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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

FORM 10-Q

(Mark One)

 

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

For the quarterly period ended September 30, 2004

or

o   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

 

Registrant, State of Incorporation,
Address and Telephone Number

 

I.R.S. Employer
Identification No.

 

 

 

 

 

1-11377

 

CINERGY CORP.

(A Delaware Corporation)

139 East Fourth Street

Cincinnati, Ohio 45202

(513) 421-9500

 

31-1385023

 

 

 

 

 

1-1232

 

THE CINCINNATI GAS & ELECTRIC COMPANY

(An Ohio Corporation)

139 East Fourth Street

Cincinnati, Ohio 45202

(513) 421-9500

 

31-0240030

 

 

 

 

 

1-3543

 

PSI ENERGY, INC.

(An Indiana Corporation)

1000 East Main Street

Plainfield, Indiana 46168

(513) 421-9500

 

35-0594457

 

 

 

 

 

2-7793

 

THE UNION LIGHT, HEAT AND POWER
COMPANY

(A Kentucky Corporation)

139 East Fourth Street

Cincinnati, Ohio 45202

(513) 421-9500

 

31-0473080

 


 

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

Yes ý  No o


 

Indicate by check mark whether each registrant is an accelerated filer (as defined in Rule 12b-2 of the Act).

 

 

Cinergy Corp.

Yes

ý

 

No

o

 

 

The Cincinnati Gas & Electric Company

Yes

o

 

No

ý

 

 

PSI Energy, Inc.

Yes

o

 

No

ý

 

 

The Union Light, Heat and Power Company

Yes

o

 

No

ý

 

 


 

This combined Form 10-Q is separately filed by Cinergy Corp., The Cincinnati Gas & Electric Company, PSI Energy, Inc., and The Union Light, Heat and Power Company.  Information contained herein relating to any individual registrant is filed by such registrant on its own behalf.  Each registrant makes no representation as to information relating to the other registrants.

 

The Union Light, Heat and Power Company meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and is therefore filing its company specific information with the reduced disclosure format specified in General Instruction H(2) of Form 10-Q.

 


 

As of October 31, 2004, shares of common stock outstanding for each registrant were as listed:

 

Registrant

 

Description

 

Shares

 

 

 

 

 

Cinergy Corp.

 

Par value $.01 per share

 

181,244,979

 

 

 

 

 

The Cincinnati Gas & Electric Company

 

Par value $8.50 per share

 

89,663,086

 

 

 

 

 

PSI Energy, Inc.

 

Without par value, stated value $.01 per share

 

53,913,701

 

 

 

 

 

The Union Light, Heat and Power Company

 

Par value $15.00 per share

 

585,333

 


 

 

 



 

TABLE OF CONTENTS

 

Item
Number

 

 

 

 

 

 

PART I.  FINANCIAL INFORMATION

 

 

 

 

 

 

 

1

 

Financial Statements

 

 

 

 

Cinergy Corp.

 

 

 

 

Condensed Consolidated Statements of Income

 

 

 

 

Condensed Consolidated Balance Sheets

 

 

 

 

Condensed Consolidated Statements of Changes in Common Stock Equity

 

 

 

 

Condensed Consolidated Statements of Cash Flows

 

 

 

 

 

 

 

 

 

The Cincinnati Gas & Electric Company

 

 

 

 

Condensed Consolidated Statements of Income and Comprehensive Income

 

 

 

 

Condensed Consolidated Balance Sheets

 

 

 

 

Condensed Consolidated Statements of Cash Flows

 

 

 

 

 

 

 

 

 

PSI Energy, Inc.

 

 

 

 

Condensed Consolidated Statements of Income and Comprehensive Income

 

 

 

 

Condensed Consolidated Balance Sheets

 

 

 

 

Condensed Consolidated Statements of Cash Flows

 

 

 

 

 

 

 

 

 

The Union Light, Heat and Power Company

 

 

 

 

Condensed Statements of Income

 

 

 

 

Condensed Balance Sheets

 

 

 

 

Condensed Statements of Cash Flows

 

 

 

 

 

 

 

 

 

Notes to Condensed Financial Statements

 

 

 

 

 

 

 

2

 

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

 

 

 

Introduction

 

 

 

 

Organization

 

 

 

 

Liquidity and Capital Resources

 

 

 

 

2004 Quarterly Results of Operations - Historical

 

 

 

 

2004 Year to Date Results of Operations - Historical

 

 

 

 

Results of Operations - Future

 

 

 

 

 

 

 

3

 

Quantitative and Qualitative Disclosures About Market Risk

 

 

 

 

 

 

 

4

 

Controls and Procedures

 

 

 

 

 

 

 

 

 

PART II.  OTHER INFORMATION

 

 

 

 

 

 

 

1

 

Legal Proceedings

 

 

 

 

 

 

 

2

 

Unregistered Sales of Equity Securities and Use of Proceeds

 

 

 

 

 

 

 

6

 

Exhibits

 

 

 

 

 

 

 

 

 

Signatures

 

 

 

2



 

CINERGY CORP.

AND SUBSIDIARY COMPANIES

 

3



 

CINERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

 

 

 

Quarter Ended
September 30

 

Year to Date
September 30

 

 

 

2004

 

2003

 

2004

 

2003

 

 

 

(in thousands, except per share amounts)

 

 

 

(unaudited)

 

Operating Revenues

 

 

 

 

 

 

 

 

 

Electric

 

$994,074

 

$920,638

 

$2,764,468

 

$2,512,954

 

Gas

 

65,298

 

124,533

 

524,226

 

638,378

 

Other

 

69,211

 

46,806

 

182,284

 

142,525

 

Total Operating Revenues

 

1,128,583

 

1,091,977

 

3,470,978

 

3,293,857

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Expenses

 

 

 

 

 

 

 

 

 

Fuel and purchased power

 

333,771

 

329,997

 

914,404

 

840,332

 

Gas purchased

 

19,792

 

79,582

 

290,728

 

368,896

 

Operation and maintenance

 

412,720

 

323,401

 

1,184,451

 

985,528

 

Depreciation

 

122,099

 

98,522

 

341,287

 

300,145

 

Taxes other than income taxes

 

57,001

 

55,828

 

204,320

 

200,535

 

Total Operating Expenses

 

945,383

 

887,330

 

2,935,190

 

2,695,436

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Income

 

183,200

 

204,647

 

535,788

 

598,421

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Equity in Earnings of Unconsolidated Subsidiaries

 

8,016

 

4,956

 

18,095

 

11,652

 

Miscellaneous Income (Expense) – Net

 

(944

)

12,296

 

(11,419

)

27,678

 

Interest Expense

 

71,775

 

73,905

 

209,446

 

193,734

 

Preferred Dividend Requirement of Subsidiary Trust

 

 

 

 

11,940

 

Preferred Dividend Requirements of Subsidiaries

 

858

 

858

 

2,574

 

2,574

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Before Taxes

 

117,639

 

147,136

 

330,444

 

429,503

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Taxes

 

24,716

 

35,155

 

76,002

 

102,121

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Before Discontinued Operations and Cumulative Effect of Changes in Accounting Principles

 

92,923

 

111,981

 

254,442

 

327,382

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Discontinued operations, net of tax

 

 

 

 

8,875

 

Cumulative effect of changes in accounting principles, net of tax (Note 1(d)(ii))

 

 

 

 

26,462

 

Net Income

 

$92,923

 

$111,981

 

$254,442

 

$362,719

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average Common Shares Outstanding

 

180,881

 

177,751

 

180,129

 

175,944

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Common Share – Basic (Note 10)

 

 

 

 

 

 

 

 

 

Income before discontinued operations and cumulative effect of changes in accounting principles

 

$0.51

 

$0.63

 

$1.41

 

$1.86

 

Discontinued operations, net of tax

 

 

 

 

0.05

 

Cumulative effect of changes in accounting principles, net of tax

 

 

 

 

0.15

 

Net income

 

$0.51

 

$0.63

 

$1.41

 

$2.06

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Common Share – Diluted (Note 10)

 

 

 

 

 

 

 

 

 

Income before discontinued operations and cumulative effect of changes in accounting principles

 

$0.50

 

$0.62

 

$1.39

 

$1.84

 

Discontinued operations, net of tax

 

 

 

 

0.05

 

Cumulative effect of changes in accounting principles, net of tax

 

 

 

 

0.15

 

Net income

 

$0.50

 

$0.62

 

$1.39

 

$2.04

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Dividends Declared Per Common Share

 

$0.47

 

$0.46

 

$1.41

 

$1.38

 

 

 

 

 

 

 

 

 

 

 

 

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

 

4



 

CINERGY CORP.
CONDENSED CONSOLIDATED BALANCE SHEETS

 

ASSETS

 

 

 

September 30
2004

 

December 31
2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Current Assets

 

 

 

 

 

Cash and cash equivalents

 

$

152,374

 

$

169,120

 

Restricted deposits

 

140,944

 

92,813

 

Notes receivable, current

 

84,171

 

189,854

 

Accounts receivable less accumulated provision for doubtful accounts of $5,724 at September 30, 2004, and $7,884 at December 31, 2003

 

822,989

 

1,074,518

 

Fuel, emission allowances, and supplies

 

436,113

 

357,625

 

Energy risk management current assets

 

469,592

 

305,058

 

Prepayments and other

 

127,847

 

53,609

 

Total Current Assets

 

2,234,030

 

2,242,597

 

 

 

 

 

 

 

 

 

 

 

 

 

Property, Plant, and Equipment – at Cost

 

 

 

 

 

Utility plant in service

 

10,049,768

 

9,732,123

 

Construction work in progress

 

282,488

 

275,459

 

Total Utility Plant

 

10,332,256

 

10,007,582

 

Non-regulated property, plant, and equipment

 

4,620,851

 

4,527,943

 

Accumulated depreciation

 

5,159,602

 

4,908,019

 

Net Property, Plant, and Equipment

 

9,793,505

 

9,627,506

 

 

 

 

 

 

 

 

 

 

 

 

 

Other Assets

 

 

 

 

 

Regulatory assets

 

992,917

 

1,012,151

 

Investments in unconsolidated subsidiaries

 

516,732

 

494,520

 

Energy risk management non-current assets

 

136,756

 

97,334

 

Notes receivable, non-current

 

199,005

 

213,853

 

Other investments

 

120,964

 

184,044

 

Goodwill and other intangible assets

 

61,426

 

45,349

 

Other

 

187,995

 

197,351

 

Total Other Assets

 

2,215,795

 

2,244,602

 

 

 

 

 

 

 

 

 

 

 

 

 

Assets of Discontinued Operations

 

 

4,501

 

 

 

 

 

 

 

Total Assets

 

$

14,243,330

 

$

14,119,206

 

 

 

 

 

 

 

 

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

 

5



 

CINERGY CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS

 

LIABILITIES AND SHAREHOLDERS’ EQUITY

 

 

 

September 30
2004

 

December 31
2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

Current Liabilities

 

 

 

 

 

Accounts payable

 

$

1,078,526

 

$

1,240,423

 

Accrued taxes

 

137,099

 

217,993

 

Accrued interest

 

61,191

 

68,952

 

Notes payable and other short-term obligations (Note 4)

 

1,196,763

 

351,412

 

Long-term debt due within one year

 

220,413

 

839,103

 

Energy risk management current liabilities

 

396,148

 

296,122

 

Other

 

145,072

 

107,438

 

Total Current Liabilities

 

3,235,212

 

3,121,443

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-Current Liabilities

 

 

 

 

 

Long-term debt (Note 3)

 

3,935,936

 

4,131,909

 

Deferred income taxes

 

1,648,069

 

1,557,981

 

Unamortized investment tax credits

 

101,977

 

108,884

 

Accrued pension and other postretirement benefit costs

 

602,698

 

662,834

 

Accrued cost of removal

 

520,844

 

490,856

 

Energy risk management non-current liabilities

 

133,328

 

64,861

 

Other

 

221,509

 

205,344

 

Total Non-Current Liabilities

 

7,164,361

 

7,222,669

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities of Discontinued Operations

 

 

11,594

 

 

 

 

 

 

 

Commitments and Contingencies (Note 6)

 

 

 

 

 

 

 

 

 

 

 

Total Liabilities

 

10,399,573

 

10,355,706

 

 

 

 

 

 

 

 

 

 

 

 

 

Cumulative Preferred Stock of Subsidiaries

 

 

 

 

 

Not subject to mandatory redemption

 

62,818

 

62,818

 

 

 

 

 

 

 

 

 

 

 

 

 

Common Stock Equity (Note 2)

 

 

 

 

 

Common stock - $.01 par value; authorized shares – 600,000,000; issued shares – 181,122,065 at September 30, 2004, and 178,438,369 at December 31, 2003; outstanding shares – 180,995,556 at September 30, 2004, and 178,336,854 at December 31, 2003

 

1,811

 

1,784

 

Paid-in capital

 

2,272,651

 

2,195,985

 

Retained earnings

 

1,551,848

 

1,551,003

 

Treasury shares at cost – 126,509 shares at September 30, 2004, and 101,515 shares at December 31, 2003

 

(4,026

)

(3,255

)

Accumulated other comprehensive loss

 

(41,345

)

(44,835

)

Total Common Stock Equity

 

3,780,939

 

3,700,682

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Liabilities and Shareholders’ Equity

 

$

14,243,330

 

$

14,119,206

 

 

 

 

 

 

 

 

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

 

6



 

CINERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCK EQUITY

 

 

 

Common
Stock

 

Paid-in
Capital

 

Retained
Earnings

 

Treasury
Stock

 

Accumulated
Other
Comprehensive
Income (Loss)

 

Total
Common
Stock
Equity

 

 

 

(dollars in thousands, except per share amounts)

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Quarter Ended September 30, 2004

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance at July 1, 2004 (180,323,246 shares)

 

$

1,804

 

$

2,248,084

 

$

1,543,883

 

$

(3,966

)

$

(39,804

)

$

3,750,001

 

Comprehensive income:

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income

 

 

 

 

 

92,923

 

 

 

 

 

92,923

 

Other comprehensive loss, net of tax effect of $1,162

 

 

 

 

 

 

 

 

 

 

 

 

 

Foreign currency translation adjustment

 

 

 

 

 

 

 

 

 

(741

)

(741

)

Unrealized loss on investment trusts

 

 

 

 

 

 

 

 

 

(662

)

(662

)

Cash flow hedges

 

 

 

 

 

 

 

 

 

(138

)

(138

)

Total comprehensive income

 

 

 

 

 

 

 

 

 

 

 

91,382

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Issuance of common stock – net (675,273 shares)

 

7

 

20,989

 

 

 

 

 

 

 

20,996

 

Treasury shares purchased (2,963 shares)

 

 

 

 

 

 

 

(60

)

 

 

(60

)

Dividends on common stock ($0.47 per share)

 

 

 

 

 

(84,873

)

 

 

 

 

(84,873

)

Other

 

 

 

3,578

 

(85

)

 

 

 

 

3,493

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Ending balance at September 30, 2004 (180,995,556 shares)

 

$

1,811

 

$

2,272,651

 

$

1,551,848

 

$

(4,026

)

$

(41,345

)

$

3,780,939

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Quarter Ended September 30, 2003

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance at July 1, 2003 (176,947,118 shares)

 

$

1,769

 

$

2,135,968

 

$

1,495,502

 

$

 

$

(24,423

)

$

3,608,816

 

Comprehensive income:

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income

 

 

 

 

 

111,981

 

 

 

 

 

111,981

 

Other comprehensive income (loss), net of tax effect of $2,532

 

 

 

 

 

 

 

 

 

 

 

 

 

Foreign currency translation adjustment

 

 

 

 

 

 

 

 

 

(8,365

)

(8,365

)

Minimum pension liability adjustment

 

 

 

 

 

 

 

 

 

26

 

26

 

Unrealized gain on investment trusts

 

 

 

 

 

 

 

 

 

32

 

32

 

Cash flow hedges

 

 

 

 

 

 

 

 

 

3,050

 

3,050

 

Total comprehensive income

 

 

 

 

 

 

 

 

 

 

 

106,724

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Issuance of common stock – net (952,704 shares)

 

10

 

31,824

 

 

 

 

 

 

 

31,834

 

Dividends on common stock ($0.46 per share)

 

 

 

 

 

(81,725

)

 

 

 

 

(81,725

)

Other

 

 

 

2,600

 

(31

)

 

 

 

 

2,569

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Ending balance at September 30, 2003 (177,899,822 shares)

 

$

1,779

 

$

2,170,392

 

$

1,525,727

 

$

 

$

(29,680

)

$

3,668,218

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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

 

7



 

CINERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCK EQUITY

(Continued)

 

 

 

Common
Stock

 

Paid-in
Capital

 

Retained
Earnings

 

Treasury
Stock

 

Accumulated
Other
Comprehensive
Income (Loss)

 

Total
Common
Stock
Equity

 

 

 

(dollars in thousands, except per share amounts)

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year to Date September 30, 2004

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance at January 1, 2004 (178,336,854 shares)

 

$

1,784

 

$

2,195,985

 

$

1,551,003

 

$

(3,255

)

$

(44,835

)

$

3,700,682

 

Comprehensive income:

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income

 

 

 

 

 

254,442

 

 

 

 

 

254,442

 

Other comprehensive income (loss), net of tax effect of $(1,928)

 

 

 

 

 

 

 

 

 

 

 

 

 

Foreign currency translation adjustment

 

 

 

 

 

 

 

 

 

691

 

691

 

Unrealized loss on investment trusts

 

 

 

 

 

 

 

 

 

(166

)

(166

)

Cash flow hedges

 

 

 

 

 

 

 

 

 

2,965

 

2,965

 

Total comprehensive income

 

 

 

 

 

 

 

 

 

 

 

257,932

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Issuance of common stock – net (2,683,696 shares)

 

27

 

67,200

 

 

 

 

 

 

 

67,227

 

Treasury shares purchased (24,994 shares)

 

 

 

 

 

 

 

(771

)

 

 

(771

)

Dividends on common stock ($1.41 per share)

 

 

 

 

 

(253,418

)

 

 

 

 

(253,418

)

Other

 

 

 

9,466

 

(179

)

 

 

 

 

9,287

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Ending balance at September 30, 2004 (180,995,556 shares)

 

$

1,811

 

$

2,272,651

 

$

1,551,848

 

$

(4,026

)

$

(41,345

)

$

3,780,939

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year to Date September 30, 2003

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

$

1,687

 

$

1,918,136

 

$

1,403,453

 

$

 

$

(29,800

)

$

3,293,476

 

Balance at January 1, 2003 (168,663,115 shares)

 

 

 

 

 

 

 

 

 

 

 

 

 

Comprehensive income:

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income

 

 

 

 

 

362,719

 

 

 

 

 

362,719

 

Other comprehensive income (loss), net of tax effect of $(26)

 

 

 

 

 

 

 

 

 

 

 

 

 

Foreign currency translation adjustment, net of reclassification adjustments of $6,134 (net of tax)

 

 

 

 

 

 

 

 

 

(2,312

)

(2,312

)

Minimum pension liability adjustment

 

 

 

 

 

 

 

 

 

26

 

26

 

Unrealized gain on investment trusts

 

 

 

 

 

 

 

 

 

2,551

 

2,551

 

Cash flow hedges

 

 

 

 

 

 

 

 

 

(145

)

(145

)

Total comprehensive income

 

 

 

 

 

 

 

 

 

 

 

362,839

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Issuance of common stock – net (9,236,707 shares)

 

92

 

251,179

 

 

 

 

 

 

 

251,271

 

Dividends on common stock ($1.38 per share)

 

 

 

 

 

(240,402

)

 

 

 

 

(240,402

)

Other

 

 

 

1,077

 

(43

)

 

 

 

 

1,034

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Ending balance at September 30, 2003 (177,899,822 shares)

 

$

1,779

 

$

2,170,392

 

$

1,525,727

 

$

 

$

(29,680

)

$

3,668,218

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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

 

8



 

CINERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

 

 

 

Year to Date
September 30

 

 

 

2004

 

2003

 

 

 

 

 

 

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

Cash Flows from Continuing Operations

 

 

 

 

 

Operating Activities

 

 

 

 

 

Net income

 

$

254,442

 

$

362,719

 

Adjustments to reconcile net income to net cash provided by operating activities:

 

 

 

 

 

Depreciation

 

341,287

 

300,145

 

Income of discontinued operations, net of tax

 

 

(8,875

)

Loss on impairment or disposal of subsidiaries and investments, net

 

38,268

 

 

Cumulative effect of changes in accounting principles, net of tax

 

 

(26,462

)

Change in net position of energy risk management activities

 

(35,463

)

(18,097

)

Deferred income taxes and investment tax credits – net

 

81,649

 

35,828

 

Equity in earnings of unconsolidated subsidiaries

 

(18,095

)

(11,652

)

Allowance for equity funds used during construction

 

(1,122

)

(7,111

)

Regulatory assets deferrals

 

(55,877

)

(47,863

)

Regulatory assets amortization

 

74,176

 

74,277

 

Accrued pension and other postretirement benefit costs

 

(60,136

)

(19,792

)

Deferred costs under gas cost recovery mechanism

 

16,762

 

(31,803

)

Cost of removal

 

(13,037

)

(10,658

)

Changes in current assets and current liabilities:

 

 

 

 

 

Accounts and notes receivable

 

358,465

 

338,099

 

Fuel, emission allowances, and supplies

 

(78,502

)

(3,288

)

Prepayments

 

(70,124

)

(29,923

)

Accounts payable

 

(161,574

)

(364,181

)

Accrued taxes and interest

 

(88,347

)

(15,069

)

Other assets

 

(14,726

)

11,265

 

Other liabilities

 

68,087

 

58,130

 

Net cash provided by operating activities

 

636,133

 

585,689

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

Change in short-term debt

 

783,258

 

(332,414

)

Issuance of long-term debt

 

 

688,166

 

Redemption of long-term debt

 

(824,411

)

(187,873

)

Issuance of common stock

 

67,227

 

251,271

 

Dividends on common stock

 

(253,418

)

(240,402

)

Net cash provided by (used in) financing activities

 

(227,344

)

178,748

 

 

 

 

 

 

 

Investing Activities

 

 

 

 

 

Construction expenditures (less allowance for equity funds used during construction)

 

(473,354

)

(498,013

)

Proceeds from notes receivable

 

12,966

 

5,076

 

Withdrawal of restricted cash held on deposit

 

14,861

 

 

Acquisitions and other investments

 

(9,734

)

(36,464

)

Proceeds from disposition of subsidiaries and investments

 

29,726

 

51,252

 

Net cash used in investing activities

 

(425,535

)

(478,149

)

 

 

 

 

 

 

Net increase (decrease) in cash and cash equivalents from continuing operations

 

(16,746

)

286,288

 

Cash and cash equivalents from continuing operations at beginning of period

 

169,120

 

200,112

 

Cash and cash equivalents from continuing operations at end of period

 

$

152,374

 

$

486,400

 

 

 

 

 

 

 

Cash Flows from Discontinued Operations

 

 

 

 

 

Operating activities

 

$

(7,093

)

$

(7,285

)

Financing activities

 

7,093

 

(13,484

)

Investing activities

 

 

(202

)

Net decrease in cash and cash equivalents from discontinued operations

 

 

(20,971

)

Cash and cash equivalents from discontinued operations at beginning of period

 

 

20,971

 

Cash and cash equivalents from discontinued operations at end of period

 

$

 

$

 

 

 

 

 

 

 

Supplemental Disclosure of Cash Flow Information

 

 

 

 

 

Cash paid during the period for:

 

 

 

 

 

Interest (net of amount capitalized)

 

$

219,100

 

$

182,108

 

Income taxes

 

$

46,272

 

$

90,281

 

Non-cash financing activities:

 

 

 

 

 

Issuance of debt securities held as restricted cash

 

$

54,890

 

$

 

 

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

 

9



 

THE CINCINNATI GAS &
ELECTRIC COMPANY

AND SUBSIDIARY COMPANIES

 

10



 

THE CINCINNATI GAS & ELECTRIC COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

 

 

 

Quarter Ended
September 30

 

Year to Date
September 30

 

 

 

2004

 

2003

 

2004

 

2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

Operating Revenues

 

 

 

 

 

 

 

 

 

Electric

 

$

493,742

 

$

474,840

 

$

1,386,625

 

$

1,300,859

 

Gas

 

60,055

 

66,399

 

478,358

 

426,986

 

Total Operating Revenues

 

553,797

 

541,239

 

1,864,983

 

1,727,845

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Expenses

 

 

 

 

 

 

 

 

 

Fuel and purchased power

 

155,963

 

144,794

 

426,754

 

381,615

 

Gas purchased

 

19,721

 

32,223

 

290,656

 

252,074

 

Operation and maintenance

 

166,589

 

133,466

 

482,248

 

394,156

 

Depreciation

 

45,943

 

42,542

 

135,806

 

142,119

 

Taxes other than income taxes

 

45,316

 

44,553

 

158,816

 

154,810

 

Total Operating Expenses

 

433,532

 

397,578

 

1,494,280

 

1,324,774

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Income

 

120,265

 

143,661

 

370,703

 

403,071

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Miscellaneous Income – Net

 

7,204

 

9,654

 

13,247

 

23,137

 

Interest Expense

 

24,083

 

29,514

 

68,934

 

84,781

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Before Taxes

 

103,386

 

123,801

 

315,016

 

341,427

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Taxes

 

39,313

 

44,938

 

118,179

 

125,347

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Before Cumulative Effect of Changes in Accounting Principles

 

64,073

 

78,863

 

196,837

 

216,080

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cumulative effect of changes in accounting principles, net of tax (Note 1(d)(ii))

 

 

 

 

30,938

 

 

 

 

 

 

 

 

 

 

 

Net Income

 

$

64,073

 

$

78,863

 

$

196,837

 

$

247,018

 

 

 

 

 

 

 

 

 

 

 

Preferred Dividend Requirement

 

211

 

211

 

634

 

634

 

 

 

 

 

 

 

 

 

 

 

Net Income Applicable to Common Stock

 

$

63,862

 

$

78,652

 

$

196,203

 

$

246,384

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net Income

 

$

64,073

 

$

78,863

 

$

196,837

 

$

247,018

 

 

 

 

 

 

 

 

 

 

 

Other Comprehensive Income (Loss), Net of Tax

 

(2

)

2,720

 

2,881

 

(307

)

 

 

 

 

 

 

 

 

 

 

Comprehensive Income

 

$

64,071

 

$

81,583

 

$

199,718

 

$

246,711

 

 

 

 

 

 

 

 

 

 

 

 

The accompanying notes as they relate to The Cincinnati Gas & Electric Company are an integral part of these condensed consolidated financial statements.

 

11



 

THE CINCINNATI GAS & ELECTRIC COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

 

ASSETS

 

 

 

September 30
2004

 

December 31
2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Current Assets

 

 

 

 

 

Cash and cash equivalents

 

$

9,225

 

$

15,842

 

Restricted deposits

 

120

 

137

 

Notes receivable from affiliated companies

 

33,534

 

110,149

 

Accounts receivable less accumulated provision for doubtful accounts of  $984 at September 30, 2004, and $1,602 at December 31, 2003

 

210,693

 

107,733

 

Accounts receivable from affiliated companies

 

48,243

 

58,406

 

Fuel, emission allowances, and supplies

 

185,720

 

135,948

 

Energy risk management current assets

 

178,155

 

72,830

 

Prepayments and other

 

51,697

 

15,049

 

Total Current Assets

 

717,387

 

516,094

 

 

 

 

 

 

 

 

 

 

 

 

 

Property, Plant, and Equipment – at Cost

 

 

 

 

 

Utility plant in service

 

 

 

 

 

Electric

 

2,232,418

 

2,155,457

 

Gas

 

1,155,415

 

1,104,797

 

Common

 

291,302

 

288,394

 

Total Utility Plant In Service

 

3,679,135

 

3,548,648

 

Construction work in progress

 

65,285

 

71,947

 

Total Utility Plant

 

3,744,420

 

3,620,595

 

Non-regulated property, plant, and equipment

 

3,627,899

 

3,576,187

 

Accumulated depreciation

 

2,719,785

 

2,625,568

 

Net Property, Plant, and Equipment

 

4,652,534

 

4,571,214

 

 

 

 

 

 

 

 

 

 

 

 

 

Other Assets

 

 

 

 

 

Regulatory assets

 

578,522

 

594,764

 

Energy risk management non-current assets

 

48,205

 

36,583

 

Other

 

89,320

 

90,824

 

Total Other Assets

 

716,047

 

722,171

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Assets

 

$

6,085,968

 

$

5,809,479

 

 

 

 

 

 

 

 

The accompanying notes as they relate to The Cincinnati Gas & Electric Company are an integral part of these condensed consolidated financial statements.

 

12



 

THE CINCINNATI GAS & ELECTRIC COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

 

LIABILITIES AND SHAREHOLDERS’ EQUITY

 

 

 

September 30
2004

 

December 31
2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Current Liabilities

 

 

 

 

 

Accounts payable

 

$

330,002

 

$

217,652

 

Accounts payable to affiliated companies

 

34,714

 

136,470

 

Accrued taxes

 

177,519

 

146,216

 

Accrued interest

 

21,800

 

21,572

 

Notes payable and other short-term obligations (Note 4)

 

112,100

 

112,100

 

Notes payable to affiliated companies (Note 4)

 

242,039

 

49,126

 

Long-term debt due within one year

 

150,000

 

110,000

 

Energy risk management current liabilities

 

126,171

 

77,791

 

Other

 

36,304

 

32,319

 

Total Current Liabilities

 

1,230,649

 

903,246

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-Current Liabilities

 

 

 

 

 

Long-term debt (Note 3)

 

1,309,738

 

1,458,807

 

Deferred income taxes

 

1,037,868

 

985,481

 

Unamortized investment tax credits

 

74,600

 

79,186

 

Accrued pension and other postretirement benefit costs

 

199,106

 

219,393

 

Accrued cost of removal

 

161,865

 

155,336

 

Energy risk management non-current liabilities

 

48,200

 

11,665

 

Other

 

66,689

 

69,687

 

Total Non-Current Liabilities

 

2,898,066

 

2,979,555

 

 

 

 

 

 

 

 

 

 

 

 

 

Commitments and Contingencies (Note 6)

 

 

 

 

 

 

 

 

 

 

 

Total Liabilities

 

4,128,715

 

3,882,801

 

 

 

 

 

 

 

 

 

 

 

 

 

Cumulative Preferred Stock

 

 

 

 

 

Not subject to mandatory redemption

 

20,485

 

20,485

 

 

 

 

 

 

 

 

 

 

 

 

 

Common Stock Equity

 

 

 

 

 

Common stock – $8.50 par value; authorized shares – 120,000,000; outstanding  shares – 89,663,086 at September 30, 2004, and December 31, 2003

 

762,136

 

762,136

 

Paid-in capital

 

586,528

 

586,528

 

Retained earnings

 

617,687

 

589,993

 

Accumulated other comprehensive loss

 

(29,583

)

(32,464

)

Total Common Stock Equity

 

1,936,768

 

1,906,193

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Liabilities and Shareholders’ Equity

 

$

6,085,968

 

$

5,809,479

 

 

 

 

 

 

 

 

The accompanying notes as they relate to The Cincinnati Gas & Electric Company are an integral part of these condensed consolidated financial statements.

 

13



 

THE CINCINNATI GAS & ELECTRIC COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

 

 

 

Year to Date
September 30

 

 

 

2004

 

2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Operating Activities

 

 

 

 

 

Net income

 

$

196,837

 

$

247,018

 

Adjustments to reconcile net income to net cash provided by operating activities:

 

 

 

 

 

Depreciation

 

135,806

 

142,119

 

Deferred income taxes and investment tax credits – net

 

47,546

 

35,406

 

Cumulative effect of changes in accounting principles, net of tax

 

 

(30,938

)

Change in net position of energy risk management activities

 

(32,032

)

(24,465

)

Allowance for equity funds used during construction

 

(699

)

(2,566

)

Regulatory assets deferrals

 

(28,231

)

(17,984

)

Regulatory assets amortization

 

41,688

 

31,411

 

Accrued pension and other postretirement benefit costs

 

(20,287

)

4,719

 

Deferred costs under gas cost recovery mechanism

 

16,762

 

(31,803

)

Cost of removal

 

(5,490

)

 

Changes in current assets and current liabilities:

 

 

 

 

 

Accounts and notes receivable

 

(20,238

)

157,926

 

Fuel, emission allowances, and supplies

 

(49,786

)

(29,517

)

Prepayments

 

(36,751

)

(8,040

)

Accounts payable

 

11,201

 

(163,059

)

Accrued taxes and interest

 

31,839

 

44,048

 

Other assets

 

(14,009

)

6,990

 

Other liabilities

 

5,973

 

(15,350

)

 

 

 

 

 

 

Net cash provided by operating activities

 

280,129

 

345,915

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

Change in short-term debt, including net affiliate notes

 

196,383

 

(44,374

)

Issuance of long-term debt

 

 

256,198

 

Redemption of long-term debt

 

(110,000

)

(100,000

)

Dividends on preferred stock

 

(634

)

(634

)

Dividends on common stock

 

(168,509

)

(166,655

)

 

 

 

 

 

 

Net cash used in financing activities

 

(82,760

)

(55,465

)

 

 

 

 

 

 

Investing Activities

 

 

 

 

 

Construction expenditures (less allowance for equity funds used during  construction)

 

(219,307

)

(236,235

)

Proceeds from disposition of subsidiaries and investments

 

15,321

 

 

 

 

 

 

 

 

Net cash used in investing activities

 

(203,986

)

(236,235

)

 

 

 

 

 

 

Net increase (decrease) in cash and cash equivalents

 

(6,617

)

54,215

 

 

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

15,842

 

45,336

 

 

 

 

 

 

 

Cash and cash equivalents at end of period

 

$

9,225

 

$

99,551

 

 

 

 

 

 

 

 

 

 

 

 

 

Supplemental Disclosure of Cash Flow Information

 

 

 

 

 

Cash paid during the period for:

 

 

 

 

 

Interest (net of amount capitalized)

 

$

65,629

 

$

69,321

 

Income taxes

 

$

16,646

 

$

38,146

 

 

 

 

 

 

 

 

The accompanying notes as they relate to The Cincinnati Gas & Electric Company are an integral part of these condensed consolidated financial statements.

 

14



 

PSI ENERGY, INC.

AND SUBSIDIARY COMPANY

 

15



 

PSI ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

 

 

 

Quarter Ended
September 30

 

Year to Date
September 30

 

 

 

2004

 

2003

 

2004

 

2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

Operating Revenues

 

 

 

 

 

 

 

 

 

Electric

 

$

480,089

 

$

437,084

 

$

1,310,812

 

$

1,210,157

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Expenses

 

 

 

 

 

 

 

 

 

Fuel and purchased power

 

160,541

 

177,786

 

436,937

 

466,656

 

Operation and maintenance

 

134,586

 

118,848

 

399,788

 

361,146

 

Depreciation

 

62,106

 

41,360

 

165,996

 

121,776

 

Taxes other than income taxes

 

10,481

 

10,322

 

41,014

 

42,354

 

Total Operating Expenses

 

367,714

 

348,316

 

1,043,735

 

991,932

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Income

 

112,375

 

88,768

 

267,077

 

218,225

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Miscellaneous Income (Expense) – Net

 

2,213

 

(2,221

)

5,777

 

5,348

 

Interest Expense

 

24,864

 

22,147

 

66,489

 

64,574

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Before Taxes

 

89,724

 

64,400

 

206,365

 

158,999

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Taxes

 

41,237

 

26,808

 

91,626

 

64,107

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Before Cumulative Effect of a Change in Accounting Principle

 

48,487

 

37,592

 

114,739

 

94,892

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cumulative effect of a change in accounting principle, net of tax (Note 1(d)(ii))

 

 

 

 

(494

)

 

 

 

 

 

 

 

 

 

 

Net Income

 

$

48,487

 

$

37,592

 

$

114,739

 

$

94,398

 

 

 

 

 

 

 

 

 

 

 

Preferred Dividend Requirement

 

647

 

647

 

1,940

 

1,940

 

 

 

 

 

 

 

 

 

 

 

Net Income Applicable to Common Stock

 

$

47,840

 

$

36,945

 

$

112,799

 

$

92,458

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net Income

 

$

48,487

 

$

37,592

 

$

114,739

 

$

94,398

 

 

 

 

 

 

 

 

 

 

 

Other Comprehensive Income (Loss), Net of Tax

 

(614

)

(77

)

(248

)

2,247

 

 

 

 

 

 

 

 

 

 

 

Comprehensive Income

 

$

47,873

 

$

37,515

 

$

114,491

 

$

96,645

 

 

 

 

 

 

 

 

 

 

 

 

The accompanying notes as they relate to PSI Energy, Inc. are an integral part of these condensed consolidated financial statements.

 

16



 

PSI ENERGY, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

 

ASSETS

 

 

 

September 30
2004

 

December 31
2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Current Assets

 

 

 

 

 

Cash and cash equivalents

 

$

32,108

 

$

6,565

 

Restricted deposits

 

140,644

 

92,675

 

Notes receivable from affiliated companies

 

31,295

 

65,715

 

Accounts receivable less accumulated provision for doubtful accounts of  $209 at September 30, 2004, and $1,110 at December 31, 2003

 

44,563

 

37,194

 

Accounts receivable from affiliated companies

 

2,390

 

459

 

Fuel, emission allowances, and supplies

 

128,092

 

149,392

 

Energy risk management current assets

 

4,544

 

7,959

 

Prepayments and other

 

5,424

 

5,303

 

Total Current Assets

 

389,060

 

365,262

 

 

 

 

 

 

 

 

 

 

 

 

 

Property, Plant, and Equipment – at Cost

 

 

 

 

 

Utility plant in service

 

6,370,633

 

6,183,475

 

Construction work in progress

 

217,203

 

203,512

 

Total Utility Plant

 

6,587,836

 

6,386,987

 

Accumulated depreciation

 

2,256,363

 

2,133,235

 

Net Property, Plant, and Equipment

 

4,331,473

 

4,253,752

 

 

 

 

 

 

 

 

 

 

 

 

 

Other Assets

 

 

 

 

 

Regulatory assets

 

414,395

 

417,387

 

Energy risk management non-current assets

 

2,396

 

7,061

 

Other investments

 

68,451

 

66,803

 

Other

 

38,938

 

29,372

 

Total Other Assets

 

524,180

 

520,623

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Assets

 

$

5,244,713

 

$

5,139,637

 

 

 

 

 

 

 

 

The accompanying notes as they relate to PSI Energy, Inc. are an integral part of these condensed consolidated financial statements.

 

17



 

PSI ENERGY, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

 

LIABILITIES AND SHAREHOLDERS’ EQUITY

 

 

 

September 30
2004

 

December 31
2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Current Liabilities

 

 

 

 

 

Accounts payable

 

$

80,001

 

$

58,286

 

Accounts payable to affiliated companies

 

44,884

 

69,746

 

Accrued taxes

 

71,963

 

69,419

 

Accrued interest

 

26,926

 

26,615

 

Notes payable and other short-term obligations (Note 4)

 

135,500

 

80,500

 

Notes payable to affiliated companies (Note 4)

 

153,589

 

188,446

 

Long-term debt due within one year

 

51,100

 

 

Energy risk management current liabilities

 

4,328

 

14,744

 

Other

 

24,295

 

25,636

 

Total Current Liabilities

 

592,586

 

533,392

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-Current Liabilities

 

 

 

 

 

Long-term debt

 

1,669,821

 

1,720,476

 

Deferred income taxes

 

624,143

 

573,946

 

Unamortized investment tax credits

 

27,377

 

29,698

 

Accrued pension and other postretirement benefit costs

 

185,843

 

193,336

 

Accrued cost of removal

 

358,979

 

335,520

 

Energy risk management non-current liabilities

 

1,028

 

2,796

 

Other

 

81,580

 

74,958

 

Total Non-Current Liabilities

 

2,948,771

 

2,930,730

 

 

 

 

 

 

 

 

 

 

 

 

 

Commitments and Contingencies (Note 6)

 

 

 

 

 

 

 

 

 

 

 

Total Liabilities

 

3,541,357

 

3,464,122

 

 

 

 

 

 

 

 

 

 

 

 

 

Cumulative Preferred Stock

 

 

 

 

 

Not subject to mandatory redemption

 

42,333

 

42,333

 

 

 

 

 

 

 

 

 

 

 

 

 

Common Stock Equity

 

 

 

 

 

Common stock – without par value; $.01 stated value; authorized shares – 60,000,000; outstanding shares – 53,913,701 at September 30, 2004, and December 31, 2003

 

539

 

539

 

Paid-in capital

 

627,274

 

627,274

 

Retained earnings

 

1,046,879

 

1,018,790

 

Accumulated other comprehensive loss

 

(13,669

)

(13,421

)

Total Common Stock Equity

 

1,661,023

 

1,633,182

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Liabilities and Shareholders’ Equity

 

$

5,244,713

 

$

5,139,637

 

 

 

 

 

 

 

 

The accompanying notes as they relate to PSI Energy, Inc. are an integral part of these condensed consolidated financial statements.

 

18



 

PSI ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

 

 

 

Year to Date
September 30

 

 

 

2004

 

2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Operating Activities

 

 

 

 

 

Net income

 

$

114,739

 

$

94,398

 

Adjustments to reconcile net income to net cash provided by operating activities:

 

 

 

 

 

Depreciation

 

165,996

 

121,776

 

Cumulative effect of a change in accounting principle, net of tax

 

 

494

 

Deferred income taxes and investment tax credits – net

 

48,045

 

14,370

 

Change in net position of energy risk management activities

 

(4,104

)

(1,731

)

Allowance for equity funds used during construction

 

(423

)

(4,545

)

Regulatory assets deferrals

 

(27,646

)

(29,879

)

Regulatory assets amortization

 

32,488

 

42,867

 

Accrued pension and other postretirement benefit costs

 

(7,493

)

(7,471

)

Cost of removal

 

(7,547

)

(10,658

)

Changes in current assets and current liabilities:

 

 

 

 

 

Accounts and notes receivable

 

25,120

 

65,280

 

Fuel, emission allowances, and supplies

 

21,300

 

27,971

 

Prepayments

 

(820

)

(154

)

Accounts payable

 

(3,147

)

(164,989

)

Accrued taxes and interest

 

2,855

 

14,388

 

Other assets

 

(12,655

)

(6,824

)

Other liabilities

 

4,956

 

(909

)

 

 

 

 

 

 

Net cash provided by operating activities

 

351,664

 

154,384

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

Change in short-term debt, including net affiliate notes

 

(34,857

)

(8,091

)

Issuance of long-term debt

 

 

431,968

 

Redemption of long-term debt

 

 

(459,865

)

Contribution from parent

 

 

200,000

 

Dividends on preferred stock

 

(1,940

)

(1,940

)

Dividends on common stock

 

(84,709

)

(73,324

)

 

 

 

 

 

 

Net cash provided by (used in) financing activities

 

(121,506

)

88,748

 

 

 

 

 

 

 

Investing Activities

 

 

 

 

 

Construction expenditures (less allowance for equity funds used during construction)

 

(217,413

)

(231,201

)

Withdrawal of restricted cash held on deposit

 

14,861

 

 

Other investments

 

(2,063

)

(2,486

)

 

 

 

 

 

 

Net cash used in investing activities

 

(204,615

)

(233,687

)

 

 

 

 

 

 

Net increase in cash and cash equivalents

 

25,543

 

9,445

 

 

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

6,565

 

2,007

 

 

 

 

 

 

 

Cash and cash equivalents at end of period

 

$

32,108

 

$

11,452

 

 

 

 

 

 

 

 

 

 

 

 

 

Supplemental Disclosure of Cash Flow Information

 

 

 

 

 

Cash paid during the period for:

 

 

 

 

 

Interest (net of amount capitalized)

 

$

74,245

 

$

72,455

 

Income taxes

 

$

28,302

 

$

50,419

 

 

 

 

 

 

 

Non-cash financing activities:

 

 

 

 

 

Issuance of promissory notes to affiliated company for acquisition of assets

 

$

 

$

375,969

 

Issuance of debt securities held as restricted cash

 

$

54,890

 

$

 

 

 

 

 

 

 

 

The accompanying notes as they relate to PSI Energy, Inc. are an integral part of these condensed consolidated financial statements.

 

19



 

THE UNION LIGHT, HEAT
AND POWER COMPANY

 

20



 

THE UNION LIGHT, HEAT AND POWER COMPANY

CONDENSED STATEMENTS OF INCOME

 

 

 

Quarter Ended
September 30

 

Year to Date
September 30

 

 

 

2004

 

2003

 

2004

 

2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

Operating Revenues

 

 

 

 

 

 

 

 

 

Electric

 

$

63,751

 

$

64,199

 

$

176,698

 

$

170,224

 

Gas

 

11,119

 

11,240

 

85,243

 

75,007

 

Total Operating Revenues

 

74,870

 

75,439

 

261,941

 

245,231

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Expenses

 

 

 

 

 

 

 

 

 

Electricity purchased from parent company for resale

 

45,461

 

44,546

 

124,768

 

120,805

 

Gas purchased

 

5,214

 

5,620

 

53,528

 

46,570

 

Operation and maintenance

 

14,893

 

14,689

 

42,448

 

41,068

 

Depreciation

 

4,992

 

4,554

 

14,944

 

13,582

 

Taxes other than income taxes

 

(567

)

1,135

 

2,110

 

3,417

 

Total Operating Expenses

 

69,993

 

70,544

 

237,798

 

225,442

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Income

 

4,877

 

4,895

 

24,143

 

19,789

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Miscellaneous Income – Net

 

294

 

886

 

1,035

 

3,266

 

Interest Expense

 

1,263

 

1,548

 

3,760

 

4,520

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Before Taxes

 

3,908

 

4,233

 

21,418

 

18,535

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income Taxes

 

1,608

 

1,667

 

8,139

 

7,058

 

 

 

 

 

 

 

 

 

 

 

Net Income

 

$

2,300

 

$

2,566

 

$

13,279

 

$

11,477

 

 

 

 

 

 

 

 

 

 

 

 

The accompanying notes as they relate to The Union Light, Heat and Power Company are an integral part of these condensed financial statements.

 

21



 

THE UNION LIGHT, HEAT AND POWER COMPANY

CONDENSED BALANCE SHEETS

 

ASSETS

 

 

 

September 30
2004

 

December 31
2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Current Assets

 

 

 

 

 

Cash and cash equivalents

 

$

7,699

 

$

1,899

 

Notes receivable from affiliated companies

 

5,301

 

17,906

 

Accounts receivable less accumulated provision for doubtful accounts of  $17 at September 30, 2004, and $192 at December 31, 2003

 

1,937

 

2,458

 

Accounts receivable from affiliated companies

 

169

 

4,407

 

Fuel and supplies

 

10,789

 

7,936

 

Prepayments and other

 

427

 

279

 

Total Current Assets

 

26,322

 

34,885

 

 

 

 

 

 

 

 

 

 

 

 

 

Property, Plant, and Equipment – at Cost

 

 

 

 

 

Utility plant in service

 

 

 

 

 

Electric

 

283,525

 

273,895

 

Gas

 

251,354

 

239,670

 

Common

 

53,551

 

53,297

 

Total Utility Plant In Service

 

588,430

 

566,862

 

Construction work in progress

 

6,887

 

6,165

 

Total Utility Plant

 

595,317

 

573,027

 

Accumulated depreciation

 

186,142

 

176,368

 

Net Property, Plant, and Equipment

 

409,175

 

396,659

 

 

 

 

 

 

 

 

 

 

 

 

 

Other Assets

 

 

 

 

 

Regulatory assets

 

13,182

 

13,224

 

Other

 

716

 

3,903

 

Total Other Assets

 

13,898

 

17,127

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Assets

 

$

449,395

 

$

448,671

 

 

 

 

 

 

 

 

The accompanying notes as they relate to The Union Light, Heat and Power Company are an integral part of these condensed financial statements.

 

22



 

THE UNION LIGHT, HEAT AND POWER COMPANY

CONDENSED BALANCE SHEETS

 

LIABILITIES AND SHAREHOLDER’S EQUITY

 

 

 

September 30
2004

 

December 31
2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

 

 

 

 

 

 

Current Liabilities

 

 

 

 

 

Accounts payable

 

$

3,145

 

$

13,431

 

Accounts payable to affiliated companies

 

18,701

 

21,131

 

Accrued taxes

 

5,804

 

298

 

Accrued interest

 

997

 

1,230

 

Notes payable to affiliated companies (Note 4)

 

36,895

 

45,233

 

Other

 

6,738

 

6,815

 

Total Current Liabilities

 

72,280

 

88,138

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-Current Liabilities

 

 

 

 

 

Long-term debt

 

54,708

 

54,685

 

Deferred income taxes

 

59,546

 

55,488

 

Unamortized investment tax credits

 

2,687

 

2,879

 

Accrued pension and other postretirement benefit costs

 

14,829

 

16,953

 

Accrued cost of removal

 

29,029

 

27,443

 

Other

 

13,681

 

13,729

 

Total Non-Current Liabilities

 

174,480

 

171,177

 

 

 

 

 

 

 

 

 

 

 

 

 

Commitments and Contingencies (Note 6)

 

 

 

 

 

 

 

 

 

 

 

Total Liabilities

 

246,760

 

259,315

 

 

 

 

 

 

 

 

 

 

 

 

 

Common Stock Equity

 

 

 

 

 

Common stock – $15.00 par value; authorized shares – 1,000,000; outstanding shares – 585,333 at September 30, 2004, and December 31, 2003

 

8,780

 

8,780

 

Paid-in capital

 

23,541

 

23,541

 

Retained earnings

 

170,803

 

157,524

 

Accumulated other comprehensive loss

 

(489

)

(489

)

Total Common Stock Equity

 

202,635

 

189,356

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Liabilities and Shareholder’s Equity

 

$

449,395

 

$

448,671

 

 

 

 

 

 

 

 

The accompanying notes as they relate to The Union Light, Heat and Power Company are an integral part of these condensed financial statements.

 

23



THE UNION LIGHT, HEAT AND POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

 

 

 

Year to Date
September 30

 

 

 

2004

 

2003

 

 

 

(dollars in thousands)

 

 

 

(unaudited)

 

Operating Activities

 

 

 

 

 

Net income

 

$

13,279

 

$

11,477

 

Adjustments to reconcile net income to net cash provided by operating activities:

 

 

 

 

 

Depreciation

 

14,944

 

13,582

 

Deferred income taxes and investment tax credits – net

 

3,865

 

4,157

 

Allowance for equity funds used during construction

 

12

 

(224

)

Regulatory assets deferrals

 

(1,139

)

(424

)

Regulatory assets amortization

 

1,046

 

505

 

Accrued pension and other postretirement benefit costs

 

(2,124

)

338

 

Deferred costs under gas cost recovery mechanism

 

3,990

 

(7,279

)

Cost of removal

 

(1,267

)

 

Changes in current assets and current liabilities:

 

 

 

 

 

Accounts and notes receivable

 

17,364

 

10,776

 

Fuel and supplies

 

(2,853

)

(1,592

)

Prepayments

 

(148

)

(102

)

Accounts payable

 

(12,716

)

(10,047

)

Accrued taxes and interest

 

5,273

 

2,453

 

Other assets

 

409

 

1,071

 

Other liabilities

 

(1,178

)

375

 

 

 

 

 

 

 

Net cash provided by operating activities

 

38,757

 

25,066

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

Change in short-term debt, including net affiliate notes

 

(8,338

)

9,650

 

Dividends on common stock

 

 

(6,305

)

 

 

 

 

 

 

Net cash provided by (used in) financing activities

 

(8,338

)

3,345

 

 

 

 

 

 

 

Investing Activities

 

 

 

 

 

Construction expenditures (less allowance for equity funds used during construction)

 

(24,619

)

(27,229

)

 

 

 

 

 

 

Net cash used in investing activities

 

(24,619

)

(27,229

)

 

 

 

 

 

 

Net increase in cash and cash equivalents

 

5,800

 

1,182

 

 

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

1,899

 

3,926

 

 

 

 

 

 

 

Cash and cash equivalents at end of period

 

$

7,699

 

$

5,108

 

 

 

 

 

 

 

Supplemental Disclosure of Cash Flow Information

 

 

 

 

 

Cash paid during the period for:

 

 

 

 

 

Interest (net of amount capitalized)

 

$

3,814

 

$

4,240

 

Income taxes

 

$

4

 

$

3,001

 

 

The accompanying notes as they relate to The Union Light, Heat and Power Company are an integral part of these condensed financial statements.

 

24



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

In this report Cinergy (which includes Cinergy Corp. and all of our regulated and non-regulated subsidiaries) is, at times, referred to in the first person as “we”, “our”, or “us”.  In addition, when discussing Cinergy’s financial information, it necessarily includes the results of The Cincinnati Gas & Electric Company (CG&E), PSI Energy, Inc. (PSI), The Union Light, Heat and Power Company (ULH&P) and all of Cinergy’s other consolidated subsidiaries.  When discussing CG&E’s financial information, it necessarily includes the results of ULH&P and all of CG&E’s other consolidated subsidiaries.

 

1.      Summary of Significant Accounting Policies

 

(a)                                  Presentation

 

Our Condensed Financial Statements reflect all adjustments (which include normal, recurring adjustments) necessary in the opinion of the registrants for a fair presentation of the interim results.  These results are not necessarily indicative of results for a full year.  These statements should be read in conjunction with the Financial Statements and the notes thereto included in the registrants’ combined Form 10-K for the year ended December 31, 2003 (2003 10-K).  Certain amounts in the 2003 Condensed Financial Statements have been reclassified to conform to the 2004 presentation.

 

Management makes estimates and assumptions when preparing financial statements under generally accepted accounting principles.  Key estimates and judgments include:

 

                  Valuing derivative contracts used in our energy marketing and trading activities;

                  Evaluating the regulatory recoverability of various costs;

                  Providing reserves for contingencies, including legal, environmental, and income taxes;

                  Calculations of unbilled revenues; and

                  Evaluating various non-regulated fixed assets and investments for impairment.

 

These estimates and judgments are discussed more fully in Critical Accounting Policies in our 2003 10-K.  Actual results could differ, as these estimates and assumptions involve judgment about future events or performance. 

 

(b)                                  Revenue Recognition

 

(i)           Utility Revenues

 

CG&E, PSI, and ULH&P (collectively, our utility operating companies) record Operating Revenues for electric and gas service when delivered to customers.  Customers are billed throughout the month as both gas and electric meters are read.  We recognize revenues for retail energy sales that have not yet been billed, but where gas or electricity has been consumed.  This is termed “unbilled revenues” and is a widely recognized and accepted practice for utilities.  In making our estimates of unbilled revenues, we use complex systems that consider various factors, including weather, in our calculation of retail customer consumption at the end of each month.  Given the use of these systems and the fact that customers are billed monthly, we believe it is unlikely that materially different results will occur in future periods when these amounts are subsequently billed.

 

25



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

The amount of unbilled revenues for Cinergy, CG&E, PSI, and ULH&P as of September 30, 2004 and 2003, were as follows:

 

 

 

 

 

 

 

 

 

2004

 

2003

 

 

 

(in millions)

 

Cinergy

 

$

137

 

$

117

 

CG&E and subsidiaries

 

68

 

60

 

PSI

 

69

 

57

 

ULH&P

 

12

 

11

 

 

(ii)          Energy Marketing and Trading Revenues

 

We market and trade electricity, natural gas, and other energy-related products.  Many of the contracts associated with these products qualify as derivatives in accordance with Statement of Financial Accounting Standards No. 133, Accounting for Derivative Instruments and Hedging Activities.  We designate derivative transactions as either trading or non-trading at the time they are originated in accordance with Emerging Issues Task Force (EITF) Issue 02-3, Issues Involved in Accounting for Derivative Contracts Held for Trading Purposes and Contracts Involved in Energy Trading and Risk Management Activities.  Generally, trading contracts are reported on a net basis and non-trading contracts are reported on a gross basis.  Net reporting requires presentation of realized and unrealized gains and losses on trading derivatives on a net basis in Operating Revenues.  Gross reporting requires presentation of sales contracts in Operating Revenues and purchase contracts in Fuel and purchased power expense or Gas purchased expense.

 

(c)                                  Derivatives

 

Cinergy designates derivatives as fair value hedges for certain volumes of our natural gas held in storage.  Under this accounting election, changes in the fair value of both the derivative as well as the hedged item (the specified gas held in storage) are included in Gas Operating Revenues in Cinergy’s Condensed Consolidated Statements of Income.  We assess the effectiveness of the derivatives in offsetting the change in fair value of the gas held in storage on a quarterly basis.  Selected information on Cinergy’s hedge accounting activities were as follows:

 

 

 

 

 

 

 

 

 

Quarter Ended
September 30, 2004

 

Year to Date
September 30, 2004

 

 

 

(in millions)

 

 

 

 

 

 

 

Portion of gain (loss) on hedging instruments determined to be ineffective and included in net income

 

$

(3

)

$

 

Portion of gain (loss) on hedging instruments excluded from assessment of effectiveness and included in net income

 

(6

)

(8

)

 

 

 

 

 

 

Total

 

$

(9

)

$

(8

)

 

 

 

 

 

 

 

(d)                                  Accounting Changes

 

(i)           Consolidation of Variable Interest Entities (VIE)

 

In January 2003, the Financial Accounting Standards Board (FASB) issued Interpretation No. 46, Consolidation of Variable Interest Entities (Interpretation 46), which significantly changes the consolidation requirements for traditional special purpose entities (SPE) and certain other entities

 

26



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

subject to its scope.  This interpretation defines a VIE as (a) an entity that does not have sufficient equity to support its activities without additional financial support or (b) any entity that has equity investors that do not have voting rights, do not absorb first dollar losses, or receive returns.  These entities must be consolidated whenever Cinergy would be anticipated to absorb greater than 50 percent of the losses or receive greater than 50 percent of the returns.

 

In accordance with its two stage adoption guidance, we implemented Interpretation 46 for traditional SPEs on July 1, 2003, and for all other entities, including certain operating joint ventures, as of March 31, 2004.  The consolidation of certain operating joint ventures as of March 31, 2004, did not have a material impact on our financial position or results of operations.

 

Cinergy also holds interests in several joint ventures, primarily engaged in cogeneration and energy efficiency operations, that are considered VIEs which do not require consolidation.  Our exposure to loss from our involvement with these entities is not material. 

 

(ii)          Cumulative Effect of Changes in Accounting Principles

 

In 2003, Cinergy, CG&E, and PSI recognized Cumulative effect of changes in accounting principles, net of tax gain/(loss) of approximately $26 million, $31 million, and $(0.5) million, respectively.  The cumulative effect of changes in accounting principles was a result of the adoption of Statement of Financial Accounting Standards No. 143, Accounting for Asset Retirement Obligations and the rescission of EITF Issue 98-10, Accounting for Contracts Involved in Energy Trading and Risk Management Activities as discussed in the 2003 10-K.

 

2.      Common Stock

 

As discussed in the 2003 10-K, Cinergy issues new Cinergy Corp. common stock shares to satisfy obligations under certain of its employee stock plans and the Cinergy Corp. Direct Stock Purchase and Dividend Reinvestment Plan.  During the nine months ended September 30, 2004, Cinergy issued approximately 2.7 million shares under these plans.

 

3.      Long-term Debt

 

In February 2004, CG&E repaid at maturity $110 million of its 6.45% First Mortgage Bonds.

 

In April 2004, Cinergy Corp. repaid at maturity $200 million of its 6.125% Debentures.

 

In September 2004, Cinergy Corp. repaid at maturity $500 million of its 6.25% Debentures.

 

4.      Notes Payable and Other Short-term Obligations

 

(a)                                  Short-term Notes

 

In April 2004, Cinergy Corp. successfully placed two senior unsecured revolving credit facilities with an aggregate borrowing capacity of $1.5 billion, comprised of a $500 million 364-day facility and a $1 billion three-year facility.  These facilities replaced two facilities that were scheduled to expire in April and May of 2004, respectively.

 

27



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

At September 30, 2004, Cinergy Corp. had approximately $582 million remaining unused and available capacity relating to its $1.5 billion revolving credit facilities.  These revolving credit facilities include the following:

 

 

 

 

 

 

 

 

 

 

 

Credit Facility

 

Expiration

 

Established
Lines

 

Outstanding
and
Committed

 

Unused and
Available

 

 

 

 

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

364-day senior revolving

 

April 2005

 

 

 

 

 

 

 

Direct borrowing

 

 

 

$

 

 

$

 

$

 

 

Commercial paper support

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total 364-day facility

 

 

 

500

 

 

500

 

 

 

 

 

 

 

 

 

 

 

Three-year senior revolving

 

April 2007

 

 

 

 

 

 

 

Direct borrowing

 

 

 

 

 

 

 

 

Commercial paper support

 

 

 

 

 

912

 

 

 

Letter of credit support

 

 

 

 

 

6

 

 

 

 

 

 

 

 

 

 

 

 

 

Total three-year facility

 

 

 

1,000

 

918

 

82

 

 

 

 

 

 

 

 

 

 

 

Total Credit Facilities

 

 

 

$

1,500

 

$

918

 

$

582

 

 

 

 

 

 

 

 

 

 

 

 

(b)                                  Commercial Paper

 

Cinergy Corp.’s commercial paper program is supported by Cinergy Corp.’s $1.5 billion revolving credit facilities.  The commercial paper program supports, in part, the short-term borrowing needs of CG&E and PSI and eliminates their need for separate commercial paper programs.  In September 2004, Cinergy Corp. expanded its commercial paper program from $800 million to a maximum outstanding principal amount of $1.5 billion.  As of September 30, 2004, Cinergy Corp. had $912 million in commercial paper outstanding.

 

(c)                                  Variable Rate Pollution Control Notes

 

In August 2004, PSI borrowed the proceeds from the issuance by the Indiana Development Finance Authority of $55 million principal amount of its Environmental Revenue Bonds, Series 2004A, due August 2039.  The initial interest rate for the bonds was 1.13 percent and is reset weekly.  Proceeds from the borrowing will be used for the acquisition and construction of various solid waste disposal facilities located at various generating stations in Indiana.  The $55 million is being held in escrow by an independent trustee and will be drawn upon as facilities are built.  Holders of these notes are entitled to credit enhancement in the form of a standby letter of credit which, if drawn upon, provides for the payment of both interest and principal on the notes.  Because the holders of these notes have the right to have their notes redeemed on a weekly basis, they are reflected in Notes payable and other short-term obligations on Cinergy’s and PSI’s balance sheets.

 

28



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

The following table summarizes our Notes payable and other short-term obligations and Notes payable to affiliated companies.

 

 

 

 

 

 

 

 

 

 

 

 

 

September 30, 2004

 

December 31, 2003

 

 

 

Established
Lines

 

Outstanding

 

Established
Lines

 

Outstanding

 

 

 

(in millions)

 

Cinergy

 

 

 

 

 

 

 

 

 

Cinergy Corp.

 

 

 

 

 

 

 

 

 

Revolving lines

 

$

1,500

 

$

 

$

1,000

 

$

 

Uncommitted lines(1)

 

40

 

 

40

 

 

Commercial paper(2)

 

 

 

912

 

 

 

146

 

 

 

 

 

 

 

 

 

 

 

Utility operating companies

 

 

 

 

 

 

 

 

 

Uncommitted lines(1)

 

75

 

 

75

 

 

Pollution control notes

 

 

 

248

 

 

 

193

 

 

 

 

 

 

 

 

 

 

 

Non-regulated subsidiaries

 

 

 

 

 

 

 

 

 

Revolving lines

 

14

 

10

 

19

 

10

 

Short-term debt

 

 

 

2

 

 

 

2

 

Pollution control notes

 

 

 

25

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy Total

 

 

 

$

1,197

 

 

 

$

351

 

 

 

 

 

 

 

 

 

 

 

CG&E and subsidiaries

 

 

 

 

 

 

 

 

 

Uncommitted lines(1)

 

$

15

 

$

 

$

15

 

$

 

Pollution control notes

 

 

 

112

 

 

 

112

 

Money pool

 

 

 

242

 

 

 

49

 

 

 

 

 

 

 

 

 

 

 

CG&E Total

 

 

 

$

354

 

 

 

$

161

 

 

 

 

 

 

 

 

 

 

 

PSI

 

 

 

 

 

 

 

 

 

Uncommitted lines(1)

 

$

60

 

$

 

$

60

 

$

 

Pollution control notes

 

 

 

136

 

 

 

81

 

Money pool

 

 

 

154

 

 

 

188

 

 

 

 

 

 

 

 

 

 

 

PSI Total

 

 

 

$

290

 

 

 

$

269

 

 

 

 

 

 

 

 

 

 

 

ULH&P

 

 

 

 

 

 

 

 

 

Money pool

 

 

 

$

37

 

 

 

$

45

 

 

 

 

 

 

 

 

 

 

 

ULH&P Total

 

 

 

$

37

 

 

 

$

45

 

 

(1)

 

These facilities are not guaranteed sources of capital and represent an informal agreement to lend money, subject to availability, with pricing to be determined at the time of advance.

 

 

 

(2)

 

In September 2004, Cinergy Corp. increased its commercial paper program limit from $800 million to $1.5 billion.  The commercial paper program is supported by Cinergy Corp.’s revolving lines of credit.

 

In our credit facilities, Cinergy Corp. has covenanted to maintain:

 

                  a consolidated net worth of $2 billion; and

                  ratio of consolidated indebtedness to consolidated total capitalization not in excess of 65 percent.

 

A breach of these covenants could result in the termination of the credit facilities and the acceleration of the related indebtedness.  In addition to breaches of covenants, certain other events that could result in the termination of available credit and acceleration of the related indebtedness include:

 

                  bankruptcy;

 

29



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

                  defaults in the payment of other indebtedness; and

                  judgments against the company that are not paid or insured.

 

The latter two events, however, are subject to dollar-based materiality thresholds.

 

5.      Energy Trading Credit Risk

 

Cinergy’s extension of credit for energy marketing and trading is governed by a Corporate Credit Policy.  Written guidelines approved by Cinergy’s Risk Policy Committee document the management approval levels for credit limits, evaluation of creditworthiness, and credit risk mitigation procedures.  Exposures to credit risks are monitored daily by the Corporate Credit Risk function, which is independent of all trading operations.  As of September 30, 2004, approximately 90 percent of the credit exposure, net of credit collateral, related to energy trading and marketing activity was with counterparties rated investment grade or the counterparties’ obligations were guaranteed or secured by an investment grade entity.  The majority of these investment grade counterparties are externally rated.  If a counterparty has an external rating, the lower of Standard & Poor’s or Moody’s Investors Service is used; otherwise, Cinergy’s internal rating of the counterparty is used.  The remaining 10 percent represents $65 million with counterparties rated non-investment grade.

 

As of September 30, 2004, CG&E had a concentration of trading credit exposure of approximately $39 million with two counterparties accounting for greater than 10 percent of CG&E’s total trading credit exposure.  These counterparties are rated investment grade.

 

Energy commodity prices can be extremely volatile and the market can, at times, lack liquidity.  Because of these issues, credit risk for energy commodities is generally greater than with other commodity trading.

 

We continually review and monitor our credit exposure to all counterparties and secondary counterparties.  If appropriate, we may adjust our credit reserves to attempt to compensate for increased credit risk within the industry.  Counterparty credit limits may be adjusted on a daily basis in response to changes in a counterparty’s creditworthiness, financial status, or public debt ratings.

 

6.      Commitments and Contingencies

 

(a)                                  Environmental

 

(i)           Ozone Transport Rulemakings

 

In October 1998, the United States Environmental Protection Agency (EPA) finalized its ozone transport rule, also known as the Nitrogen Oxide (NOX) State Implementation Plan (SIP) Call, which addresses wind-blown ozone and ozone precursors that impact air quality in downwind states.  The EPA’s final rule, which applies to 22 states in the eastern United States including the three states in which our electric utilities operate, required states to develop rules to reduce NOX emissions from utility and industrial sources.  In a related matter, in response to petitions filed by several states alleging air quality impacts from upwind sources located in other states, the EPA issued a rule pursuant to Section 126 of the Clean Air Act (CAA) that required reductions similar to those required

 

30



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

under the NOX SIP Call.  Various states and industry groups challenged the final rules in the Court of Appeals for the District of Columbia Circuit, but the court upheld the key provisions of the rules.

 

The EPA has proposed withdrawal of the Section 126 rule in states with approved rules under the final NOX SIP Call, which includes Indiana, Kentucky, and Ohio.  All three states have adopted a cap and trade program as the mechanism to achieve the required reductions.  In September 2000, Cinergy announced a plan for its subsidiaries, CG&E and PSI, to invest in pollution control and other equipment to reduce NOX emissions.  We have installed selective catalytic reduction units (SCR) and other pollution controls and implemented certain combustion improvements at various generating stations to meet the May 2004 compliance deadline under the NOX SIP Call.  Cinergy also utilizes the NOX emission allowance market to buy or sell NOX emission allowances as appropriate.  We currently estimate that we will incur capital costs of approximately $44 million in addition to $757 million already incurred to comply with this program.

 

(ii)          Section 126 Petitions

 

In March 2004, the state of North Carolina filed a petition under Section 126 of the CAA in which it alleges that sources in 13 upwind states including Ohio, Indiana, and Kentucky, significantly contribute to North Carolina’s non-attainment with certain ambient air quality standards.  Depending on the EPA’s final disposition of the pending petition and its proposal discussed above, Cinergy’s generating stations could become subject to requirements for additional sulfur dioxide and NOX emissions reductions.  It is unclear at this time whether any additional reductions would be necessary beyond those required under the CAA.

 

(iii)         Clean Air Act Lawsuit

 

In November 1999, and through subsequent amendments, the United States brought a lawsuit in the United States Federal District Court for the Southern District of Indiana (District Court) against Cinergy, CG&E, and PSI alleging various violations of the CAA.  Specifically, the lawsuit alleges that we violated the CAA by not obtaining Prevention of Significant Deterioration (PSD), Non-Attainment New Source Review (NSR), and Ohio and Indiana SIP permits for various projects at our owned and co-owned generating stations.  Additionally, the suit claims that we violated an Administrative Consent Order entered into in 1998 between the EPA and Cinergy relating to alleged violations of Ohio’s SIP provisions governing particulate matter at Unit 1 at CG&E’s W.C. Beckjord Generating Station (Beckjord Station).  The suit seeks (1) injunctive relief to require installation of pollution control technology on various generating units at CG&E’s Beckjord Station and Miami Fort Generating Station (Miami Fort Station), and PSI’s Cayuga Generating Station, Gallagher Generating Station, Wabash River Generating Station, and Gibson Generating Station (Gibson Station), and (2) civil penalties in amounts of up to $27,500 per day for each violation.  In addition, three northeast states and two environmental groups have intervened in the case.  The case is currently in discovery, and the District Court has set the case for trial by jury commencing in February 2006.

 

In March 2000, the United States also filed in the District Court an amended complaint in a separate lawsuit alleging violations of the CAA relating to PSD, NSR, and Ohio SIP requirements regarding various generating stations, including a generating station operated by Columbus Southern Power Company (CSP) and jointly-owned by CSP, The Dayton Power and Light Company (DP&L), and CG&E.  The EPA is seeking injunctive relief and civil penalties of up to $27,500 per day for each

 

31



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

violation.  This suit is being defended by CSP.  In April 2001, the District Court in that case ruled that the Government and the intervening plaintiff environmental groups cannot seek monetary damages for alleged violations that occurred prior to November 3, 1994; however, they are entitled to seek injunctive relief for such alleged violations.  Neither party appealed that decision.

 

In addition, Cinergy and CG&E have been informed by DP&L that in June 2000, the EPA issued a Notice of Violation (NOV) to DP&L for alleged violations of PSD, NSR, and Ohio SIP requirements at a generating station operated by DP&L and jointly-owned by CG&E.  The NOV indicated the EPA may (1) issue an order requiring compliance with the requirements of the Ohio SIP, or (2) bring a civil action seeking injunctive relief and civil penalties of up to $27,500 per day for each violation.  In September 2004, Marilyn Wall and the Sierra Club brought a lawsuit against Cinergy, DP&L and CSP for alleged violations of the CAA at this same generating station.

 

It is not possible to predict whether resolution of these matters would have a material effect on our financial position or results of operations.  We intend to defend against the allegations, discussed above, vigorously in court. 

 

 (iv)        Carbon Dioxide (CO2 ) Lawsuit

 

In July 2004, the states of Connecticut, New York, California, Iowa, New Jersey, Rhode Island, Vermont, Wisconsin, and the City of New York brought a lawsuit in the United States District Court for the Southern District of New York against Cinergy and American Electric Power Company, Inc., American Electric Power Service Corporation, The Southern Company, Tennessee Valley Authority, and Xcel Energy Inc.  That same day, a similar lawsuit was filed against the same companies by Open Space Institute, Inc., Open Space Conservancy, Inc., and The Audubon Society of New Hampshire.  These lawsuits allege that the defendants’ emissions of CO2 from the combustion of fossil fuels at electric generating facilities contribute to global warming and amount to a public nuisance.  The complaints also allege that the defendants could generate the same amount of electricity while emitting significantly less CO2.  Plaintiffs are seeking an injunction requiring each defendant to cap its CO2 emissions and then reduce them by a specified percentage each year for at least a decade.  Cinergy intends to defend this lawsuit vigorously in court and filed a motion to dismiss with the other defendants in September 2004; however, we are not able to predict whether resolution of these matters would have a material effect on our financial position or results of operations.

 

(v)           Selective Catalytic Reduction Units at Gibson Generating Station

 

In May 2004, SCRs and other pollution control equipment became operational at Units 4 and 5 of PSI’s Gibson Station in accordance with compliance deadlines under the NOX SIP Call.  In June and July 2004, Gibson Station temporarily shut down the equipment on these units due to a concern over an acid aerosol mist haze (plume) sometimes occurring in areas near the plant.  Portions of the plume from those units’ stacks appeared to break apart and descend to ground level at certain times under certain weather conditions.  As a result, and, working with the City of Mt. Carmel, Illinois, Illinois EPA, Indiana Department of Environmental Management (IDEM), United States EPA, and the State of Illinois, we developed a protocol regarding the use of the SCRs while we explore alternatives to address this issue.  After the protocol was finalized, the Illinois Attorney General brought an action in Wabash County Circuit Court against PSI seeking a preliminary injunction to enforce the protocol.  In August 2004, the court granted that preliminary injunction.  PSI is appealing that decision to the Fifth District Appellate Court, but we cannot predict the ultimate outcome of that appeal or of the underlying action by the Illinois Attorney General.

 

32



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

We will seek recovery of any related capital as well as increased emission allowance expenditures through the regulatory process.  We do not believe costs related to resolving this matter will have a material impact on our financial position or results of operations.

 

(vi)         Manufactured Gas Plant (MGP) Sites

 

Prior to the 1950s, gas was produced at MGP sites through a process that involved the heating of coal and/or oil.  The gas produced from this process was sold for residential, commercial, and industrial uses.

 

Coal tar residues, related hydrocarbons, and various metals have been found at former MGP sites in Indiana, including at least 22 sites that PSI or its predecessors previously owned and sold in a series of transactions with Northern Indiana Public Service Company (NIPSCO) and Indiana Gas Company, Inc. (IGC).

 

The 22 sites are in the process of being studied and will be remediated, if necessary.  In 1998 NIPSCO, IGC, and PSI entered into Site Participation and Cost Sharing Agreements to allocate liability and responsibilities between them.  The IDEM oversees investigation and cleanup of all of these sites.  Thus far, PSI has primary responsibility for investigating, monitoring and, if necessary, remediating nine of these sites.  In December 2003, PSI entered into a voluntary remediation plan with the state of Indiana, providing a formal framework for the investigation and cleanup of the sites for which PSI has primary responsibility.

 

In April 1998, PSI filed suit in Hendricks County in the state of Indiana against its general liability insurance carriers.  PSI sought a declaratory judgment to obligate its insurance carriers to (1) defend MGP claims against PSI and compensate PSI for its costs of investigating, preventing, mitigating, and remediating damage to property and paying claims related to MGP sites; or (2) pay PSI’s cost of defense.  The trial court issued a variety of rulings with respect to the claims and defenses in the litigation.  PSI appealed certain adverse rulings to the Indiana Court of Appeals and the appellate court has remanded the case to the trial court.  The court has set the case for trial commencing in January 2005.  At the present time, PSI cannot predict the outcome of this litigation, including the outcome of the appeals.

 

PSI has accrued costs related to investigation, remediation, and groundwater monitoring for those sites where such costs are probable and can be reasonably estimated.  We will continue to investigate and remediate the sites as outlined in the voluntary remediation plan.  As additional facts become known and investigation is completed, we will assess whether the likelihood of incurring additional costs becomes probable.  Until all investigation and remediation is complete, we are unable to determine the overall impact on our financial position or results of operations.

 

CG&E and ULH&P have performed site assessments on certain of their sites where we believe MGP activities have occurred at some point in the past and have found no imminent risk to the environment.  At the present time, CG&E and ULH&P cannot predict whether investigation and/or remediation will be required in the future at any of these sites.

 

33



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

(vii)        Asbestos Claims Litigation

 

CG&E and PSI have been named as defendants or co-defendants in lawsuits related to asbestos at their electric generating stations.  Currently, there are approximately 100 pending lawsuits.  In these lawsuits, plaintiffs claim to have been exposed to asbestos-containing products in the course of their work at the CG&E and PSI generating stations.  The plaintiffs further claim that as the property owner of the generating stations, CG&E and PSI should be held liable for their injuries and illnesses based on an alleged duty to warn and protect them from any asbestos exposure.  A majority of the lawsuits to date have been brought against PSI.  The impact on CG&E’s and PSI’s financial position or results of operations of these cases to date has not been material.

 

Of these lawsuits, one case filed against PSI has been tried to verdict.  The jury returned a verdict against PSI in the amount of approximately $500,000 on a negligence claim and a verdict for PSI on punitive damages.  PSI received an adverse ruling in its initial appeal of the negligence claim verdict, but the Indiana Supreme Court accepted the transfer of the case, and heard oral argument in June 2004.  In addition, PSI has settled a number of other lawsuits for amounts, which neither individually nor in the aggregate, are material to PSI’s financial position or results of operations.

 

At this time, CG&E and PSI are not able to predict the ultimate outcome of these lawsuits or the impact on CG&E’s and PSI’s financial position or results of operations.

 

(b)                                  Regulatory

 

(i)           PSI Retail Electric Rate Case

 

In December 2002, PSI filed a petition with the Indiana Utility Regulatory Commission (IURC) seeking approval of an increase in base retail electric rates and approval of certain rate recovery mechanisms.  In May 2004, the IURC issued an order in this case and, consequently, PSI implemented base retail electric rate changes to its tariffs.  When combined with revenue increases attributable to PSI’s environmental construction-work-in-progress tracking mechanism, the order results in an approximate $140 million increase in annual revenues.  PSI’s original request for an approximate $180 million annual revenue increase was reduced by approximately $20 million for a lower return on equity, approximately $15 million related to profits from off-system sales (subject to future adjustment through a tracking mechanism and a 50/50 sharing agreement), and approximately $5 million of additional items.  The order authorizes full recovery of all requested regulatory assets and an overall 7.3 percent return, including a 10.5 percent return on equity.  In addition, the IURC’s order provides PSI the continuation of a purchased power tracker and the establishment of new trackers for future NOX emission allowance costs and certain costs related to the Midwest Independent System Operator, Inc.

 

(ii)          CG&E Rate Filings

 

As discussed in more detail in the 2003 10-K, CG&E made multiple rate filings in 2003 with the Public Utilities Commission of Ohio (PUCO) seeking approval of CG&E's methodology for establishing market-based rates for generation service at the end of the market development period and to recover investments made in the transmission and distribution system.  In December 2003, these filings, and CG&E's proposal for establishing its post-market development period market pricing methodology, were consolidated for hearing before the PUCO.  In addition, the PUCO requested in these proceedings that CG&E propose a rate stabilization plan as an alternative to market-based rates so as to mitigate the potential for significant rate increases when the market development (frozen rate) period comes to an end.  There is no requirement in Ohio law that CG&E file such a plan.  However, in January 2004, CG&E filed its proposed rate stabilization plan.

 

In May 2004, CG&E entered into a settlement agreement with many of the parties to these proceedings requesting that the PUCO approve a modified version of the rate stabilization plan.  Under this plan, CG&E would begin to collect a non-bypassable provider of last resort (POLR) charge intended to provide recovery for increased capacity reserves, environmental compliance and emission allowance expenditures.  The plan also established a bypassable generation charge, which included a fuel cost recovery mechanism.  It allowed for a two-year extension of the residential regulatory transition charge (RTC) in 2009 and 2010 and a three-year extension of the five percent residential generation rate reduction in the years 2006-2008.  Finally, it provided for deferral and recovery of certain transmission and distribution costs.

 

 

34



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

In September 2004, the PUCO issued an order seeking to modify several key provisions of this settlement.  The PUCO order, among other things, would not allow extension of the RTC for residential customers or permit deferral and recovery of certain transmission and distribution costs from residential customers. The PUCO order would allow CG&E to end the five percent generation rate reduction for residential customers (i.e., increase the residential generation rate by five percent) beginning January 1, 2006, but would also allow certain customers who have switched to another generation supplier to entirely avoid the POLR charge.  As a result of these modifications, CG&E filed a petition for rehearing in October 2004.  The rehearing petition requests one of the following to be effective January 1, 2005 for non-residential customers and January 1, 2006 for residential customers:

 

      Approval of the modified rate stabilization plan reflected in the May 2004 settlement (as discussed above);

      Approval of a further modified rate stabilization plan, which includes some of the same provisions as the May 2004 plan.  However, this plan (a) changes the POLR charge to provide recovery only for environmental compliance expenditures and allows customers that have switched to by-pass this charge, (b) adds an infrastructure maintenance fund charge, (c) adds a system reliability tracker that would provide recovery primarily for capacity and purchased power, (d) includes recovery of emission allowances costs as part of the fuel cost recovery mechanism, and (e) ends the five percent generation rate reduction for residential customers but does not include an extension of the residential RTC; or

      Approval to proceed with market-based rates, which is permitted under CG&E’s existing transition plan.

 

A rehearing order is expected in the fourth quarter of 2004.  We cannot predict the outcome of this proceeding.  Because the rate stabilization plan is a voluntary filing on CG&E's part, CG&E may reject the PUCO's order if it provides for a rate stabilization plan that is unacceptable to CG&E.

 

In conjunction with the consolidated filings discussed above, CG&E has also filed an application for an annual increase of approximately $78 million in electric distribution base rates, to be effective in the first quarter of 2005 for non-residential customers and January 1, 2006 for residential customers.  The proposed rate stabilization plans described above provide for CG&E to withdraw this base rate case upon approval of the rate stabilization plan.  In such event, CG&E can then file a new distribution base rate case, with rates to become effective January 1, 2006.  If the PUCO's order on rehearing provides for a rate stabilization plan that is unacceptable to CG&E, CG&E may seek to proceed immediately with market-based rates for its commercial, industrial and other public authority customer classes and also proceed immediately with this base rate case for such classes.  Market based rates must be approved by the PUCO and would eliminate the various deferral and recovery mechanisms contemplated with the rate stabilization plan.

 

(iii)         ULH&P Gas Rate Case

 

In the second quarter of 2001, ULH&P filed a retail gas rate case with the Kentucky Public Service Commission (KPSC) requesting, among other things, deferral of costs associated with an accelerated gas main replacement program of up to $112 million over ten years.  The costs would be recovered through a tracking mechanism for an initial three year period, with the possibility of renewal up to ten years.  The tracking mechanism allows ULH&P to recover depreciation costs and rate of return annually over the life of the deferred assets.  Through September 30, 2004, ULH&P has recovered approximately $3.9 million under this tracking mechanism.  The Kentucky Attorney General has

 

35



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

appealed to the Franklin Circuit Court the KPSC’s approval of the tracking mechanism and the new tracking mechanism rates.  At the present time, ULH&P cannot predict the timing or outcome of this litigation.

 

(iv)         Gas Distribution Plant

 

In June 2003, the PUCO approved an amended settlement agreement between CG&E and the PUCO Staff in a gas distribution safety case arising out of a gas leak at a service head-adapter (SHA) style riser on CG&E’s distribution system.  The amended settlement agreement required CG&E to expend a minimum of $700,000 to replace SHA risers by December 31, 2003, and to file a comprehensive plan addressing all SHA risers on its distribution system.  Cinergy has approximately 180,000 SHA risers on its distribution system, of which approximately 150,000 are in CG&E’s service area and approximately 30,000 are in ULH&P’s service area.  Further investigation to determine whether any additional SHA risers will need maintenance or replacement is estimated to be completed by the end of the third quarter of 2005.  If CG&E and ULH&P determine that replacement of all SHA risers is appropriate, we currently estimate that the replacement cost could be approximately $70 million for CG&E, which includes approximately $10 million for ULH&PCG&E and ULH&P would pursue recovery of this cost through rates.  At this time, Cinergy, CG&E, and ULH&P cannot predict the outcome of this matter.

 

(c)                                  Other

 

(i)           Gas Customer Choice

 

In January 2000, Cinergy Investments, Inc. (Investments) sold Cinergy Resources, Inc. (Resources), a former subsidiary, to Licking Rural Electrification, Inc., doing business as The Energy Cooperative.  In February 2001, Cinergy, CG&E, and Resources were named as defendants in three class action lawsuits brought by customers relating to The Energy Cooperative's removal from the Ohio Gas Customer Choice program and the failure to deliver gas to customers.  Subsequently, these class action suits were amended and consolidated into one suit (Class-action).  In October 2001, Cinergy, CG&E, and Investments initiated litigation against The Energy Cooperative requesting indemnification by The Energy Cooperative for the claims asserted by former customers in the Class-action litigation (Cinergy lawsuit). 

 

In March 2001, Cinergy, CG&E, and Investments were named as defendants in a lawsuit filed by The Energy Cooperative and Resources (Energy Cooperative lawsuit).  This lawsuit concerned any obligations or liabilities Investments may have had to The Energy Cooperative following its sale of Resources.  All three matters were settled in the second quarter of 2004.  In the Energy Cooperative lawsuit, The Energy Cooperative agreed to indemnify Cinergy, CG&E and Investments for the claims asserted by the former residential customers in the Class-action litigation.  In exchange, Cinergy has agreed to settle claims that it brought in the Cinergy lawsuit.  The settlement is pending final court approval.  None of these settlements are material to Cinergy’s financial position or results of operations.

 

 

(ii)          Energy Market Investigations

 

In July 2003, Cinergy received a subpoena from the Commodity Futures Trading Commission (CFTC).  As has been previously reported by the press, the CFTC has served subpoenas on numerous

 

36



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

other energy companies.  The CFTC request sought certain information regarding our trading activities, including price reporting to energy industry publications for the period May 2000 through January 2001.  Based on our review of these matters, we terminated one employee and took disciplinary action on a second employee.  We have been cooperating fully with the CFTC and are negotiating to resolve this investigation.

 

In August 2003, Cinergy, along with Cinergy Marketing & Trading (Marketing & Trading) and 37 other companies, was named as a defendant in civil litigation filed as a purported class action on behalf of all persons who purchased and/or sold New York Mercantile Exchange natural gas futures and options contracts between January 1, 2000, and December 31, 2002.  The complaint alleges that improper price reporting caused damages to the class.  Two similar lawsuits have subsequently been filed, and these three lawsuits have been consolidated for pretrial purposes.  Plaintiffs filed a consolidated class action complaint in January 2004.  Cinergy’s motion to dismiss was granted in September 2004 and Marketing & Trading’s motion to dismiss is currently before the court.  We believe this action is without merit and intend to defend this lawsuit vigorously.

 

In the second quarter of 2003, Cinergy received initial and follow-up third-party subpoenas from the Securities and Exchange Commission (SEC) requesting information related to particular trading activity with one of its counterparties who was the target of an investigation by the SEC.  Cinergy has fully cooperated with the SEC in connection with this matter.

 

Cinergy has also been cooperating with the Assistant United States Attorney in the Southern District of Texas regarding various investigations the Assistant United States Attorney has into energy market practices.  We understand that we are neither a target nor are we under investigation by the Department of Justice in relation to these communications.

 

At this time, we do not believe the outcome of these investigations and litigation will have a material impact on Cinergy’s financial position or results of operations.

 

(iii)         Patents

 

Ronald A. Katz Technology Licensing, L.P. (RAKTL) has offered us a license to a portfolio of patents claiming that the patents may be infringed by certain products and services utilized by us.  The patents purportedly relate to various aspects of telephone call processing in Cinergy call centers.  As of this date, no legal proceedings have been instituted against us, but if the RAKTL patents are valid, enforceable, and apply to our business, we could be required to seek a license from RAKTL or to discontinue certain activities.  Based on the information we have at this time, we do not believe resolution of this matter will have a material impact on our financial position or results of operations.

 

(iv)         Synthetic Fuel

 

In July 2002, Cinergy Capital & Trading acquired a coal-based synthetic fuel production facility.  The synthetic fuel produced at this facility qualifies for tax credits (through 2007) in accordance with Internal Revenue Code (IRC) Section 29 if certain requirements are satisfied.  The three key requirements are that (a) the synthetic fuel differs significantly in chemical composition from the coal used to produce such synthetic fuel, (b) the fuel produced is sold to an unrelated entity and (c) the fuel was produced from a facility that was placed in service before July 1, 1998.

 

37



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

During the third quarter of 2004, several unrelated entities announced the Internal Revenue Service’s (IRS) intent to challenge the placed in service dates of some of the entities’ synthetic fuel plants.  A successful IRS challenge could result in disallowance of all credits previously claimed for fuel produced by the subject plants.  Cinergy’s sale of synthetic fuel has generated approximately $189 million in tax credits through September 2004.

 

The IRS has not yet audited Cinergy for any tax year in which Cinergy has claimed Section 29 credits related to synthetic fuel.  However, it is reasonable to anticipate that the IRS will evaluate the placed in service date and other key requirements for claiming the credit.

 

Cinergy received a private letter ruling from the IRS in connection with the acquisition of the facility that specifically addressed the significant chemical change requirement.  Additionally, although not addressed in the letter ruling, we believe that our facility’s in service date meets the Section 29 requirements. 

 

IRC Section 29 also provides for a phase out of the credit based on the price of crude oil.  The phase-out is based on a prescribed calculation and definition of crude oil prices within the IRC.  Although the price of crude oil has increased significantly in 2004, we presently do not expect any impact on our ability to utilize Section 29 credits in 2004.  Our results for the nine months ended September 30, 2004 include $69 million of tax credits.  If crude oil prices continue to increase, our ability to utilize credits beyond 2004 could be impacted.

 

(v)           Guarantees

 

In the ordinary course of business, Cinergy enters into various agreements providing financial or performance assurances to third parties on behalf of certain unconsolidated subsidiaries and joint ventures.  These agreements are entered into primarily to support or enhance the creditworthiness otherwise attributed to these entities on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish their intended commercial purposes.  The guarantees have various termination dates, from short-term (less than one year) to open-ended. 

 

In many cases, the maximum potential amount of an outstanding guarantee is an express term, set forth in the guarantee agreement, representing the maximum potential obligation of Cinergy under that guarantee (excluding, at times, certain legal fees to which a guaranty beneficiary may be entitled).  In those cases where there is no maximum potential amount expressly set forth in the guarantee agreement, we calculate the maximum potential amount by considering the terms of the guaranteed transactions, to the extent such amount is estimable.

 

Cinergy has guaranteed the payment of $11 million as of September 30, 2004, for borrowings by individuals under the Director, Officer, and Key Employee Stock Purchase Program.  Cinergy may be obligated to pay the debt’s principal and any related interest in the event of an unexcused breach of a guaranteed payment obligation by certain directors, officers, and key employees.  The guarantees do not have a set termination date; however, the borrowings associated with these guarantees are due in the first quarter of 2005.

 

Cinergy Corp. has also provided performance guarantees on behalf of certain unconsolidated subsidiaries and joint ventures.  These guarantees support performance under various agreements and instruments (such as construction contracts, operations and maintenance agreements, and energy

 

38



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

service agreements).  Cinergy Corp. may be liable in the event of an unexcused breach of a guaranteed performance obligation by an unconsolidated subsidiary.  Cinergy Corp. has estimated its maximum potential liability to be $72 million under these guarantees as of September 30, 2004.  Cinergy Corp. may also have recourse to third parties for claims required to be paid under certain of these guarantees.  The majority of these guarantees expire at the completion of the underlying performance agreement, the majority of which expire from 2016 to 2019.

 

Cinergy has entered into contracts that include indemnification provisions as a routine part of its business activities.  Examples of these contracts include purchase and sale agreements and operating agreements.  In general, these provisions indemnify the counterparty for matters such as breaches of representations and warranties and covenants contained in the contract.  In some cases, particularly with respect to purchase and sale agreements, the potential liability for certain indemnification obligations is capped, in whole or in part (generally at an aggregate amount not exceeding the sale price), and subject to a deductible amount before any payments would become due.  In other cases (such as indemnifications for willful misconduct of employees in a joint venture), the maximum potential liability is not estimable given that the magnitude of any claims under those indemnifications would be a function of the extent of damages actually incurred.  Cinergy has estimated the maximum potential liability, where estimable, to be $127 million under these indemnification provisions.  The termination period for the majority of matters provided by indemnification provisions in these types of agreements generally ranges from 2004 to 2009.   

 

We believe the likelihood that Cinergy would be required to perform or otherwise incur any significant losses associated with any or all of the guarantees described in the preceding paragraphs is remote.

 

7.     Pension and Other Postretirement Benefits

 

As discussed in the 2003 10-K, Cinergy Corp. sponsors both pension and other postretirement benefits plans.  Our qualified defined benefit pension plans cover substantially all United States employees meeting certain minimum age and service requirements.  Funding for the qualified defined benefit pension plans is based on actuarially determined contributions, the maximum of which is generally the amount deductible for income tax purposes and the minimum being that required by the Employee Retirement Income Security Act of 1974, as amended.  The pension plans’ assets consist of investments in equity and debt securities.  In addition, we sponsor non-qualified pension plans that cover officers, certain other key employees, and non-employee directors.  We provide certain health care and life insurance benefits to retired United States employees and their eligible dependents.  These benefits are subject to minimum age and service requirements.  The health care benefits include medical coverage, dental coverage, and prescription drugs and are subject to certain limitations, such as deductibles and co-payments.

 

39



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

Our benefit plans’ costs for the quarter and year to date ended September 30, 2004 and 2003, included the following components:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Qualified
Pension Benefits

 

Non-Qualified
Pension Benefits

 

Other Postretirement
Benefits

 

Quarter Ended September 30

 

2004

 

2003

 

2004

 

2003

 

2004

 

2003

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Service cost

 

$

8.8

 

$

7.8

 

$

1.2

 

$

0.8

 

$

1.2

 

$

1.0

 

Interest cost

 

22.1

 

21.5

 

1.7

 

1.6

 

5.4

 

5.6

 

Expected return on plans’ assets

 

(20.1

)

(20.2

)

 

 

 

 

Amortization of transition (asset) obligation

 

(0.1

)

(0.2

)

 

 

0.1

 

0.9

 

Amortization of prior service cost

 

1.1

 

1.2

 

0.5

 

0.3

 

 

 

Recognized actuarial (gain) loss

 

0.5

 

 

0.7

 

0.5

 

1.9

 

1.3

 

Voluntary early retirement costs (Statement 88)(1)

 

 

2.1

 

 

 

 

 

Net periodic benefit cost

 

$

12.3

 

$

12.2

 

$

4.1

 

$

3.2

 

$

8.6

 

$

8.8

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year to Date September 30

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Service cost

 

$

26.4

 

$

23.4

 

$

3.6

 

$

2.4

 

$

3.8

 

$

3.0

 

Interest cost

 

66.3

 

64.5

 

5.1

 

4.8

 

16.8

 

16.8

 

Expected return on plans’ assets

 

(60.3

)

(60.6

)

 

 

 

 

Amortization of transition (asset) obligation

 

(0.3

)

(0.6

)

 

 

1.0

 

2.6

 

Amortization of prior service cost

 

3.3

 

3.6

 

1.5

 

0.9

 

 

 

Recognized actuarial (gain) loss

 

1.5

 

 

2.1

 

1.5

 

5.9

 

3.9

 

Voluntary early retirement costs (Statement 88)(1)

 

 

6.3

 

 

 

 

 

Net periodic benefit cost

 

$

36.9

 

$

36.6

 

$

12.3

 

$

9.6

 

$

27.5

 

$

26.3

 

 

(1)

 

Statement of Financial Accounting Standards No. 88, Employers’ Accounting for Settlements and Curtailments of Defined Benefit Pension Plans and for Termination Benefits (Statement 88).

 

The net periodic benefit costs by registrant for the quarter and year to date ended September 30, 2004 and 2003, were as follows:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Qualified
Pension Benefits

 

Non-Qualified
Pension Benefits

 

Other Postretirement
Benefits

 

Quarter Ended September 30

 

2004

 

2003

 

2004

 

2003

 

2004

 

2003

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

$

12.3

 

$

12.2

 

$

4.1

 

$

3.2

 

$

8.6

 

$

8.8

 

CG&E and subsidiaries

 

3.7

 

2.4

 

0.2

 

0.2

 

2.0

 

2.3

 

PSI

 

3.2

 

2.9

 

0.2

 

0.2

 

4.7

 

4.4

 

ULH&P

 

0.4

 

0.3

 

 

 

0.2

 

0.2

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year to Date September 30

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

$

36.9

 

$

36.6

 

$

12.3

 

$

9.6

 

$

27.5

 

$

26.3

 

CG&E and subsidiaries

 

11.1

 

7.2

 

0.6

 

0.6

 

6.6

 

6.9

 

PSI

 

9.6

 

8.7

 

0.6

 

0.6

 

14.7

 

13.2

 

ULH&P

 

1.2

 

0.9

 

 

 

0.6

 

0.6

 

 

(1)

 

The results of Cinergy also include amounts related to non-registrants.

 

On December 8, 2003, President Bush signed into law the Medicare Prescription Drug, Improvement and Modernization Act of 2003 (the Act).  The Act introduced a prescription drug benefit to retirees as well as a federal subsidy to sponsors of retiree health care benefit plans that provide a prescription drug benefit that is actuarially equivalent to the benefit provided by Medicare.  We believe that our

 

40



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

coverage for prescription drugs is at least actuarially equivalent to the benefits provided by Medicare for most current retirees because our benefits for that group substantially exceed the benefits provided by Medicare, thereby allowing us to qualify for the subsidy.  We have accounted for the subsidy as a reduction of our accumulated postretirement benefit obligation (APBO).  The APBO was reduced by approximately $17 million and will be amortized as an actuarial gain over future periods, thus reducing future benefit costs.  The impact on our 2004 net periodic benefit cost is not material.  Our accounting treatment for the subsidy is consistent with FASB Staff Position No. 106-2, Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003.

 

8.     Investment Activity

 

(a)                                  Investment Impairment

 

Cinergy holds a portfolio of direct and indirect investments in the Power Technology and Infrastructure Services Business Unit (Power Technology and Infrastructure) (discussed further in Note 9).  During 2004, Cinergy recognized approximately $49 million in impairment charges associated with this portfolio.  The majority of these charges relate to a company in which Cinergy holds a non-controlling interest, that agreed to sell its major assets.  This company is involved in the development and sale of outage management software.  Based on the terms of the transaction, Cinergy concluded that this cost method investment was other-than-temporarily impaired.  These impairment charges are included in Miscellaneous Income (Expense) – Net in Cinergy’s Condensed Consolidated Statements of Income.

 

(b)                                  Sale of Investment

 

Power Technology and Infrastructure holds an investment in a company that develops, owns and operates wireless communication towers.  In July 2004, this company agreed to sell the majority of its assets.  The transaction is expected to close in the fourth quarter of 2004 and we would anticipate recording a gain of approximately $20 million relating to this sale at that time.  These earnings will be reflected in Equity in Earnings of Unconsolidated Subsidiaries in Cinergy’s Condensed Consolidated Statements of Income.

 

9.     Financial Information by Business Segment

 

As discussed in the 2003 10-K, we conduct operations through our subsidiaries, and manage through the following three reportable segments:

 

                  Commercial Business Unit (Commercial);

                  Regulated Businesses Business Unit (Regulated Businesses); and

                  Power Technology and Infrastructure Services Business Unit (Power Technology and Infrastructure).

 

Commercial manages wholesale generation and energy marketing and trading of energy commodities.  Additionally, Commercial operates and maintains our electric generating plants including some of our jointly-owned plants.  Commercial is also responsible for all of our international operations, performs energy risk management activities, and provides customized energy solutions.

 

41



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

Regulated Businesses consists of PSI’s regulated, integrated utility operations, and Cinergy’s other regulated electric and gas transmission and distribution systems.  Regulated Businesses plans, constructs, operates, and maintains Cinergy’s transmission and distribution systems and delivers gas and electric energy to consumers.  Regulated Businesses also earns revenues from wholesale customers primarily by transmitting electric power through Cinergy’s transmission system.

 

Power Technology and Infrastructure primarily manages Cinergy Ventures, LLC (Ventures).  Ventures identifies, invests in, and integrates new energy technologies into Cinergy’s existing businesses, focused primarily on operational efficiencies and clean energy technologies.  In addition, Power Technology and Infrastructure manages our investments in other energy infrastructure and telecommunication service providers.

 

Following are the financial results by business unit.  Certain prior year amounts have been reclassified to conform to the current presentation.

 

42



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

Financial results by business unit for the quarters ended September 30, 2004, and September 30, 2003, are as indicated below. 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy Business Units

 

 

 

 

 

 

 

Commercial

 

Regulated
Businesses

 

Power Technology
and Infrastructure

 

Total

 

Reconciling
Eliminations (1)

 

Consolidated

 

 

 

(in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Quarter ended September 30, 2004

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

 

 

 

 

 

 

 

 

 

 

 

 

External customers

 

$

432,284

 

$

696,298

 

$

1

 

$

1,128,583

 

$

 

$

1,128,583

 

Intersegment revenues

 

45,701

 

59

 

 

45,760

 

(45,760

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gross margins

 

 

 

 

 

 

 

 

 

 

 

 

 

Electric

 

201,373

 

458,930

 

 

660,303

 

 

660,303

(3)

Gas

 

5,622

 

39,884

 

 

45,506

 

 

45,506

(4)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Segment profit (loss)(2)

 

42,165

 

61,493

 

(10,735

)

92,923

 

 

92,923

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Quarter ended September 30, 2003

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

 

 

 

 

 

 

 

 

 

 

 

 

External customers

 

$

439,040

 

$

652,965

 

$

(28

)

$

1,091,977

 

$

 

$

1,091,977

 

Intersegment revenues

 

43,056

 

126

 

 

43,182

 

(43,182

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gross margins

 

 

 

 

 

 

 

 

 

 

 

 

 

Electric

 

190,569

 

400,072

 

 

590,641

 

 

590,641

(3)

Gas

 

11,415

 

33,536

 

 

44,951

 

 

44,951

(4)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Segment profit (loss)(2)

 

52,204

 

62,814

 

(3,037

)

111,981

 

 

111,981

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(1)

The Reconciling Eliminations category eliminates the intersegment revenues of Commercial.

(2)

Management utilizes segment profit (loss), after taxes, to evaluate segment performance.

(3)

Electric gross margin is calculated as Electric operating revenues less Fuel and purchased power expense from the Condensed Consolidated Statements of Income.

(4)

Gas gross margin is calculated as Gas operating revenues less Gas purchased expense from the Condensed Consolidated Statements of Income.

 

 

 

 

43



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

Financial results by business unit for year to date September 30, 2004 and September 30, 2003, are as indicated below.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy Business Units

 

 

 

 

 

 

 

Commercial

 

Regulated
Businesses

 

Power Technology
and Infrastructure

 

Total

 

Reconciling
Eliminations(1)

 

Consolidated

 

 

 

(in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year to Date September 30, 2004

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

 

 

 

 

 

 

 

 

 

 

 

 

External customers

 

$

1,228,388

 

$

2,242,585

 

$

5

 

$

3,470,978

 

$

 

$

3,470,978

 

Intersegment revenues

 

124,945

 

83

 

 

125,028

 

(125,028

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gross margins

 

 

 

 

 

 

 

 

 

 

 

 

 

Electric

 

570,119

 

1,279,945

 

 

1,850,064

 

 

1,850,064

(3)

Gas

 

45,314

 

188,184

 

 

233,498

 

 

233,498

(4)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Segment profit (loss)(2)

 

117,637

 

176,786

 

(39,981

)

254,442

 

 

254,442

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year to Date September 30, 2003

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

 

 

 

 

 

 

 

 

 

 

 

 

External customers

 

$

1,222,898

 

$

2,070,984

 

$

(25

)

$

3,293,857

 

$

 

$

3,293,857

 

Intersegment revenues

 

143,995

 

132

 

 

144,127

 

(144,127

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gross margins

 

 

 

 

 

 

 

 

 

 

 

 

 

Electric

 

540,250

 

1,132,372

 

 

1,672,622

 

 

1,672,622

(3)

Gas

 

96,331

 

173,151

 

 

269,482

 

 

269,482

(4)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Discontinued operations, net of tax

 

8,875

 

 

 

8,875

 

 

8,875

 

Cumulative effect of changes in accounting principle, net of tax

 

26,462

 

 

 

26,462

 

 

26,462

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Segment profit (loss)(2)

 

213,641

 

162,988

 

(13,910

)

362,719

 

 

362,719

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(1)

The Reconciling Eliminations category eliminates the intersegment revenues of Commercial.

(2)

Management utilizes segment profit (loss), after taxes, to evaluate segment performance.

(3)

Electric gross margin is calculated as Electric operating revenues less Fuel and purchased power expense from the Condensed Consolidated Statements of Income.

(4)

Gas gross margin is calculated as Gas operating revenues less Gas purchased expense from the Condensed Consolidated Statements of Income.

 

 

 

 

44



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

Total segment assets at September 30, 2004, and December 31, 2003, are as indicated below:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy Business Units

 

 

 

 

 

 

 

Commercial

 

Regulated
Businesses

 

Power Technology
and Infrastructure

 

Total

 

All
Other (1)

 

Consolidated

 

 

 

(in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Segment assets from continuing operations

 

$

5,362,090

 

$

8,689,306

 

$

132,793

 

$

14,184,189

 

$

59,141

 

$

14,243,330

 

Segment assets from discontinued operations

 

 

 

 

 

 

 

Total segment assets at September 30, 2004

 

$

5,362,090

 

$

8,689,306

 

$

132,793

 

$

14,184,189

 

$

59,141

 

$

14,243,330

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Segment assets from continuing operations

 

$

5,360,886

 

$

8,515,478

 

$

175,619

 

$

14,051,983

 

$

62,722

 

$

 14,114,705

 

Segment assets from discontinued operations

 

4,501

 

 

 

4,501

 

 

4,501

 

Total segment assets at December 31, 2003

 

$

5,365,387

 

$

8,515,478

 

$

175,619

 

$

14,056,484

 

$

62,722

 

$

 14,119,206

 

 


(1)

The All Other category represents miscellaneous corporate items which are not allocated to business units for purposes of segment performance measurement.

 

 

45



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

10.  Earnings Per Common Share (EPS)

 

A reconciliation of EPS – basic to EPS –diluted is presented below for the quarters ended September 30, 2004 and 2003:

 

 

 

 

 

 

 

 

 

 

 

Income

 

Shares

 

EPS

 

 

 

(in thousands, except per share amounts)

 

Quarter Ended September 30, 2004

 

 

 

 

 

 

 

EPS – basic:

 

 

 

 

 

 

 

Net Income

 

$

92,923

 

180,881

 

$

0.51

 

 

 

 

 

 

 

 

 

Effect of dilutive securities:

 

 

 

 

 

 

 

Common stock options

 

 

 

616

 

 

 

Directors’ compensation plans

 

 

 

148

 

 

 

Contingently issuable common stock

 

 

 

710

 

 

 

Stock purchase contracts

 

 

 

1,123

 

 

 

 

 

 

 

 

 

 

 

EPS - diluted:

 

 

 

 

 

 

 

Net income plus assumed conversions

 

$

92,923

 

183,478

 

$

0.50

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Quarter Ended September 30, 2003

 

 

 

 

 

 

 

EPS – basic:

 

 

 

 

 

 

 

Net Income

 

$

111,981

 

177,751

 

$

0.63

 

 

 

 

 

 

 

 

 

Effect of dilutive securities:

 

 

 

 

 

 

 

Common stock options

 

 

 

629

 

 

 

Directors’ compensation plans

 

 

 

148

 

 

 

Contingently issuable common stock

 

 

 

891

 

 

 

Stock purchase contracts

 

 

 

118

 

 

 

 

 

 

 

 

 

 

 

EPS - diluted:

 

 

 

 

 

 

 

Net income plus assumed conversions

 

$

111,981

 

179,537

 

$

0.62

 

 

 

 

 

 

 

 

 

 

Options to purchase shares of common stock are excluded from the calculation of EPS - diluted, if they are considered to be anti-dilutive.  Approximately 0.9 million and 2.1 million shares were excluded from the EPS - diluted calculation for the quarters ended September 30, 2004 and 2003, respectively.

 

Also excluded from the EPS - diluted calculation for the quarters ended September 30, 2004 and 2003, are up to 9.7 million and 10.7 million shares, respectively, issuable pursuant to the stock purchase contracts issued by Cinergy Corp. in December 2001 associated with the preferred trust securities transaction.  The number of shares issuable pursuant to the stock purchase contracts is contingent upon the market price of Cinergy Corp. stock in February 2005 and could range between 9.2 and 10.8 million shares.

 

 

46



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

A reconciliation of EPS – basic to EPS –diluted is presented below for the year to date September 30, 2004 and 2003:

 

 

 

 

 

 

 

 

 

 

 

Income

 

Shares

 

EPS

 

 

 

(in thousands, except per share amounts)

 

Year to Date September 30, 2004

 

 

 

 

 

 

 

EPS – basic:

 

 

 

 

 

 

 

Net Income

 

$

254,442

 

180,129

 

$

1.41

 

 

 

 

 

 

 

 

 

Effect of dilutive securities:

 

 

 

 

 

 

 

Common stock options

 

 

 

675

 

 

 

Directors’ compensation plans

 

 

 

148

 

 

 

Contingently issuable common stock

 

 

 

585

 

 

 

Stock purchase contracts

 

 

 

1,027

 

 

 

 

 

 

 

 

 

 

 

EPS - diluted:

 

 

 

 

 

 

 

Net income plus assumed conversions

 

$

254,442

 

182,564

 

$

1.39

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year to Date September 30, 2003

 

 

 

 

 

 

 

EPS – basic:

 

 

 

 

 

 

 

Income before discontinued operations and cumulative effect of changes in accounting principles

 

$

327,382

 

 

 

$

1.86

 

Discontinued operations, net of tax

 

8,875

 

 

 

0.05

 

Cumulative effect of changes in accounting principles, net of tax

 

26,462

 

 

 

0.15

 

Net Income

 

$

362,719

 

175,944

 

$

2.06

 

 

 

 

 

 

 

 

 

Effect of dilutive securities:

 

 

 

 

 

 

 

Common stock options

 

 

 

738

 

 

 

Directors’ compensation plans

 

 

 

147

 

 

 

Contingently issuable common stock

 

 

 

811

 

 

 

Stock purchase contracts

 

 

 

39

 

 

 

 

 

 

 

 

 

 

 

EPS - diluted:

 

 

 

 

 

 

 

Net income plus assumed conversions

 

$

362,719

 

177,679

 

$

2.04

 

 

 

 

 

 

 

 

 

 

Options to purchase shares of common stock are excluded from the calculation of EPS - diluted, if they are considered to be anti-dilutive.  Approximately 0.9 million and 2.1 million shares were excluded from the EPS - diluted calculation for the year to date September 30, 2004 and 2003, respectively.

 

Also excluded from the EPS - diluted calculation for the year to date September 30, 2004 and 2003, are up to 9.8 million and 10.8 million shares, respectively, issuable pursuant to the stock purchase contracts issued by Cinergy Corp. in December 2001 associated with the preferred trust securities transaction.  The number of shares issuable pursuant to the stock purchase contracts is contingent upon the market price of Cinergy Corp. stock in February 2005 and could range between 9.2 and 10.8 million shares.

 

11.  Transfer of Generating Assets

 

In December 2002, the IURC approved a settlement agreement among PSI, the Indiana Office of the Utility Consumer Counselor, and the IURC Staff authorizing PSI’s purchases of the Henry County, Indiana and Butler County, Ohio, gas-fired peaking plants from two non-regulated affiliates.  In February 2003, the Federal Energy Regulatory Commission (FERC) issued an order under Section 203 of the Federal Power Act authorizing PSI’s acquisitions of the plants, which occurred on

 

 

47



 

NOTES TO CONDENSED FINANCIAL STATEMENTS

 

February 5, 2003.  Subsequently, in April 2003, the FERC issued a tolling order allowing additional time to consider a request for rehearing filed in response to the February 2003 FERC order.  In September 2004, FERC issued an order denying the request for rehearing and affirming the acquisition of the plants.

 

In July 2003, ULH&P filed an application with the KPSC requesting a certificate of public convenience and necessity to acquire CG&E’s 68.9 percent ownership interest in the East Bend Generating Station, located in Boone County, Kentucky, the Woodsdale Generating Station, located in Butler County, Ohio, and one generating unit at the four-unit Miami Fort Station located in Hamilton County, Ohio.  In December 2003, the KPSC conditionally approved this application.  The transfer, which will be made at net book value, will not affect current electric rates for ULH&P’s customers, as power will be provided under the same terms as under the current wholesale power contract with CG&E through at least December 31, 2006.  In September 2004, ULH&P filed applications with the FERC and the SEC seeking regulatory approvals for aspects of this transaction.  At this time, ULH&P is unable to predict the outcome of this matter.

 

 

48



 

CAUTIONARY STATEMENTS

 

CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING INFORMATION

 

This document includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934.  Forward-looking statements are based on management’s beliefs and assumptions.  These forward-looking statements are identified by terms and phrases such as “anticipate”, “believe”, “intend”, “estimate”, “expect”, “continue”, “should”, “could”, “may”, “plan”, “project”, “predict”, “will”, and similar expressions.

 

Forward-looking statements involve risks and uncertainties that may cause actual results to be materially different from the results predicted.  Factors that could cause actual results to differ materially from those indicated in any forward-looking statement include, but are not limited to:

 

                  Factors affecting operations, such as:

 

(1)          unanticipated weather conditions;

(2)          unscheduled generation outages;

(3)          unusual maintenance or repairs;

(4)          unanticipated changes in costs;

(5)          environmental incidents; and

(6)          electric transmission or gas pipeline system constraints.

 

                  Legislative and regulatory initiatives.

 

                  Additional competition in electric or gas markets and continued industry consolidation.

 

                  Financial or regulatory accounting principles including costs of compliance with existing and future environmental requirements.

 

                  Political, legal, and economic conditions and developments in the countries in which we have a presence.

 

                  Changing market conditions and other factors related to physical energy and financial trading activities.

 

                  The performance of projects undertaken by our non-regulated businesses and the success of efforts to invest in and develop new opportunities.

 

                  Availability of, or cost of, capital.

 

                  Employee workforce factors.

 

                  Delays and other obstacles associated with mergers, acquisitions, and investments in joint ventures.

 

                  Costs and effects of legal and administrative proceedings, settlements, investigations, and claims.  Examples can be found in Note 6 of the “Notes to Condensed Financial Statements” in “Item 1. Financial Statements”.

 

We undertake no obligation to update the information contained herein.

 

 

49



 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

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

 

In this report Cinergy (which includes Cinergy Corp. and all of our regulated and non-regulated subsidiaries) is, at times, referred to in the first person as “we”, “our”, or “us”.  In addition, when discussing Cinergy’s financial information, it necessarily includes the results of The Cincinnati Gas & Electric Company (CG&E), PSI Energy, Inc. (PSI), The Union Light, Heat and Power Company (ULH&P), and all of Cinergy’s other consolidated subsidiaries.  When discussing CG&E’s financial information, it necessarily includes the results of ULH&P and all of CG&E’s other consolidated subsidiaries.

 

The following discussion should be read in conjunction with the accompanying financial statements and related notes included elsewhere in this report and the combined Form 10-K for the year ended December 31, 2003 (2003 10-K).  The results discussed below are not necessarily indicative of the results to be expected in any future periods.

 

INTRODUCTION

 

In Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A), we explain our general operating environment, as well as our liquidity, capital resources, and results of operations.  Specifically, we discuss the following:

 

                  factors affecting current and future operations;

                  potential sources of cash for future capital expenditures;

                  why revenues and expenses changed from period to period; and

                  how the above items affect our overall financial condition.

 

ORGANIZATION

 

Cinergy Corp., a Delaware corporation organized in 1993, owns all outstanding common stock of CG&E and PSI, both of which are public utilities.  As a result of this ownership, we are considered a utility holding company.  Because we are a holding company with material utility subsidiaries operating in multiple states, we are registered with and are subject to regulation by the Securities and Exchange Commission (SEC) under the Public Utility Holding Company Act of 1935, as amended (PUHCA).  Our other principal subsidiaries are Cinergy Services, Inc. (Services) and Cinergy Investments, Inc. (Investments).

 

CG&E, an Ohio corporation organized in 1837, is a combination electric and gas public utility company that provides service primarily in the southwestern portion of Ohio and, through ULH&P, in nearby areas of Kentucky.  CG&E is responsible for the majority of our power marketing and trading activity.  CG&E’s principal subsidiary, ULH&P, is a Kentucky corporation organized in 1901, that provides electric and gas service in northern Kentucky.  CG&E’s other subsidiaries are insignificant to its results of operations.

 

PSI, an Indiana corporation organized in 1942, is a vertically integrated and regulated electric utility that provides service in north central, central, and southern Indiana.

 

50



 

MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

Services is a service company that provides our subsidiaries with a variety of centralized administrative, management, and support services.  Investments holds most of our domestic non-regulated, energy-related businesses and investments, including gas marketing and trading operations.

 

The majority of our operating revenues are derived from the sale of electricity and the sale and/or transportation of natural gas.

 

LIQUIDITY AND CAPITAL RESOURCES

 

Environmental Issues

 

In December 2003, the United States Environmental Protection Agency (EPA) proposed the Clean Air Interstate Rule (CAIR), formerly the Interstate Air Quality Rule, that would require states to revise their State Implementation Plans (SIP) to address alleged contributions to downwind non-attainment with the revised National Ambient Air Quality Standards for ozone and fine particulate matter.  The proposed rule would establish a two-phase, regional cap and trade program for sulfur dioxide (SO2) and nitrogen oxide (NOX), affecting approximately 30 states, including Ohio, Indiana, and Kentucky, and would require SO2 and NOX emissions to be cut approximately 70 percent and 65 percent, respectively, by 2015.  The EPA is expected to issue final rules by December 2004.

 

In December 2003, the EPA also issued draft regulations regarding required reductions in mercury emissions from coal-fired power plants.  The draft regulations include two possible alternatives to address emissions reductions.  One alternative would include a cap and trade approach to mercury.  The other would be a source specific reduction in emissions, without a cap and trade approach.  The cap and trade approach would provide a longer compliance horizon and provide more flexible compliance options for coal-fired generators.  The cap and trade approach would require a reduction of approximately 30 percent by 2010 and 70 percent by 2018.  The source specific reduction approach would require a reduction of approximately 30 percent by 2008.  The EPA must issue final rules by March 2005.

 

Over the 2004-2008 time period, estimated capital costs associated with reducing mercury, SO2, and NOX in compliance with the currently proposed CAIR and mercury rule are not expected to exceed approximately $1.65 billion if the EPA approves the mercury cap and trade approach and approximately $2.15 billion if the EPA approves the source specific reduction approach without a cap and trade.  Approximately 55 percent of these estimated environmental costs would be incurred at PSI’s coal-fired plants, for which recovery would be pursued in accordance with regulatory statutes governing environmental cost recovery.  CG&E has proposed three alternatives to the Public Utilities Commission of Ohio (PUCO) for determining rates after the market development period ends.  Two of these alternatives include partial recovery of depreciation and financing costs for 2005-2008.  See Note 6(b)(ii) of the “Notes to Condensed Financial Statements” in “Item 1. Financial Statements” for more details.

 

The mercury cap and trade approach would provide Cinergy with more flexible compliance options, including the purchase of allowances in lieu of further capital expenditures with respect to these investments.  The above estimates include estimated costs to comply at plants that we own but do not operate (which includes 14 percent and 34 percent of Cinergy’s and CG&E’s megawatt hour (MWh) capacity, respectively).  These costs may change when taking into consideration compliance plans of

 

51



 

MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

co-owners or operators involved.  Moreover, as market conditions change, additional compliance options may become available and our plans will be adjusted accordingly.  Costs associated with mercury reduction may be different than those predicted, depending on the type of program the EPA finalizes and the stringency and timing of the ultimate requirements.

 

In May 2004, the EPA issued proposed revisions to its regional haze rules and implementing guidelines in response to a 2002 judicial ruling overturning key provisions of the original program.  The regional haze program is aimed at reducing certain emissions impacting visibility in national parks and wilderness areas.  The EPA is currently considering whether SO2 and NOX reductions under the CAIR regulation will also satisfy the reduction requirements under the regional haze rule.  However, the regional haze rule, when finalized, could potentially require significant additional SO2 and NOX reductions necessitating the installation of pollution controls for certain generating units at Cinergy’s power plants.  In light of the EPA’s ongoing rulemaking efforts and the fact that the states have yet to announce how they will implement the final rule, at this time, it is not possible to predict whether the regional haze rule will have a material effect on our financial position or results of operations.

 

In April 2004, the EPA made final state non-attainment area designations to implement the revised ozone standard.  Several counties in which we operate have been designated as being in non-attainment with the new ozone standard.  The EPA is also under a court ordered deadline to make final non-attainment area designations for the new fine particulate standard by December 15, 2004.  Several counties in which we operate are likely to be designated as non-attainment for the fine particulate standard.  Those counties that are designated as being in non-attainment with the new ozone and/or fine particulate standards are required to develop a plan of compliance.  Although the EPA has attempted to structure the CAIR to resolve purported utility contributions to ozone and fine particulate non-attainment, at this time, Cinergy cannot predict the effect of current or future non-attainment designations on its financial position or results of operations.

 

Carbon Dioxide (CO2) Lawsuit

 

In July 2004, the states of Connecticut, New York, California, Iowa, New Jersey, Rhode Island, Vermont, Wisconsin, and the City of New York brought a lawsuit in the United States District Court for the Southern District of New York against Cinergy and American Electric Power Company, Inc., American Electric Power Service Corporation, The Southern Company, Tennessee Valley Authority, and Xcel Energy Inc.  That same day, a similar lawsuit was filed against the same companies by Open Space Institute, Inc., Open Space Conservancy, Inc., and The Audubon Society of New Hampshire.  These lawsuits allege that the defendants’ emissions of CO2 from the combustion of fossil fuels at electric generating facilities contribute to global warming and amount to a public nuisance.  The complaints also allege that the defendants could generate the same amount of electricity while emitting significantly less CO2.  Plaintiffs are seeking an injunction requiring each defendant to cap its CO2 emissions and then reduce them by a specified percentage each year for at least a decade.  Cinergy intends to defend this lawsuit vigorously in court and filed a motion to dismiss with the other defendants in September 2004; however, we are not able to predict whether resolution of these matters would have a material effect on our financial position or results of operations.

 

52



 

MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

Notice of Intent to Sue at Zimmer Generating Station (Zimmer Station)

 

In July 2004, Cinergy received a notice of intent to sue under the Clean Air Act (CAA) from attorneys representing citizens of the Village of Moscow, Ohio, the town adjacent to CG&E’s Zimmer Station, which notice is required as a predicate to a citizen’s enforcement suit under the CAA.  The letter alleges that emissions from Zimmer Station violate the CAA and the Ohio SIP and are causing a public nuisance.  At this time, we cannot predict whether the outcome of this matter will have a material impact on our financial position or results of operations.

 

Selective Catalytic Reduction Units (SCR) at Gibson Generating Station (Gibson Station)

 

In May 2004, SCRs and other pollution control equipment became operational at Units 4 and 5 of PSI’s Gibson Station in accordance with compliance deadlines under the NOX SIP Call.  In June and July 2004, Gibson Station temporarily shut down the equipment on these units due to a concern over an acid aerosol mist haze (plume) sometimes occurring in areas near the plant.  Portions of the plume from those units’ stacks appeared to break apart and descend to ground level at certain times under certain weather conditions.  As a result, and, working with the City of Mt. Carmel, Illinois, Illinois EPA, Indiana Department of Environmental Management, United States EPA, and the State of Illinois, we developed a protocol regarding the use of the SCRs while we explore alternatives to address this issue.  After the protocol was finalized, the Illinois Attorney General brought an action in Wabash County Circuit Court against PSI seeking a preliminary injunction to enforce the protocol.  In August 2004, the court granted that preliminary injunction.  PSI is appealing that decision to the Fifth District Appellate Court, but we cannot predict the ultimate outcome of that appeal or of the underlying action by the Illinois Attorney General.

 

We will seek recovery of any related capital as well as increased emission allowance expenditures through the regulatory process.  We do not believe costs related to resolving this matter will have a material impact on our financial position or results of operations.

 

Other Investing Activities

 

Our ability to invest in growth initiatives is limited by certain legal and regulatory requirements, including PUHCA.  The PUHCA limits the types of non-utility businesses in which Cinergy and other registered holding companies under PUHCA can invest as well as the amount of capital that can be invested in permissible non-utility businesses.  Also, the timing and amount of investments in the non-utility businesses is dependent on the development and favorable evaluations of opportunities.  Under the PUHCA restrictions, we are allowed to invest or commit to invest in certain non-utility businesses, including:

 

                  Exempt Wholesale Generators (EWG) and Foreign Utility Companies (FUCO)

 

An EWG is an entity, certified by the Federal Energy Regulatory Commission (FERC), devoted exclusively to owning and/or operating, and selling power from one or more electric generating facilities.  An EWG whose generating facilities are located in the United States is limited to making only wholesale sales of electricity.  An entity claiming status as an EWG must provide notification thereof to the SEC under PUHCA.

 

A FUCO is a company all of whose utility assets and operations are located outside the United States and which are used for the generation, transmission, or distribution of

 

53



 

MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

electric energy for sale at retail or wholesale, or the distribution of gas at retail.  A FUCO may not derive any income, directly or indirectly, from the generation, transmission, or distribution of electric energy for sale or the distribution of gas at retail within the United States.  An entity claiming status as a FUCO must provide notification thereof to the SEC under PUHCA.

 

Cinergy has been granted SEC authority under PUHCA to invest (including by way of guarantees) an aggregate amount in EWGs and FUCOs equal to the sum of (1) our average consolidated retained earnings from time to time plus (2) $2 billion.  As of September 30, 2004, we had invested or committed to invest approximately $0.9 billion in EWGs and FUCOs, leaving available investment capacity under the order of approximately $2.7 billion.

 

                  Qualifying Facilities and Energy-Related Non-utility Entities

 

SEC regulations under the PUHCA permit Cinergy and other registered holding companies to invest and/or guarantee an amount equal to 15 percent of consolidated capitalization (consolidated capitalization is the sum of Notes payable and other short-term obligations, Long-term debt (including amounts due within one year), Cumulative Preferred Stock of Subsidiaries, and total Common Stock Equity) in domestic qualifying cogeneration and small power production plants (qualifying facilities) and certain other domestic energy-related non-utility entities.  At September 30, 2004, we had invested and/or guaranteed approximately $0.9 billion of the $1.4 billion available.

 

In August 2004, Cinergy filed an application with the SEC requesting authority under PUHCA to increase its investment and/or guarantee amount by $2 billion above the current authorized amount.  Cinergy has requested the SEC to issue an order authorizing the increase in the fourth quarter of 2004.

 

                  Energy-Related Assets

 

Cinergy has been granted SEC authority under PUHCA to invest up to $1 billion in non-utility Energy-Related Assets within the United States, Canada, and Mexico.  Energy-Related Assets include natural gas exploration, development, production, gathering, processing, storage and transportation facilities and equipment, liquid oil reserves and storage facilities, and associated assets, facilities and equipment, but would exclude any assets, facilities, or equipment that would cause the owner or operator thereof to be deemed a public utility company.  As of September 30, 2004, we did not have any investments in these Energy-Related Assets.

 

                  Infrastructure Services Companies

 

Cinergy has been granted SEC authority under PUHCA to invest up to $500 million in companies that derive or will derive substantially all of their operating revenues from the sale of Infrastructure Services including:

 

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MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

                  Design, construction, retrofit, and maintenance of utility transmission and distribution systems;

                  Installation and maintenance of natural gas pipelines, water and sewer pipelines, and underground and overhead telecommunications networks; and

                  Installation and servicing of meter reading devices and related communications networks, including fiber optic cable.

 

At September 30, 2004, we had invested approximately $29 million in Infrastructure Services companies.

 

Guarantees

 

We are subject to an SEC order under the PUHCA, which limits the amounts Cinergy Corp. can have outstanding under guarantees at any one time to $2 billion.  As of September 30, 2004, we had $705 million outstanding under the guarantees issued, of which approximately 93 percent represents guarantees of obligations for entities consolidated in Cinergy’s financial statements.  The amount outstanding represents Cinergy Corp.’s guarantees of liabilities and commitments of its consolidated subsidiaries, unconsolidated subsidiaries, and joint ventures.  See Note 6(c)(v) of the “Notes to Condensed Financial Statements” in “Item 1. Financial Statements” for a discussion of guarantees in accordance with Financial Accounting Standards Board (FASB) Interpretation No. 45, Guarantor’s Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others (Interpretation 45).  Interpretation 45 requires disclosure of maximum potential liabilities for guarantees issued on behalf of unconsolidated subsidiaries and joint ventures and under indemnification clauses in various contracts.  The Interpretation 45 disclosure differs from the PUHCA restrictions in that it requires a calculation of maximum potential liability, rather than actual amounts outstanding; it excludes guarantees issued on behalf of consolidated subsidiaries; and it includes potential liabilities under indemnification clauses.

 

Marketing & Trading Liquidity Risks

 

Cinergy has certain contracts in place, primarily with trading counterparties, that may require the settlement of open positions or the issuance of collateral in the event our debt ratings are downgraded below investment grade.  Based upon our September 30, 2004 trading portfolio, if such an event were to occur, Cinergy would be required to issue up to approximately $140 million related to its gas and power trading operations, of which $78 million is related to CG&E.

 

Capital Resources

 

Cinergy, CG&E, PSI, and ULH&P meet current and future capital requirement needs through a combination of internally and externally generated funds, including the issuance of debt and/or equity securities.  Cinergy, CG&E, PSI, and ULH&P believe that they have adequate financial resources to meet their future needs.

 

Sales of Accounts Receivable

 

CG&E, PSI, and ULH&P have an agreement with Cinergy Receivables Company, LLC (Cinergy Receivables), an affiliate, to sell, on a revolving basis, nearly all of the retail accounts receivable and

 

55



 

MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

related collections of CG&E, PSI, and ULH&P.  Cinergy Receivables funds its purchase with borrowings from commercial paper conduits that obtain a security interest in the receivables.  This program accelerates the collection of cash for CG&E, PSI, and ULH&P related to these retail receivables.  Cinergy Corp. does not consolidate Cinergy Receivables since it meets the requirements to be accounted for as a qualifying special purpose entity (SPE).  A decline in the long-term senior unsecured credit ratings of CG&E, PSI, and ULH&P below investment grade would result in the termination of the sale program and discontinuance of future sales of receivables.

 

Notes Payable and Other Short-term Obligations

 

We are required to secure authority to issue short-term debt from the SEC under the PUHCA and from the PUCO.  The SEC under the PUHCA regulates the issuance of short-term debt by Cinergy Corp., PSI, and ULH&P.  The PUCO has regulatory jurisdiction over the issuance of short-term debt by CG&E.

 

 

 

 

 

 

 

Short-term Regulatory Authority
September 30, 2004

 

 

 

(in millions)

 

 

 

 

 

 

 

Authority

 

Outstanding

 

 

 

 

 

 

 

Cinergy Corp.

 

$

5,000

(1)

$

912

 

CG&E and subsidiaries

 

665

 

242

 

PSI

 

600

 

154

 

ULH&P

 

65

 

37

 

 

 

(1)

Cinergy Corp., under the PUHCA, has approval to increase total capitalization (excluding retained earnings and accumulated other comprehensive income (loss)), which may be any combination of short-term debt, long-term debt, and equity securities, to $5 billion.  Outside this requirement, Cinergy Corp. is not subject to specific regulatory debt authorizations.

 

 

 

For the purposes of quantifying regulatory authority, short-term debt includes revolving credit and uncommitted credit line borrowings, intercompany money pool obligations, and commercial paper. Cinergy Corp.’s short-term borrowings consist primarily of unsecured revolving lines of credit and the sale of commercial paper.  Cinergy Corp.’s $1.5 billion revolving credit facilities and commercial paper program also support the short-term borrowing needs of CG&E, PSI, and ULH&P.  In addition, Cinergy Corp., CG&E, and PSI maintain uncommitted lines of credit.  These facilities are not firm sources of capital but rather informal agreements to lend money, subject to availability, with pricing determined at the time of advance.

 

Variable Rate Pollution Control Notes

 

In August 2004, PSI borrowed the proceeds from the issuance by the Indiana Development Finance Authority of $55 million principal amount of its Environmental Revenue Bonds, Series 2004A, due August 2039.  The initial interest rate for the bonds was 1.13 percent and is reset weekly.  Proceeds from the borrowing will be used for the acquisition and construction of various solid waste disposal facilities located at various generating stations in Indiana.  The $55 million is being held in escrow by an independent trustee and will be drawn upon as facilities are built.  Holders of these notes are entitled to credit enhancement in the form of a standby letter of credit, which if drawn upon, provides for the payment of both interest and principal on the notes.  Because the holders of these notes have

 

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MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

the right to have their notes redeemed on a weekly basis, they are reflected in Notes payable and other short-term obligations on the balance sheets of Cinergy and PSI.

 

The following is a summary of outstanding short-term borrowings for Cinergy, CG&E, PSI, and ULH&P, including variable rate pollution control notes:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Short-term Borrowings
September 30, 2004

 

 

 

Established
Lines

 

Outstanding

 

Unused

 

Standby
Liquidity(3)

 

Available
Revolving
Lines of
Credit

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy

 

 

 

 

 

 

 

 

 

 

 

Cinergy Corp.

 

 

 

 

 

 

 

 

 

 

 

Revolving lines

 

$

1,500

 

$

 

$

1,500

 

$

918

 

$

582

 

Uncommitted lines(1)

 

40

 

 

40

 

 

 

 

 

Commercial paper(2)

 

 

 

912

 

588

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Utility operating companies

 

 

 

 

 

 

 

 

 

 

 

Uncommitted lines(1)

 

75

 

 

75

 

 

 

 

 

Pollution control notes

 

 

 

248

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-regulated subsidiaries

 

 

 

 

 

 

 

 

 

 

 

Revolving lines

 

14

 

10

 

4

 

 

 

4

 

Short-term debt

 

 

 

2

 

 

 

 

 

 

 

Pollution control notes

 

 

 

25

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy Total

 

 

 

$

1,197

 

 

 

 

 

$

586

 

 

 

 

 

 

 

 

 

 

 

 

 

CG&E and subsidiaries

 

 

 

 

 

 

 

 

 

 

 

Uncommitted lines(1)

 

$

15

 

$

 

$

15

 

 

 

 

 

Pollution control notes

 

 

 

112

 

 

 

 

 

 

 

Money pool

 

 

 

242

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

CG&E Total

 

 

 

$

354

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

PSI

 

 

 

 

 

 

 

 

 

 

 

Uncommitted lines(1)

 

$

60

 

$

 

$

60

 

 

 

 

 

Pollution control notes

 

 

 

136

 

 

 

 

 

 

 

Money pool

 

 

 

154

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

PSI Total

 

 

 

$

290

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ULH&P

 

 

 

 

 

 

 

 

 

 

 

Money pool

 

 

 

$

37

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ULH&P Total

 

 

 

$

37

 

 

 

 

 

 

 

 

 

(1)

These facilities are not guaranteed sources of capital and represent an informal agreement to lend money, subject to availability, with pricing to be determined at the time of advance.

(2)

In September 2004, Cinergy Corp. increased its commercial paper program limit from $800 million to $1.5 billion.  The commercial paper program is supported by Cinergy Corp.’s revolving lines of credit.

(3)

Standby liquidity is reserved against the revolving lines to support the commercial paper program and outstanding letters of credit (currently $912 million and $6 million, respectively).

 

 

 

In April 2004, Cinergy Corp. successfully placed two senior unsecured revolving credit facilities with an aggregate borrowing capacity of $1.5 billion, comprised of a $500 million 364-day facility

 

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MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

and a $1 billion three-year facility.  These facilities replaced two facilities that expired in April and May 2004.

 

At September 30, 2004, Cinergy Corp. had approximately $582 million remaining unused and available capacity relating to its $1.5 billion revolving credit facilities.  These revolving credit facilities include the following:

 

 

 

 

 

 

 

 

 

 

 

Credit Facility

 

Expiration

 

Established Lines

 

Outstanding
and
Committed

 

Unused and
Available

 

 

 

 

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

364-day senior revolving

 

April 2005

 

 

 

 

 

 

 

Direct borrowing

 

 

 

$

 

 

$

 

$

 

 

Commercial paper support

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total 364-day facility

 

 

 

500

 

 

500

 

 

 

 

 

 

 

 

 

 

 

Three-year senior revolving

 

April 2007

 

 

 

 

 

 

 

Direct borrowing

 

 

 

 

 

 

 

 

Commercial paper support

 

 

 

 

 

912

 

 

 

Letter of credit support

 

 

 

 

 

6

 

 

 

 

 

 

 

 

 

 

 

 

 

Total three-year facility

 

 

 

1,000

 

918

 

82

 

 

 

 

 

 

 

 

 

 

 

Total Credit Facilities

 

 

 

$

1,500

 

$

918

 

$

582

 

 

 

 

 

 

 

 

 

 

 

 

In our credit facilities, Cinergy Corp. has covenanted to maintain:

 

                  a consolidated net worth of $2 billion; and

                  a ratio of consolidated indebtedness to consolidated total capitalization not in excess of 65 percent.

 

A breach of these covenants could result in the termination of the credit facilities and the acceleration of the related indebtedness.  In addition to breaches of covenants, certain other events that could result in the termination of available credit and acceleration of the related indebtedness include:

 

                  bankruptcy;

                  defaults in the payment of other indebtedness; and

                  judgments against the company that are not paid or insured.

 

The latter two events, however, are subject to dollar-based materiality thresholds.

 

Long-term Debt

 

We are required to secure authority to issue long-term debt from the SEC under the PUHCA and the state utility commissions of Ohio, Kentucky, and Indiana.  The SEC under the PUHCA regulates the issuance of long-term debt by Cinergy Corp.  The respective state utility commissions regulate the issuance of long-term debt by our utility operating companies.

 

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MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

A current summary of our long-term debt authorizations at September 30, 2004, was as follows:

 

 

 

 

 

 

 

 

 

 

 

Authorized

 

Used

 

Available

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Cinergy Corp.

 

 

 

 

 

 

 

PUHCA total capitalization(1)

 

$

5,000

 

$

1,705

 

$

3,295

 

 

 

 

 

 

 

 

 

CG&E and subsidiaries(2)

 

 

 

 

 

 

 

State Public Utility Commissions

 

$

575

 

$

 

$

575

 

State Public Utility Commission - Tax-Exempt

 

250

 

 

250

 

 

 

 

 

 

 

 

 

PSI

 

 

 

 

 

 

 

State Public Utility Commission

 

$

500

 

$

 

$

500

 

State Public Utility Commission - Tax-Exempt

 

250

 

55

 

195

 

 

 

 

 

 

 

 

 

ULH&P

 

 

 

 

 

 

 

State Public Utility Commission

 

$

75

 

$

 

$

75

 

 

 

(1)

Cinergy Corp., under PUHCA, has approval to increase total capitalization (excluding retained earnings and accumulated other comprehensive income (loss)), which may be any combination of short-term debt, long-term debt, and equity securities, by $5 billion.  Outside this requirement, Cinergy Corp. is not subject to specific regulatory debt authorizations.

(2)

Includes amounts for ULH&P.

 

 

 

 

Cinergy Corp. has an effective shelf registration statement with the SEC relating to the issuance of up to $750 million in any combination of common stock, preferred stock, stock purchase contracts or unsecured debt securities, of which approximately $574 million remains available for issuance.  CG&E has an effective shelf registration statement with the SEC relating to the issuance of up to $800 million in any combination of unsecured debt securities, first mortgage bonds, or preferred stock, all of which remains available for issuance.  PSI has an effective shelf registration statement with the SEC relating to the issuance of up to $800 million in any combination of unsecured debt securities, first mortgage bonds, or preferred stock, all of which remains available for issuance.  ULH&P has an effective shelf registration statement with the SEC for the issuance of up to $75 million in unsecured debt securities, all of which remains available for issuance.  ULH&P also has effective shelf registration statements with the SEC relating to the issuance of up to $40 million in first mortgage bonds, of which $20 million remains available for issuance.

 

Off-Balance Sheet Arrangements

 

As discussed in the 2003 10-K, Cinergy uses off-balance sheet arrangements from time to time to facilitate financing of various projects.  Cinergy’s primary off-balance sheet arrangements involve (a) the sale of accounts receivable to a qualifying SPE, and (b) a forward stock contract that will result in the issuances of between 9.2 and 10.8 million Cinergy Corp. common shares in February 2005.

 

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MD&A - LIQUIDITY AND CAPITAL RESOURCES

 

Securities Ratings

 

As of September 30, 2004, the major credit rating agencies rated our securities as follows:

 

 

 

 

 

 

 

 

 

 

 

Fitch(1)

 

Moody’s(2)

 

S&P(3)

 

 

 

 

 

 

 

 

 

Cinergy Corp.

 

 

 

 

 

 

 

Corporate Credit

 

BBB+

 

Baa2

 

BBB+

 

Senior Unsecured Debt

 

BBB+

 

Baa2

 

BBB

 

Commercial Paper

 

F-2

 

P-2

 

A-2

 

Preferred Trust Securities

 

BBB+

 

Baa2

 

BBB

 

 

 

 

 

 

 

 

 

CG&E

 

 

 

 

 

 

 

Senior Secured Debt

 

A-

 

A3

 

A-

 

Senior Unsecured Debt

 

BBB+

 

Baa1

 

BBB

 

Junior Unsecured Debt

 

BBB

 

Baa2

 

BBB-

 

Preferred Stock

 

BBB

 

Baa3

 

BBB-

 

Commercial Paper

 

F-2

 

P-2

 

Not Rated

 

 

 

 

 

 

 

 

 

PSI

 

 

 

 

 

 

 

Senior Secured Debt

 

A-

 

A3

 

A-

 

Senior Unsecured Debt

 

BBB+

 

Baa1

 

BBB

 

Junior Unsecured Debt

 

BBB

 

Baa2

 

BBB-

 

Preferred Stock

 

BBB

 

Baa3

 

BBB-

 

Commercial Paper

 

F-2

 

P-2

 

Not Rated

 

 

 

 

 

 

 

 

 

ULH&P

 

 

 

 

 

 

 

Senior Unsecured Debt

 

Not Rated

 

Baa1

 

BBB

 

 

 

(1)

Fitch Ratings (Fitch)

(2)

Moody’s Investors Service (Moody’s)

(3)

Standard & Poor’s (S&P)

 

 

The highest investment grade credit rating for Fitch is AAA, Moody’s is Aaal, and S&P is AAA.

The lowest investment grade credit rating for Fitch is BBB-, Moody’s is Baa3, and S&P is BBB-.

 

 

A security rating is not a recommendation to buy, sell, or hold securities.  These securities ratings may be revised or withdrawn at any time, and each rating should be evaluated independently of any other rating.

 

Equity

 

As discussed in the 2003 10-K, Cinergy issues new Cinergy Corp. common stock shares to satisfy obligations under certain of its employee stock plans and the Cinergy Corp. Direct Stock Purchase and Dividend Reinvestment Plan.  During the nine months ended September 30, 2004, Cinergy issued approximately 2.7 million shares under these plans.

 

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MD&A - QUARTERLY RESULTS OF OPERATIONS - HISTORICAL

 

The Results of Operations discussions for Cinergy, CG&E, and PSI are combined within this section.

 

2004 QUARTERLY RESULTS OF OPERATIONS - HISTORICAL

 

Summary of Results

 

Electric and gas gross margins and net income for Cinergy, CG&E, and PSI for the quarters ended September 30, 2004 and 2003 were as follows:

 

 

 

 

Cinergy(1)

 

CG&E and subsidiaries

 

PSI

 

 

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

 

 

(in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income

 

$

92,923

 

$

111,981

 

(19,058

)

(17

)

$

64,073

 

$

78,863

 

$

(14,790

)

(19

)

$

48,487

 

$

37,592

 

$

10,895

 

29

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Electric gross margin(2)

 

660,303

 

590,641

 

69,662

 

12

 

337,779

 

330,046

 

7,733

 

2

 

319,548

 

259,298

 

60,250

 

23

 

Gas gross margin(3)

 

45,506

 

44,951

 

555

 

1

 

40,334

 

34,176

 

6,158

 

18

 

 

 

 

 

 

 

(1)

The results of Cinergy also include amounts related to non-registrants.

(2)

Electric gross margin is calculated as Electric operating revenues less Fuel and purchased power expense from the Condensed Consolidated Statements of Income.

(3)

Gas gross margin is calculated as Gas operating revenues less Gas purchased expense from the Condensed Consolidated Statements of Income.

 

 

 

Cinergy’s decrease in net income was primarily attributable to the following factors:

 

                  Higher Operation and maintenance expense due, in part, to increased emission allowance expenses;

                  Higher Depreciation expense; and

                  Impairment and disposal charges on certain investments in the Power Technology and Infrastructure Services Business Unit (Power Technology and Infrastructure) (reflected in Miscellaneous Income (Expense) — Net).

                  These expenses were offset by higher electric gross margins and an adjustment to decrease the estimated annual effective tax rate.

 

CG&E’s decrease in net income was primarily attributable to the following factors:

 

                  Higher Operation and maintenance expense due primarily to increased emission allowance expenses.

                  These higher expenses were offset, in part, by higher electric and gas gross margins.

 

PSI’s increase in net income was primarily attributable to the following factors:

 

                  Higher electric gross margins.

                  These higher margins were offset, in part, by higher Operation and maintenance expense, higher Depreciation expense and an adjustment to increase the estimated annual effective tax rate.

 

61



 

MD&A -QUARTERLY RESULTS OF OPERATIONS - HISTORICAL

 

Electric Margins

 

Cinergy’s, CG&E’s, and PSI’s electric gross margins increased for the quarter ended September 30, 2004, as compared to the same period last year.  Cinergy’s and PSI’s variances include a higher price received per MWh primarily due to the Indiana Utility Regulatory Commission’s (IURC) approval of PSI’s average base retail electric rate increase of eight percent in May 2004.  This is discussed further in Note 6(b)(i) of the “Notes to Condensed Financial Statements” in “Item 1. Financial Statements”.  For all three companies, growth in non-weather related demand was offset by a decline in MWh sales due to milder weather in the current period.  Cinergy’s and CG&E’s variances reflect an increase in net revenues on power marketing, trading, and origination contracts.

 

Cinergy’s and CG&E’s variances also reflect a decline due to an increase in the average price of fuel for the period.  Offsetting most of this decline was an increase in coal origination, which includes contract structuring and marketing of physical coal.

 

Electric Operating Revenues

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

CG&E and subsidiaries

 

PSI

 

 

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

 

 

 

 

 

 

 

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Retail

 

$

792

 

$

744

 

$

48

 

6

 

$

383

 

$

377

 

$

6

 

2

 

$

409

 

$

367

 

$

42

 

11

 

Wholesale

 

139

 

141

 

(2

)

(1

)

59

 

65

 

(6

)

(9

)

56

 

61

 

(5

)

(8

Other

 

63

 

36

 

27

 

75

 

52

 

33

 

19

 

58

 

15

 

9

 

6

 

67

 

Total

 

$

994

 

$

921

 

$

73

 

8

 

$

494

 

$

475

 

$

19

 

4

 

$

480

 

$

437

 

$

43

 

10

 

 

 

(1)              The results of Cinergy also include amounts related to non-registrants.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Heating degree-days and cooling degree-days are metrics commonly used in the utility industry as a measure of the impact weather has on results of operations.  Heating degree-days and cooling degree-days in CG&E’s and PSI’s service territories for the quarters ended September 30, 2004 and 2003, were as follows:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

CG&E and subsidiaries

 

PSI

 

 

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Heating degree-days(1)

 

36

 

72

 

(36

)

(50

)

42

 

91

 

(49

)

(54

)

Cooling degree-days(2)

 

540

 

638

 

(98

)

(15

)

535

 

642

 

(107

)

(17

)

 

 

(1)

Heating degree-days are the differences between the average temperature for each day and 65 degrees, assuming the average temperature is less than 65 degrees.

(2)

Cooling degree-days are the differences between the average temperature for each day and 65 degrees, assuming the average temperature is greater than 65 degrees.

 

 

 

Although cooling degree-days declined, retail electric operating revenues increased for Cinergy and PSI in the third quarter of 2004 as compared to 2003.  This was mainly due to an increase in the average retail price per MWh, which resulted in approximately $49 million and $45 million higher retail revenues for Cinergy and PSI, respectively.  The higher retail prices primarily reflect a higher

 

62



 

MD&A -QUARTERLY RESULTS OF OPERATIONS - HISTORICAL

 

price received per MWh due to PSI’s base retail electric rate case.  For all three companies, growth in non-weather related demand was offset by a decline in MWh sales due to milder weather in the current period.

 

Electric wholesale revenues remained relatively flat for Cinergy and decreased for CG&E and PSI for the quarter ended September 30, 2004, as compared to 2003.  Cinergy’s wholesale revenues increased approximately $14 million from non-regulated energy service subsidiaries that started operations, or became fully consolidated, after September 30, 2003.  Additionally, net revenues on power marketing, trading, and origination contracts increased approximately $11 million.  The increase in power trading results is attributable to higher margins on physical and financial trading primarily related to regional spreads between the mideast and midwest markets.  These increases were offset by decreases in wholesale sales from generation available after serving regulated retail customers.

 

CG&E’s variance reflects decreases in wholesale sales from generation available after serving regulated retail customers.  Partially offsetting this decrease was an approximate $15 million increase in net revenues on power marketing, trading, and origination contracts.  The increase in power trading results is attributable to higher margins on physical and financial trading primarily related to regional spreads between the mideast and midwest markets.  The majority of PSI’s decrease was attributable to decreases in wholesale sales from generation available after serving regulated retail customers.

 

The decreases in wholesale sales from generation available after serving regulated retail customers were primarily caused by lower demand.  In addition, lower market prices caused our generation to be less economic when it was available for wholesale transactions.  As a result, there were fewer opportunities to sell into the wholesale market from generation in the third quarter of 2004, as compared to 2003.

 

Other electric operating revenues increased for Cinergy, CG&E, and PSI for the quarter ended September 30, 2004, as compared to 2003.  Cinergy’s and CG&E’s higher other electric operating revenues reflect increases in coal origination of approximately $23 million.  Coal origination includes contract structuring and marketing of physical coal.  Cinergy’s, CG&E’s, and PSI’s increases also reflect approximately $8 million, $2 million, and $6 million, respectively, of higher transmission revenues primarily resulting from Midwest Independent System Operator, Inc. (Midwest ISO) operations.

 

Fuel and Purchased Power

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

CG&E and subsidiaries

 

PSI

 

 

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

 

 

 

 

 

 

 

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fuel used for generation

 

$

259

 

$

270

 

$

(11

)

(4

)

$

99

 

$

94

 

$

5

 

5

 

$

139

 

$

164

 

$

(25

)

(15

)

Coal origination costs

 

29

 

17

 

12

 

71

 

29

 

17

 

12

 

71

 

 

 

 

 

Total fuel

 

$

288

 

$

287

 

$

1

 

 

$

128

 

$

111

 

$

17

 

15

 

$

139

 

$

164

 

$

(25

)

(15

)

Purchased power

 

46

 

43

 

3

 

7

 

28

 

34

 

(6

)

(18

)

22

 

14

 

8

 

57

 

Fuel and purchased power

 

$

334

 

$

330

 

$

4

 

1

 

$

156

 

$

145

 

$

11

 

8

 

$

161

 

$

178

 

$

(17

)

(10

)

 

(1)

The results of Cinergy also include amounts related to non-registrants.

 

 

 

63



 

MD&A -QUARTERLY RESULTS OF OPERATIONS - HISTORICAL

 

Fuel

 

Fuel expense represents the cost of coal, natural gas, and oil that is used to generate electricity, and the cost of coal origination, which includes contract structuring and marketing of physical coal.  The following table details the changes to expense for fuel used in generation from the quarter ended September 30, 2003, to the quarter ended September 30, 2004:

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

CG&E

 

PSI

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Fuel Expense – September 30, 2003

 

$

270

 

$

94

 

$

164

 

 

 

 

 

 

 

 

 

Increase (Decrease) due to changes in:

 

 

 

 

 

 

 

Price of fuel

 

12

 

13

 

(1

)

Deferred fuel cost

 

(14

)

 

(14

)

Fuel consumption

 

(18

)

(8

)

(10

)

Non-regulated subsidiaries

 

9

 

 

 

 

 

 

 

 

 

 

 

Fuel Expense – September 30, 2004

 

$

259

 

$

99

 

$

139

 

 

 

(1)

The results of Cinergy also include amounts related to non-registrants.

 

 

 

Deferred fuel cost represents changes in fuel expense associated with PSI’s fuel adjustment charge, which recovers retail fuel costs from customers on a dollar-for-dollar basis.  The fuel adjustment charge is calculated based on the estimated cost of fuel in the next three-month period.  PSI records any under-recovery or over-recovery resulting from these differences as a deferred asset or liability until it is billed or refunded to its customers, at which point it is adjusted through fuel expense.

 

Purchased Power

 

Purchased power expense increased for Cinergy and PSI and decreased for CG&E for the quarter ended September 30, 2004, as compared to 2003.  Cinergy’s and PSI’s increases primarily reflect a greater volume of MWhs purchased to serve PSI’s native load and wholesale full requirements customers.  Partially offsetting Cinergy’s increase and primarily causing CG&E’s decrease was a reduction in the amount of MWhs purchased to serve CG&E’s wholesale full requirements customers and a lower price paid per MWh for these purchases.

 

Gas Margins

 

CG&E’s gas gross margins increased and Cinergy’s remained relatively flat for the quarter ended September 30, 2004, as compared to the same period last year.  CG&E’s gas margins increased by approximately $6 million primarily due to rate tariff adjustments.

 

Cinergy’s gas margins remained relatively flat as CG&E’s increase was offset by lower margins from our gas marketing and trading business.  Margins for our gas marketing and trading business decreased primarily due to timing differences in revenue recognition between physical storage activities and the associated derivative contracts that hedge the physical storage.  Our gas marketing and trading business regularly hedges its price exposure of natural gas held in storage by selling derivative contracts for winter month delivery.  The majority of the gas held in storage is designated as being hedged under Statement of Financial Accounting Standards No. 133, Accounting for Derivative Instruments and Hedging Activities’ (Statement 133) fair value hedge accounting model, which allows the gas to be accounted for at its fair value (based on spot prices).  Under generally accepted

 

64



 

MD&A -QUARTERLY RESULTS OF OPERATIONS - HISTORICAL

 

accounting principles (GAAP), the derivative contracts hedging the gas are accounted for at fair value (based on forward winter prices).  Conversely, the agreements with pipelines to store this natural gas until the winter periods are not derivatives and are not adjusted for changes in fair value (see footnote 1 in the table below).  Significant increases in natural gas prices during the third quarter of 2004, especially prices for winter months, resulted in an unrealized loss on the derivative contracts that is included in current earnings.  However, the economic benefit of these increased prices for the gas held in storage will not be recognized in revenues until spot and winter prices of gas converge (which we expect will occur in the winter months when the natural gas is withdrawn from storage and sold).

 

For a more complete understanding of our gas marketing and trading results, we have prepared the following table which reconciles the gas margins under GAAP, the impact of adjusting these margins for the fair value of pipeline agreements and certain gas held in storage, and the resulting adjusted gas margins:

 

 

 

 

 

 

 

 

 

 

 

2004

 

2003

 

Change

 

 

 

(dollars in millions)

 

 

 

 

 

 

 

 

 

Gas margins, as reported (GAAP)

 

$

5

 

$

11

 

$

(6

)

 

 

 

 

 

 

 

 

Fair value adjustments not recognized under GAAP(1)

 

21

(2)

1

 

20

 

 

 

 

 

 

 

 

 

Adjusted gas margins

 

$

26

 

$

12

 

$

14

 

 

 

(1)

Relates to fair value of storage agreements.  The value of a storage agreement is the ability to store and optimize gas between periods of lower prices (typically summer) and periods of higher prices (typically winter).  A large component of the fair value is therefore the differences between winter prices and spot prices.  As this spread gets wider, the value of a storage agreement increases.

(2)

The magnitude of the adjustment in 2004 is driven by forward price increases in the winter months that are significantly larger than spot price increases, which caused a recognized loss on the derivative sales in winter offset by an unrecognized gain on the related storage agreements.  While such price changes from one quarter to the next are not unprecedented, they are the most significant they have been since we discontinued the application of fair value accounting to natural gas held in storage and pipeline agreements on January 1, 2003, with the rescission of Emerging Issues Task Force Issue 98-10, Accounting for Contracts Involved in Energy Trading and Risk Management Activities (EITF 98-10).

 

 

 

Adjusted gas margins represent a more economic view of the business with all elements of the business reflected at fair value.  The resulting increase in adjusted gas margins from our gas marketing and trading business is primarily a result of an increase in physical and financial trading margins resulting from favorable price movements in the third quarter of 2004.

 

Other Revenues

 

Other revenues for Cinergy increased for the quarter ended September 30, 2004, as compared to 2003, primarily due to increased revenues of approximately $22 million from the sale of synthetic fuel as a result of an increase in demand for our synthetic fuel.

 

Operating Expenses

 

Operation and Maintenance

 

Operation and maintenance expense increased for Cinergy, CG&E, and PSI for the quarter ended September 30, 2004, as compared to 2003.  Approximately $27 million of Cinergy’s increase is due to an increase in the production of synthetic fuel as a result of an increase in demand for our synthetic fuel.  Cinergy’s, CG&E’s, and PSI’s increases include approximately $15 million, $7 million, and $8

 

65



 

MD&A -QUARTERLY RESULTS OF OPERATIONS - HISTORICAL

 

million, respectively, of higher expenses related to emission allowances.  These increases primarily reflect higher expenses due to an increase in the cost of SO2 emission allowances as market prices have increased.  Cinergy’s and PSI’s increases also resulted from timing differences in the recovery of SO2 emission allowances costs under PSI’s emission allowances tracking mechanism authorized by the IURC.

 

Maintenance expenses, primarily production and distribution related, were higher by approximately $7 million for both Cinergy and CG&E.  The increases for Cinergy, CG&E, and PSI also reflect costs incurred in the third quarter of 2004 related to a continuous improvement initiative of approximately $6 million, $3 million, and $2 million, respectively.  Approximately $5 million of Cinergy’s increase relates to non-regulated energy service subsidiaries that started operations, or became fully consolidated, after the second quarter of 2003.  Partially offsetting Cinergy’s increases were approximately $12 million of costs incurred in 2003 associated with the bankruptcy of Enron Corp.

 

Depreciation

 

Depreciation expense increased for Cinergy and PSI for the quarter ended September 30, 2004, as compared to 2003.  Approximately $12 million of Cinergy’s and PSI’s increase was due to the addition of depreciable plant primarily for pollution control equipment.  Also contributing to Cinergy’s and PSI’s higher depreciation expense was an approximate $7.5 million increase due to higher depreciation rates effective June 2004 that were approved in PSI’s latest retail rate case.

 

Miscellaneous Income (Expense) – Net

 

Miscellaneous Income (Expense) – Net decreased for Cinergy and CG&E and increased for PSI for the quarter ended September 30, 2004, as compared to 2003.  Cinergy’s decrease reflects approximately $15 million in impairment and disposal charges on certain investments in Power Technology and Infrastructure.  The values of these investments reflect our estimates and judgments about the future performance of these investments, for which actual results may differ.  CG&E’s decrease and PSI’s increase was primarily a result of a final reconciliation recorded in 2003 between the two entities of a previous demutualization of a medical insurance carrier used by both companies.

 

Income Taxes

 

The effective income tax rate decreased for Cinergy and increased for CG&E and PSI for the quarter ended September 30, 2004, as compared to 2003.  Cinergy’s 2004 effective tax rate is expected to be approximately 23 percent, a decrease of one percent from our prior estimate.  The change results from a revision in estimated 2004 pre-tax income with no adjustment to the estimated annual tax credits associated with the production and sale of synthetic fuel for the year.  CG&E’s and PSI’s increases reflect revisions to estimated 2004 pre-tax income and changes in permanent differences which have an incremental effect on tax expense.

 

In July 2002, Cinergy Capital & Trading, Inc. (Capital & Trading) acquired a coal-based synthetic fuel production facility.  The synthetic fuel produced at this facility qualifies for tax credits in accordance with Section 29 of the Internal Revenue Code (IRC).  Eligibility for these credits expires after 2007.  Cinergy received a private letter ruling from the Internal Revenue Service (IRS) in connection with the acquisition of the facility.  To date, Cinergy has recorded approximately $189 million in tax

 

66



 

MD&A -QUARTERLY RESULTS OF OPERATIONS - HISTORICAL

 

credits, including approximately $69 million in 2004.  See Note 6(c)(iv) of the “Notes to Condensed Financial Statements” in “Item 1. Financial Statements” for more detail.

 

67



 

MD&A -year to date results of operations - historical

 

2004 YEAR TO DATE RESULTS OF OPERATIONS - HISTORICAL

 

Summary of Results

 

Electric and gas gross margins and net income for Cinergy, CG&E, and PSI for the nine months ended September 30, 2004 and 2003, were as follows:

 

 

 

 

 

Cinergy(1)

 

CG&E and subsidiaries

 

PSI

 

 

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

 

 

(in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income

 

$

254,442

 

$

362,719

 

$

(108,277

)

(30

)

$

196,837

 

$

247,018

 

$

(50,181

)

(20

)

$

114,739

 

$

94,398

 

$

20,341

 

22

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Electric gross margin(2)

 

1,850,064

 

1,672,622

 

177,442

 

11

 

959,871

 

919,244

 

40,627

 

4

 

873,875

 

743,501

 

130,374

 

18

 

Gas gross margin(3)

 

233,498

 

269,482

 

(35,984

)

(13

)

187,702

 

174,912

 

12,790

 

7

 

 

 

 

 

 

 

(1)

The results of Cinergy also include amounts related to non-registrants.

(2)

Electric gross margin is calculated as Electric operating revenues less Fuel and purchased power expense from the Condensed Consolidated Statements of Income.

(3)

Gas gross margin is calculated as Gas operating revenues less Gas purchased expense from the Condensed Consolidated Statements of Income.

 

 

 

Cinergy’s decrease in net income was primarily attributable to the following factors:

 

                  Higher Operation and maintenance expense due, in part, to greater emission allowance expenses;

                  Higher Depreciation expense;

                  Impairment and disposal charges on certain investments in Power Technology and Infrastructure (reflected in Miscellaneous Income (Expense) — Net);

                  Lower gas margins in our gas marketing and trading business;

                  Net gains recognized in the first quarter of 2003 resulting from the implementation of certain accounting changes that have been reflected as cumulative effects of changes in accounting principles; and

                  Gains realized in the second quarter of 2003 from the disposal of discontinued operations.

                  These variances were offset, in part, by an increase in electric gross margins.

 

CG&E’s decrease in net income was primarily attributable to the following factors:

 

                  Higher Operation and maintenance expense due primarily to greater emission allowance expenses, consulting fees for a continuous improvement initiative and higher employee benefit expenses; and

                  Net gains recognized in the first quarter of 2003 resulting from the implementation of certain accounting changes that have been reflected as cumulative effects of changes in accounting principles.

                  These variances were offset, in part, by increases in electric and gas gross margins.

 

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MD&A -year to date results of operations - historical

 

PSI’s increase in net income was primarily attributable to the following factors:

 

                  Higher electric gross margins.

                  These higher margins were offset, in part, by higher Operation and maintenance expense, higher Depreciation expense and an adjustment to increase the estimated annual effective tax rate.

 

Electric Margins

 

Cinergy’s, CG&E’s, and PSI’s electric gross margins increased for the nine months ended September 30, 2004, as compared to the same period last year.  Cinergy’s and PSI’s increases included a higher price received per MWh primarily due to the IURC’s approval of PSI’s average base retail electric rate increase of eight percent in May 2004 and certain rate tariff adjustments.  Also contributing to the increase in electric gross margins for all three companies were additional MWhs delivered due to growth in non-weather related demand.  Cinergy’s and CG&E’s variances reflect an increase in net revenues on power marketing, trading, and origination contracts.

 

Cinergy’s and CG&E’s variances also reflect a decline due to an increase in the average price of fuel for the period.  This decline was partially offset by an increase in coal origination, which includes contract structuring and marketing of physical coal.

 

Electric Operating Revenues

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

CG&E and subsidiaries

 

PSI

 

 

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

 

 

 

 

 

 

 

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Retail

 

$

2,157

 

$

2,063

 

$

94

 

5

 

$

1,057

 

$

1,030

 

$

27

 

3

 

$

1,100

 

$

1,033

 

$

67

 

6

 

Wholesale

 

459

 

364

 

95

 

26

 

204

 

194

 

10

 

5

 

177

 

156

 

21

 

13

 

Other

 

148

 

86

 

 

62

 

72

 

126

 

77

 

 

49

 

64

 

34

 

21

 

 

13

 

62

 

Total

 

$

2,764

 

$

2,513

 

$

251

 

10

 

$

1,387

 

$

1,301

 

$

86

 

7

 

$

1,311

 

$

1,210

 

$

101

 

8

 

 

 

(1)

The results of Cinergy also include amounts related to non-registrants.

 

 

 

Heating degree-days and cooling degree-days are metrics commonly used in the utility industry as a measure of the impact weather has on results of operations.  Heating degree-days and cooling degree-days in CG&E’s and PSI’s service territories for the nine months ended September 30, 2004 and 2003, were as follows:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

CG&E and subsidiaries

 

PSI

 

 

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Heating degree-days(1)

 

3,121

 

3,387

 

(266

)

(8

)

3,256

 

3,697

 

(441

)

(12

)

Cooling degree-days(2)

 

867

 

804

 

63

 

8

 

879

 

841

 

38

 

5

 

 

 

(1)

Heating degree-days are the differences between the average temperature for each day and 65 degrees, assuming the average temperature is less than 65 degrees.

(2)

Cooling degree-days are the differences between the average temperature for each day and 65 degrees, assuming the average temperature is greater than 65 degrees.

 

 

 

69



 

MD&A -year to date results of operations - historical

 

The change in degree days for the nine months ended September 30, 2004, as compared to 2003, did not have a material effect on electric operating revenues.

 

Retail electric operating revenues increased for Cinergy primarily due to a three percent increase in MWhs delivered by CG&E and PSI for the nine months ended September 30, 2004, as compared to 2003.  These increases resulted in approximately $59 million, $28 million, and $31 million higher retail revenues for Cinergy, CG&E, and PSI, respectively.  The increase in MWhs delivered primarily reflects growth in non-weather related demand.

 

Also contributing to the increase in retail electric operating revenues for Cinergy and primarily causing the increase in retail electric operating revenues for PSI were two percent and three percent increases, respectively, in the average retail price per MWh for the first nine months of 2004, as compared to 2003.  These average increases resulted in approximately $35 million and $36 million higher retail electric operating revenues for Cinergy and PSI, respectively.  Contributing to the average price increase was a higher price received per MWh due to PSI’s base retail electric rate case.  Also contributing to the average price increase were approximately $17 million in increases in rate tariff adjustments related to emission allowances and clean coal technology tracking mechanisms.

 

Electric wholesale revenues increased for Cinergy, CG&E, and PSI for the nine months ended September 30, 2004, as compared to 2003.  Cinergy’s increase includes a number of factors.  Approximately $41 million of the variance includes increases in wholesale revenues from non-regulated energy service subsidiaries that started operations, or became fully consolidated, after the first half of 2003.  Net revenues on power marketing, trading, and origination contracts increased approximately $34 million.  The increase in power trading results is attributable to higher margins on physical and financial trading primarily related to regional spreads between the mideast and midwest markets.  The majority of the remaining increase was attributable to increases in wholesale sales from generation available after serving regulated retail customers.

 

CG&E’s net revenues on power marketing, trading, and origination contracts increased approximately $35 million.  The increase in power trading results is attributable to higher margins on physical and financial trading primarily related to regional spreads between the mideast and midwest markets.  This increase was offset by a decrease in MWhs available for wholesale activity due in part to a decrease in generation available for these transactions.  The majority of PSI’s increase was attributable to a greater amount of wholesale sales from generation available after serving regulated retail customers.

 

Other electric operating revenues increased for Cinergy, CG&E, and PSI for the nine months ended September 30, 2004, as compared to 2003.  Cinergy’s and CG&E’s higher other electric operating revenues reflect increases in coal origination of approximately $37 million.  Coal origination includes contract structuring and marketing of physical coal.  Cinergy’s, CG&E’s, and PSI’s increases also reflect approximately $19 million, $7 million, and $12 million, respectively, of higher transmission revenues primarily resulting from Midwest ISO operations.

 

70



 

MD&A -year to date results of operations - historical

 

Fuel and Purchased Power

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

CG&E and subsidiaries

 

PSI

 

 

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

2004

 

2003

 

Change

 

%
Change

 

 

 

 

 

 

 

 

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fuel used for generation

 

$

719

 

$

705

 

$

14

 

2

 

$

290

 

$

263

 

$

27

 

10

 

$

369

 

$

415

 

$

(46

)

(11

)

Coal origination costs

 

68

 

41

 

27

 

66

 

68

 

41

 

27

 

66

 

 

 

 

 

Total fuel

 

$

787

 

$

746

 

$

41

 

5

 

$

358

 

$

304

 

$

54

 

18

 

$

369

 

$

415

 

$

(46

)

(11

)

Purchased power

 

127

 

94

 

33

 

35

 

69

 

78

 

(9

)

(12

)

68

 

52

 

16

 

31

 

Fuel and purchased power

 

$

914

 

$

840

 

$

74

 

9

 

$

427

 

$

382

 

$

45

 

12

 

$

437

 

$

467

 

$

(30

)

(6

)

 

 

(1)

The results of Cinergy also include amounts related to non-registrants.

 

 

 

Fuel

 

Fuel expense represents the cost of coal, natural gas, and oil that is used to generate electricity, and the cost of coal origination, which includes contract structuring and marketing of physical coal.  The following table details the changes to expense for fuel used in generation from the nine months ended September 30, 2003, to the nine months ended September 30, 2004:

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

CG&E

 

PSI

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Fuel expense - September 30, 2003

 

$

705

 

$

263

 

$

415

 

 

 

 

 

 

 

 

 

Increase (decrease) due to changes in:

 

 

 

 

 

 

 

Price of fuel

 

39

 

36

 

3

 

Deferred fuel cost

 

(64

)

 

(64

)

Fuel consumption

 

6

 

(9

)

15

 

Non-regulated subsidiaries

 

33

 

 

 

 

 

 

 

 

 

 

 

Fuel expense - September 30, 2004

 

$

719

 

$

290

 

$

369

 

 

 

(1)

The results of Cinergy also include amounts related to non-registrants.

 

 

 

Deferred fuel cost represents changes in fuel expense associated with PSI’s fuel adjustment charge, which recovers retail fuel costs from customers on a dollar-for-dollar basis.  The fuel adjustment charge is calculated based on the estimated cost of fuel in the next three-month period.  PSI records any under-recovery or over-recovery resulting from these differences as a deferred asset or liability until it is billed or refunded to its customers, at which point it is adjusted through fuel expense.

 

Purchased Power

 

Purchased power expense increased for Cinergy and PSI and decreased for CG&E for the nine months ended September 30, 2004, as compared to 2003.  Cinergy’s increase was primarily due to a significantly greater number of third party purchases by its subsidiaries in 2004.  In 2003, Cinergy’s subsidiaries’ purchased power expense included certain intercompany purchases that were eliminated in consolidation.

 

Also contributing to Cinergy’s increase and primarily causing PSI’s increase were additional costs of purchases made for PSI’s wholesale full requirements customers resulting from an increase in both the amount of MWhs purchased for these customers and the price paid per MWh.  Partially offsetting Cinergy’s increase and primarily causing CG&E’s decrease was a reduction in the amount of MWhs

 

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MD&A -year to date results of operations - historical

 

purchased to serve CG&E’s wholesale full requirements customers, partially offset by an increase in the price paid per MWh for these purchases.

 

Gas Margins

 

CG&E’s gas gross margins increased and Cinergy’s decreased for the nine months ended September 30, 2004, as compared to the same period last year.  CG&E’s approximate $13 million increase in gas margins included an increase of approximately $21 million primarily due to rate tariff adjustments associated with the gas main replacement program, a low-income subsidy program, and Ohio excise taxes.  This was offset by an approximate $8 million decrease reflecting less volume sold due to milder weather during 2004.  Heating degree days decreased approximately eight percent in CG&E’s service territory in the first nine months of 2004, as compared to 2003.

 

Lower margins from our gas marketing and trading business caused an overall decline in Cinergy’s gas margins.  Margins for our gas marketing and trading business decreased, in part, due to timing differences in revenue recognition between physical storage activities and the associated derivative contracts that hedge the physical storage.  Our gas marketing and trading business regularly hedges its price exposure of natural gas held in storage by selling derivative contracts for winter month delivery.  The majority of the gas held in storage is designated as being hedged under Statement 133’s fair value hedge accounting model, which allows the gas to be accounted for at its fair value (based on spot prices).  Under GAAP, the derivative contracts hedging the gas are accounted for at fair value (based on forward winter prices).  Conversely, the agreements with pipelines to store this natural gas until the winter periods are not derivatives and are not adjusted for changes in fair value (see footnote 1 in the table below).  Significant increases in natural gas prices during the third quarter of 2004, especially prices for winter months, resulted in an unrealized loss on the derivative contracts that is included in current earnings.  However, the economic benefit of these increased prices for the gas held in storage will not be recognized in revenue until spot and winter prices of gas converge (which we expect will occur in the winter months when the natural gas is withdrawn from storage and sold).

 

For a more complete understanding of our gas marketing and trading results, we have prepared the following table which reconciles the gas margins under GAAP, the impact of adjusting these margins for the fair value of pipeline agreements and certain gas held in storage, and the resulting adjusted gas margins:

 

 

 

 

 

 

 

 

 

 

 

2004

 

2003

 

Change

 

 

 

(dollars in millions)

 

 

 

 

 

 

 

 

 

Gas margins, as reported (GAAP)

 

$

46

 

$

95

 

$

(49

)

 

 

 

 

 

 

 

 

Fair value adjustments not recognized under GAAP (1)

 

21

(2)

(6

)

27

 

 

 

 

 

 

 

 

 

Adjusted gas margins

 

$

67

 

$

89

 

$

(22

)

 

 

(1)

Relates to fair value of storage agreements.  The value of a storage agreement is the ability to store and optimize gas between periods of lower prices (typically summer) and periods of higher prices (typically winter).  A large component of the fair value is therefore the differences between winter prices and spot prices.  As this spread gets wider, the value of a storage agreement increases.

(2)

The magnitude of the adjustment in 2004 is driven by forward price increases in the winter months that are significantly larger than spot price increases, which caused a recognized loss on the derivative sales in winter offset by an unrecognized gain on the related storage agreements.  While such price changes from one quarter to the next are not unprecedented, they are the most significant they have been since we discontinued the application of fair value accounting to natural gas held in storage and pipeline agreements on January 1, 2003 with the rescission of EITF 98-10.

 

 

 

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Adjusted gas margins represent a more economic view of the business with all elements of the business reflected at fair value.  The resulting decrease in adjusted gas margins was primarily a result of an approximate $26 million decline in physical and financial trading margins from our North American gas marketing and trading business, primarily resulting from fewer trading opportunities caused by lower volatility, lower price levels, and milder weather in the first quarter of 2004.  Natural gas prices were extremely volatile in the first quarter of 2003.

 

Other Revenues

 

Other revenues for Cinergy increased for the nine months ended September 30, 2004, as compared to 2003, primarily due to increased revenues of approximately $22 million from non-regulated energy service subsidiaries that started operations, or became fully consolidated, after the first half of 2003.  Also contributing to the increase were increased revenues of approximately $20 million from the sale of synthetic fuel as a result of an increase in demand for our synthetic fuel.

 

Operating Expenses

 

Operation and Maintenance

 

Operation and maintenance expense increased for Cinergy, CG&E, and PSI for the nine months ended September 30, 2004, as compared to 2003.  Cinergy’s, CG&E’s, and PSI’s increases include approximately $58 million, $25 million, and $33 million, respectively, of higher expenses related to emission allowances. These increases primarily reflect higher expenses due to an increase in the cost of SO2 emission allowances as market prices have increased.  Cinergy’s and PSI’s increases also resulted from timing differences in the recovery of SO2 emission allowances costs under PSI’s emission allowances tracking mechanism authorized by the IURC and an increase in the number of SO2 emission allowances used during the period.  Approximately $35 million of Cinergy’s increase is due to an increase in the production of synthetic fuel as a result of an increase in demand for our synthetic fuel.

 

The higher Operation and maintenance expense also reflects costs incurred in 2004 related to a continuous improvement initiative of approximately $18 million, $8 million, and $7 million for Cinergy, CG&E, and PSI, respectively.  Employee benefit expenses increased approximately $12 million, $5 million, and $5 million for Cinergy, CG&E, and PSI, respectively.  Approximately $18 million of Cinergy’s increase is due to non-regulated energy service subsidiaries that started operations, or became fully consolidated, after the second quarter of 2003.  In addition, higher costs of approximately $9 million, $7 million, and $2 million for Cinergy, CG&E, and PSI, respectively, were due to changes in transmission costs largely resulting from changes in the Midwest ISO operations in 2003.  Maintenance expenses, primarily production and distribution related, were higher by approximately $19 million and $17 million for Cinergy and CG&E, respectively.  Partially offsetting Cinergy’s increases were approximately $12 million of costs incurred in 2003 associated with the bankruptcy of Enron Corp.

 

Depreciation

 

Depreciation expense increased for Cinergy and PSI, and decreased for CG&E for the nine months ended September 30, 2004, as compared to 2003.  Approximately $31 million of Cinergy’s and PSI’s increase was due to the addition of depreciable plant primarily for pollution control equipment. Also contributing to Cinergy’s and PSI’s higher depreciation expense was an approximate $10 million

 

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increase due to higher depreciation rates effective June 2004 that were approved in PSI’s latest retail rate case.

 

Partially offsetting Cinergy’s increase and contributing to CG&E’s decrease was an approximate $15 million reduction due to longer estimated useful lives of CG&E’s generation assets resulting from a depreciation study completed during the third quarter of 2003.  Approximately $6 million of Cinergy’s increase and partially offsetting CG&E’s decrease was the addition of depreciable plant primarily for pollution control equipment and additions related to the accelerated gas main replacement program.

 

Miscellaneous Income (Expense) – Net

 

Miscellaneous Income (Expense) – Net decreased for Cinergy and CG&E and increased slightly for PSI for the nine months ended September 30, 2004.  Cinergy’s decrease reflects approximately $49 million in impairment and disposal charges on certain investments in Power Technology and Infrastructure.  The values of these investments reflect our estimates and judgments about the future performance of these investments, for which actual results may differ.  The majority of these charges relate to a company, in which Cinergy holds a non-controlling interest, that agreed to sell its major assets.  This company is involved in the development and sale of outage management software.  The decrease was partially offset by interest income of approximately $9 million on the notes receivable of two subsidiaries consolidated in the third quarter of 2003, as discussed in the 2003 10-K.  CG&E’s decrease and PSI’s increase was due, in part, to a final reconciliation recorded in 2003 between the two entities of a previous demutualization of a medical insurance carrier used by both companies.  Also contributing to CG&E’s decrease and partially offsetting PSI’s increase was a decline in the allowance for equity funds used during construction resulting from certain assets being placed into service and a decrease in the equity rate applied.

 

Interest Expense

 

Interest Expense increased for Cinergy and decreased for CG&E for the nine months ended September 30, 2004, as compared to 2003.  Approximately $12 million of Cinergy’s increase reflects the recognition of a note payable to a trust.  Also reflected in Cinergy’s increase is approximately $9 million related to additional debt recorded in accordance with the consolidation of two new entities.  The note payable and additional debt were both recorded in the third quarter of 2003 resulting from the adoption of FASB Interpretation No. 46, Consolidation of Variable Interest Entities (Interpretation 46), as discussed in the 2003 10-K.  Partially offsetting Cinergy’s increases and primarily contributing to CG&E’s decrease was a decline in CG&E’s average long-term debt for the nine months ended September 30, 2004, as compared to 2003.  Also partially offsetting Cinergy’s increases and contributing to CG&E’s decrease were charges recorded during 2003 associated with the re-financing of certain debt.

 

Preferred Dividend Requirement of Subsidiary Trust

 

Preferred Dividend Requirement of Subsidiary Trust decreased for Cinergy for the nine months ended September 30, 2004, as compared to 2003, as a result of the implementation of Interpretation 46.  Effective July 1, 2003, the preferred trust securities and the related dividends are no longer reported in Cinergy’s financial statements.  However, interest expense is still being incurred on a note payable to this trust as discussed above.

 

 

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MD&A – YEAR TO DATE RESULTS OF OPERATIONS - HISTORICAL

 

Income Taxes

 

The effective income tax rate decreased for Cinergy, remained flat for CG&E, and increased for PSI for the nine months ended September 30, 2004, as compared to 2003.  Cinergy’s 2004 effective income tax rate is expected to be approximately 23 percent as compared to 24 percent in 2003.  The decrease in the effective income tax rate is a result of a greater amount of estimated annual tax credits associated with the production and sale of synthetic fuel for 2004 as compared to 2003.  PSI’s effective tax rate increase reflects a revision in estimated 2004 pre-tax income and changes in permanent differences which have an incremental effect on tax expense.

 

In July 2002, Capital & Trading acquired a coal-based synthetic fuel production facility.  The synthetic fuel produced at this facility qualifies for tax credits in accordance with Section 29 of the IRC.  Eligibility for these credits expires after 2007.  Cinergy received a private letter ruling from the IRS in connection with the acquisition of the facility.  To date, Cinergy has recorded approximately $189 million in tax credits, including approximately $69 million in 2004.  See Note 6(c)(iv) of the “Notes to Condensed Financial Statements” in “Item 1. Financial Statements” for more details.

 

Discontinued Operations

 

During the second quarter of 2003, Cinergy completed the disposal of its gas distribution operation in South Africa, sold its remaining wind assets in the United States, and substantially sold or liquidated the assets of its energy trading operation in the Czech Republic.  Pursuant to Statement of Financial Accounting Standards No. 144, Accounting for the Impairment or Disposal of Long-lived Assets, these investments have been classified as discontinued operations in our financial statements.

 

Cumulative Effect of Changes in Accounting Principles, Net of Tax

 

In 2003, Cinergy, CG&E, and PSI recognized a Cumulative effect of changes in accounting principles, net of tax gain/(loss) of approximately $26 million, $31 million, and $(0.5) million, respectively.  The cumulative effect of changes in accounting principles was a result of the adoption of Statement of Financial Accounting Standards No. 143, Accounting for Asset Retirement Obligations and the rescission of EITF 98-10.

 

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MD&A – YEAR TO DATE RESULTS OF OPERATIONS - HISTORICAL

 

ULH&P

 

The Results of Operations discussion for ULH&P is presented only for the nine months ended September 30, 2004, in accordance with General Instruction H(2)(a) of Form 10-Q.

 

Electric and gas gross margins and net income for ULH&P for the nine months ended September 30, 2004 and 2003, were as follows:

 

 

 

 

 

 

 

 

 

 

 

 

 

ULH&P

 

 

 

2004

 

2003

 

Change

 

%
Change

 

 

 

(in thousands)

 

 

 

 

 

Electric gross margin(1)

 

$

51,930

 

$

49,419

 

$

2,511

 

5

 

Gas gross margin(2)

 

31,715

 

28,437

 

3,278

 

12

 

 

 

 

 

 

 

 

 

 

 

Net income

 

13,279

 

11,477

 

1,802

 

16

 

 

(1)

Electric gross margin is calculated as Electric operating revenues less Electricity purchased from parent company for resale expense from the Condensed Statements of Income.

(2)

Gas gross margin is calculated as Gas operating revenues less Gas purchased expense from the Condensed Statements of Income.

 

 

Summary of Results

 

Electric and gas gross margins increased for ULH&P for the nine months ended September 30, 2004, as compared to 2003.  The increase in electric gross margins reflects a greater amount of MWhs delivered due to growth in non-weather related demand.  The increase in gas gross margins was due, in part, to rate tariff adjustments associated with the gas main replacement program and the demand-side management program, which encourages efficient customer gas usage.

 

The increase in net income for the year was primarily due to the increased electric and gas gross margins discussed above.  Also contributing to the increase was a reduction in property taxes during the first nine months of 2004, as compared to 2003.  These increases were partially offset by higher Depreciation expense primarily related to non-utility property and higher Operation and maintenance expense associated with transmission costs, demand-side management programs, and maintenance.

 

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MD&A - RESULTS OF OPERATIONS - FUTURE

 

FUTURE EXPECTATIONS/TRENDS

 

In the “Future Expectations/Trends” section, we discuss electric and gas industry developments, market risk sensitive instruments and positions, and accounting matters.  Each of these discussions will address the current status and potential future impact on our financial position and results of operations.

 

ELECTRIC INDUSTRY

 

Ohio

 

As discussed in more detail in the 2003 10-K, CG&E made multiple rate filings in 2003 with the PUCO seeking approval of CG&E's methodology for establishing market-based rates for generation service at the end of the market development period and to recover investments made in the transmission and distribution system.  In December 2003, these filings, and CG&E’s proposal for establishing its post-market development period market pricing methodology, were consolidated for hearing before the PUCO.  In addition, the PUCO requested in these proceedings that CG&E propose a rate stabilization plan as an alternative to market-based rates so as to mitigate the potential for significant rate increases when the market development (frozen rate) period comes to an end. There is no requirement in Ohio law that CG&E file such a plan. However, in January 2004, CG&E filed its proposed rate stabilization plan.

 

In May 2004, CG&E entered into a settlement agreement with many of the parties to these proceedings requesting that the PUCO approve a modified version of the rate stabilization plan.  Under this plan, CG&E would begin to collect a non-bypassable provider of last resort (POLR) charge intended to provide recovery for increased capacity reserves, environmental compliance and emission allowance expenditures.  The plan also established a bypassable generation charge, which included a fuel cost recovery mechanism.  It allowed for a two-year extension of the residential regulatory transition charge (RTC) in 2009 and 2010 and a three-year extension of the five percent residential generation rate reduction in the years 2006-2008.  Finally, it provided for deferral and recovery of certain transmission and distribution costs.

 

In September 2004, the PUCO issued an order seeking to modify several key provisions of this settlement.  The PUCO order, among other things, would not allow extension of the RTC for residential customers or permit deferral and recovery of certain transmission and distribution costs from residential customers. The PUCO order would allow CG&E to end the five percent generation rate reduction for residential customers (i.e., increase the residential generation rate by five percent) beginning January 1, 2006, but would also allow certain customers who have switched to another generation supplier to entirely avoid the POLR charge.  As a result of these modifications, CG&E filed a petition for rehearing in October 2004.  The rehearing petition requests one of the following to be effective January 1, 2005 for non-residential customers and January 1, 2006 for residential customers:

 

      Approval of the modified rate stabilization plan reflected in the May 2004 settlement (as discussed above);

      Approval of a further modified rate stabilization plan, which includes some of the same provisions as the May 2004 plan.  However, this plan (a) changes the POLR charge to provide recovery only for environmental compliance expenditures and allows customers that have switched to by-pass this charge, (b) adds an infrastructure maintenance fund charge, (c) adds a system reliability tracker that would provide recovery primarily for capacity and purchased power, (d) includes recovery of emission allowances costs as part of the fuel cost recovery mechanism, and (e) ends the five percent generation rate reduction for residential customers but does not include an extension of the residential RTC; or,

      Approval to proceed with market-based rates, which is permitted under CG&E’s existing transition plan.

 

A rehearing order is expected in the fourth quarter of 2004.  We cannot predict the outcome of this proceeding.  Because the rate stabilization plan is a voluntary filing on CG&E's part, CG&E may reject the PUCO's order if it provides for a rate stabilization plan that is unacceptable to CG&E.

 

In conjunction with the consolidated filings discussed above, CG&E has also filed an application for an annual increase of approximately $78 million in electric distribution base rates, to be effective in the first quarter of 2005 for non-residential customers and January 1, 2006 for residential customers.  The proposed rate stabilization plans described above provide for CG&E to withdraw this base rate case upon approval of the rate stabilization plan.  In such event, CG&E can then file a new distribution base rate case, with rates to become effective January 1, 2006.  If the PUCO's order on rehearing provides for a rate stabilization plan that is unacceptable to CG&E, CG&E may seek to proceed immediately with market-based rates for its commercial, industrial and other public authority customer classes and also proceed immediately with this base rate case for such classes.  Market based rates must be approved by the PUCO and would eliminate the various deferral and recovery mechanisms contemplated with the rate stabilization plan.

 

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FERC and Midwest ISO

 

Day-Ahead and Real-Time Energy Markets

 

In response to prior FERC orders, in March 2004, the Midwest ISO filed with the FERC proposed changes to its existing transmission tariff to add terms and conditions to implement a centralized security-constrained economic dispatch platform supported by a Day-Ahead and Real-Time Energy Market design, including Locational Marginal Pricing and Financial Transmission Rights (Energy Markets Tariff).  In May 2004, the FERC released an order scheduling the start-up of the Energy Markets Tariff for no earlier than March 1, 2005, and establishing various procedures for resolving outstanding issues.  In August and September 2004, FERC issued orders that, among other things, conditionally approved the Energy Markets Tariff.  Requests for rehearing of these orders were subsequently filed.  At this time, Cinergy cannot predict the outcome of this matter or whether it will have a material effect on our financial position or results of operations.

 

Blackout Report

 

In April 2004, the United States-Canada Power System Outage Task Force issued its Final Report on the August 14, 2003 Blackout in the United States and Canada.  The report reviewed the causes of the Blackout and made 46 recommendations intended to minimize the likelihood and scope of similar events in the future.  One of the recommendations is to make reliability standards mandatory and enforceable with penalties for noncompliance.  In the past, compliance with North American Electric Reliability Council’s reliability standards and guidelines has largely been voluntary.  At this time, we do not believe the recommendations of the Final Report, if implemented, will have a material impact on our financial position or results of operations.

 

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MD&A - - RESULTS OF OPERATIONS - FUTURE

 

FERC’s Market Screen Orders

 

In April 2004, FERC issued an order establishing a new, interim set of market power screens for use in evaluating sales of wholesale power at market-based rates.  In July 2004, the FERC issued an order generally affirming that order.  In April 2004, the FERC also commenced a rulemaking to evaluate whether its overall test for market-based rates should be continued, and to determine a permanent market power test to replace the interim test.  That rulemaking process remains pending.  Under FERC’s interim generation market power analysis, as a member of Midwest ISO, Cinergy could consider the Midwest ISO geographic market for purposes of FERC’s market power analysis once Midwest ISO has a sufficient market structure and a single energy market.  Cinergy does not believe it has market power in generation.  However, if Cinergy was unable to establish that it does not have the ability to exercise market power in generation, it would result in the loss of market-based rate authority in certain regions of the wholesale market and, assuming such loss of market-based rate authority, would require Cinergy to charge certain wholesale customers cost-based rates for wholesale sales of electricity.  In October 2004, FERC issued proposed rules that may affect how and when circumstances have changed to an extent that requires FERC review of previously granted authorization to sell at existing market-based rates.  At this time, we cannot predict the outcome of these matters and whether they will have a material effect on our financial position or results of operations.

 

GAS INDUSTRY

 

Gas Prices

 

Natural gas prices remained relatively high during the first three quarters of 2004 and are expected to escalate even more in the fourth quarter. It appears likely that the price of natural gas will maintain its historic high level through most of 2005.  Price movement will be driven by the effects of weather conditions, availability of supply, and changes in demand and storage inventories.  Currently, neither CG&E nor ULH&P profit from changes in the cost of natural gas since natural gas purchase costs are passed directly to the customer dollar-for-dollar under the gas cost recovery mechanism that is mandated under state law.

 

In May 2003, ULH&P filed an application with the Kentucky Public Service Commission (KPSC) requesting approval of a price mitigation program designed to mitigate the effects of gas price volatility on customers.  In June 2003, the KPSC approved this program through March 31, 2005.  The program will allow the pre-arranging of between 20-75 percent of winter heating season base load gas requirements and up to 50 percent of summer season base load gas requirements.  CG&E similarly mitigates its gas procurement costs, however, CG&E’s gas price mitigation program has not been pre-approved by the PUCO but rather it is subject to PUCO review as part of the normal gas cost recovery process.

 

CG&E and ULH&P use primarily long-term fixed price contracts and contracts with a ceiling and floor on the price.  These contracts employ the normal purchases and sales scope exception, and do not involve hedges under Statement 133.

 

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MARKET RISK SENSITIVE INSTRUMENTS AND POSITIONS

 

The transactions associated with the Commercial Business Unit’s (Commercial) energy marketing and trading activities and substantial investment in generation assets give rise to various risks, including price risk.  Price risk represents the potential risk of loss from adverse changes in the market price of electricity or other energy commodities.  As Commercial continues to develop its energy marketing and trading business, its exposure to movements in the price of electricity and other energy commodities may become greater.  As a result, we may be subject to increased future earnings volatility.

 

As discussed in the 2003 10-K, CG&E and PSI executed a new joint operating agreement in April 2002 whereby we chose to originate all new power marketing and trading contracts since April 2002 on behalf of CG&E only.  Historically, such contracts were executed on behalf of PSI and CG&E jointly.  PSI’s remaining contracts, entered into prior to the new joint operating agreement, are not material.  Additionally, we expect that PSI will not enter into new power marketing and trading contracts in the future.  Therefore, we have not presented PSI separately in the fair value and credit risk tables below.

 

Changes in Fair Value

 

The changes in fair value of the energy risk management assets and liabilities, for the periods ended September 30, 2004 and 2003, are presented in the table below:

 

 

 

 

 

 

 

 

 

 

 

 

 

Change in Fair Value
Year to Date

 

 

 

September 30, 2004

 

September 30, 2003

 

 

 

Cinergy(1)

 

CG&E

 

Cinergy(1)

 

CG&E

 

 

 

(in millions)

 

 

 

 

 

Fair value of contracts outstanding at beginning of year

 

$

41

 

$

20

 

$

75

 

$

42

 

 

 

 

 

 

 

 

 

 

 

Changes in fair value attributable to changes in valuation techniques and assumptions (2)

 

 

 

1

 

1

 

 

 

 

 

 

 

 

 

 

 

Other changes in fair value (3)

 

129

 

60

 

120

 

40

 

 

 

 

 

 

 

 

 

 

 

Option premiums paid/(received)

 

1

 

4

 

(6

)

3

 

 

 

 

 

 

 

 

 

 

 

Accounting changes (4)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cumulative effect of changes in accounting principle

 

 

 

(20

)

(14

)

 

 

 

 

 

 

 

 

 

 

Consolidation of previously unconsolidated entities

 

 

 

7

 

 

 

 

 

 

 

 

 

 

 

 

Contracts settled

 

(93

)

(32

)

(129

)

(48

)

 

 

 

 

 

 

 

 

 

 

Fair value of contracts outstanding at end of period

 

$

78

 

$

52

 

$

48

 

$

24

 

 

(1)

The results of Cinergy also include amounts related to non-registrants.

(2)

Represents changes in fair value recognized in income, caused by changes in assumptions used in calculating fair value or changes in modeling techniques.

(3)

Represents changes in fair value, recognized in income, primarily attributable to fluctuations in price.  This amount includes both realized and unrealized gains on energy trading contracts.

(4)

See Note 1(q)(iv) and Note 1(q)(vi) of the “Notes to Financial Statements” of the 2003 10-K for further information.

 

 

 

 

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MD&A - - RESULTS OF OPERATIONS - FUTURE

 

The following are the balances at September 30, 2004 and 2003, of our energy risk management assets and liabilities:

 

 

 

 

 

 

 

 

 

 

 

 

 

September 30, 2004

 

September 30, 2003

 

 

 

Cinergy(1)

 

CG&E

 

Cinergy(1)

 

CG&E

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

Energy risk management assets – current

 

$

470

 

$

178

 

$

224

 

$

79

 

Energy risk management assets – non-current

 

137

 

48

 

127

 

62

 

 

 

 

 

 

 

 

 

 

 

Energy risk management liabilities – current

 

396

 

126

 

186

 

73

 

Energy risk management liabilities – non-current

 

133

 

48

 

117

 

44

 

 

 

 

 

 

 

 

 

 

 

 

 

$

78

 

$

52

 

$

48

 

$

24

 

 

(1)

The results of Cinergy also include amounts related to non-registrants.

 

 

 

The following table presents the expected maturity of the energy risk management assets and liabilities as of September 30, 2004, for Cinergy and CG&E:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fair Value of Contracts as of September 30, 2004

 

 

 

 

 

 

 

Maturing

 

 

 

Source of Fair Value(1)

 

Within
12 months

 

12-36
months

 

36-60
months

 

Thereafter

 

Total
Fair Value

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy(2)

 

 

 

 

 

 

 

 

 

 

 

Prices actively quoted

 

$

70

 

$

5

 

$

 

$

 

$

75

 

 

 

 

 

 

 

 

 

 

 

 

 

Prices based on models and other valuation methods(3)

 

5

 

3

 

 

(5

)

3

 

 

 

 

 

 

 

 

 

 

 

 

 

Total

 

$

75

 

$

8

 

$

 

$

(5

)

$

78

 

 

 

 

 

 

 

 

 

 

 

 

 

CG&E

 

 

 

 

 

 

 

 

 

 

 

Prices actively quoted

 

$

44

 

$

3

 

$

 

$

 

$

47

 

 

 

 

 

 

 

 

 

 

 

 

 

Prices based on models and other valuation methods(3)

 

8

 

(2

)

(1

)

 

5

 

 

 

 

 

 

 

 

 

 

 

 

 

Total

 

$

52

 

$

1

 

$

(1

)

$

 

$

52

 

 

(1)

While liquidity varies by trading regions, active quotes are generally available for two years for standard electricity transactions and three years for standard gas transactions.  Non-standard transactions are classified based on the extent, if any, of modeling used in determining fair value.  Long-term transactions can have portions in both categories depending on the tenor.

(2)

The results of Cinergy also include amounts related to non-registrants.

(3)

A substantial portion of those amounts include option values.

 

 

 

Energy Trading Credit Risk

 

Cinergy’s extension of credit for energy marketing and trading is governed by a Corporate Credit Policy.  Written guidelines approved by Cinergy’s Risk Policy Committee document the management approval levels for credit limits, evaluation of creditworthiness, and credit risk mitigation procedures.  Cinergy analyzes net credit exposure and establishes credit reserves based on the counterparties’ credit rating, payment history, and tenor of the outstanding obligation.  Exposures to credit risks are monitored daily by the Corporate Credit Risk function, which is independent of all

 

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trading operations.  Energy commodity prices can be extremely volatile and the market can, at times, lack liquidity.  Because of these issues, credit risk for energy commodities is generally greater than with other commodity trading.

 

The following tables provide information regarding Cinergy’s and CG&E’s exposure on energy trading contracts as well as the expected maturities of those exposures as of September 30, 2004.  The tables include accounts receivable and energy risk management assets, which are net of accounts payable and energy risk management liabilities with the same counterparties when we have the right of offset.  The credit collateral shown in the following tables includes cash and letters of credit.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cinergy(1)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Rating

 

Total
Exposure
Before Credit
Collateral

 

Credit
Collateral

 

Net
Exposure

 

Percentage of
Total
Net Exposure

 

Number of
Counterparties
Greater than 10%
of Total Net Exposure

 

Net Exposure of
Counterparties
Greater than 10% of
Total Net Exposure
(4)

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Investment Grade(2)

 

$

561

 

$

70

 

$

491

 

78

%

 

$

 

Internally Rated-Investment Grade(3)

 

77

 

 

77

 

12

 

 

 

Non-Investment Grade

 

94

 

54

 

40

 

6

 

 

 

Internally Rated-Non-Investment Grade

 

48

 

23

 

25

 

4

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total

 

$

780

 

$

147

 

$

633

 

100

%

 

$

 

 

 

 

Maturity of Credit Risk Exposure

 

 

 

 

 

Rating

 

Less than
2 Years

 

2-5 Years

 

Exposure
Greater than
5 Years

 

Total Exposure
Before Credit
Collateral

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

Investment Grade(2)

 

$

480

 

$

66

 

$

15

 

$

561

 

Internally Rated-Investment Grade(3)

 

72

 

5

 

 

77

 

Non-Investment Grade

 

93

 

1

 

 

94

 

Internally Rated-Non-Investment Grade

 

48

 

 

 

48

 

 

 

 

 

 

 

 

 

 

 

Total

 

$

693

 

$

72

 

$

15

 

$

780

 

 

(1)

Includes amounts related to non-registrants.

(2)

Includes counterparties rated Investment Grade or the counterparties’ obligations are guaranteed or secured by an Investment Grade entity.

(3)

Counterparties include a variety of entities, including investor-owned utilities, privately held companies, cities and municipalities.  Cinergy assigns internal credit ratings to all counterparties within our credit risk portfolio, applying fundamental analytical tools.  Included in this analysis is a review of (but not limited to) counterparty financial statements with consideration given to off-balance sheet obligations and assets, specific business environment, access to capital, and indicators from debt and equity capital markets.

(4)

Exposures, positive or negative, with counterparties that are related to one another are not aggregated when no right of offset exists and as a result, credit is extended and evaluated on a separate basis.

 

 

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MD&A - - RESULTS OF OPERATIONS - FUTURE

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

CG&E

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Rating

 

Total
Exposure
Before Credit
Collateral

 

Credit
Collateral

 

Net
Exposure

 

Percentage of
Total
Net Exposure

 

Number of
Counterparties
Greater than 10%
of Total Net Exposure

 

Net Exposure of
Counterparties
Greater than 10% of
Total Net Exposure
(3)

 

 

 

(in millions)

Investment Grade(1)

 

$

193

 

$

41

 

$

152

 

93

%

2

 

$

39

 

Internally Rated-Investment Grade(2)

 

9

 

 

9

 

5

 

 

 

Non-Investment Grade

 

24

 

21

 

3

 

2

 

 

 

Internally Rated-Non-Investment Grade

 

3

 

3

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total

 

$

229

 

$

65

 

$

164

 

100

%

2

 

$

39

 

 

 

 

Maturity of Credit Risk Exposure

 

 

 

 

 

Rating

 

Less than
2 Years

 

2-5 Years

 

Exposure
Greater than
5 Years

 

Total Exposure
Before Credit
Collateral

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

Investment Grade(1)

 

$

168

 

$

25

 

$

 

$

193

 

Internally Rated-Investment Grade(2)

 

9

 

 

 

9

 

Non-Investment Grade

 

23

 

1

 

 

24

 

Internally Rated-Non-Investment Grade

 

3

 

 

 

3

 

 

 

 

 

 

 

 

 

 

 

Total

 

$

203

 

$

26

 

$

 

$

229

 

 

(1)

Includes counterparties rated Investment Grade or the counterparties’ obligations are guaranteed or secured by an Investment Grade entity.

(2)

Counterparties include various cities and municipalities.

(3)

Exposures, positive or negative, with counterparties that are related to one another are not aggregated when no right of offset exists and as a result, credit is extended and evaluated on a separate basis.

 

 

ACCOUNTING MATTERS

 

Critical Accounting Policies

 

Preparation of financial statements and related disclosures in compliance with GAAP requires the use of assumptions and estimates.  In certain instances, the application of GAAP requires judgments regarding future events, including the likelihood of success of particular initiatives, legal and regulatory challenges, and anticipated recovery of costs.  Therefore, the possibility exists for materially different reported amounts under different conditions or assumptions.

 

Cinergy’s 2003 10-K includes a discussion of accounting policies that are significant to the presentation of Cinergy’s financial position and results of operations.  These include:

 

                  Fair Value Accounting for Energy Marketing and Trading;

                  Retail Customer Revenue Recognition;

                  Regulatory Accounting;

                  Pension and Other Postretirement Benefits;

                  Income Taxes;

                  Legal and Environmental Contingencies; and

                  Impairment of Long-lived Assets.

 

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MD&A - - RESULTS OF OPERATIONS - FUTURE

 

Accounting Changes

 

Consolidation of Variable Interest Entities (VIE)

 

In January 2003, the FASB issued Interpretation 46, which significantly changes the consolidation requirements for traditional SPEs and certain other entities subject to its scope.  This interpretation defines a VIE as (a) an entity that does not have sufficient equity to support its activities without additional financial support or (b) any entity that has equity investors that do not have voting rights, do not absorb first dollar losses, or receive returns.  These entities must be consolidated whenever Cinergy would be anticipated to absorb greater than 50 percent of the losses or receive greater than 50 percent of the returns.

 

In accordance with its two stage adoption guidance, we implemented Interpretation 46 for traditional SPEs on July 1, 2003, and for all other entities, including certain operating joint ventures, as of March 31, 2004.  The consolidation of certain operating joint ventures as of March 31, 2004, did not have a material impact on our financial position or results of operations.

 

Cinergy also holds interests in several joint ventures, primarily engaged in cogeneration and energy efficiency operations, that are considered VIEs which do not require consolidation.  Our exposure to loss from our involvement with these entities is not material.

 

OTHER

 

Sale of Investment

 

Power Technology and Infrastructure holds an investment in a company that develops, owns and operates wireless communication towers.  In July 2004, this company agreed to sell the majority of its assets.  The transaction is expected to close in the fourth quarter of 2004 and we would anticipate recording a gain of approximately $20 million relating to this sale at that time.  These earnings will be reflected in Equity in Earnings of Unconsolidated Subsidiaries in Cinergy’s Condensed Consolidated Statements of Income.

 

Synthetic Fuel

 

In July 2002, Capital & Trading acquired a coal-based synthetic fuel production facility.  The synthetic fuel produced at this facility qualifies for tax credits (through 2007) in accordance with IRC Section 29 if certain requirements are satisfied.  The three key requirements are that (a) the synthetic fuel differs significantly in chemical composition from the coal used to produce such synthetic fuel, (b) the fuel produced is sold to an unrelated entity and (c) the fuel was produced from a facility that was placed in service before July 1, 1998.

 

During the third quarter of 2004, several unrelated entities announced the IRS’s intent to challenge the placed in service dates of some of the entities’ synthetic fuel plants.  A successful IRS challenge could result in disallowance of all credits previously claimed for fuel produced by the subject plants.  Cinergy’s sale of synthetic fuel has generated approximately $189 million in tax credits through September 2004.

 

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MD&A - - RESULTS OF OPERATIONS - FUTURE

 

The IRS has not yet audited Cinergy for any tax year in which Cinergy has claimed Section 29 credits related to synthetic fuel.  However, it is reasonable to anticipate that the IRS will evaluate the placed in service date and other key requirements for claiming the credit.

 

Cinergy received a private letter ruling from the IRS in connection with the acquisition of the facility that specifically addressed the significant chemical change requirement.  Additionally, although not addressed in the letter ruling, we believe that our facility’s in service date meets the Section 29 requirements.

 

IRC Section 29 also provides for a phase out of the credit based on the price of crude oil.  The phase-out is based on a prescribed calculation and definition of crude oil prices within the IRC.  Although the price of crude oil has increased significantly in 2004, we presently do not expect any impact on our ability to utilize Section 29 credits in 2004.  Our results for the nine months ended September 30, 2004 include $69 million of tax credits.  If crude oil prices continue to increase, our ability to utilize credits beyond 2004 could be impacted.

 

Other Tax Matters

 

Certain tax matters, for which tax contingency provisions have been made, are likely to be resolved as early as the fourth quarter of 2004 or the first half of 2005.  The resolution of these issues could result in an adjustment in the tax provisions for these items.  However, we cannot determine the magnitude of the potential adjustment until resolution occurs.

 

85



 

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

 

ITEM 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

 

This information is provided in, and incorporated by reference from, the “Market Risk Sensitive Instruments and Positions” section in “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in “Part I. Financial Information”.

 

86



 

CONTROLS AND PROCEDURES

 

ITEM 4.  CONTROLS AND PROCEDURES

 

Disclosure controls and procedures are our controls and other procedures that are designed to provide reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Securities Exchange Act of 1934 (Exchange Act) is recorded, processed, summarized, and reported, within the time periods specified in the Securities and Exchange Commission’s (SEC) rules and forms.  Disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by us in the reports that we file under the Exchange Act is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate to allow timely decisions regarding required disclosure.

 

Under the supervision and with the participation of our management, including our chief executive officer and chief financial officer, we have evaluated the effectiveness of our disclosure controls and procedures as of September 30, 2004, and, based upon this evaluation, our chief executive officer and chief financial officer have concluded that these controls and procedures are effective in providing reasonable assurance that information requiring disclosure is recorded, processed, summarized, and reported within the timeframe specified by the SEC’s rules and forms.

 

Under the supervision and with the participation of our management, including our chief executive officer and chief financial officer, we have evaluated any change in our internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the fiscal quarter ended September 30, 2004 and found no change that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

 

87



 

PART II. OTHER INFORMATION

 

PART II.  OTHER INFORMATION

 

ITEM 1.  LEGAL PROCEEDINGS

 

CLEAN AIR ACT (CAA) LAWSUIT

 

In November 1999, and through subsequent amendments, the United States brought a lawsuit in the United States Federal District Court for the Southern District of Indiana (District Court) against Cinergy, The Cincinnati Gas & Electric Company (CG&E), and PSI Energy, Inc. (PSI) alleging various violations of the CAA.  Specifically, the lawsuit alleges that we violated the CAA by not obtaining Prevention of Significant Deterioration (PSD), Non-Attainment New Source Review (NSR), and Ohio and Indiana State Implementation Plan (SIP) permits for various projects at our owned and co-owned generating stations.  Additionally, the suit claims that we violated an Administrative Consent Order entered into in 1998 between the Environmental Protection Agency (EPA) and Cinergy relating to alleged violations of Ohio’s SIP provisions governing particulate matter at Unit 1 at CG&E’s W.C. Beckjord Generating Station (Beckjord Station).  The suit seeks (1) injunctive relief to require installation of pollution control technology on various generating units at CG&E’s Beckjord Station and Miami Fort Generating Station, and PSI’s Cayuga Generating Station, Gallagher Generating Station, Wabash River Generating Station, and Gibson Generating Station (Gibson Station), and (2) civil penalties in amounts of up to $27,500 per day for each violation.  In addition, three northeast states and two environmental groups have intervened in the case.  The case is currently in discovery, and the District Court has set the case for trial by jury commencing in February 2006.

 

In March 2000, the United States also filed in the District Court an amended complaint in a separate lawsuit alleging violations of the CAA relating to PSD, NSR, and Ohio SIP requirements regarding various generating stations, including a generating station operated by Columbus Southern Power Company (CSP) and jointly-owned by CSP, The Dayton Power and Light Company (DP&L), and CG&E.  The EPA is seeking injunctive relief and civil penalties of up to $27,500 per day for each violation.  This suit is being defended by CSP.  In April 2001, the District Court in that case ruled that the Government and the intervening plaintiff environmental groups cannot seek monetary damages for alleged violations that occurred prior to November 3, 1994; however, they are entitled to seek injunctive relief for such alleged violations.  Neither party appealed that decision.

 

In addition, Cinergy and CG&E have been informed by DP&L that in June 2000, the EPA issued a Notice of Violation (NOV) to DP&L for alleged violations of PSD, NSR, and Ohio SIP requirements at a generating station operated by DP&L and jointly-owned by CG&E.  The NOV indicated the EPA may (1) issue an order requiring compliance with the requirements of the Ohio SIP, or (2) bring a civil action seeking injunctive relief and civil penalties of up to $27,500 per day for each violation.  In September 2004, Marilyn Wall and the Sierra Club brought a lawsuit against Cinergy, DP&L and CSP for alleged violations of the CAA at this same generating station.

 

It is not possible to predict whether resolution of these matters would have a material effect on our financial position or results of operations. We intend to defend against the allegations, discussed above, vigorously in court.

 

88



 

PART II. OTHER INFORMATION

 

CARBON DIOXIDE (CO2) LAWSUIT

 

In July 2004, the states of Connecticut, New York, California, Iowa, New Jersey, Rhode Island, Vermont, Wisconsin, and the City of New York brought a lawsuit in the United States District Court for the Southern District of New York against Cinergy and American Electric Power Company, Inc., American Electric Power Service Corporation, The Southern Company, Tennessee Valley Authority, and Xcel Energy Inc.  That same day, a similar lawsuit was filed against the same companies by Open Space Institute, Inc., Open Space Conservancy, Inc., and The Audubon Society of New Hampshire.  These lawsuits allege that the defendants’ emissions of CO2 from the combustion of fossil fuels at electric generating facilities contribute to global warming and amount to a public nuisance.  The complaints also allege that the defendants could generate the same amount of electricity while emitting significantly less CO2.  Plaintiffs are seeking an injunction requiring each defendant to cap its CO2 emissions and then reduce them by a specified percentage each year for at least a decade.  Cinergy intends to defend this lawsuit vigorously in court and filed a motion to dismiss with the other defendants in September 2004; however, we are not able to predict whether resolution of these matters would have a material effect on our financial position or results of operations.

 

SELECTIVE CATALYTIC REDUCTION UNITS (SCR) AT GIBSON GENERATING STATION

 

In May 2004, SCRs and other pollution control equipment became operational at Units 4 and 5 of PSI’s Gibson Station in accordance with compliance deadlines under the NOX SIP Call.  In June and July 2004, Gibson Station temporarily shut down the equipment on these units due to a concern over an acid aerosol mist haze (plume) sometimes occurring in areas near the plant.  Portions of the plume from those units’ stacks appeared to break apart and descend to ground level at certain times under certain weather conditions.  As a result, and, working with the City of Mt. Carmel, Illinois, Illinois EPA, Indiana Department of Environmental Management, United States EPA, and the State of Illinois, we developed a protocol regarding the use of the SCRs while we explore alternatives to address this issue.  After the protocol was finalized, the Illinois Attorney General brought an action in Wabash County Circuit Court on August 9, 2004 against PSI seeking a preliminary injunction to enforce the protocol.  In August 2004, the court granted that preliminary injunction.  PSI appealed that decision to the Fifth District Appellate Court at Mt. Vernon, Illinois on October 6, 2004, but we cannot predict the ultimate outcome of that appeal or of the underlying action by the Illinois Attorney General.

 

We will seek recovery of any related capital as well as increased emission allowance expenditures through the regulatory process.  We do not believe costs related to resolving this matter will have a material impact on our financial position or results of operations.

 

MANUFACTURED GAS PLANT (MGP) SITES

 

Prior to the 1950s, gas was produced at MGP sites through a process that involved the heating of coal and/or oil.  The gas produced from this process was sold for residential, commercial, and industrial uses.

 

Coal tar residues, related hydrocarbons, and various metals have been found at former MGP sites in Indiana, including at least 22 sites that PSI or its predecessors previously owned and sold in a series of transactions with Northern Indiana Public Service Company (NIPSCO) and Indiana Gas Company, Inc. (IGC).

 

The 22 sites are in the process of being studied and will be remediated, if necessary.  In 1998 NIPSCO, IGC, and PSI entered into Site Participation and Cost Sharing Agreements to allocate liability and responsibilities between them.  The Indiana Department of Environmental Management oversees investigation and cleanup of all of these sites.  Thus far, PSI has primary responsibility for investigating, monitoring and, if necessary, remediating nine of these sites.  In December 2003, PSI entered into a voluntary remediation plan with the state of Indiana, providing a formal framework for the investigation and cleanup of the sites for which PSI has primary responsibility.

 

In April 1998, PSI filed suit in Hendricks County in the state of Indiana against its general liability insurance carriers.  PSI sought a declaratory judgment to obligate its insurance carriers to (1) defend MGP claims against PSI and compensate PSI for its costs of investigating, preventing, mitigating, and remediating damage to property and paying claims related to MGP sites; or (2) pay PSI’s cost of defense.  The trial court issued a variety of rulings with respect to the claims and defenses in the litigation.  PSI appealed certain adverse rulings to the Indiana Court of Appeals and the appellate court has remanded the case to the trial court.  The court has set the case for trial commencing in January 2005.  At the present time, PSI cannot predict the outcome of this litigation, including the outcome of the appeals.

 

89



 

PART II. OTHER INFORMATION

 

PSI has accrued costs related to investigation, remediation, and groundwater monitoring for those sites where such costs are probable and can be reasonably estimated.  We will continue to investigate and remediate the sites as outlined in the voluntary remediation plan.  As additional facts become known and investigation is completed, we will assess whether the likelihood of incurring additional costs becomes probable.  Until all investigation and remediation is complete, we are unable to determine the overall impact on our financial position or results of operations.

 

CG&E and ULH&P have performed site assessments on certain of their sites where we believe MGP activities have occurred at some point in the past and have found no imminent risk to the environment.  At the present time, CG&E and ULH&P cannot predict whether investigation and/or remediation will be required in the future at any of these sites.

 

ASBESTOS CLAIMS LITIGATION

 

CG&E and PSI have been named as defendants or co-defendants in lawsuits related to asbestos at their electric generating stations.  Currently, there are approximately 100 pending lawsuits.  In these lawsuits, plaintiffs claim to have been exposed to asbestos-containing products in the course of their work at the CG&E and PSI generating stations.  The plaintiffs further claim that as the property owner of the generating stations, CG&E and PSI should be held liable for their injuries and illnesses based on an alleged duty to warn and protect them from any asbestos exposure.  A majority of the lawsuits to date have been brought against PSI.  The impact on CG&E’s and PSI’s financial position or results of operations of these cases to date has not been material.

 

Of these lawsuits, one case filed against PSI has been tried to verdict.  The jury returned a verdict against PSI in the amount of approximately $500,000 on a negligence claim and a verdict for PSI on punitive damages.  PSI received an adverse ruling in its initial appeal of the negligence claim verdict, but the Indiana Supreme Court accepted the transfer of the case, and heard oral argument in June 2004.  In addition, PSI has settled a number of other lawsuits for amounts, which neither individually nor in the aggregate, are material to PSI’s financial position or results of operations.

 

At this time, CG&E and PSI are not able to predict the ultimate outcome of these lawsuits or the impact on CG&E’s and PSI’s financial position or results of operations.

 

90



 

PART II. OTHER INFORMATION

 

ITEM 2.  UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

 

The number of shares (or units) provided in the table below represent shares exchanged in connection with employee option exercises and shares purchased by the plan trustee on behalf of the 401(k) Excess Plan.

 

 

 

 

 

 

 

 

 

 

 

Period

 

(a) Total Number of
Shares (or Units)
Purchased

 

(b) Average Price
Paid per Share
(or Unit)

 

(c) Total Number of
Shares (or Units)
Purchased as Part of
Publicly Announced
Plans or Programs

 

(d) Maximum
Number (or
Approximate Dollar
Value) of Shares (or
Units) that May Yet
Be Purchased
Under the Plans or
Programs

 

 

 

 

 

 

 

 

 

 

 

July 1 – July 31

 

1,086

 

$

38.15

 

N/A

 

N/A

 

August 1 – August 31

 

136,085

 

$

39.63

 

N/A

 

N/A

 

September 1 – September 30

 

3,053

 

$

40.45

 

N/A

 

N/A

 

 

 

 

 

 

 

 

 

 

 

 

91



 

PART II. OTHER INFORMATION

 

ITEM 6.  EXHIBITS

 

The documents listed below are being furnished or filed on behalf of Cinergy Corp., The Cincinnati Gas & Electric Company (CG&E), PSI Energy, Inc. (PSI), and The Union Light, Heat and Power Company (ULH&P).  Exhibits not identified as previously furnished or filed are furnished or filed herewith:

 

Exhibit
Designation

 

Registrant

 

Nature of Exhibit

 

Previously Filed
as Exhibit to:

 

 

 

 

 

 

 

Additional Exhibits

 

 

 

 

 

 

10-rrr

 

Cinergy Corp.

 

Form of incentive stock option grant agreement.

 

 

10-sss

 

Cinergy Corp.

 

Form of non-qualified stock option grant agreement.

 

 

10-ttt

 

Cinergy Corp.

 

Form of restricted stock grant agreement.

 

 

10-uuu

 

Cinergy Corp.

 

Form of performance share grant agreement.

 

 

10-vvv

 

Cinergy Corp.

 

Form of phantom stock grant agreement.

 

 

 

 

 

 

 

 

 

Certificates

 

 

 

 

 

 

 

 

 

 

 

 

 

31-a

 

Cinergy Corp. CG&E PSI ULH&P

 

Certification by James E. Rogers pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

 

 

 

 

 

 

 

 

 

31-b

 

Cinergy Corp. CG&E PSI ULH&P

 

Certification by James L. Turner pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

 

 

 

 

 

 

 

 

 

32-a

 

Cinergy Corp. CG&E PSI ULH&P

 

Certification by James E. Rogers pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

 

 

 

 

 

 

 

 

 

32-b

 

Cinergy Corp. CG&E PSI ULH&P

 

Certification by James L. Turner pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

 

 

 

 

 

 

 

 

 

 

92



 

SIGNATURES

 

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

 

CINERGY CORP.

THE CINCINNATI GAS & ELECTRIC COMPANY

PSI ENERGY, INC.

THE UNION LIGHT, HEAT AND POWER COMPANY

Registrants

 

 

      Date: November 5, 2004

    /s/

Lynn J. Good

 

 

 

Lynn J. Good

 

 

(duly authorized officer
and
principal accounting officer)

 

 

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