of the SEC, and is providing information in
response to their requests.
Impact of Recently Issued Accounting Guidance
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. The Company adopted this statement on
January 1, 2003. The adoption was not material to the Company's results of
operations or financial condition.
SFAS 149
In April 2003, the FASB issued SFAS No. 149, "Amendment of Statement 133 on
Derivative Instruments and Hedging Activities" (SFAS 149). SFAS 149 amends and
clarifies the accounting guidance on (1) derivative instruments (including
certain derivative instruments embedded in other contracts) and (2) hedging
activities that fall within the scope of FASB Statement No. 133 (SFAS 133),
Accounting for Derivative Instruments and Hedging Activities. SFAS 149 amends
SFAS 133 to reflect decisions that were made (1) as part of the process
undertaken by the Derivatives Implementation Group (DIG), which necessitated
amending SFAS 133; (2) in connection with other projects dealing with financial
instruments; and (3) regarding implementation issues related to the application
of the definition of a derivative. SFAS 149 also amends certain other existing
pronouncements, which will result in more consistent reporting of contracts that
are derivatives in their entirety or that contain embedded derivatives that
warrant separate accounting. SFAS 149 is effective (1) for contracts entered
into or modified after June 30, 2003, with certain exceptions and (2) for
hedging relationships designated after June 30. The guidance is to be applied
prospectively. Although management is still evaluating the impact of SFAS 149 on
its financial position and results of operations, the adoption is not expected
to have a material effect.
SFAS 150
In May 2003, the FASB issued SFAS No. 150, "Accounting for Certain Financial
Instruments with Characteristics of Both Liabilities and Equity" (SFAS 150).
SFAS 150 requires issuers to classify as liabilities the following three types
of freestanding financial instruments: mandatorily redeemable financial
instruments; obligations to repurchase the issuer's equity shares by
transferring assets; and certain obligations to issue a variable number of
shares. SFAS 150 is effective immediately for all financial instruments entered
into or modified after May 31, 2003. For all other instruments, SFAS 150 applies
to the Company's third quarter of 2003. The Company has approximately $200,000
of outstanding preferred stock of a subsidiary that is redeemable on terms
outside the Company's control. However, the preferred stock is not redeemable on
a specified or determinable date or upon an event that is certain to occur.
Therefore, SFAS 150's adoption will not affect the Company's results of
operations or financial condition.
FASB Interpretation (FIN) 45
In November 2002, the FASB issued Interpretation 45, "Guarantor's Accounting and
Disclosure Requirements for Guarantees, Including Indirect Guarantees of
Indebtedness of Others" (FIN 45). FIN 45 clarifies the requirements for a
guarantor's accounting for and disclosure of certain guarantees issued and
outstanding and that a guarantor is required to recognize, at the inception of a
guarantee, a liability for the fair value of the obligations it has undertaken.
The initial recognition and measurement provisions are applicable on a
prospective basis to guarantees issued or modified after December 31, 2002.
Since that date, the adoption has not had a material effect on the Company's
results of operations or financial condition. The incremental disclosure
requirements are included in these financial statements in Note 8.
FIN 46
In January 2003, the FASB issued Interpretation 46, "Consolidation of Variable
Interest Entities" (FIN 46). FIN 46 addresses consolidation by business
enterprises of variable interest entities and significantly changes the
consolidation requirements for those entities. FIN 46 is intended to achieve
more consistent application of consolidation policies to variable interest
entities and, thus improves comparability between enterprises engaged in similar
activities when those activities are conducted through variable interest
entities. FIN 46 applies to variable interest entities created after January 31,
2003 and to variable interest entities in which an enterprise obtains an
interest after that date. FIN 46 applies to the Company's third quarter of 2003
for variable interest entities in which the Company holds a variable interest
acquired before February 1, 2003. Although management is still evaluating the
impact of FIN 46 on its financial position and results of operations, the
adoption is not expected to have a material effect.
Financial Condition
Within Vectren's consolidated group, VUHI funds short-term and long-term
financing needs of the utility group operations, and Vectren Capital Corp
(Vectren Capital) funds short-term and long-term financing needs of the
nonregulated and corporate operations. Vectren Corporation guarantees Vectren
Capital's debt, but does not guarantee VUHI's debt. Vectren Capital's long-term
and short-term obligations outstanding at June 30, 2003 totaled $113.0 million
and $68.6 million, respectively. VUHI's outstanding long-term and short-term
borrowing arrangements are jointly and severally guaranteed by Indiana Gas,
SIGECO, and VEDO. VUHI's long-term and short-term obligations outstanding at
June 30, 2003 totaled $350.0 million and $318.6 million, respectively.
Additionally, prior to VUHI's formation, Indiana Gas and SIGECO funded their
operations separately, and therefore, have long-term debt outstanding funded
solely by their operations.
Utility operations have historically funded the Company's common stock
dividends. Nonregulated operations have demonstrated sustained profitability,
and the ability to generate cash flows. These cash flows are ordinarily
reinvested in other nonregulated ventures or used for corporate expenses.
VUHI's and Indiana Gas' credit ratings on outstanding senior unsecured debt at
June 30, 2003 are A-/Baa1 as rated by Standard and Poor's Ratings Services
(Standard and Poor's) and Moody's Investors Service (Moody's), respectively.
SIGECO's credit ratings on outstanding senior unsecured debt at June 30, 2003
are BBB+/Baa1. SIGECO's credit ratings on outstanding secured debt at June 30,
2003 are A-/A3. VUHI's commercial paper has a credit rating of A-2/P-2. Vectren
Capital's senior unsecured debt is rated BBB+/Baa2. Moody's current outlook is
stable while Standard and Poor's current outlook is negative. The ratings of
Moody's and Standard and Poor's are categorized as investment grade and are
unchanged from December 31, 2002. In July 2003, Standard and Poor's reaffirmed
its ratings, and Moody's reaffirmed its ratings on VUHI's senior unsecured debt.
A security rating is not a recommendation to buy, sell, or hold securities. The
rating is subject to revision or withdrawal at any time, and each rating should
be evaluated independently of any other rating. Standard and Poor's and Moody's
lowest level investment grade rating is BBB- and Baa3, respectively.
The Company's consolidated equity capitalization objective is 45-55% of total
capitalization. This objective may have varied, and will vary, depending on
particular business opportunities, capital spending requirements, and seasonal
factors that affect the Company's operation. The Company's equity component was
48% and 46% of total capitalization, including current maturities of long-term
debt and long-term debt subject to tender, at June 30, 2003 and December 31,
2002, respectively.
The Company expects the majority of its capital expenditures, investments, and
debt security redemptions to be provided by internally generated funds. However,
additional permanent financing will be required due to significant capital
expenditures for NOx compliance equipment at SIGECO and plans to further
strengthen the Company's capital structure and the capital structures of VUHI
and its utility subsidiaries. These plans include the issuance of new equity and
debt and the calling of certain long-term debt at SIGECO and Indiana Gas. In
April 2003, the Company filed with the United States Securities and Exchange
Commission a registration statement, as amended, to issue a maximum of $180
million of new equity securities and to issue $200 million in debt securities at
VUHI. The registration statement was declared effective on June 27, 2003.
Subsequent to June 30, 2003, the Company initiated these transactions as more
fully described below.
Sources & Uses of Liquidity
Operating Cash Flow
The Company's primary and historical source of liquidity to fund working capital
requirements has been cash generated from operations, which for the six months
ended June 30, 2003 and 2002 was $170.5 million and $254.2 million,
respectively. The decrease of $83.7 million is primarily the result of more
favorable changes in working capital accounts occurring in 2002 due to a return
to lower gas prices in that year, offset by increased earnings before non-cash
charges in 2003.
Financing Cash Flow
Although working capital requirements are generally funded by cash flow from
operations, the Company uses short-term borrowings to supplement working capital
needs when accounts receivable balances are at their highest and gas storage is
refilled. Additionally short-term borrowings are required for capital projects
and investments until they are permanently financed.
Cash flow required for financing activities of $83.6 million for the six months
ended June 30, 2003 includes $49.8 million in payments to decrease borrowings
outstanding and increased common stock dividends compared to 2002. In 2002,
higher operating cash flow was used to repay $122.6 million in borrowings.
Financing Transactions
In January, 2003, the Company called the remaining $23.8 million of Indiana Gas'
9.375% private placement notes originally due in 2021. The total amount paid on
redemption was $24.9 million. Pursuant to regulatory authority the premium paid
was deferred as a regulatory asset. Also in January, 2003, other debt of Indiana
Gas totaling $15.0 million and of SIGECO totaling $1.0 million was paid as
scheduled.
At December 31, 2002, the Company had $26.6 million of adjustable rate senior
unsecured bonds which could, at the election of the bondholder, be tendered to
the Company when interest rates are reset. Such bonds were classified as
long-term debt subject to tender. During the second quarter, the Company
re-marketed those bonds on a long-term basis and has therefore reclassified them
as long-term debt at June 30, 2003.
Financing Activity Subsequent to June 30, 2003
With respect to the permanent financing strategy discussed above, the Company
initiated the following transactions subsequent to June 30, 2003.
Equity Issuance
In August 2003, the Company completed a public offering of 6.5 million shares of
its common stock, which was priced at $22.81 per share to yield total gross
proceeds $148.3 million. The Company also has granted the underwriters a 30-day
option to purchase up to an additional 975,000 shares of the Company's common
stock at the public offering price to cover over-allotments, if any. The public
offering of the shares closed on August 13, 2003 with net proceeds of
approximately $143 million (excluding any proceeds from an over-allotment
option).
VUHI Debt Issuance
Subsequent to June 30 2003, VUHI issued senior unsecured notes with an aggregate
principal amount of $200 million in two $100 million tranches. The first tranche
are 10-year notes due August 2013, with an interest rate of 5.25% priced at
99.746% to yield 5.28% to maturity (2013 Notes). The second tranche are 15-year
notes due August 2018 with an interest rate of 5.75% priced at 99.177% to yield
5.80% to maturity (2018 Notes).
The notes are jointly and severally guaranteed by the Company's three public
utilities. In addition, they have no sinking fund requirements, and interest
payments are due semi-annually. The notes may be called by the Company, in whole
or in part, at any time for an amount equal to accrued and unpaid interest, plus
the greater of 100% of the principal amount or the sum of the present values of
the remaining scheduled payments of principal and interest, discounted to the
redemption date on a semi-annual basis at the Treasury Rate, as defined in the
indenture, plus 20 basis points for the 2013 Notes and 25 basis points for the
2018 Notes.
Shortly before these issues, the Company entered into several treasury locks
with a total notional amount of $150.0 million. Upon issuance of the debt, the
treasury locks were settled resulting in the Company receiving $5.7 million. The
value received will be amortized as a reduction of interest expense over the
life of the issues.
The net proceeds from the sale of the senior notes and settlement of related
hedging arrangements approximated $203 million.
SIGECO and Indiana Gas Debt Call
In August 2003, the Company initiated steps to call two first mortgage bonds
outstanding at SIGECO and a senior unsecured note outstanding at Indiana Gas.
The first SIGECO bond has a principal amount of $45.0 million, an interest rate
of 7.60%, was originally due in 2023, and may be redeemed at 103.745% of its
stated principal amount. The second SIGECO bond has a principal amount of $20.0
million, an interest rate of 7.625%, was originally due in 2025, and may be
redeemed at 103.763% of the stated principal amount. The Indiana Gas note has a
principal amount of $13.5 million, an interest rate of 6.75%, was originally due
in 2028, and may be redeemed at the principal amount. These transactions are
expected to take place in September 2003. Pursuant to regulatory authority, the
premium paid to retire the net carrying value of these notes will be deferred as
a regulatory asset.
Investing Cash Flow
Cash required for investing activities of $95.6 million for the six months ended
June 30, 2003 includes $99.9 million of requirements for capital expenditures.
Investing activities for 2002 were $103.0 million. The decrease occurring in
2003 principally results from collections of notes receivable and distributions
by unconsolidated affiliates offset by additional capital expenditures,
principally for the NOx project.
Available Sources of Liquidity
At June 30, 2003, the Company has $551 million of short-term borrowing capacity,
including $371 million for the Utility Group and $180 million for the wholly
owned Nonregulated Group and corporate operations, of which approximately $51
million is available for the Utility Group operations and approximately $109
million is available for the wholly owned Nonregulated Group and corporate
operations. The availability of short-term borrowing is reduced by outstanding
letters of credit totaling $2.5 million, collateralizing nonregulated
activities. Effective January 1, 2003, the Company transferred assets which
primarily supported the Utility Group's operations to VUHI which made available
approximately $90 million of additional nonregulated and corporate capacity.
Beginning in 2003, the Company began issuing new shares to satisfy dividend
reinvestment plan requirements. During the six months ended June 30, 2003, new
issues from stock plans added additional liquidity of approximately of $2.2
million, compared to 2002.
Potential Uses of Liquidity
Planned Capital Expenditures & Investments
Investments in nonregulated unconsolidated affiliates and total company capital
expenditures for the remainder of 2003 are estimated to be approximately $160
million.
Ratings Triggers
At June 30, 2003, $113.0 million of Vectren Capital's senior unsecured notes
were subject to cross-default and ratings trigger provisions that would provide
that the full balance outstanding is subject to prepayment if the ratings of
Indiana Gas' or SIGECO's most senior securities declined to BBB/Baa2. In
addition, accrued interest and a make whole amount based on the discounted value
of the remaining payments due on the notes would also become payable. The credit
rating of Indiana Gas' senior unsecured debt and SIGECO's secured debt remain
one level and two levels, respectively, above the ratings trigger.
Other Guarantees and Letters of Credit
In the normal course of business, Vectren Corporation issues guarantees to third
parties on behalf of its consolidated subsidiaries and unconsolidated
affiliates. Such guarantees allow those subsidiaries and affiliates to execute
transactions on more favorable terms than the subsidiary or affiliate could
obtain without such a guarantee. Guarantees may include posted letters of
credit, leasing guarantees, and performance guarantees. As of June 30, 2003,
guarantees issued and outstanding on behalf of unconsolidated affiliates
approximated $2 million. In addition, the Company has also issued a guarantee
approximating $4 million related to the residual value of an operating lease
that expires in 2006. Through June 30, 2003, the Company has not been called
upon to satisfy any obligations pursuant to its guarantees.
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 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 the
Company's actual results to differ materially from those contemplated in any
forward-looking statements include, among others, the following:
o 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 demand, shortages,
transmission problems or other developments; or electric transmission or
gas pipeline system constraints.
o Increased competition in the energy environment including effects of
industry restructuring and unbundling.
o 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.
o 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 electric and natural gas
transmission and distribution, natural gas gathering and processing,
electric power supply; and similar entities with regulatory oversight.
o Economic conditions including the effects of an economic downturn,
inflation rates, and monetary fluctuations.
o 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.
o The performance of projects undertaken by the Company's nonregulated
businesses and the success of efforts to invest in and develop new
opportunities, including but not limited to, the realization of Section 29
income tax credits and the Company's coal mining, gas marketing, and
broadband strategies.
o Direct or indirect effects on our business, financial condition or
liquidity resulting from a change in our credit rating, changes in interest
rates, and/or changes in market perceptions of the utility industry and
other energy-related industries.
o Employee or contractor workforce factors including changes in key
executives, collective bargaining agreements with union employees, or work
stoppages.
o Legal and regulatory delays and other obstacles associated with mergers,
acquisitions, and investments in joint ventures.
o 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.
o 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 is exposed to various business risks associated with commodity
prices, interest rates, and counter-party credit. These financial exposures are
monitored and managed by the Company as an integral part of its overall risk
management program. The Company's risk management program includes, among other
things, the use of derivatives to mitigate risk.
The Company also executes derivative contracts in the normal course of
operations while buying and selling commodities and other fungible goods to be
used in operations and while optimizing generation assets. The Company does not
execute derivative contracts it designates as trading.
These risks are not significantly different from the information set forth in
Item 7A Quantitative and Qualitative Disclosures About Market Risk included in
the Vectren 2002 Form 10-K/A and is therefore not presented herein.
ITEM 4. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
As of June 30, 2003, the Company carried out an evaluation under the supervision
and with the participation of the Chief Executive Officer and Chief Financial
Officer of the effectiveness and the design and operation of the Company's
disclosure controls and procedures. Based on that evaluation, the Chief
Executive Officer and the Chief Financial Officer have concluded that the
Company's disclosure controls and procedures provide reasonable assurance that
material information relating to the Company required to be disclosed by the
Company in its filings under the Securities Exchange Act of 1934 (Exchange Act)
is brought to their attention on a timely basis.
Disclosure controls and procedures, as defined by the Exchange Act in Rules
13a-15(e) and 15d-15(e), are controls and other procedures of the Company that
are designed to ensure that information required to be disclosed by the Company
in the reports filed or submitted by it under the Exchange Act is recorded,
processed, summarized, and reported within the time periods specified in the
SEC's rules and forms. "Disclosure controls and procedures" include, without
limitation, controls and procedures designed to ensure that information required
to be disclosed by the Company in its Exchange Act reports is accumulated and
communicated to the Company's management, including its principal executive and
financial officers, as appropriate to allow timely decisions regarding required
disclosure.
Changes in Internal Control Over Financial Reporting
During the quarter ended June 30, 2003, there have been no significant changes
to the Company's internal control over financial reporting that has materially
affected, or is reasonably likely to materially affect, the Company's internal
control over financial reporting.
Internal control over financial reporting is defined by the SEC in Final Rule:
Management's Reports on Internal Control Over Financial Reporting and
Certification of Disclosure in Exchange Act Periodic Reports. The final rule
defines internal control over financial reporting as a process designed by, or
under the supervision of, the registrant's principal executive and principal
financial officers, or persons performing similar functions, and effected by the
registrant's board of directors, management and other personnel, to provide
reasonable assurance regarding the reliability of financial reporting and the
preparation of financial statements for external purposes in accordance with
generally accepted accounting principles and includes those policies and
procedures that: (1) Pertain to the maintenance of records that in reasonable
detail accurately and fairly reflect the transactions and dispositions of the
assets of the registrant; (2) Provide reasonable assurance that transactions are
recorded as necessary to permit preparation of financial statements in
accordance with generally accepted accounting principles, and that receipts and
expenditures of the registrant are being made only in accordance with
authorizations of management and directors of the registrant; and (3) Provide
reasonable assurance regarding prevention or timely detection of unauthorized
acquisition, use or disposition of the registrant's assets that could have a
material effect on the financial statements.
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
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 9 of its unaudited
consolidated condensed financial statements included in Part 1 Item 1 Financial
Statements regarding the Clean Air Act and related legal proceedings.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
Vectren's Annual Meeting of Stockholders was held on May 14, 2003.
At said Annual Meeting, the stockholders voted on the following four proposals:
1. The election of four directors of the company, each to serve for up to a
three-year term or until their successors are duly qualified and elected:
Director Votes For Abstentions
----------------------------- --------------------- ---------------
John M. Dunn 59,872,414 1,109,441
Niel C. Ellerbrook 59,774,469 1,207,386
Anton H. George 59,878,818 1,103,037
Robert L. Koch II 59,984,444 997,411
The terms of office of John D. Engelbrecht, Lawrence A. Ferger, William G.
Mays, J. Timothy McGinley, Richard P. Rechter, Ronald G. Reherman, Richard
W. Shymanski, and Jean L. Wojtowicz will expire in 2004 or 2005.
2. The reappointment of Deloitte & Touche LLP (Deloitte) as the independent
accountants for the Company and its subsidiaries for 2003:
The stockholders approved Deloitte as the independent accountants by the
following votes:
Votes For Votes Against Abstentions Broker Non-Votes
----------------- ----------------- --------------- ------------------
59,005,709 1,645,489 313,808 16,849
3. A proposal to expense stock options:
The stockholders defeated the proposal by the following votes:
Votes For Votes Against Abstentions Broker Non-Votes
----------------- ----------------- --------------- ------------------
20,763,652 26,140,895 1,921,462 12,155,846
4. A proposal to use index-based options:
The stockholders defeated the proposal by the following votes:
Votes For Votes Against Abstentions Broker Non-Votes
----------------- ----------------- --------------- ------------------
9,158,878 38,088,736 1,578,395 12,155,846
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
Certifications
31.1 Certification Pursuant To Section 302 Of The Sarbanes-Oxley Act Of 2002-
Chief Executive Officer
31.2 Certification Pursuant To Section 302 Of The Sarbanes-Oxley Act Of 2002-
Chief Financial Officer
32 Certification Pursuant To Section 906 Of The Sarbanes-Oxley Act Of 2002
Other Exhibits
None
(b) Reports On Form 8-K During The Last Calendar Quarter
On April 25, 2003, Vectren Corporation filed a Current Report on Form 8-K with
respect to the release of financial information to the investment community
regarding the Company's results of operations, for the three and twelve month
periods ended March 31, 2003. The financial information was released to the
public through this filing.
Item 12. Results of Operations and Financial Condition
Item 7. Exhibits
99.1 - Press Release - Vectren Corporation Reports 1st Quarter
2003 Increase
99.2 - Cautionary Statement for Purposes of the "Safe Harbor"
Provisions of the Private Securities Litigation Reform Act
of 1995
On June 9, 2003, Vectren Corporation filed a Current Report on Form 8-K with
respect a proposed agreement between Southern Indiana Gas and Electric Company,
a wholly-owned subsidiary of Vectren Corporation, the U.S. Department of
Justice, and the U.S. Environmental Protection Agency that would lead to further
improvements in air quality and resolve the government's pending Clean Air Act
claims against SIGECO.
Item 9. Regulation FD Disclosure
Item 7. Exhibits
99.1 - Press Release - Vectren subsidiary reaches agreement with
Department of Justice, EPA
99.2 - Cautionary Statement for Purposes of the "Safe Harbor"
Provisions of the Private Securities Litigation Reform Act
of 1995
On June 30, 2003, Vectren Corporation filed a Current Report on Form 8-K to
announce 1) on June 26, 2003, Vectren Utility Holdings, Inc.'s (VUHI) revolving
credit facility was renewed and 2) on June 27, 2003, a registration statement,
originally filed on March 31, 2003, was declared effective.
Item 9. Regulation FD Disclosure
Item 7. Exhibits
99.1 - Press Release - Vectren Renews Credit Facility and
Announces Effectiveness of Registration Statement
99.2 - Cautionary Statement for Purposes of the "Safe Harbor"
Provisions of the Private Securities Litigation Reform Act
of 1995
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 CORPORATION
-------------------
Registrant
August 14, 2003 /s/Jerome A. Benkert, Jr.
-------------------------
Jerome A. Benkert, Jr.
Executive Vice President &
Chief Financial Officer
(Principal Financial Officer)
/s/M. Susan Hardwick
--------------------------
M. Susan Hardwick
Vice President & Controller
(Principal Accounting Officer)