UNITED STATES SECURITIES AND EXCHANGE COMMISSION

 

WASHINGTON, D.C. 20549

 

FORM 10-Q

 

(Mark One)

 

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

 

 

 

For the quarterly period ended June 30, 2006

 

 

 

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:  1-16455

 

Reliant Energy, Inc.

(Exact Name of Registrant as Specified in Its Charter)

 

Delaware

 

76-0655566

(State or Other Jurisdiction of Incorporation or
Organization)

 

(I.R.S. Employer Identification No.)

 

1000 Main Street

Houston, Texas 77002

(Address of Principal Executive Offices) (Zip Code)

 

(713) 497-3000

(Registrant’s Telephone Number, Including Area Code)

 

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

Yes  x    No  o

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer.
Large accelerated filer 
x  Accelerated filer o  Non-accelerated filer o

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes  o    No  x

 

As of July 31, 2006, the latest practicable date for determination, Reliant Energy, Inc. had 307,577,274 shares of common stock outstanding and no shares of treasury stock.

 

 



 

TABLE OF CONTENTS

 

Forward-Looking Information

 

 

 

 

 

PART I.

FINANCIAL INFORMATION

 

 

 

ITEM 1.

FINANCIAL STATEMENTS

 

 

Consolidated Statements of Operations (unaudited) Three and Six Months Ended June 30, 2006 and 2005

 

 

Consolidated Balance Sheets June 30, 2006 (unaudited) and December 31, 2005

 

 

Consolidated Statements of Cash Flows (unaudited) Six Months Ended June 30, 2006 and 2005

 

 

Notes to Unaudited Consolidated Interim Financial Statements

 

 

 

 

ITEM 2.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

 

Business Overview

 

 

Consolidated Results of Operations

 

 

Liquidity and Capital Resources

 

 

Off-Balance Sheet Arrangements

 

 

New Accounting Pronouncements, Significant Accounting Policies and Critical Accounting Estimates

 

 

 

 

ITEM 3.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT NON-TRADING AND TRADING ACTIVITIES AND RELATED MARKET RISKS

 

 

Market Risks and Risk Management

 

 

Non-Trading Market Risks

 

 

Trading Market Risks

 

 

 

 

ITEM 4.

CONTROLS AND PROCEDURES

 

 

Evaluation of Disclosure Controls and Procedures

 

 

Changes in Internal Control Over Financial Reporting

 

 

 

 

PART II.

OTHER INFORMATION

 

 

 

ITEM 1.

LEGAL PROCEEDINGS

 

 

 

 

ITEM 2.

UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

 

 

 

 

ITEM 4.

SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

 

 

 

 

ITEM 6.

EXHIBITS

 

 

i



 

FORWARD-LOOKING INFORMATION

 

Projections, estimates or assumptions about revenues, costs, income, cash flow and other future events are called “forward-looking statements.”  These forward-looking statements are within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Act of 1934. In some cases, you can identify forward-looking statements by words like “anticipate,” “estimate,” “believe,” “intend,” “may,” “expect” or similar words. Forward-looking statements are not guarantees of future performance. Actual results may differ from forward-looking statements. Each forward-looking statement speaks only as of its date and we are under no obligation to update these statements. For information about factors that could cause our actual results to differ from forward-looking statements, see “Risk Factors” in Item 1A of Reliant Energy, Inc.’s Annual Report on Form 10-K for the year ended December 31, 2005 (Form 10-K) and “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Recent Events” in Item 2 of this Quarterly Report on Form 10-Q.

 

ii



 

PART I.

FINANCIAL INFORMATION

 

ITEM 1.                 FINANCIAL STATEMENTS

 

RELIANT ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(Thousands of Dollars, Except Per Share Amounts)

(Unaudited)

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

Revenues:

 

 

 

 

 

 

 

 

 

Revenues (including $52,393, $45,072, $201,899 and $(100,341) unrealized gains (losses))

 

$

2,774,903

 

$

2,431,392

 

$

5,227,588

 

$

4,148,709

 

Expenses:

 

 

 

 

 

 

 

 

 

Purchased power, fuel and cost of gas sold (including $(364), $93,100, $(126,402) and $362,667 unrealized gains (losses))

 

2,233,908

 

1,838,353

 

4,483,957

 

3,180,438

 

Operation and maintenance

 

229,975

 

207,165

 

415,530

 

377,713

 

Selling, general and administrative

 

91,690

 

83,637

 

162,430

 

142,896

 

Gains on sales of assets and emission allowances, net

 

(4,854

)

(24,672

)

(156,330

)

(23,919

)

Depreciation and amortization

 

91,092

 

103,920

 

171,597

 

212,372

 

Total operating expense

 

2,641,811

 

2,208,403

 

5,077,184

 

3,889,500

 

Operating Income

 

133,092

 

222,989

 

150,404

 

259,209

 

Other Income (Expense):

 

 

 

 

 

 

 

 

 

Income (loss) of equity investments, net

 

2,061

 

(3,676

)

2,387

 

(3,844

)

Other, net

 

744

 

(22,821

)

829

 

(22,879

)

Interest expense

 

(103,444

)

(98,560

)

(211,606

)

(193,906

)

Interest income

 

6,877

 

6,841

 

15,895

 

12,053

 

Total other expense

 

(93,762

)

(118,216

)

(192,495

)

(208,576

)

Income (Loss) from Continuing Operations Before Income Taxes

 

39,330

 

104,773

 

(42,091

)

50,633

 

Income tax expense

 

16,603

 

54,681

 

74,249

 

41,998

 

Income (Loss) from Continuing Operations

 

22,727

 

50,092

 

(116,340

)

8,635

 

Income (loss) from discontinued operations

 

(8,551

)

48,632

 

(3,571

)

65,167

 

Income (Loss) Before Cumulative Effect of Accounting Change

 

14,176

 

98,724

 

(119,911

)

73,802

 

Cumulative effect of accounting change, net of tax

 

 

 

968

 

 

Net Income (Loss)

 

$

14,176

 

$

98,724

 

$

(118,943

)

$

73,802

 

 

 

 

 

 

 

 

 

 

 

Basic Earnings (Loss) per Share:

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations

 

$

0.07

 

$

0.17

 

$

(0.38

)

$

0.03

 

Income (loss) from discontinued operations

 

(0.02

)

0.16

 

(0.01

)

0.22

 

Income (loss) before cumulative effect of accounting change

 

0.05

 

0.33

 

(0.39

)

0.25

 

Cumulative effect of accounting change, net of tax

 

 

 

 

 

Net income (loss)

 

$

0.05

 

$

0.33

 

$

(0.39

)

$

0.25

 

 

 

 

 

 

 

 

 

 

 

Diluted Earnings (Loss) per Share:

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations

 

$

0.07

 

$

0.16

 

$

(0.38

)

$

0.03

 

Income (loss) from discontinued operations

 

(0.02

)

0.14

 

(0.01

)

0.21

 

Income (loss) before cumulative effect of accounting change

 

0.05

 

0.30

 

(0.39

)

0.24

 

Cumulative effect of accounting change, net of tax

 

 

 

 

 

Net income (loss)

 

$

0.05

 

$

0.30

 

$

(0.39

)

$

0.24

 

 

See Notes to our Unaudited Consolidated Interim Financial Statements

 

1



 

RELIANT ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Thousands of Dollars, Except Share and Per Share Amounts)

 

 

 

June 30, 2006

 

December 31, 2005

 

 

 

(Unaudited)

 

 

 

ASSETS

 

 

 

 

 

Current Assets:

 

 

 

 

 

Cash and cash equivalents

 

$

69,819

 

$

88,397

 

Restricted cash

 

9,873

 

26,906

 

Accounts and notes receivable, principally customer, net of allowance of $33,993 and $34,054

 

1,328,865

 

1,171,673

 

Inventory

 

290,760

 

299,099

 

Derivative assets

 

322,077

 

725,964

 

Margin deposits

 

1,403,865

 

1,716,035

 

Accumulated deferred income taxes

 

254,879

 

361,547

 

Prepayments and other current assets

 

135,836

 

137,498

 

Current assets of discontinued operations

 

10,804

 

203,332

 

Total current assets

 

3,826,778

 

4,730,451

 

Property, plant and equipment, gross

 

7,149,202

 

7,112,684

 

Accumulated depreciation

 

(1,318,389

)

(1,178,624

)

Property, Plant and Equipment, net

 

5,830,813

 

5,934,060

 

Other Assets:

 

 

 

 

 

Goodwill

 

386,594

 

386,594

 

Other intangibles, net

 

460,770

 

510,582

 

Derivative assets

 

447,868

 

527,799

 

Prepaid lease

 

253,401

 

259,412

 

Other

 

328,327

 

339,112

 

Long-term assets of discontinued operations

 

 

880,796

 

Total other assets

 

1,876,960

 

2,904,295

 

Total Assets

 

$

11,534,551

 

$

13,568,806

 

 

 

 

 

 

 

LIABILITIES AND EQUITY

 

 

 

 

 

Current Liabilities:

 

 

 

 

 

Current portion of long-term debt and short-term borrowings

 

$

494,390

 

$

789,325

 

Accounts payable, principally trade

 

769,078

 

886,965

 

Derivative liabilities

 

819,086

 

1,219,954

 

Margin deposits

 

15,000

 

15,588

 

Other

 

446,038

 

397,942

 

Current liabilities of discontinued operations

 

35,270

 

96,456

 

Total current liabilities

 

2,578,862

 

3,406,230

 

Other Liabilities:

 

 

 

 

 

Derivative liabilities

 

613,022

 

812,695

 

Other

 

366,430

 

389,083

 

Long-term liabilities of discontinued operations

 

 

779,678

 

Total other liabilities

 

979,452

 

1,981,456

 

Long-term Debt

 

4,226,437

 

4,317,427

 

Commitments and Contingencies

 

 

 

 

 

Temporary Equity Stock-based Compensation

 

2,211

 

 

Stockholders’ Equity:

 

 

 

 

 

Preferred stock; par value $0.001 per share (125,000,000 shares authorized; none outstanding)

 

 

 

Common stock; par value $0.001 per share (2,000,000,000 shares authorized; 306,985,912 and 304,900,193 issued)

 

68

 

66

 

Additional paid-in capital

 

5,888,855

 

5,846,747

 

Retained deficit

 

(1,817,447

)

(1,698,504

)

Accumulated other comprehensive loss

 

(323,887

)

(284,281

)

Accumulated other comprehensive loss of discontinued operations

 

 

(335

)

Total stockholders’ equity

 

3,747,589

 

3,863,693

 

Total Liabilities and Equity

 

$

11,534,551

 

$

13,568,806

 

 

See Notes to our Unaudited Consolidated Interim Financial Statements

 

2



 

RELIANT ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of Dollars)

(Unaudited)

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

 

 

 

 

Cash Flows from Operating Activities:

 

 

 

 

 

Net income (loss)

 

$

(118,943

)

$

73,802

 

(Income) loss from discontinued operations

 

3,571

 

(65,167

)

Net income (loss) from continuing operations and cumulative effect of accounting change

 

(115,372

)

8,635

 

Adjustments to reconcile net income (loss) to net cash used in operating activities:

 

 

 

 

 

Cumulative effect of accounting change

 

(968

)

 

Depreciation and amortization

 

171,597

 

212,372

 

Deferred income taxes

 

68,644

 

37,329

 

Net unrealized gains on energy derivatives

 

(75,497

)

(262,326

)

Amortization of deferred financing costs

 

7,982

 

7,406

 

Gains on sales of assets and emission allowances, net

 

(156,330

)

(23,919

)

Other, net

 

36,766

 

46,752

 

Changes in other assets and liabilities:

 

 

 

 

 

Accounts and notes receivable, net

 

(135,413

)

(90,381

)

Inventory

 

6,269

 

(21,121

)

Margin deposits, net

 

311,582

 

(205,676

)

Net derivative assets and liabilities

 

(137,484

)

61,536

 

Western states and Cornerstone settlement payments

 

(159,319

)

 

Accounts payable

 

35,514

 

186,080

 

Other current assets

 

8,304

 

26,311

 

Other assets

 

14,663

 

(21,706

)

Taxes payable/receivable

 

(29,884

)

(14,045

)

Other current liabilities

 

31,285

 

(14,936

)

Other liabilities

 

2,845

 

11,766

 

Net cash used in continuing operations from operating activities

 

(114,816

)

(55,923

)

Net cash provided by (used in) discontinued operations from operating activities

 

(36,997

)

27,995

 

Net cash used in operating activities

 

(151,813

)

(27,928

)

Cash Flows from Investing Activities:

 

 

 

 

 

Capital expenditures

 

(41,919

)

(33,065

)

Proceeds from sales of assets, net

 

1,382

 

44,932

 

Proceeds from sales of emission allowances

 

197,201

 

70,447

 

Purchases of emission allowances

 

(3,273

)

(89,147

)

Restricted cash

 

17,033

 

29,974

 

Other, net

 

4,750

 

2,500

 

Net cash provided by continuing operations from investing activities

 

175,174

 

25,641

 

Net cash provided by discontinued operations from investing activities

 

967,568

 

20,541

 

Net cash provided by investing activities

 

1,142,742

 

46,182

 

Cash Flows from Financing Activities:

 

 

 

 

 

Payments of long-term debt

 

(326,201

)

(36,396

)

Increase (decrease) in short-term borrowings and revolving credit facilities, net

 

(55,337

)

24,019

 

Proceeds from issuances of stock

 

10,031

 

14,441

 

Net cash provided by (used in) continuing operations from financing activities

 

(371,507

)

2,064

 

Net cash used in discontinued operations from financing activities

 

(638,000

)

 

Net cash provided by (used in) financing activities

 

(1,009,507

)

2,064

 

Net Change in Cash and Cash Equivalents

 

(18,578

)

20,318

 

Cash and Cash Equivalents at Beginning of Period

 

88,397

 

105,054

 

Cash and Cash Equivalents at End of Period

 

$

69,819

 

$

125,372

 

Supplemental Disclosure of Cash Flow Information:

 

 

 

 

 

Cash Payments:

 

 

 

 

 

Interest paid (net of amounts capitalized) for continuing operations

 

$

189,243

 

$

172,296

 

Income taxes paid (net of income tax refunds received) for continuing operations

 

$

34,937

 

$

18,125

 

 

See Notes to our Unaudited Consolidated Interim Financial Statements

 

3



 

RELIANT ENERGY, INC. AND SUBSIDIARIES

 

NOTES TO UNAUDITED CONSOLIDATED INTERIM FINANCIAL STATEMENTS

 

(1)         Background and Basis of Presentation

 

(a)         Background.

 

“Reliant Energy” refers to Reliant Energy, Inc. and “we,” “us” and “our” refer to Reliant Energy, Inc. and its consolidated subsidiaries. Our business consists primarily of two business segments, retail energy and wholesale energy. See note 12. Our consolidated interim financial statements and notes (interim financial statements) are unaudited, omit certain disclosures and should be read in conjunction with our audited consolidated financial statements and notes in our Form 10-K.

 

(b)         Basis of Presentation.

 

Estimates. Management makes estimates and assumptions to prepare financial statements in conformity with accounting principles generally accepted in the United States of America (GAAP) that affect:

 

                  the reported amount of assets, liabilities and equity,

 

                  the reported amounts of revenues and expenses and

 

                  our disclosure of contingent assets and liabilities at the date of the financial statements.

 

Adjustments and Reclassifications. The interim financial statements reflect all normal recurring adjustments necessary, in management’s opinion, to present fairly our financial position and results of operations for the reported periods. Amounts reported for interim periods, however, may not be indicative of a full year period due to seasonal fluctuations in demand for electricity and energy services, changes in commodity prices, changes in our “price-to-beat” rate and other regulations, timing of maintenance and other expenditures, dispositions, changes in interest expense and other factors. We have reclassified certain immaterial amounts reported in this Form 10-Q from prior periods to conform to the 2006 presentation. These reclassifications had no impact on reported earnings/losses. We reclassified net purchases of emission allowances of $19 million for the six months ended June 30, 2005 from operating to investing cash flows.

 

Changes in Estimates for Retail Energy Sales and Costs. The revenues and the related energy supply costs in our retail energy segment include our estimates of customer usage after consideration of initial usage information provided by the independent system operators and the distribution companies. We revise these estimates and record any changes in the period as information becomes available (collectively referred to as “market usage adjustments”). During the three months ended June 30, 2006 and 2005, we recognized in gross margin (revenues less purchased power, fuel and cost of gas sold) $13 million of loss and $0, respectively, and during the six months ended June 30, 2006 and 2005, we recognized in gross margin $1 million of loss and $12 million of loss, respectively, related to market usage adjustments.

 

Change in Estimate for Derivatives. See note 5 regarding a change in accounting estimate relating to our derivatives.

 

(2)         Stock-based Compensation

 

Overview of Plans. The Compensation Committee of the Board of Directors administers our stock-based incentive plans. The Reliant Energy, Inc. 2002 Long-Term Incentive Plan and the Reliant Energy, Inc. 2002 Stock Plan permit us to grant various stock-based incentive awards to officers, key employees and directors. Awards include stock options, restricted stock, performance awards, cash awards and stock awards.

 

As of June 30, 2006, 36 million shares are authorized for issuance under our stock-based incentive plans, with no more than 25% of these shares available for grant as awards of restricted stock and non-restricted grants of common stock or units denominated in common stock. We generally issue new shares when stock options are exercised and for the issuance of our other equity-based awards.

 

4



 

Summary. Prior to January 1, 2006, we applied the intrinsic value method of accounting for employee stock-based incentive plans (APB No. 25). Effective January 1, 2006, we adopted Statement of Financial Accounting Standards No. 123R, “Share-Based Payment” (SFAS No. 123R) (using the modified prospective method), which requires compensation costs related to share-based transactions to be recognized in the financial statements based on estimated fair values at the grant dates. Our financial statements as of and for the six months ended June 30, 2006 reflect the impact of SFAS No. 123R; however, our financial statements for prior periods have not been restated to reflect, and do not include, the impact of the new standard. Our compensation expense for our stock-based incentive plans was:

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

(in millions)

 

 

 

 

 

 

 

Stock-based incentive plans compensation expense (pre-tax)

 

$

17

 

$

9

 

Income tax impact

 

(6

)

(4

)

After-tax expense

 

$

11

 

$

5

 

 

We did not capitalize any stock-based compensation costs as an asset during the six months ended June 30, 2006 and 2005.

 

We recorded a cumulative effect of an accounting change of $2 million ($1 million, net of tax of $1 million) during the three months ended March 31, 2006 related to the adoption of SFAS No. 123R for the estimated future forfeitures on the compensation expense previously recognized in our consolidated financial statements for the unvested awards outstanding as of January 1, 2006.

 

By the end of 2006, we will assess the income tax impacts and adopt one of the methods allowed under the transition provisions of SFAS No. 123R to account for excess tax benefits, if any, available to absorb tax deficiencies recognized subsequent to the adoption. During the six months ended June 30, 2006, the accounting change did not impact cash flows from operating and financing activities due to our tax net operating loss carryforwards.

 

5



 

Valuation Data. Below is the description of the methods used during the indicated periods to estimate the fair value of our various awards.

 

 

 

Prior to January 1, 2006
(APB No. 25)

 

After January 1, 2006
(SFAS No. 123R)

 

Award:

 

 

 

 

 

 

 

 

 

 

 

Time-based stock options(1)

 

Intrinsic value on the grant date

 

Black-Scholes option-pricing model value on the grant date

 

Time-based restricted stock

 

Market price of our common stock on the grant date

 

No change

 

Time-based cash(2)

 

Market price of our common stock on each reporting measurement date

 

No change

 

Key employee award program:

 

 

 

 

 

Performance-based stock(3)

 

Market price of our common stock on each reporting measurement date

 

Market price of our common stock on each reporting measurement date until accounting grant date

 

Performance-based options(3)

 

Intrinsic value of option on each reporting measurement date

 

Black-Scholes option-pricing model value on each reporting measurement date until accounting grant date

 

Performance-based cash(2)(3)

 

Market price of our common stock on each reporting measurement date

 

No change

 

Employee stock purchase plan

 

No compensation expense recorded

 

Black-Scholes option-pricing model value on the first day of the offering period

 

 


(1)              No awards were granted during the six months ended June 30, 2006.

(2)              These are liability-classified awards under SFAS No. 123R.

(3)              No awards were granted during the six months ended June 30, 2006 and 2005.

 

Time-Based Stock Options. We grant time-based stock options to officers, key employees and directors at an exercise price equal to the market value of our common stock on the grant date. Generally, options vest 33.33% per year and have a term of 10 years. Beginning January 1, 2006, compensation expense is measured at fair value on the grant date, net of estimated forfeitures, and amortized to expense on a straight-line basis over the requisite service period for the entire award.

 

Summarized time-based option activity is:

 

 

 

Six Months Ended June 30, 2006

 

 

 

Options

 

Weighted
Average
Exercise
Price

 

 

 

 

 

 

 

Beginning of period

 

11,646,667

 

$

15.21

 

Granted

 

 

 

 

Exercised

 

(830,135

)(1)

7.25

 

Forfeited

 

(20,638

)

3.51

 

Expired

 

(1,173,081

)

28.77

 

End of period

 

9,622,813

 

14.27

 

Weighted average grant date fair value

 

N/A

 

 

 

 


(1)              Received proceeds of $6 million. Intrinsic value was $3 million on the exercise date. No tax benefits are expected to be realized in 2006 due to our tax net operating loss carryforwards.

 

During the six months ended June 30, 2005, we granted 30,000 time-based options with a weighted average exercise price of $12.47. During the six months ended June 30, 2005, we received proceeds for the exercise of time-

 

6



 

based options of $11 million for which the intrinsic value was $7 million. No tax benefits were realized during 2005 due to our tax net operating loss carryforwards.

 

For time-based options outstanding as of June 30, 2006:

 

 

 

Options

 

Weighted
Average
Exercise
Price

 

Weighted
Average Remaining
Contractual
Term (Years)

 

Aggregate Intrinsic
Value

 

 

 

 

 

 

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

Outstanding

 

9,622,813

(1)(2)

$

14.27

 

4.3

 

$

29

 

Exercisable

 

9,380,098

 

14.50

 

4.2

 

27

 

 


(1)              We estimate that none of these will be forfeited.

(2)              As of June 30, 2006, the total compensation cost related to nonvested time-based stock options not yet recognized and the weighted-average period over which it is expected to be recognized is $0.3 million and 0.3 years, respectively.

 

Time-Based Restricted Stock Awards. We grant time-based restricted stock awards to officers, key employees and directors. In general, these awards vest, subject to the participant’s continued employment, three years from the grant date. Beginning January 1, 2006, compensation expense is measured at fair value on the grant date, net of estimated forfeitures, and amortized to expense on a straight-line basis over the requisite service period.

 

Summarized restricted stock award activity is:

 

 

 

Six Months Ended June 30, 2006

 

 

 

Shares

 

Weighted
Average Grant
Date Fair Value

 

 

 

 

 

 

 

Beginning of period

 

1,855,583

 

$

6.96

 

Granted

 

313,674

 

11.51

 

Vested

 

(794,792

)(1)

4.78

 

Forfeited

 

(71,010

)

8.46

 

End of period

 

1,303,455

(2)

9.31

 

 


(1)              Based on the market price of our common stock on the vesting date, $8 million in fair value vested.

(2)              We estimate that 188,938 of these will be forfeited.

 

During the six months ended June 30, 2005, $6 million in fair value of our time-based restricted stock vested based on the market price of our common stock on the vesting date. During the six months ended June 30, 2005, the weighted average grant date fair value of time-based restricted stock activity was $12.49. As of June 30, 2006, the total compensation cost related to nonvested time-based restricted stock awards not yet recognized and the weighted-average period over which it is expected to be recognized is $5 million and 1.5 years, respectively.

 

Time-Based Cash Awards. We grant time-based cash awards (cash units with each cash unit having an equivalent fair market value of one share of our common stock on the vesting date) to officers and key employees. In general, these awards vest, subject to the participant’s continued employment, three years from the grant date. Compensation expense is measured at fair value on each financial reporting measurement date, net of estimated forfeitures, and amortized to expense on a straight-line basis over the requisite service period. We have a liability recorded of $4 million for these time-based cash awards as of June 30, 2006.

 

During the six months ended June 30, 2006 and 2005, no time-based cash awards vested and we did not pay cash for any stock-based liabilities. As of June 30, 2006, the total compensation cost related to nonvested time-based cash awards not yet recognized and the weighted-average period over which it is expected to be recognized is $5 million and 1.7 years, respectively.

 

Performance-Based Awards. We grant performance-based awards to officers and key employees. The number of performance-based awards earned is determined at the end of each performance period. All of the outstanding performance-based awards as of June 30, 2006 are for the 2004-2006 performance period, which is the requisite service period. Beginning January 1, 2006, compensation expense is measured at fair value, net of estimated forfeitures, at each reporting measurement date preceding the grant date for accounting purposes. We have broadly

 

7



 

interpreted the criteria for determining if the service inception date precedes the grant date for our performance-based awards under SFAS No. 123R. For our performance-based cash unit awards, we have a liability recorded of $12 million as of June 30, 2006.

 

The Compensation Committee granted the 2004-2006 performance-based awards through the Key Employee Award Program (the Key Employee Program) established under the Reliant Energy, Inc. 2002 Long-Term Incentive Plan. Under the Key Employee Program, each performance-based award represents a targeted award of (a) 16,000 shares of performance-based stock, (b) 68,000 performance-based stock options and (c) 16,000 cash units with each cash unit having an equivalent fair market value of one share of our common stock on the vesting date. The Key Employee Program provides for a payout ranging from 0% to 140% of the targeted award level, as determined by the Compensation Committee in its sole discretion after considering various qualitative and quantitative performance criteria. These criteria include (a) reducing the ratio of our adjusted net debt to adjusted EBITDA to at least 3.5, (b) delivering superior customer value and (c) building a great company to work for, taking into consideration market conditions for each factor. The Compensation Committee has the discretion to weight the various performance objectives as it deems appropriate.

 

Summarized performance-based stock award activity of the Key Employee Program assuming a maximum payout (140%) is:

 

 

 

Six Months Ended June 30, 2006

 

 

 

Shares

 

Reporting
Measurement
Date Fair Value

 

 

 

 

 

 

 

Beginning of period

 

1,825,600

 

 

 

Granted

 

 

 

 

Vested

 

 

 

 

Forfeited

 

(67,200

)

 

 

End of period

 

1,758,400

(1)

$

11.98

 

 


(1)              We estimate no awards will be forfeited prior to vesting.

 

Summarized performance-based option activity of the Key Employee Program assuming a maximum payout (140%) is:

 

 

 

Six Months Ended June 30, 2006

 

 

 

Options

 

Weighted
Average
Exercise
Price

 

Weighted Average
Remaining
Contractual Term
(Years)

 

 

 

 

 

 

 

 

 

Beginning of period

 

7,758,800

 

$

8.35

 

 

 

Granted

 

 

 

 

 

Exercised

 

 

 

 

 

Forfeited

 

(285,600

)

8.14

 

 

 

Expired

 

 

 

 

 

End of period

 

7,473,200

(1)(2)

8.36

 

7.7

 

Exercisable at end of period

 

 

 

 

 


(1)              We estimate no awards will be forfeited prior to vesting.

(2)              The aggregate intrinsic value is $27 million.

 

During the six months ended June 30, 2005, no performance-based stock awards or options were granted or exercised.

 

8



 

Our option awards under the Key Employee Program are based on the following weighted average assumptions and resulting fair values:

 

 

 

Six Months Ended June 30, 2006

 

 

 

 

 

Expected term in years(1)

 

3.5

 

Estimated volatility(2)

 

48.60

%

Risk-free interest rate

 

5.25

%

Dividend yield

 

0

%

Weighted-average fair value

 

$

6.36

 

 


(1)              The expected term is based on a projection of exercise behavior considering the contractual terms and the participants of the option awards.

(2)              We estimated volatility based on historical and implied volatility of our common stock.

 

During the six months ended June 30, 2006 and 2005, no performance-based awards vested. As of June 30, 2006, the total compensation cost related to nonvested performance based awards not yet recognized and the weighted-average period over which it is expected to be recognized is $11 million and 0.5 years, respectively.

 

Employee Stock Purchase Plan. We have 18 million shares of authorized common stock reserved and approved for issuance under the Reliant Energy, Inc. Employee Stock Purchase Plan (ESPP). Under the ESPP, substantially all employees can purchase our common stock through payroll deductions of up to 15% of eligible compensation during semiannual offering periods commencing on January 1 and July 1 of each year. The share price paid by participants equals 85% of the lesser of the average market price on the first or last business day of each offering period.

 

Our employee stock purchase plan awards are based on the following weighted average assumptions and resulting fair values:

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005(1)

 

 

 

 

 

 

 

Expected term in years

 

0.5

 

0.5

 

Estimated volatility(2)

 

52.88

%

34.87

%

Risk-free interest rate

 

4.40

%

2.63

%

Dividend yield

 

0

%

0

%

Weighted-average fair value

 

$

3.16

 

$

3.42

 

 


(1)              Because we applied APB No. 25 during 2005, this was only used for pro-forma data.

(2)              We estimated volatility based on the historical volatility of our common stock.

 

During the six months ended June 30, 2006 and 2005, we issued 359,966 shares and 371,606 shares, respectively, under the ESPP and received $3 million and $3 million, respectively, from the sale of shares to employees. Approximately 11.1 million reserved unissued shares were available under the ESPP as of June 30, 2006.

 

9



 

Pro-forma Data for 2005. If employee stock-based compensation costs had been expensed based on the fair value (determined using the Black-Scholes model and market price of our common stock) method of accounting applied to all stock-based awards, our pro forma results would be:

 

 

 

Three Months Ended
June 30,

 

Six Months Ended
June 30,

 

 

 

2005

 

2005

 

 

 

(in millions, except per-share amounts)

 

 

 

 

 

 

 

Net income, as reported

 

$

99

 

$

74

 

Add: Stock-based employee compensation expense included in reported net income, net of related tax effects

 

6

 

5

 

Deduct: Total stock-based employee compensation expense determined under fair value based method for all awards, net of related tax effects

 

(5

)

(10

)

Pro forma net income

 

$

100

 

$

69

 

 

 

 

 

 

 

Earnings per share:

 

 

 

 

 

Basic, as reported

 

$

0.33

 

$

0.25

 

Basic, pro forma

 

$

0.33

 

$

0.23

 

Diluted, as reported

 

$

0.30

 

$

0.24

 

Diluted, pro forma

 

$

0.30

 

$

0.22

 

 

Classification. Through December 31, 2005, our accruals for our stock-based incentive awards were recorded as liabilities. Beginning January 1, 2006, for equity awards, we reclassified our accrual of $23 million to equity, of which $5 million was classified as temporary equity stock-based compensation based on the redemption amount of the award as of the grant date, and the remainder was classified as additional paid-in capital in stockholders’ equity. Some of our equity stock-based awards provide for the settlement of the award in cash by us pursuant to change of control provisions and we do not believe it is probable these awards will become redeemable.

 

Other. We did not use cash to settle equity instruments granted under stock-based compensation plans during the six months ended June 30, 2006 and 2005. During the six months ended June 30, 2006 and 2005, there were no significant modifications to our outstanding stock-based awards.

 

(3)         Comprehensive Income (Loss)

 

The components of total comprehensive income (loss) are:

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions)

 

(in millions)

 

Net income (loss)

 

$

14

 

$

99

 

$

(119

)

$

74

 

Other comprehensive income (loss), net of tax:

 

 

 

 

 

 

 

 

 

Deferred loss from cash flow hedges

 

(15

)

(34

)

(111

)

(114

)

Reclassification of net deferred (gain) loss from cash flow hedges realized in net income/loss

 

29

 

(22

)

71

 

(31

)

Comprehensive income (loss)

 

$

28

 

$

43

 

$

(159

)

$

(71

)

 

(4)         Goodwill

 

2006 Annual Goodwill Impairment Tests. We completed our annual goodwill impairment tests for our wholesale energy and retail energy reporting units effective April 1, 2006. No impairments occurred.

 

Estimation of Our Wholesale Energy Reporting Unit’s Fair Value. We updated a number of subjective factors and significant assumptions to estimate fair value in our April 2006 test compared to our September 2005 test, including (a) appropriate weighting of valuation approaches (income approach, market approach and comparable public company approach), (b) projections about future power generation margins, (c) estimates of our future cost

 

10



 

structure, (d) required level of working capital and (e) assumed EBITDA multiple for terminal values, which changed from 8.0 to 7.5 primarily due to market factors affecting public company comparisons. See note 4(a) to our consolidated financial statements in our Form 10-K.

 

(5)         Derivative Instruments

 

For discussion of our derivative activities, see notes 2(d) and 5 to our consolidated financial statements in our Form 10-K. The income (loss) of our energy and interest rate derivative instruments is:

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions)

 

Energy derivatives:

 

 

 

 

 

 

 

 

 

Hedge ineffectiveness

 

$

(21

)

$

(8

)

$

(70

)

$

(1

)

Other net unrealized gains

 

73

 

146

 

145

 

263

 

Interest rate derivatives:

 

 

 

 

 

 

 

 

 

Hedge ineffectiveness

 

 

 

 

 

Other net unrealized losses

 

(2

)

(4

)

(5

)

(8

)

Total(1)(2)

 

$

50

 

$

134

 

$

70

 

$

254

 

 


(1)              No component of the derivatives’ gain or loss was excluded from the assessment of effectiveness.

(2)              During the three months ended June 30, 2006 and 2005, $0 and during the six months ended June 30, 2006 and 2005, $3 million and $0, respectively, were recognized in our results of continuing operations as a result of the discontinuance of cash flow hedges because it was probable that the forecasted transaction would not occur.

 

During the three months ended June 30, 2006, we refined our methodology for estimating fair value of derivative instruments cleared and settled through brokers by modifying our discounting assumptions to be consistent with discounting assumptions used in estimating fair value of exchange-traded futures contracts. This change in accounting estimate had an impact during the three and six months ended June 30, 2006 as follows (income (loss)):

 

 

 

Three and Six Months Ended
June 30, 2006

 

 

 

Income/Loss from Continuing
Operations before
Income Taxes

 

Net Income/Loss

 

 

 

(in millions)

 

 

 

 

 

 

 

Cash flow hedges(1)

 

$

 

$

 

Mark-to-market derivatives

 

(32

)(2)

(20

)

Total

 

$

(32

)

$

(20

)(3)

 


(1)              The impact relating to cash flow hedges was an increase in our net derivative liabilities of $9 million and a $5 million increase in accumulated other comprehensive loss, net of income taxes.

(2)              This amount represented an increase in our net derivative liabilities and an increase in net unrealized losses on energy derivatives, which were recorded $(1) million in revenues and $(31) million in purchased power, fuel and cost of gas sold.

(3)              This represents a $(0.06) impact on diluted earnings/loss per share for the three and six months ended June 30, 2006.

 

Our derivative portfolio, excluding cash flow hedges, is $168 million (net liability) and $308 million (net liability) as of June 30, 2006 and December 31, 2005, respectively. Our cash flow hedges are valued at $494 million (net liability) and $471 million (net liability) as of June 30, 2006 and December 31, 2005, respectively.

 

As of June 30, 2006 and December 31, 2005, the maximum length of time we were hedging our exposure to the variability in future cash flows that may result from changes in commodity prices was seven years. As of June 30, 2006 and December 31, 2005, accumulated other comprehensive loss from derivatives was $324 million and $284 million, respectively. As of June 30, 2006, we expect $190 million of accumulated other comprehensive loss to be reclassified into our results of operations during the period from July 1, 2006 to June 30, 2007. However, the actual amount reclassified into earnings will vary from the amounts recorded as of June 30, 2006, due to future changes in market prices.

 

11



 

Although we discontinued our proprietary energy trading business in March 2003, we have legacy positions, which will be closed as economically feasible or in accordance with their terms. The margins associated with these transactions are (income (loss)):

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

 

$

(1

)

$

 

$

(1

)

Purchased power, fuel and cost of gas sold

 

 

1

 

10

 

(15

)

Gross margin

 

$

 

$

 

$

10

 

$

(16

)

 

(6)         Debt

 

Our outstanding debt is:

 

 

 

June 30, 2006

 

December 31, 2005

 

 

 

Weighted
Average
Stated
Interest
Rate
(1)

 

Long-term

 

Current

 

Weighted
Average
Stated
Interest
Rate
(1)

 

Long-term

 

Current

 

 

 

(in millions, except interest rates)

 

Banking or Credit Facilities, Bonds and Notes:

 

 

 

 

 

 

 

 

 

 

 

 

 

Reliant Energy:

 

 

 

 

 

 

 

 

 

 

 

 

 

Senior secured revolver due 2009

 

8.80

%

$

323

 

$

 

8.40

%

$

383

 

$

 

Senior secured term loans (B1) due 2010(2)

 

7.47

 

222

 

13

 

6.09

 

240

 

313

 

Senior secured term loans (B2) due 2010

 

7.65

 

294

 

3

 

6.91

 

296

 

3

 

Senior secured notes due 2010

 

9.25

 

550

 

 

9.25

 

550

 

 

Senior secured notes due 2013

 

9.50

 

550

 

 

9.50

 

550

 

 

Senior secured notes due 2014

 

6.75

 

750

 

 

6.75

 

750

 

 

Convertible senior subordinated notes due 2010 (unsecured)

 

5.00

 

275

 

 

5.00

 

275

 

 

Subsidiary Obligations:

 

 

 

 

 

 

 

 

 

 

 

 

 

Orion Power Holdings, Inc. senior notes due 2010 (unsecured)

 

12.00

 

400

 

 

12.00

 

400

 

 

PEDFA(3) fixed-rate bonds for Seward plant due 2036

 

6.75

 

500

 

 

6.75

 

500

 

 

Reliant Energy Channelview LP(4):

 

 

 

 

 

 

 

 

 

 

 

 

 

Term loans and revolving working capital facility:

 

 

 

 

 

 

 

 

 

 

 

 

 

Floating rate debt due 2006 to 2024

 

6.92

 

253

 

18

 

6.04

 

259

 

14

 

Fixed rate debt due 2014 to 2024

 

9.55

 

75

 

 

9.55

 

75

 

 

RE Retail Receivables, LLC facility due 2006

 

5.59

 

 

450

 

4.71

 

 

450

 

Total facilities, bonds and notes

 

 

 

4,192

 

484

 

 

 

4,278

 

780

 

Other:

 

 

 

 

 

 

 

 

 

 

 

 

 

Adjustment to fair value of debt(5)

 

 

 

34

 

10

 

 

 

39

 

9

 

Total other debt

 

 

 

34

 

10

 

 

 

39

 

9

 

Total debt

 

 

 

$

4,226

 

$

494

 

 

 

$

4,317

 

$

789

 

 


(1)              The weighted average stated interest rates are for borrowings outstanding as of June 30, 2006 or December 31, 2005.

(2)              As of December 31, 2005, we classified $638 million as discontinued operations. See note 14.

(3)              PEDFA is defined as Pennsylvania Economic Development Financing Authority.

(4)              We have obtained an updated waiver from the lenders, which expires on May 1, 2007, relating to insurance requirements specified in the credit agreement.

(5)              Included in interest expense during the three months ended June 30, 2006 and 2005 is amortization of $2 million and $2 million, respectively, and included in interest expense during the six months ended June 30, 2006 and 2005 is amortization of $4 million and $4 million, respectively, for valuation adjustments for debt.

 

12



 

Amounts borrowed and available for borrowing under our senior secured revolver as of June 30, 2006 are:

 

 

 

Total Committed
Credit

 

Drawn
Amount

 

Letters of Credit

 

Unused
Amount

 

 

 

(in millions)

 

Reliant Energy senior secured revolver due 2009

 

$

1,700

 

$

323

 

$

592

 

$

785

 

 

RE Retail Receivables, LLC Facility. We have a receivables facility arrangement to sell an undivided interest in accounts receivable from our retail business to financial institutions on an ongoing basis. The assets of the special purpose subsidiary that purchases the receivables and then resells receivables under the facility are available first and foremost to satisfy the claims of its creditors. The special purpose subsidiary is a separate entity, which we consolidate. We have extended this facility through October 31, 2006.

 

(7)         Earnings Per Share

 

Reconciliations of the amounts used in the basic and diluted earnings (loss) per common share computations are:

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations (basic)

 

$

23

 

$

50

 

$

(116

)

$

9

 

Plus: Interest expense on 5.00% convertible senior subordinated notes, net of tax

 

2

 

2

 

(1)

 

Income (loss) from continuing operations (diluted)

 

$

25

 

$

52

 

$

(116

)

$

9

 

 


(1)              As we incurred a loss from continuing operations for this period, diluted loss per share is calculated the same as basic loss per share.

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(shares in thousands)

 

 

 

 

 

 

 

 

 

 

 

Diluted Weighted Average Shares Calculation:

 

 

 

 

 

 

 

 

 

Weighted average shares outstanding

 

306,780

 

301,250

 

306,208

 

300,848

 

Plus: Incremental shares from assumed conversions:

 

 

 

 

 

 

 

 

 

Stock options

 

2,309

 

2,100

 

(1)

2,360

 

Restricted stock and performance-based shares

 

604

 

1,136

 

(1)

1,205

 

Employee stock purchase plan

 

81

 

29

 

(1)

24

 

5.00% convertible senior subordinated notes

 

28,823

 

28,823

 

(1)

 

Warrants

 

3,995

 

4,341

 

(1)

4,470

 

Weighted average shares outstanding assuming conversion

 

342,592

 

337,679

 

306,208

 

308,907

 

 


(1)              See note (1) above regarding diluted loss per share.

 

13



 

We excluded the following items from diluted earnings (loss) per common share due to the anti-dilutive effect:

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(shares in thousands, dollars in millions)

 

 

 

 

 

 

 

 

 

 

 

Shares excluded from the calculation of diluted earnings (loss) per share

 

 

 

35,657

(1)

28,823

(1)

 

 

 

 

 

 

 

 

 

 

Shares excluded from the calculation of diluted earnings (loss) per share because the exercise price exceeded the average market price

 

3,159

(2)

4,396

(2)

5,233

(2)

4,284

(2)

 

 

 

 

 

 

 

 

 

 

Interest expense that would be added to income if 5.00% convertible senior subordinated notes were dilutive

 

$

 

$

 

$

4

 

$

4

 

 


(1)              Potential shares excluded may consist of convertible senior subordinated notes, warrants, stock options, restricted stock, performance-based shares and/or shares related to employee stock purchase plan.

(2)              Relates to stock options.

 

(8)         Income Taxes

 

(a)         Tax Rate Reconciliation.

 

A reconciliation of the federal statutory income tax rate to the effective income tax rate is:

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions, except percentages)

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

$

39

 

$

105

 

$

(42

)

$

51

 

Federal statutory rate

 

35

%

35

%

35

%

35

%

Income tax expense (benefit) at statutory rate

 

14

 

37

 

(15

)

18

 

Net addition (reduction) in taxes resulting from:

 

 

 

 

 

 

 

 

 

Federal tax reserves

 

 

1

 

1

 

2

 

Federal valuation allowance

 

20

 

6

 

90

 

6

 

Settlement of shareholder class action lawsuits

 

 

2

 

 

2

 

State income taxes, net of federal income taxes

 

2

 

7

 

15

 

12

 

Texas state law changes(1)

 

(19

)

 

(19

)

 

Other, net

 

(1

)

2

 

2

 

2

 

Total

 

2

 

18

 

89

 

24

 

Income tax expense from continuing operations

 

$

16

 

$

55

 

$

74

 

$

42

 

Effective rate

 

42

%

52

%

Not Meaningful

 

83

%

 


(1)              See note 8(d) below.

 

(b) Valuation Allowances.

 

We assess quarterly our future ability to use federal, state and foreign net operating losses, capital losses and other deferred tax assets. As a result of our recent history of losses and the change in our net federal deferred tax assets, we recorded $20 million and $90 million in valuation allowances against these tax assets during the three and six months ended June 30, 2006, respectively.

 

14



 

(c)          Tax Contingencies.

 

Our income tax returns, including years when we were included in CenterPoint Energy, Inc.’s (CenterPoint) consolidated tax group, for the 1997 to 2004 tax reporting periods are under audit by federal and state taxing authorities. These audits may result in additional taxes and interest or revisions of the timing of tax payments. We evaluate the need for contingent tax liabilities on a quarterly basis and record any estimable and probable tax exposures in our results of operations.

 

We have received proposed tax assessments from certain taxing authorities, which are currently at varying stages of appeals. The issues primarily relate to temporary differences and include deductions for plant abandonments, bad debts, capitalization of costs to plant and inventory, depreciable lives and various other matters. It could take several years to resolve these contingencies.

 

As of June 30, 2006 and December 31, 2005, we have accrued contingent federal and state tax liabilities related to our continuing operations of $41 million and $46 million, respectively. These balances are primarily classified in other long-term liabilities. We do not believe these contingencies will be resolved within the next 12 months.

 

As of June 30, 2006 and December 31, 2005, we have accrued contingent federal tax liabilities related to our discontinued European energy operations of $11 million included in other long-term liabilities in continuing operations. We reserved these amounts for potential future federal income tax assessments on certain income from our former European subsidiaries. If sustained, these assessments would increase our capital loss carryforwards by $45 million and reduce our tax net operating loss carryforwards by the same amount.

 

We believe that the substantial majority of certain payments and charges are deductible for income tax purposes; however, no assurance can be given that the Internal Revenue Service would not assert, or that a court would not sustain, a contrary position. These payments and/or charges include:

 

                  $177 million to CenterPoint during 2004 related to our residential customers. See note 13(d) to our consolidated financial statements in our Form 10-K.

 

                  $68 million during 2005 to settle the class action lawsuits against us for claims alleging violations of securities laws. See note 13(c) to our consolidated financial statements in our Form 10-K.

 

                  A pre-tax charge of $351 million during 2005 to settle certain civil litigation and claims relating to the Western states energy crisis. See note 13(a) to our consolidated financial statements in our Form 10-K.

 

(d)         Changes in Accounting for Income Taxes or Tax Laws.

 

The Financial Accounting Standards Board recently issued guidance clarifying the accounting for uncertainty in income taxes recognized in our financial statements. Pursuant to the new guidance, which becomes effective for us in 2007, tax benefits are only recorded for positions where it is more-likely-than-not that our reported tax return treatment would be sustained if audited by relevant taxing authorities. Additional rules are provided for interest, penalties, changes in benefit recognition and other related matters. We cannot currently predict the effect this interpretation will have on our consolidated financial statements.

 

In May 2006, the State of Texas enacted substantial changes to its tax system. Effective January 1, 2007, the current Texas franchise tax comprised of taxable capital and earned surplus components will be replaced with a revised franchise tax based on modified gross revenue. As a result of the Texas law change, during the second quarter of 2006, we decreased our net deferred state tax liabilities by $19 million to reflect the estimated cumulative change to deferred tax items.

 

 (9)      Guarantees

 

We have guaranteed certain non-qualified benefits of CenterPoint’s existing retirees at September 20, 2002. The estimated maximum potential amount of future payments under the guarantee was approximately $57 million as of June 30, 2006. We believe the likelihood that we would incur any significant losses under this guarantee is remote and, therefore, have not recorded a liability in our consolidated balance sheet as of June 30, 2006.

 

We also guarantee the $500 million PEDFA bonds, which are included in our consolidated balance sheet as outstanding debt. Our guarantees are secured by guarantees from all of our subsidiaries that guarantee the

 

15



 

December 2004 credit facilities and the collateral that secures our senior secured notes and October 2005 credit facility. The guarantees require us to comply with covenants substantially identical to those in the senior secured notes indentures. The PEDFA bonds will become secured by certain assets of Seward if the collateral supporting both the senior secured notes and our guarantees is released. Our maximum potential obligation under the guarantees is for payment of the principal of $500 million and related interest charges at a fixed rate of 6.75%.

 

We have guaranteed payments to a third party relating to energy sales from El Dorado Energy, LLC, a former investment. The estimated maximum potential amount of future payments under this guarantee is approximately $21 million as of June 30, 2006. We secured a portion of the guarantee with letters of credit. We have not recorded a liability in our consolidated balance sheet for this guarantee.

 

We enter into contracts that include indemnification and guarantee provisions. In general, we enter into contracts with indemnities for matters such as breaches of representations and warranties and covenants contained in the contract and/or against certain specified liabilities. Examples of these contracts include asset sales agreements, retail supply agreements, service agreements and procurement agreements.

 

In our debt agreements, we typically indemnify against liabilities that arise from the preparation, entry into, administration or enforcement of the agreement.

 

We are unable to estimate our maximum potential exposure under these provisions until an event triggering payment under these provisions occurs. Based on current information, we consider the likelihood of making any material payments under these provisions to be remote.

 

(10) Contingencies

 

We are parties to many legal proceedings, some of which involve substantial claim amounts. Unless otherwise noted, we cannot predict the outcome of these proceedings. In this note, we disclose only proceedings that became reportable during the three months ended June 30, 2006 and material developments in previously reported proceedings. For information about previously reported proceedings, see note 12 to our consolidated financial statements in our Form 10-K and note 10 to our interim financial statements in our Quarterly Report on Form 10-Q for the period ended March 31, 2006, which notes (as updated below) are incorporated by reference into, and filed as exhibits to, this Form 10-Q.

 

Legal Matters.

 

Pending Western States Electricity and Natural Gas Litigation.

 

Natural Gas Actions. In February 2006, we executed our settlement agreement for the New York class action lawsuits (Cornerstone settlement agreement), which was approved in May 2006 by the United States District Court for the Southern District of New York. We paid the $8 million Cornerstone settlement to the plaintiffs during the first quarter of 2006.

 

In May 2006, a class action lawsuit was filed in the District Court of the City and County of Denver, Colorado, relating to alleged conduct to increase natural gas prices in violation of antitrust and similar laws during the period January 2000 through October 2002. The lawsuit seeks restitution and expenses and also names our subsidiary, Reliant Energy Services, Inc., as a party.

 

Electricity Actions. In May 2006 and July 2006, the California Superior Court approved our settlement agreement for the majority of the lawsuits in California relating to alleged conduct to increase electricity prices in violation of antitrust, unfair competition and similar laws. In accordance with the terms of the settlement agreement, in June 2006 and July 2006, we paid $3 million and $1 million, respectively, to the plaintiffs. There are two remaining lawsuits on appeal from orders that dismissed these cases in our favor. A third case is pending at the trial court level.

 

16



 

(11)  Supplemental Guarantor Information

 

Our wholly-owned subsidiaries are either (a) full and unconditional guarantors, jointly and severally, or (b) non-guarantors of the senior secured notes.

 

Condensed Consolidating Statements of Operations.

 

 

 

Three Months Ended June 30, 2006

 

 

 

Reliant Energy

 

Guarantors

 

Non-Guarantors

 

Adjustments (1)

 

Consolidated

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

 

$

2,807

 

$

333

 

$

(365

)

$

2,775

 

Purchased power, fuel and cost of gas sold

 

 

2,395

 

197

 

(358

)

2,234

 

Operation and maintenance

 

 

108

 

130

 

(7

)

231

 

Selling, general and administrative

 

 

73

 

19

 

 

92

 

(Gain) loss on sales of receivables

 

 

19

 

(19

)

 

 

Gains on sales of assets and emission allowances, net

 

 

 

(5

)

 

(5

)

Depreciation and amortization

 

 

45

 

46

 

 

91

 

Total

 

 

2,640

 

368

 

(365

)

2,643

 

Operating income (loss)

 

 

167

 

(35

)

 

132

 

Income of equity investments, net

 

 

2

 

 

 

2

 

Other, net

 

 

1

 

 

 

1

 

Income (loss) of equity investments of consolidated subsidiaries

 

44

 

(14

)

 

(30

)

 

Interest expense

 

(72

)

(8

)

(23

)

 

(103

)

Interest income

 

 

6

 

1

 

 

7

 

Interest income (expense) – affiliated companies, net

 

56

 

(33

)

(23

)

 

 

Total other income (expense)

 

28

 

(46

)

(45

)

(30

)

(93

)

Income (loss) from continuing operations before income taxes

 

28

 

121

 

(80

)

(30

)

39

 

Income tax expense (benefit)(2)

 

14

 

32

 

(30

)

 

16

 

Income (loss) from continuing operations

 

14

 

89

 

(50

)

(30

)

23

 

Loss from discontinued operations

 

 

(1

)

(8

)

 

(9

)

Net income (loss)

 

$

14

 

$

88

 

$

(58

)

$

(30

)

$

14

 

 

 

 

Three Months Ended June 30, 2005

 

 

 

Reliant Energy

 

Guarantors

 

Non-Guarantors

 

Adjustments (1)

 

Consolidated

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

 

$

2,418

 

$

354

 

$

(340

)

$

2,432

 

Purchased power, fuel and cost of gas sold

 

(1

)

1,972

 

203

 

(335

)

1,839

 

Operation and maintenance

 

 

93

 

119

 

(5

)

207

 

Selling, general and administrative

 

 

57

 

26

 

 

83

 

(Gain) loss on sales of receivables

 

 

12

 

(12

)

 

 

Gains on sales of assets and emission allowances, net

 

 

(3

)

(24

)

2

 

(25

)

Depreciation and amortization

 

 

54

 

51

 

 

105

 

Total

 

(1

)

2,185

 

363

 

(338

)

2,209

 

Operating income (loss)

 

1

 

233

 

(9

)

(2

)

223

 

Loss of equity investments, net

 

 

(4

)

 

 

(4

)

Income (loss) of equity investments of consolidated subsidiaries

 

122

 

(10

)

 

(112

)

 

Other, net

 

 

(23

)

 

 

(23

)

Interest expense

 

(68

)

(10

)

(20

)

 

(98

)

Interest income

 

 

6

 

1

 

 

7

 

Interest income (expense) – affiliated companies, net

 

33

 

(11

)

(22

)

 

 

Total other income (expense)

 

87

 

(52

)

(41

)

(112

)

(118

)

Income (loss) from continuing operations before income taxes

 

88

 

181

 

(50

)

(114

)

105

 

Income tax expense (benefit)

 

(9

)

84

 

(20

)

 

55

 

Income (loss) from continuing operations

 

97

 

97

 

(30

)

(114

)

50

 

Income from discontinued operations

 

2

 

28

 

19

 

 

49

 

Net income (loss)

 

$

99

 

$

125

 

$

(11

)

$

(114

)

$

99

 

 

17



 

 

 

Six Months Ended June 30, 2006

 

 

 

Reliant Energy

 

Guarantors

 

Non-Guarantors

 

Adjustments (1)

 

Consolidated

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

 

$

5,296

 

$

682

 

$

(750

)

$

5,228

 

Purchased power, fuel and cost of gas sold

 

 

4,817

 

404

 

(737

)

4,484

 

Operation and maintenance

 

 

201

 

228

 

(13

)

416

 

Selling, general and administrative

 

 

125

 

37

 

 

162

 

(Gain) loss on sales of receivables

 

 

37

 

(37

)

 

 

Gains on sales of assets and emission allowances, net

 

 

(19

)

(137

)

 

(156

)

Depreciation and amortization

 

 

93

 

79

 

 

172

 

Total

 

 

5,254

 

574

 

(750

)

5,078

 

Operating income

 

 

42

 

108

 

 

150

 

Income of equity investments, net

 

 

2

 

 

 

2

 

Other, net

 

 

1

 

 

 

1

 

Income of equity investments of consolidated subsidiaries

 

1

 

7

 

 

(8

)

 

Interest expense

 

(148

)

(19

)

(44

)

 

(211

)

Interest income

 

 

13

 

3

 

 

16

 

Interest income (expense) – affiliated companies, net

 

112

 

(65

)

(47

)

 

 

Total other expense

 

(35

)

(61

)

(88

)

(8

)

(192

)

Income (loss) from continuing operations before income taxes

 

(35

)

(19

)

20

 

(8

)

(42

)

Income tax expense (benefit)(2)

 

80

 

(21

)

15

 

 

74

 

Income (loss) from continuing operations

 

(115

)

2

 

5

 

(8

)

(116

)

Income (loss) from discontinued operations

 

(4

)

(4

)

4

 

 

(4

)

Cumulative effect of accounting change, net of tax

 

 

1

 

 

 

1

 

Net income (loss)

 

$

(119

)

$

(1

)

$

9

 

$

(8

)

$

(119

)

 

 

 

Six Months Ended June 30, 2005

 

 

 

Reliant Energy

 

Guarantors

 

Non-Guarantors

 

Adjustments (1)

 

Consolidated

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

 

$

4,147

 

$

695

 

$

(693

)

$

4,149

 

Purchased power, fuel and cost of gas sold

 

(1

)

3,478

 

387

 

(683

)

3,181

 

Operation and maintenance

 

 

177

 

210

 

(10

)

377

 

Selling, general and administrative

 

 

94

 

49

 

 

143

 

(Gain) loss on sales of receivables

 

 

23

 

(23

)

 

 

Gains on sales of assets and emission allowances, net

 

 

(3

)

(24

)

3

 

(24

)

Depreciation and amortization

 

 

111

 

102

 

 

213

 

Total

 

(1

)

3,880

 

701

 

(690

)

3,890

 

Operating income (loss)

 

1

 

267

 

(6

)

(3

)

259

 

Loss of equity investments, net

 

 

(4

)

 

 

(4

)

Income (loss) of equity investments of consolidated subsidiaries

 

118

 

(12

)

 

(106

)

 

Other, net

 

 

(23

)

 

 

(23

)

Interest expense

 

(135

)

(18

)

(40

)

 

(193

)

Interest income

 

 

11

 

1

 

 

12

 

Interest income (expense) – affiliated companies, net

 

65

 

(22

)

(43

)

 

 

Total other income (expense)

 

48

 

(68

)

(82

)

(106

)

(208

)

Income (loss) from continuing operations before income taxes

 

49

 

199

 

(88

)

(109

)

51

 

Income tax expense (benefit)

 

(21

)

96

 

(33

)

 

42

 

Income (loss) from continuing operations

 

70

 

103

 

(55

)

(109

)

9

 

Income from discontinued operations

 

4

 

35

 

26

 

 

65

 

Net income (loss)

 

$

74

 

$

138

 

$

(29

)

$

(109

)

$

74

 

 


(1)              These amounts relate to either (a) eliminations and adjustments recorded in the normal consolidation process or (b) reclassifications recorded due to differences in classifications at the subsidiary levels compared to the consolidated level.

(2)              During the three and six months ended June 30, 2006, we recorded federal valuation allowances of $20 million and $90 million, respectively, related to our net federal deferred tax assets. This amount is reflected in the “Reliant Energy” column. See note 8.

 

18



 

Condensed Consolidating Balance Sheets.

 

 

 

June 30, 2006

 

 

 

Reliant Energy

 

Guarantors

 

Non-Guarantors

 

Adjustments (1)

 

Consolidated

 

 

 

(in millions)

 

ASSETS

 

 

 

 

 

 

 

 

 

 

 

Current Assets:

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

3

 

$

39

 

$

29

 

$

(1

)

$

70

 

Restricted cash

 

 

 

9

 

1

 

10

 

Accounts and notes receivable, principally customer, net

 

 

298

 

1,041

 

(10

)

1,329

 

Accounts and notes receivable – affiliated companies

 

976

 

1,534

 

1,067

 

(3,577

)

 

Inventory

 

 

149

 

142

 

 

291

 

Derivative assets

 

 

307

 

15

 

 

322

 

Other current assets

 

 

1,823

 

109

 

(138

)

1,794

 

Current assets of discontinued operations

 

 

10

 

1

 

 

11

 

Total current assets

 

979

 

4,160

 

2,413

 

(3,725

)

3,827

 

Property, Plant and Equipment, net

 

 

3,171

 

2,660

 

 

5,831

 

Other Assets:

 

 

 

 

 

 

 

 

 

 

 

Goodwill

 

 

84

 

184

 

119

 

387

 

Other intangibles, net

 

 

151

 

310

 

 

461

 

Notes receivable – affiliated companies

 

2,256

 

774

 

94

 

(3,124

)

 

Equity investments of consolidated subsidiaries

 

3,693

 

450

 

 

(4,143

)

 

Derivative assets

 

 

440

 

8

 

 

448

 

Other long-term assets(2)

 

87

 

295

 

355

 

(156

)

581

 

Total other assets

 

6,036

 

2,194

 

951

 

(7,304

)

1,877

 

Total Assets

 

$

7,015

 

$

9,525

 

$

6,024

 

$

(11,029

)

$

11,535

 

 

 

 

 

 

 

 

 

 

 

 

 

LIABILITIES AND EQUITY

 

 

 

 

 

 

 

 

 

 

 

Current Liabilities:

 

 

 

 

 

 

 

 

 

 

 

Current portion of long-term debt and short-term borrowings

 

$

16

 

$

 

$

478

 

$

 

$

494

 

Accounts payable, principally trade

 

5

 

716

 

48

 

 

769

 

Accounts and notes payable – affiliated companies

 

 

2,037

 

1,540

 

(3,577

)

 

Derivative liabilities

 

 

766

 

53

 

 

819

 

Other current liabilities

 

204

 

347

 

59

 

(148

)

462

 

Current liabilities of discontinued operations

 

 

9

 

26

 

 

35

 

Total current liabilities

 

225

 

3,875

 

2,204

 

(3,725

)

2,579

 

Other Liabilities:

 

 

 

 

 

 

 

 

 

 

 

Notes payable – affiliated companies

 

 

2,335

 

789

 

(3,124

)

 

Derivative liabilities

 

 

466

 

147

 

 

613

 

Other long-term liabilities(2)

 

76

 

221

 

226

 

(156

)

367

 

Total other liabilities

 

76

 

3,022

 

1,162

 

(3,280

)

980

 

Long-term Debt

 

2,964

 

501

 

761

 

 

4,226

 

Commitments and Contingencies

 

 

 

 

 

 

 

 

 

 

 

Temporary Equity Stock-based Compensation

 

2

 

 

 

 

2

 

Total Stockholders’ Equity(2)

 

3,748

 

2,127

 

1,897

 

(4,024

)

3,748

 

Total Liabilities and Equity

 

$

7,015

 

$

9,525

 

$

6,024

 

$

(11,029

)

$

11,535

 

 

19



 

 

 

December 31, 2005

 

 

 

Reliant Energy

 

Guarantors

 

Non-Guarantors

 

Adjustments (1)

 

Consolidated

 

 

 

(in millions)

 

ASSETS

 

 

 

 

 

 

 

 

 

 

 

Current Assets:

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

3

 

$

40

 

$

45

 

$

 

$

88

 

Restricted cash

 

 

 

27

 

 

27

 

Accounts and notes receivable, principally customer, net

 

 

348

 

840

 

(16

)

1,172

 

Accounts and notes receivable – affiliated companies

 

802

 

1,395

 

1,096

 

(3,293

)

 

Inventory

 

 

161

 

138

 

 

299

 

Derivative assets

 

 

639

 

87

 

 

726

 

Other current assets

 

1

 

2,129

 

91

 

(6

)

2,215

 

Current assets of discontinued operations

 

2

 

46

 

157

 

(2

)

203

 

Total current assets

 

808

 

4,758

 

2,481

 

(3,317

)

4,730

 

Property, Plant and Equipment, net

 

 

3,246

 

2,688

 

 

5,934

 

Other Assets:

 

 

 

 

 

 

 

 

 

 

 

Goodwill

 

 

84

 

184

 

119

 

387

 

Other intangibles, net

 

 

182

 

329

 

 

511

 

Notes receivable – affiliated companies

 

2,506

 

812

 

2

 

(3,320

)

 

Equity investments of consolidated subsidiaries

 

3,721

 

364

 

 

(4,085

)

 

Derivative assets

 

 

521

 

7

 

 

528

 

Other long-term assets

 

188

 

180

 

380

 

(150

)

598

 

Long-term assets of discontinued operations

 

720

 

 

873

 

(712

)

881

 

Total other assets

 

7,135

 

2,143

 

1,775

 

(8,148

)

2,905

 

Total Assets

 

$

7,943

 

$

10,147

 

$

6,944

 

$

(11,465

)

$

13,569

 

 

 

 

 

 

 

 

 

 

 

 

 

LIABILITIES AND EQUITY

 

 

 

 

 

 

 

 

 

 

 

Current Liabilities:

 

 

 

 

 

 

 

 

 

 

 

Current portion of long-term debt and short-term borrowings

 

$

316

 

$

 

$

473

 

$

 

$

789

 

Accounts payable, principally trade

 

8

 

848

 

31

 

 

887

 

Accounts and notes payable – affiliated companies

 

 

1,826

 

1,467

 

(3,293

)

 

Derivative liabilities

 

 

1,081

 

139

 

 

1,220

 

Other current liabilities

 

62

 

305

 

69

 

(22

)

414

 

Current liabilities of discontinued operations

 

 

49

 

49

 

(2

)

96

 

Total current liabilities

 

386

 

4,109

 

2,228

 

(3,317

)

3,406

 

Other Liabilities:

 

 

 

 

 

 

 

 

 

 

 

Notes payable – affiliated companies

 

 

2,512

 

808

 

(3,320

)

 

Derivative liabilities

 

 

657

 

156

 

 

813

 

Other long-term liabilities

 

11

 

262

 

266

 

(150

)

389

 

Long-term liabilities of discontinued operations

 

638

 

 

854

 

(712

)

780

 

Total other liabilities

 

649

 

3,431

 

2,084

 

(4,182

)

1,982

 

Long-term Debt

 

3,044

 

501

 

772

 

 

4,317

 

Commitments and Contingencies

 

 

 

 

 

 

 

 

 

 

 

Total Stockholders’ Equity

 

3,864

 

2,106

 

1,860

 

(3,966

)

3,864

 

Total Liabilities and Equity

 

$

7,943

 

$

10,147

 

$

6,944

 

$

(11,465

)

$

13,569

 

 


(1)              These amounts relate to either (a) eliminations and adjustments recorded in the normal consolidation process or (b) reclassifications recorded due to differences in classifications at the subsidiary levels compared to the consolidated level.

(2)              See footnote (2) above under condensed consolidating statements of operations.

 

20



 

Condensed Consolidating Statements of Cash Flows.

 

 

 

Six Months Ended June 30, 2006

 

 

 

Reliant Energy

 

Guarantors(1)

 

Non-Guarantors(1)

 

Adjustments(2)

 

Consolidated

 

 

 

(in millions)

 

Cash Flows from Operating Activities:

 

 

 

 

 

 

 

 

 

 

 

Net cash used in continuing operations from operating activities

 

$

(3

)

$

(78

)

$

(34

)

$

 

$

(115

)

Net cash provided by (used in) discontinued operations from operating activities

 

3

 

(8

)

(32

)

 

(37

)

Net cash used in operating activities

 

 

(86

)

(66

)

 

(152

)

Cash Flows from Investing Activities:

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures

 

 

(19

)

(23

)

 

(42

)

Investments in, advances to and from and distributions from subsidiaries, net (3)

 

295

 

(4

)

(205

)

(86

)

 

Proceeds from sales of assets, net

 

 

 

1

 

 

1

 

Net proceeds from sales of emission allowances

 

 

55

 

139

 

 

194

 

Restricted cash

 

 

 

18

 

(1

)

17

 

Other, net

 

 

5

 

 

 

5

 

Net cash provided by (used in) continuing operations from investing activities

 

295

 

37

 

(70

)

(87

)

175

 

Net cash provided by discontinued operations from investing activities

 

712

 

 

968

 

(712

)

968

 

Net cash provided by investing activities

 

1,007

 

37

 

898

 

(799

)

1,143

 

Cash Flows from Financing Activities:

 

 

 

 

 

 

 

 

 

 

 

Payments of long-term debt

 

(319

)

 

(7

)

 

(326

)

Increase (decrease) in short-term borrowings and revolving credit facilities, net

 

(60

)

 

5

 

 

(55

)

Changes in notes with affiliated companies, net (4)

 

 

48

 

(134

)

86

 

 

Proceeds from issuances of stock

 

10

 

 

 

 

10

 

Net cash provided by (used in) continuing operations from financing activities

 

(369

)

48

 

(136

)

86

 

(371

)

Net cash used in discontinued operations from financing activities

 

(638

)

 

(712

)

712

 

(638

)

Net cash provided by (used in) financing activities

 

(1,007

)

48

 

(848

)

798

 

(1,009

)

Net Change in Cash and Cash Equivalents

 

 

(1

)

(16

)

(1

)

(18

)

Cash and Cash Equivalents at Beginning of Period

 

3

 

40

 

45

 

 

88

 

Cash and Cash Equivalents at End of Period

 

$

3

 

$

39

 

$

29

 

$

(1

)

$

70

 

 

21



 

 

 

Six Months Ended June 30, 2005

 

 

 

Reliant Energy

 

Guarantors(1)

 

Non-Guarantors(1)

 

Adjustments(2)

 

Consolidated

 

 

 

(in millions)

 

Cash Flows from Operating Activities:

 

 

 

 

 

 

 

 

 

 

 

Net cash provided by (used in) continuing operations from operating activities

 

$

(48

)

$

(42

)

$

34

 

$

 

$

(56

)

Net cash provided by discontinued operations from operating activities

 

6

 

6

 

16

 

 

28

 

Net cash provided by (used in) operating activities

 

(42

)

(36

)

50

 

 

(28

)

Cash Flows from Investing Activities:

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures

 

 

(20

)

(13

)

 

(33

)

Investments in, advances to and from and distributions from subsidiaries, net (3)

 

102

 

(6

)

(24

)

(72

)

 

Proceeds from sales of assets, net

 

 

 

45

 

 

45

 

Net proceeds from sales (purchases) of emission allowances

 

 

(40

)

21

 

 

(19

)

Restricted cash

 

 

 

30

 

 

30

 

Other, net

 

 

2

 

 

 

2

 

Net cash provided by (used in) continuing operations from investing activities

 

102

 

(64

)

59

 

(72

)

25

 

Net cash provided by (used in) discontinued operations from investing activities

 

22

 

29

 

(8

)

(22

)

21

 

Net cash provided by (used in) investing activities

 

124

 

(35

)

51

 

(94

)

46

 

Cash Flows from Financing Activities:

 

 

 

 

 

 

 

 

 

 

 

Payments of long-term debt

 

(3

)

(1

)

(32

)

 

(36

)

Increase (decrease) in short-term borrowings and revolving credit facilities, net

 

(107

)

 

131

 

 

24

 

Changes in notes with affiliated companies, net (4)

 

 

76

 

(148

)

72

 

 

Proceeds from issuances of stock

 

14

 

 

 

 

14

 

Net cash provided by (used in) continuing operations from financing activities

 

(96

)

75

 

(49

)

72

 

2

 

Net cash used in discontinued operations from financing activities

 

 

 

(22

)

22

 

 

Net cash provided by (used in) financing activities

 

(96

)

75

 

(71

)

94

 

2

 

Net Change in Cash and Cash Equivalents

 

(14

)

4

 

30

 

 

20

 

Cash and Cash Equivalents at Beginning of Period

 

25

 

33

 

47

 

 

105

 

Cash and Cash Equivalents at End of Period

 

$

11

 

$

37

 

$

77

 

$

 

$

125

 

 


(1)              During the six months ended June 30, 2006, Reliant Energy Retail Services, LLC, a guarantor, made a non-cash capital contribution of $75 million to RE Retail Receivables, LLC, its wholly owned subsidiary and a non-guarantor, in connection with the retail receivables facility. RE Retail Receivables, LLC will distribute this equity at the end of the facility. See note 6.

(2)              These amounts relate to either (a) eliminations and adjustments recorded in the normal consolidation process or (b) reclassifications recorded due to differences in classifications at the subsidiary levels compared to the consolidated level.

(3)              Net investments in, advances to and from and distributions from subsidiaries are classified as investing activities.

(4)              Net changes in notes with affiliated companies are classified as financing activities for subsidiaries of Reliant Energy and as investing activities for Reliant Energy.

 

22



 

(12)  Reportable Segments

 

Financial data for our segments are as follows:

 

 

 

Retail
Energy

 

Wholesale
Energy

 

Other
Operations

 

Eliminations

 

Consolidated

 

 

 

(in millions)

 

Three months ended June 30, 2006:

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

2,217

 

$

558

(1)

$

 

$

 

$

2,775

 

Intersegment revenues

 

 

140

 

 

(140

)

 

Gross margin(2)

 

381

 

160

 

 

 

541

 

Contribution margin(3)

 

271

 

(13

)

 

 

258

 

 

 

 

 

 

 

 

 

 

 

 

 

Three months ended June 30, 2005:

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

1,717

 

$

713

 

$

2

 

$

 

$

2,432

 

Intersegment revenues

 

 

124

 

 

(124

)

 

Gross margin(2)

 

353

 

237

 

3

 

 

593

 

Contribution margin(3)

 

270

 

81

 

1

 

 

352

 

 

 

 

 

 

 

 

 

 

 

 

 

Six months ended June 30, 2006 (except as denoted):

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

3,904

 

$

1,323

(4)

$

1

 

$

 

$

5,228

 

Intersegment revenues

 

 

286

 

 

(286

)

 

Gross margin(2)

 

374

 

369

 

1

 

 

744

 

Contribution margin(3)

 

175

 

65

 

1

 

 

241

 

Total assets as of June 30, 2006

 

2,184

 

9,886

 

535

(5)

(1,070

)

11,535

 

 

 

 

 

 

 

 

 

 

 

 

 

Six months ended June 30, 2005 (except as denoted):

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

3,021

 

$

1,125

 

$

3

 

$

 

$

4,149

 

Intersegment revenues

 

 

231

 

 

(231

)

 

Gross margin(2)

 

576

 

388

 

4

 

 

968

 

Contribution margin(3)

 

427

 

100

 

2

 

 

529

 

Total assets as of December 31, 2005

 

2,762

 

9,871

 

1,691

(6)

(755

)

13,569

 

 


(1)              Includes $382 million in revenues from a single counterparty, which represented 14% of our consolidated revenues and 68% of our wholesale energy segment revenues.

(2)              Revenues less purchased power, fuel and cost of gas sold.

(3)              Gross margin less (a) operation and maintenance, (b) selling and marketing and (c) bad debt expense.

(4)              Includes $655 million in revenues from a single counterparty, which represented 13% of our consolidated revenues and 50% of our wholesale energy segment revenues. As of June 30, 2006, $2 million was outstanding from this counterparty.

(5)              Other operations include discontinued operations of $11 million.

(6)              Other operations include discontinued operations of $1,084 million.

 

23



 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions)

 

Reconciliation of Contribution Margin to Operating Income and Operating Income to Net Income (Loss):

 

 

 

 

 

 

 

 

 

Contribution margin

 

$

258

 

$

352

 

$

241

 

$

529

 

Other general and administrative

 

40

 

49

 

75

 

81

 

Gains on sales of assets and emission allowances, net

 

(5

)

(25

)

(156

)

(24

)

Depreciation

 

77

 

88

 

151

 

187

 

Amortization

 

14

 

17

 

21

 

26

 

Operating income

 

132

 

223

 

150

 

259

 

Income (loss) of equity investments, net

 

2

 

(4

)

2

 

(4

)

Other, net

 

1

 

(23

)

1

 

(23

)

Interest expense

 

(103

)

(98

)

(211

)

(193

)

Interest income

 

7

 

7

 

16

 

12

 

Income (loss) from continuing operations before income taxes

 

39

 

105

 

(42

)

51

 

Income tax expense

 

16

 

55

 

74

 

42

 

Income (loss) from continuing operations

 

23

 

50

 

(116

)

9

 

Income (loss) from discontinued operations

 

(9

)

49

 

(4

)

65

 

Income (loss) before cumulative effect of accounting change

 

14

 

99

 

(120

)

74

 

Cumulative effect of accounting change, net of tax

 

 

 

1

 

 

Net income (loss)

 

$

14

 

$

99

 

$

(119

)

$

74

 

 

(13) Sales of Assets and Emission Allowances

 

Sales of Emission Allowances.

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

SO2(1) allowances

 

$

7

(2)

$

25

(3)

$

194

(4)

$

44

(5)

NOx(6) allowances

 

 

22

(7)

 

26

(8)

 

 

$

7

 

$

47

 

$

194

 

$

70

 

 


(1)              SO2 is sulfur dioxide.

(2)              Sold 5,000 allowances relating to 2006 through 2010 vintage years.

(3)              Sold 31,000 allowances relating to 2005 vintage year.

(4)              Sold 162,000 allowances relating to 2006 through 2010 vintage years.

(5)              Sold 59,000 allowances relating to 2005 vintage year.

(6)              NOx is nitrogen oxides.

(7)              Sold 7,000 allowances relating to 2005 through 2007 vintage years.

(8)              Sold 9,000 allowances relating to 2005 through 2007 vintage years.

 

24



 

Summary of Gains and Losses.

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

Landfill-gas fueled power plants

 

$

 

$

 

$

 

$

(4

)

REMA(1) hydropower plants

 

 

12

 

 

12

 

Emission allowances

 

5

 

11

 

156

 

15

 

Other, net

 

 

2

 

 

1

 

Gains on sales of assets and emission allowances, net

 

$

5

 

$

25

 

$

156

 

$

24

 

 


(1)              REMA is Reliant Energy Mid-Atlantic Power Holdings, LLC and its consolidated subsidiaries.

 

(14) Discontinued Operations

 

(a)         New York Plants.

 

General. In February 2006, we closed on the sale of our three remaining New York plants with an aggregate net generating capacity of approximately 2,100 megawatts (MW) for $979 million. During the third quarter of 2005, we began to report the results of the New York plants as discontinued operations. These plants were a part of our wholesale energy segment.

 

Use of Proceeds. We applied $952 million of cash proceeds, which is net of estimated city, state and transfer taxes and transaction costs, to pay down our senior secured term loans.

 

Assumptions Related to Debt, Deferred Financing Costs and Interest Expense on Discontinued Operations. Based on our contractual obligation (at the time the purchase and sale agreement was executed) to utilize a portion of the net proceeds from the sale to prepay debt, we classified $638 million of debt as discontinued operations as of December 31, 2005. See note 6. We also classified as discontinued operations the related deferred financing costs and interest expense on this debt. We allocated $0 and $10 million of related interest expense during the three months ended June 30, 2006 and 2005, respectively, and we allocated $15 million and $20 million of related interest expense during the six months ended June 30, 2006 and 2005, respectively, to discontinued operations.

 

(b)         All Discontinued Operations.

 

The following summarizes certain financial information of the businesses reported as discontinued operations:

 

 

 

New York
Plants

 

Ceredo
Plant

 

European
Energy

 

Total

 

 

 

(in millions)

 

Three months ended June 30, 2006:

 

 

 

 

 

 

 

 

 

Revenues

 

$

(1

)

$

 

$

 

$

(1

)

Loss before income tax expense/benefit

 

(2

)

 

 

(2

)

 

 

 

 

 

 

 

 

 

 

Three months ended June 30, 2005:

 

 

 

 

 

 

 

 

 

Revenues

 

$

204

 

$

 

$

 

$

204

 

Income before income tax expense/benefit

 

27

 

 

30

 

57

 

 

 

 

 

 

 

 

 

 

 

Six months ended June 30, 2006:

 

 

 

 

 

 

 

 

 

Revenues

 

$

111

 

$

 

$

 

$

111

 

Loss before income tax expense/benefit

 

(4

)

 

 

(4

)

 

 

 

 

 

 

 

 

 

 

Six months ended June 30, 2005:

 

 

 

 

 

 

 

 

 

Revenues

 

$

356

 

$

 

$

 

$

356

 

Income before income tax expense/benefit

 

54

 

 

30

 

84

 

 

25



 

The following summarizes the assets and liabilities related to our New York discontinued operations:

 

 

 

June 30, 2006

 

December 31, 2005

 

 

 

(in millions)

 

Current Assets:

 

 

 

 

 

Accounts receivable, net

 

$

1

 

$

51

 

Derivative assets

 

10

(1)

87

 

Other current assets

 

 

65

 

Total current assets

 

11

 

203

 

Property, Plant and Equipment, net

 

 

761

 

Other Assets:

 

 

 

 

 

Other intangibles, net

 

 

69

 

Derivative assets

 

 

43

 

Other

 

 

8

 

Total long-term assets

 

 

881

 

Total Assets

 

$

11

 

$

1,084

 

 

 

 

 

 

 

Current Liabilities:

 

 

 

 

 

Accounts payable

 

$

 

$

15

 

Taxes payable

 

25

(2)

15

 

Derivative liabilities

 

9

(1)

50

 

Other current liabilities

 

1

 

16

 

Total current liabilities

 

35

 

96

 

Other Liabilities:

 

 

 

 

 

Accumulated deferred income taxes

 

 

120

 

Other liabilities

 

 

22

 

Total other liabilities

 

 

142

 

Long-term Debt

 

 

638

 

Total long-term liabilities

 

 

780

 

Total Liabilities

 

$

35

 

$

876

 

Accumulated other comprehensive loss

 

$

 

$

 

 


(1)              Relates to derivatives to be settled through December 2006.

(2)              Of this amount, approximately $20 million relates to state taxes to be paid in quarterly payments through December 2006 resulting from the sale.

 

26



 

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

 

The following discussion should be read in conjunction with our Form 10-K. The discussion includes non-GAAP financial measures, which are not standardized; therefore, it may not be possible to compare these financial measures with other companies’ non-GAAP financial measures having the same or similar names. We strongly encourage investors to review our consolidated financial statements and publicly filed reports in their entirety and not to rely on any single financial measure.

 

Business Overview

 

We provide electricity and energy services to retail and wholesale customers through two business segments.

 

                  Retail energy — provides electricity and energy services to approximately 1.9 million retail electricity customers in Texas, including residential and small business customers and commercial, industrial and governmental/institutional customers. We also serve commercial, industrial and governmental/ institutional customers in the PJM Market, which is primarily Maryland, New Jersey and Pennsylvania.

 

                  Wholesale energy — provides electricity and energy services in the competitive wholesale energy markets in the United States. We own and operate power plants or contract for power generation capacity. As of June 30, 2006, we had approximately 16,000 MW of owned or leased generation capacity in operation.

 

Key earnings drivers for our retail energy segment include the margin received from sales to our retail customers and the volume of electricity sold to these customers. Key earnings drivers for the wholesale energy segment include:

 

                  the number of hours our generation is economic to operate;

 

                  the commercial capacity factor of our power plants;

 

                  unit margins received from our power plants;

 

                  other margins received, from among other things, capacity payments and ancillary services; and

 

                  the settlement of our historical hedges relative to current market prices.

 

Information regarding these key earnings drivers for our retail and wholesale energy segments for the three and six months ended June 30, 2006 and 2005 is included in this Form 10-Q.

 

Recent Events

 

In this section, we present forward-looking information about recent events that could impact our future results of operations. In addition to the factors described below, a number of other factors could affect our future results of operations, including changes in natural gas prices, plant availability, retail energy customer growth and other factors.

 

Retail Credit Structure.

 

We are currently negotiating to enter into a new retail credit structure, which is intended to substantially eliminate our net collateral postings and reduce our liquidity requirements associated with procuring supply for our retail energy business. Assuming we are successful in concluding these negotiations, we expect to sign an agreement with a credit support provider later this year. The structure is expected to be subject to various conditions to close, including amending and/or refinancing our senior secured revolver and term loans and obtaining required consents from the holders of our senior secured notes and our PEDFA bonds to amend the note indentures and our guarantees of the bonds. We began soliciting for the consents with respect to proposed amendments to the note indentures and our guarantees of the bonds on July 26, 2006. We expect to reduce our total debt outstanding upon implementation of the contemplated new retail credit structure.

 

Retail Products.

 

As part of our retail marketing efforts in Texas, we have made a concerted effort to offer retail customers competitive alternatives to the “price-to-beat.”  Through June 30, 2006, 45% of our ERCOT

 

27



 

residential customers are served under such competitive products and approximately 37% of these customers are on term products. We are striving to move customers to term products in order to provide them with stabilized and/or reduced electricity costs and at the same time reduce our attrition risk and risk around regulatory uncertainty.

 

PUCT Rule.

 

In July 2006, the Public Utility Commission of Texas adopted an emergency rule to suspend disconnection of electric service through September 30, 2006 for elderly low-income customers who contact us and designated critical care residential customers. This rule expands payment options to all low-income customers during the summer. Under the emergency rule, the affected customers will have the ability to enter into deferred payment plans to pay for their electric usage over a period of up to six billing cycles. The adoption of this emergency rule allowing certain limited classes of customers to avoid disconnection for a period of time and expanding the availability of deferred payment plans could increase our bad debt expense and have a material impact on our results of operations.

 

Stock-Based Compensation.

 

We adopted SFAS No. 123R effective January 1, 2006 related to accounting for our stock-based incentive plans. Changing from the intrinsic value method to the fair value method has not had a material impact on our consolidated financial statements. If we change our compensation system to include more stock-based incentive awards, then this change in accounting could have a material impact to our consolidated financial statements in the future. See note 2 to our interim financial statements.

 

Other.

 

For additional information regarding factors that could have an impact on our future results of operations, see “Risk Factors” in Item 1A of our Form 10-K.

 

Consolidated Results of Operations

 

Three Months Ended June 30, 2006 Compared to Three Months Ended June 30, 2005

 

We reported $14 million consolidated net income, or $0.05 diluted earnings per share, for the three months ended June 30, 2006 compared to $99 million consolidated net income, or $0.30 earnings per diluted share, for the same period in 2005.

 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

 

 

 

 

 

 

Retail energy contribution margin

 

$

271

 

$

270

 

$

1

 

Wholesale energy contribution margin

 

(13

)

81

 

(94

)

Corporate contribution margin

 

 

1

 

(1

)

Other general and administrative

 

(40

)

(49

)

9

 

Gains on sales of assets and emission allowances, net

 

5

 

25

 

(20

)

Depreciation and amortization

 

(91

)

(105

)

14

 

Income (loss) of equity investments, net

 

2

 

(4

)

6

 

Other, net

 

1

 

(23

)

24

 

Interest expense

 

(103

)

(98

)

(5

)

Interest income

 

7

 

7

 

 

Income taxes

 

(16

)

(55

)

39

 

Income from continuing operations

 

23

 

50

 

(27

)

Discontinued operations

 

(9

)

49

 

(58

)

Net income

 

$

14

 

$

99

 

$

(85

)

 

Retail Energy Segment Summary. Our retail energy segment’s contribution margin was $271 million during the three months ended June 30, 2006, compared to $270 million in the same period of 2005. The $1 million increase in contribution margin was primarily due to improved gross margin, excluding unrealized gains/losses, of $103 million, primarily offset by the net change in unrealized gains/losses on energy derivatives of $75 million and higher operation and maintenance, selling and marketing and bad debt expense of $27 million. See “— Retail Energy Margins” below for explanations.

 

28



 

Retail Energy Operational Data.

 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

(gigawatt hours)

 

Electricity Sales to End-Use Retail Customers:

 

 

 

 

 

Mass:

 

 

 

 

 

Residential:

 

 

 

 

 

Houston

 

4,572

 

4,812

 

Non-Houston

 

2,013

 

1,458

 

Small Business:

 

 

 

 

 

Houston

 

954

 

879

(1)

Non-Houston

 

382

 

193

(1)

Total Mass

 

7,921

 

7,342

 

Commercial and Industrial:

 

 

 

 

 

ERCOT(2)(3)

 

8,631

 

8,735

(1)

Non-ERCOT

 

1,539

 

1,384

 

Total Commercial and Industrial

 

10,170

 

10,119

 

Market usage adjustments(4)

 

(62

)

(147

)

Total

 

18,029

 

17,314

 

 


(1)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(2)              These volumes include customers of the General Land Office for whom we provide services.

(3)              ERCOT is the Electric Reliability Council of Texas.

(4)              See note 1 to our interim financial statements.

 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

(in thousands, metered locations)

 

Weighted Average Retail Customer Count:

 

 

 

 

 

Mass:

 

 

 

 

 

Residential:

 

 

 

 

 

Houston

 

1,189

 

1,276

 

Non-Houston

 

490

 

371

 

Small Business:

 

 

 

 

 

Houston

 

134

 

140

(1)

Non-Houston

 

27

 

15

(1)

Total Mass

 

1,840

 

1,802

 

Commercial and Industrial:

 

 

 

 

 

ERCOT(2)

 

75

 

72

(1)

Non-ERCOT

 

2

 

1

 

Total Commercial and Industrial

 

77

 

73

 

Total

 

1,917

 

1,875

 

 


(1)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(2)              Includes customers of the General Land Office for whom we provide services.

 

29



 

 

 

June 30, 2006

 

December 31, 2005

 

 

 

(in thousands, metered locations)

 

Retail Customers:

 

 

 

 

 

Mass:

 

 

 

 

 

Residential:

 

 

 

 

 

Houston

 

1,169

 

1,213

 

Non-Houston

 

502

 

462

 

Small Business:

 

 

 

 

 

Houston

 

133

 

137

(1)

Non-Houston

 

29

 

29

(1)

Total Mass

 

1,833

 

1,841

 

Commercial and Industrial:

 

 

 

 

 

ERCOT(2)

 

76

 

70

(1)

Non-ERCOT

 

2

 

2

 

Total Commercial and Industrial

 

78

 

72

 

Total

 

1,911

 

1,913

 

 


(1)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(2)              Includes customers of the General Land Office for whom we provide services.

 

Retail Energy Revenues.

 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

Retail energy revenues from end-use retail customers:

 

 

 

 

 

 

 

Mass:

 

 

 

 

 

 

 

Residential:

 

 

 

 

 

 

 

Houston

 

$

746

 

$

621

 

$

125

(1)

Non-Houston

 

283

 

150

 

133

(2)

Small Business:

 

 

 

 

 

 

 

Houston

 

156

 

113

(3)

43

(1)

Non-Houston

 

53

 

21

(3)

32

(4)

Total Mass

 

1,238

 

905

 

333

 

Commercial and Industrial:

 

 

 

 

 

 

 

ERCOT

 

771

 

651

(3)

120

(5)

Non-ERCOT

 

98

 

82

 

16

(4)

Total Commercial and Industrial

 

869

 

733

 

136

 

Total

 

2,107

 

1,638

 

469

 

 

 

 

 

 

 

 

 

Retail energy revenues from resales of purchased power and other hedging activities

 

120

 

90

 

30

 

Market usage adjustments

 

(7

)

(11

)

4

(6)

Unrealized losses on energy derivatives

 

(3

)

 

(3

)(7)

Total retail energy revenues

 

$

2,217

 

$

1,717

 

$

500

 

 


(1)              Increase primarily due to increases in sales prices to customers due to increases in the price of natural gas.

(2)              Increase primarily due to (a) increases in sales prices to customers due to increases in the price of natural gas and (b) increased volumes due to increased customers.

(3)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(4)              Increase primarily due to (a) increased volumes due to increased customers and (b) increases in sales prices to customers due to increases in the price of natural gas.

(5)              Increase primarily due to (a) fixed price contracts renewed at higher rates due to higher prices of natural gas and (b) variable rate contracts, which are tied to the market price of natural gas. These increases were partially offset by decreased volumes.

(6)              See footnote (4) under “Three Months Ended June 30, 2006 Compared to Three Months Ended June 30, 2005 — Retail Energy Margins.”

(7)              See footnote (5) under “Three Months Ended June 30, 2006 Compared to Three Months Ended June 30, 2005 — Retail Energy Margins.”

 

30



 

Retail Energy Purchased Power.

 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Costs of purchased power

 

$

1,727

 

$

1,360

 

$

367

(1)

Retail energy intersegments costs

 

140

 

124

 

16

(2)

Market usage adjustments

 

6

 

(11

)

17

(3)

Unrealized gains on energy derivatives

 

(37

)

(109

)

72

(4)

Total retail energy purchased power

 

$

1,836

 

$

1,364

 

$

472

 

 


(1)              Increase primarily due to (a) increases in the price of purchased power due to higher market prices of electricity primarily driven by higher natural gas prices, (b) higher volumes due to increased customers and (c) increased cost of transmission and distribution losses in ERCOT. These increases were partially offset by (a) our economic supply hedges that allowed us to benefit from lower gas prices and (b) decreases in other supply costs.

(2)              Increase primarily due to higher volumes due to more sales in PJM.

(3)              See footnote (4) under “Three Months Ended June 30, 2006 Compared to Three Months Ended June 30, 2005 — Retail Energy Margins.”

(4)              See footnote (5) under “Three Months Ended June 30, 2006 Compared to Three Months Ended June 30, 2005 — Retail Energy Margins.”

 

Retail Energy Margins.

 

In analyzing the results of our retail energy segment, we use the non-GAAP financial measure “total retail energy gross margin, excluding unrealized gains/losses,” which excludes unrealized gains/losses on energy derivatives as described below. We use this measure in addition to, and in conjunction with, contribution margin and retail energy gross margin in order to analyze the results of the retail energy segment. Retail energy gross margin, excluding unrealized gains/losses should not be relied upon to the exclusion of GAAP financial measures. The item that is excluded from this measure has a recurring effect on our earnings and reflects aspects of our business that are not taken into account by the measure retail energy gross margin, excluding unrealized gains/losses. We compensate for the limitations of the measure retail energy gross margin, excluding unrealized gains/losses by also using and analyzing GAAP measures to understand our business.

 

Unrealized Gains/Losses on Energy Derivatives. We use derivative instruments to manage operational or market constraints, to increase the return on our generation assets and to execute our retail energy segment’s supply procurement strategy. Some derivative instruments receive mark-to-market accounting treatment, which requires us to record non-cash gains/losses related to future periods based on current changes in forward commodity prices. We refer to these gains and losses prior to settlement, as well as ineffectiveness on cash flow hedges, as “unrealized gains/losses on energy derivatives.”  In some cases, the related underlying transactions being hedged receive accrual accounting treatment, resulting in a mismatch of accounting treatments. Since the application of mark-to-market accounting has the effect of pulling forward into current periods non-cash gains/losses relating to future delivery periods, analysis of results of operations from one period to another can be difficult. We believe that excluding these unrealized gains/losses provides a more meaningful representation of our economic performance in the reporting period and is therefore useful to us, investors, analysts and others in facilitating the analysis of our results of operations from one period to another. These gains/losses are also not a function of the operating performance of our generation assets, and excluding their impact helps isolate the operating performance of our generation assets under prevailing market conditions.

 

31



 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Mass gross margin

 

$

272

 

$

203

(1)

$

69

(2)

Commercial and industrial gross margin

 

88

 

41

(1)

47

(3)

Market usage adjustments

 

(13

)

 

(13

)(4)

Total retail energy gross margin, excluding unrealized gains/losses

 

347

 

244

 

103

 

Unrealized gains on energy derivatives

 

34

 

109

 

(75

)(5)

Total retail energy gross margin

 

381

 

353

 

28

 

Operation and maintenance

 

58

 

49

 

9

(6)

Selling and marketing expense

 

30

 

22

 

8

(7)

Bad debt expense

 

22

 

12

 

10

(8)

Total retail energy contribution margin

 

$

271

 

$

270

 

$

1

 

 


(1)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(2)              Excluding $4 million realized loss impact of terminated and subsequent replacement contracts in 2006, unit margins increased 33% primarily due to our economic supply hedges that allowed us to benefit from lower gas prices. This increase was partially offset by increased costs of transmission and distribution losses in ERCOT.

(3)              Excluding $4 million realized loss impact of terminated and subsequent replacement contracts in 2006, unit margins increased $5.04 per megawatt hour (MWh) due to decreases in other supply costs. This increase was partially offset by increased costs of transmission and distribution losses in ERCOT.

(4)              See note 1 to our interim financial statements.

(5)              Decrease primarily due to (a) $138 million in losses resulting from the impact of natural gas and power prices on our forward short gas and forward long power positions held during 2006 as compared to 2005, (b) $26 million in unrealized losses during 2006 due to a change in accounting estimate (see note 5 to our interim financial statements) and (c) $18 million decrease due to cash flow hedge ineffectiveness during 2006 as compared to 2005. These decreases were partially offset by $107 million reversal of previously recognized unrealized losses resulting from the settlement of positions during 2006 when compared to the same period in 2005.

(6)              Increase primarily due to gross receipts tax of $9 million due to higher billings.

(7)              Increase primarily due to additional marketing campaigns.

(8)              Increase primarily due to an increase in residential bad debt expense rate effective January 1, 2006 primarily due to higher energy costs, coupled with an increase in residential revenues.

 

32



 

Wholesale Energy Segment Summary. Our wholesale energy segment’s contribution margin was $(13) million during the three months ended June 30, 2006, compared to $81 million in the same period of 2005. The $94 million decrease in contribution margin was primarily due to (a) $47 million decrease in gross margin related to historical wholesale hedges, (b) $17 million increase in operation and maintenance expenses, (c) $16 million decrease in open wholesale gross margin and (d) $11 million net change in unrealized gains/losses on energy derivatives. See “— Wholesale Energy Margins” below for explanations.

 

Wholesale Energy Operational and Financial Data.

 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

GWh

 

% Economic(1)

 

GWh

 

% Economic(1)

 

 

 

 

 

 

 

 

 

 

 

Economic Generation Volume(2):

 

 

 

 

 

 

 

 

 

PJM Coal

 

5,869.0

 

81

%

5,602.8

 

78

%

MISO Coal

 

1,758.9

 

64

%

1,406.8

 

50

%

PJM/MISO Gas

 

249.8

 

3

%

454.9

 

6

%

West

 

349.5

 

5

%

47.3

 

1

%

Other

 

1,462.1

 

92

%

1,570.7

 

61

%

Total

 

9,689.3

 

37

%

9,082.5

 

36

%

 

 

 

 

 

 

 

 

 

 

Commercial Capacity Factor(3):

 

 

 

 

 

 

 

 

 

PJM Coal

 

70.3

%

 

 

74.9

%

 

 

MISO Coal

 

76.6

%

 

 

84.7

%

 

 

PJM/MISO Gas

 

91.6

%

 

 

75.9

%

 

 

West

 

87.6

%

 

 

100.0

%

 

 

Other

 

94.2

%

 

 

82.7

%

 

 

Total

 

76.3

%

 

 

77.9

%

 

 

 

 

 

 

 

 

 

 

 

 

Generation Volume(4):

 

 

 

 

 

 

 

 

 

PJM Coal

 

4,128.1

 

 

 

4,194.8

 

 

 

MISO Coal

 

1,347.6

 

 

 

1,191.3

 

 

 

PJM/MISO Gas

 

228.9

 

 

 

345.2

 

 

 

West

 

306.2

 

 

 

47.3

 

 

 

Other

 

1,377.4

 

 

 

1,299.7

 

 

 

Total

 

7,388.2

 

 

 

7,078.3

 

 

 

 

 

 

 

 

 

 

 

 

 

Unit Margin ($/MWh)(5):

 

 

 

 

 

 

 

 

 

PJM Coal

 

$

26.16

 

 

 

$

25.51

 

 

 

MISO Coal

 

19.29

 

 

 

28.54

 

 

 

PJM/MISO Gas

 

30.58

 

 

 

26.07

 

 

 

West

 

NM

(6)

 

 

NM

 

 

 

Other

 

 

 

 

0.77

 

 

 

Total weighted average

 

$

18.68

 

 

 

$

20.63

 

 

 

 


(1)              The percent economic represents economic generation volume divided by maximum generation at 100% plant availability.

(2)              Economic generation volume is estimated generation at 100% plant availability based on an hourly analysis of when it is economical to generate based on the price of power, fuel, emission allowances and variable operating costs.

(3)              Commercial capacity factor is the generation volume divided by the economic generation.

(4)              Excludes generation volume related to power purchase agreements, which includes tolling agreements.

(5)              Represents open energy gross margin divided by generation volume. This measure is useful to us as it details the impact on open energy gross margin from a price perspective.

(6)              NM is not meaningful.

 

33



 

Wholesale Energy Revenues.

 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Wholesale energy third-party revenues

 

$

502

 

$

668

 

$

(166

)(1)

Wholesale energy intersegment revenues

 

140

 

124

 

16

(2)

Unrealized gains on energy derivatives

 

56

 

45

 

11

(3)

Total wholesale energy revenues

 

$

698

 

$

837

 

$

(139

)

 


(1)              Decrease primarily due to (a) lower contracted prices of natural gas and power and (b) decreased natural gas sales volumes, partially offset by increased power sales volumes.

(2)              Increase primarily due to higher volumes due to more retail energy segment sales in PJM.

(3)              See footnote (6) under “Three Months Ended June 30, 2006 Compared to Three Months Ended June 30, 2005 — Wholesale Energy Margins.”

 

Wholesale Energy Purchased Power, Fuel and Cost of Gas Sold.

 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Wholesale energy third-party costs

 

$

500

 

$

584

 

$

(84

)(1)

Unrealized losses on energy derivatives

 

38

 

16

 

22

(2)

Total wholesale energy

 

$

538

 

$

600

 

$

(62

)

 


(1)              Decrease primarily due to (a) lower contracted prices of natural gas and purchased power and (b) decreased natural gas volumes. These decreases were partially offset by (a) higher contracted coal prices and (b) increased volumes of purchased power.

(2)              See footnote (6) under “Three Months Ended June 30, 2006 Compared to Three Months Ended June 30, 2005 — Wholesale Energy Margins.”

 

Wholesale Energy Margins.

 

In analyzing the results of our wholesale energy segment, we use the non-GAAP financial measures “open energy gross margin” and “open wholesale gross margin,” which exclude the items below. We use these measures in addition to, and in conjunction with, contribution margin and wholesale energy gross margin in order to analyze the results of the wholesale energy segment. Open energy gross margin and open wholesale gross margin should not be relied upon to the exclusion of GAAP financial measures. The items that are excluded from open energy gross margin and open wholesale gross margin have or have had a recurring effect on our earnings and reflect aspects of our business that are not taken into account by these measures. We compensate for the limitations of the measures open energy gross margin and open wholesale gross margin by also using and analyzing GAAP measures to understand our business.

 

Unrealized Gains/Losses on Energy Derivatives. See above under “— Retail Energy Margins”.

 

Historical Wholesale Hedges. We exclude the effect of certain historical, although recurring until the contracts terminate, wholesale hedges that were entered into in order to hedge the economics of our wholesale operations. We believe that it is useful to us, investors, analysts and others to show our results in the absence of these hedges. The impact of these historical hedges on our financial results is not a function of the operating performance of our generation assets and excluding the impact better reflects the operating performance of our generation assets based on prevailing market conditions.

 

Changes in California-Related Receivables and Reserves. We excluded the impact of changes in receivables and reserves relating to energy sales in California from October 2000 through June 2001. We reached a settlement concerning these receivables during the third quarter of 2005. Because of the market conditions and regulatory events that underlie the changes in receivables and reserves, we believe that excluding this item provides a more meaningful representation of our results of operations on an ongoing basis and is therefore useful to us, investors, analysts and others in facilitating the analysis of our results of operations from one period to another. For additional information, see note 13 to our consolidated financial statements in our Form 10-K.

 

34



 

 

 

Three Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

Open energy gross margin(1):

 

 

 

 

 

 

 

PJM Coal

 

$

108

 

$

107

 

$

1

 

MISO Coal

 

26

 

34

 

(8

)(2)

PJM/MISO Gas

 

7

 

9

 

(2

)

West

 

(3

)

(5

)

2

 

Other

 

 

1

 

(1

)

Total

 

138

 

146

 

(8

)

 

 

 

 

 

 

 

 

Other margin(3):

 

 

 

 

 

 

 

PJM Coal

 

7

 

10

 

(3

)

MISO Coal

 

2

 

4

 

(2

)

PJM/MISO Gas

 

10

 

12

 

(2

)

West

 

46

 

51

 

(5

)

Other

 

28

 

24

 

4

 

Total

 

93

 

101

 

(8

)

 

 

 

 

 

 

 

 

Total open wholesale gross margin

 

231

 

247

 

(16

)

 

 

 

 

 

 

 

 

Historical wholesale hedges(4)

 

(89

)

(42

)

(47

)(5)

Net unrealized gains on energy derivatives

 

18

 

29

 

(11

)(6)

Changes in California-related receivables and reserves

 

 

3

 

(3

)

 

 

 

 

 

 

 

 

Wholesale energy gross margin

 

160

 

237

 

(77

)

Operation and maintenance

 

173

 

156

 

17

(7)

Bad debt expense

 

 

 

 

Total wholesale energy contribution margin

 

$

(13

)

$

81

 

$

(94

)

 


(1)              Open energy gross margin is a model-derived number based on generation volume assuming (a) it had been sold at day-ahead power prices in the case of coal-fired generation and real-time power prices in the case of natural gas-fired generation and (b) it had been purchased at delivered spot fuel prices, each without regard to the effect of our historical wholesale hedges or prices actually paid or received.

(2)              Decrease primarily due to (a) lower commercial capacity factor driven by higher maintenance and unplanned outages and (b) lower unit margins (lower power prices partially offset by lower coal costs). These decreases were partially offset by higher economic generation.

(3)              Other margin represents power purchase agreements, capacity payments and ancillary revenues. In addition, other margin includes settlement of forward power and fuel sales and purchases for the West region.

(4)              Historical wholesale hedges were entered into to primarily hedge the economics of our wholesale operations. These amounts primarily relate to settlements of forward power and fuel hedges, long-term tolling purchases, long-term natural gas transportation contracts, storage contracts and our legacy energy trading. These amounts are derived based on methodology consistent with the calculation of open energy gross margin.

(5)              Increased loss primarily due to (a) $42 million impact of unwinding PJM power sales hedges in the fourth quarter of 2005, (b) $27 million due to decreases in coal market prices combined with increases in coal contract prices and (c) $8 million due to lower margins in gas transportation. These losses were partially offset by $30 million in gains on remaining power hedges due to lower market prices and lower hedged volumes.

(6)              Decrease primarily due to (a) $31 million lower unrealized gains in 2006 as compared to 2005 on positions entered to hedge the economics of our business operations, which receive mark-to-market accounting treatment and (b) $6 million in unrealized losses during 2006 due to a change in accounting estimate (see note 5 to our interim financial statements). These losses were partially offset by (a) $21 million in gains due to the reversal of previously recognized unrealized losses resulting from the settlement of positions during 2006 as compared to the same period in 2005 and (b) $5 million change due to cash flow hedge ineffectiveness during 2006 as compared to 2005.

(7)              Increase primarily due to $11 million increase in planned outages and maintenance spending primarily at our coal plants.

 

Other General and Administrative.

 

Legal costs

 

$

(11

)(1)

Salaries and benefits

 

(2

)

Contractor services and professional fees

 

3

 

Other, net

 

1

 

Net decrease in expense

 

$

(9

)

 


(1)              Decrease due to (a) $8 million settlement of shareholder class action lawsuits in 2005 and (b) $3 million of California litigation expenses in 2005.

 

35



 

Gains on Sales of Assets and Emission Allowances, Net. See note 13 to our interim financial statements.

 

Depreciation and Amortization.

 

Decrease in amortization of emission allowances

 

$

(4

)(1)

Net accelerated depreciation on certain facilities due to early retirements

 

(3

)

Information system assets fully depreciated

 

(3

)

Other, net

 

(4

)

Net decrease in expense

 

$

(14

)

 


(1)              Amortization of emission allowances was $12 million during the three months ended June 30, 2006 compared to $16 million for the same period during 2005. The decrease is primarily due to lower weighted average cost of allowances used in 2006 compared to the same period in 2005.

 

Income (Loss) of Equity Investments, Net. Income (loss) of equity investments increased $6 million primarily due to the sale of our interest in El Dorado Energy, LLC in July 2005 as we incurred a loss of $5 million from this investment during the three months ended June 30, 2005.

 

Other, Net. Other, net changed by $24 million during the three months ended June 30, 2006 compared to the same period in 2005 primarily due to a non-cash charge of $23 million in 2005 for the impairment of our investment in a communications services company. See note 18 to our consolidated financial statements in our Form 10-K.

 

Interest Expense.

 

Increase in outstanding debt

 

$

5

 

Higher interest rates

 

3

 

Other, net

 

(3

)

Net increase in expense

 

$

5

 

 

Interest Income. Interest income did not change significantly.

 

Income Tax Expense. See note 8 to our interim financial statements.

 

Discontinued Operations. See note 14 to our interim financial statements.

 

Six Months Ended June 30, 2006 Compared to Six Months Ended June 30, 2005

 

We reported $119 million consolidated net loss, or $0.39 loss per share, for the six months ended June 30, 2006 compared to $74 million consolidated net income, or $0.24 earnings per diluted share, for the same period in 2005.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

 

 

 

 

 

 

Retail energy contribution margin

 

$

175

 

$

427

 

$

(252

)

Wholesale energy contribution margin

 

65

 

100

 

(35

)

Corporate contribution margin

 

1

 

2

 

(1

)

Other general and administrative

 

(75

)

(81

)

6

 

Gains on sales of assets and emission allowances, net

 

156

 

24

 

132

 

Depreciation and amortization

 

(172

)

(213

)

41

 

Income (loss) of equity investments, net

 

2

 

(4

)

6

 

Other, net

 

1

 

(23

)

24

 

Interest expense

 

(211

)

(193

)

(18

)

Interest income

 

16

 

12

 

4

 

Income taxes

 

(74

)

(42

)

(32

)

Income (loss) from continuing operations

 

(116

)

9

 

(125

)

Discontinued operations

 

(4

)

65

 

(69

)

Cumulative effect of accounting change, net of tax

 

1

 

 

1

 

Net income (loss)

 

$

(119

)

$

74

 

$

(193

)

 

36



 

Retail Energy Segment Summary. Our retail energy segment’s contribution margin was $175 million during the six months ended June 30, 2006, compared to $427 million in the same period of 2005. The $252 million decrease in contribution margin was primarily due to the net change in unrealized gains/losses on energy derivatives of $292 million. Gross margin, excluding unrealized gains/losses, increased $90 million and operation and maintenance, selling and marketing and bad debt expense increased $50 million. See “— Retail Energy Margins” below for explanations.

 

Retail Energy Operational Data.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

(gigawatt hours)

 

Electricity Sales to End-Use Retail Customers:

 

 

 

 

 

Mass:

 

 

 

 

 

Residential:

 

 

 

 

 

Houston

 

7,399

 

8,042

 

Non-Houston

 

3,502

 

2,626

 

Small Business:

 

 

 

 

 

Houston

 

1,719

 

1,689

(1)

Non-Houston

 

652

 

331

(1)

Total Mass

 

13,272

 

12,688

 

Commercial and Industrial:

 

 

 

 

 

ERCOT(2)

 

16,147

 

16,923

(1)

Non-ERCOT

 

3,143

 

2,580

 

Total Commercial and Industrial

 

19,290

 

19,503

 

Market usage adjustments(3)

 

11

 

(238

)

Total

 

32,573

 

31,953

 

 


(1)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(2)              These volumes include customers of the General Land Office for whom we provide services.

(3)              See note 1 to our interim financial statements.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

(in thousands, metered locations)

 

Weighted Average Retail Customer Count:

 

 

 

 

 

Mass:

 

 

 

 

 

Residential:

 

 

 

 

 

Houston

 

1,201

 

1,289

 

Non-Houston

 

480

 

358

 

Small Business:

 

 

 

 

 

Houston

 

135

 

141

(1)

Non-Houston

 

28

 

14

(1)

Total Mass

 

1,844

 

1,802

 

Commercial and Industrial:

 

 

 

 

 

ERCOT(2)

 

74

 

73

(1)

Non-ERCOT

 

2

 

1

 

Total Commercial and Industrial

 

76

 

74

 

Total

 

1,920

 

1,876

 

 


(1)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(2)              Includes customers of the General Land Office for whom we provide services.

 

37



 

Retail Energy Revenues.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

Retail energy revenues from end-use retail customers:

 

 

 

 

 

 

 

Mass:

 

 

 

 

 

 

 

Residential:

 

 

 

 

 

 

 

Houston

 

$

1,184

 

$

995

 

$

189

(1)

Non-Houston

 

471

 

264

 

207

(2)

Small Business:

 

 

 

 

 

 

 

Houston

 

273

 

205

(3)

68

(4)

Non-Houston

 

90

 

36

(3)

54

(5)

Total Mass

 

2,018

 

1,500

 

518

 

Commercial and Industrial:

 

 

 

 

 

 

 

ERCOT

 

1,467

 

1,219

(3)

248

(6)

Non-ERCOT

 

210

 

152

 

58

(5)

Total Commercial and Industrial

 

1,677

 

1,371

 

306

 

Total

 

3,695

 

2,871

 

824

 

 

 

 

 

 

 

 

 

Retail energy revenues from resales of purchased power and other hedging activities

 

205

 

172

 

33

 

Market usage adjustments

 

7

 

(22

)

29

(7)

Unrealized losses on energy derivatives

 

(3

)

 

(3

)(8)

Total retail energy revenues

 

$

3,904

 

$

3,021

 

$

883

 

 


(1)              Increase primarily due to increases in sales prices to customers due to increases in the price of natural gas partially offset by lower volumes due to fewer customers.

(2)              Increase primarily due to (a) increases in sales prices to customers due to increases in the price of natural gas and (b) increased volumes due to increased customers.

(3)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(4)              Increase primarily due to increases in sales prices to customers due to increases in the price of natural gas.

(5)              Increase primarily due to (a) increased volumes due to increased customers and (b) increases in sales prices to customers due to increases in the price of natural gas.

(6)              Increase primarily due to (a) fixed price contracts renewed at higher rates due to higher prices of natural gas and (b) variable rate contracts, which are tied to the market price of natural gas. These increases were partially offset by decreased volumes.

(7)              See footnote (4) under “Six Months Ended June 30, 2006 Compared to Six Months Ended June 30, 2005 — Retail Energy Margins.”

(8)              See footnote (5) under “Six Months Ended June 30, 2006 Compared to Six Months Ended June 30, 2005 — Retail Energy Margins.”

 

Retail Energy Purchased Power.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Costs of purchased power

 

$

3,209

 

$

2,486

 

$

723

(1)

Retail energy intersegments costs

 

286

 

231

 

55

(2)

Market usage adjustments

 

8

 

(10

)

18

(3)

Unrealized (gains) losses on energy derivatives

 

27

 

(262

)

289

(4)

Total retail energy purchased power

 

$

3,530

 

$

2,445

 

$

1,085

 

 


(1)              Increase primarily due to (a) increases in the price of purchased power due to higher market prices of electricity primarily driven by higher natural gas prices and (b) increased cost of transmission and distribution losses in ERCOT. These increases were partially offset by (a) the impact of terminated commodity contracts and subsequent replacement contracts and (b) our economic supply hedges that allowed us to benefit from lower gas prices.

(2)              Increase primarily due to higher volumes due to more sales in PJM.

(3)              See footnote (4) under “Six Months Ended June 30, 2006 Compared to Six Months Ended June 30, 2005 — Retail Energy Margins.”

(4)              See footnote (5) under “Six Months Ended June 30, 2006 Compared to Six Months Ended June 30, 2005 — Retail Energy Margins.”

 

38



 

Retail Energy Margins.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Mass gross margin

 

$

297

 

$

284

(1)

$

13

(2)

Commercial and industrial gross margin

 

108

 

42

(1)

66

(3)

Market usage adjustments

 

(1

)

(12

)

11

(4)

Total retail energy gross margin, excluding unrealized gains/losses

 

404

 

314

 

90

 

Unrealized gains (losses) on energy derivatives

 

(30

)

262

 

(292

)(5)

Total retail energy gross margin

 

374

 

576

 

(202

)

Operation and maintenance

 

109

 

87

 

22

(6)

Selling and marketing expense

 

54

 

41

 

13

(7)

Bad debt expense

 

36

 

21

 

15

(8)

Total retail energy contribution margin

 

$

175

 

$

427

 

$

(252

)

 


(1)              Beginning in the first quarter of 2006, we recategorized financial and operational data for customers with a peak demand between 250 kilowatts and one MW from small business within mass to commercial and industrial. The 2005 data is presented on a comparable basis.

(2)              Excluding $19 million realized income impact of terminated and subsequent replacement contracts in 2006, unit margins decreased 2% primarily due to (a) increased costs of transmission and distribution losses in ERCOT and (b) increases in other supply costs. These decreases in gross margin were partially offset by (a) our economic supply hedges that allowed us to benefit from lower gas prices and (b) increased volumes due to more customers.

(3)              Excluding $26 million realized income impact of terminated and subsequent replacement contracts in 2006, unit margins increased $2.05/MWh due to decreased other supply costs. These increases were partially offset by increased costs of transmission and distribution losses in ERCOT.

(4)              See note 1 to our interim financial statements.

(5)              Decrease primarily due to (a) $273 million in losses resulting from the impact of natural gas and power prices on our forward short gas and forward long power positions held during 2006 as compared to 2005, (b) $51 million loss due to the reversal of previously recognized unrealized gains resulting from the termination of commodity contracts with a counterparty, (c) $26 million in unrealized losses during 2006 due to a change in accounting estimate (see note 5 to our interim financial statements) and (d) $68 million decrease due to cash flow hedge ineffectiveness during 2006 as compared to 2005. These decreases were partially offset by $126 million reversal of previously recognized unrealized losses resulting from the settlement of positions during 2006 when compared to the same period in 2005.

(6)              Increase primarily due to gross receipts tax of $18 million due to higher billings.

(7)              Increase primarily due to additional marketing campaigns.

(8)              Increase primarily due to an increase in residential bad debt expense rate effective January 1, 2006 primarily due to higher energy costs, coupled with an increase in residential revenues. These increases were partially offset by a $4 million decrease due to a reduction in the commercial and industrial bad debt expense rate due to improved collections.

 

39



 

Wholesale Energy Segment Summary. Our wholesale energy segment’s contribution margin was $65 million during the six months ended June 30, 2006, compared to $100 million in the same period of 2005. The $35 million decrease in contribution margin was primarily due to (a) $137 million decrease in gross margin related to historical wholesale hedges and (b) $19 million increase in operation and maintenance expenses. These decreases to contribution margin were partially offset by (a) $105 million net change in unrealized gains/losses on energy derivatives and (b) $15 million increase in open wholesale gross margin. See “— Wholesale Energy Margins” below for explanations.

 

Wholesale Energy Operational and Financial Data.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

GWh

 

% Economic

 

GWh

 

% Economic

 

 

 

 

 

 

 

 

 

 

 

Economic Generation Volume:

 

 

 

 

 

 

 

 

 

PJM Coal

 

11,676.4

 

81

%

11,038.5

 

79

%

MISO Coal

 

3,051.7

 

56

%

3,203.3

 

57

%

PJM/MISO Gas

 

283.9

 

2

%

610.2

 

4

%

West

 

1,273.0

 

9

%

192.3

 

2

%

Other

 

2,865.4

 

88

%

2,907.8

 

59

%

Total

 

19,150.4

 

37

%

17,952.1

 

35

%

 

 

 

 

 

 

 

 

 

 

Commercial Capacity Factor:

 

 

 

 

 

 

 

 

 

PJM Coal

 

78.4

%

 

 

75.4

%

 

 

MISO Coal

 

84.3

%

 

 

87.8

%

 

 

PJM/MISO Gas

 

80.8

%

 

 

70.7

%

 

 

West

 

96.5

%

 

 

100.0

%

 

 

Other

 

88.8

%

 

 

87.7

%

 

 

Total

 

82.2

%

 

 

79.7

%

 

 

 

 

 

 

 

 

 

 

 

 

Generation Volume:

 

 

 

 

 

 

 

 

 

PJM Coal

 

9,158.4

 

 

 

8,317.8

 

 

 

MISO Coal

 

2,573.7

 

 

 

2,811.8

 

 

 

PJM/MISO Gas

 

229.5

 

 

 

431.2

 

 

 

West

 

1,228.5

 

 

 

192.3

 

 

 

Other

 

2,543.7

 

 

 

2,550.7

 

 

 

Total

 

15,733.8

 

 

 

14,303.8

 

 

 

 

 

 

 

 

 

 

 

 

 

Unit Margin ($/MWh):

 

 

 

 

 

 

 

 

 

PJM Coal

 

$

26.86

 

 

 

$

22.96

 

 

 

MISO Coal

 

20.98

 

 

 

24.54

 

 

 

PJM/MISO Gas

 

30.50

 

 

 

41.74

 

 

 

West

 

NM

 

 

 

NM

 

 

 

Other

 

NM

 

 

 

2.35

 

 

 

Total weighted average

 

$

19.32

 

 

 

$

19.44

 

 

 

 

Wholesale Energy Revenues.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Wholesale energy third-party revenues

 

$

1,118

 

$

1,225

 

$

(107

)(1)

Wholesale energy intersegment revenues

 

286

 

231

 

55

(2)

Unrealized gains (losses) on energy derivatives

 

205

 

(100

)

305

(3)

Total wholesale energy revenues

 

$

1,609

 

$

1,356

 

$

253

 

 


(1)              Decrease primarily due to (a) lower contracted prices of power and natural gas and (b) decreased natural gas sales volumes, partially offset by increased power sales volumes.

(2)              Increase primarily due to higher volumes due to more retail energy segment sales in PJM.

(3)              See footnote (8) under “Six Months Ended June 30, 2006 Compared to Six Months Ended June 30, 2005 — Wholesale Energy Margins.”

 

40



 

Wholesale Energy Purchased Power, Fuel and Cost of Gas Sold.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Wholesale energy third-party costs

 

$

1,140

 

$

1,068

 

$

72

(1)

Unrealized (gains) losses on energy derivatives

 

100

 

(100

)

200

(2)

Total wholesale energy

 

$

1,240

 

$

968

 

$

272

 

 


(1)              Increase primarily due to (a) increase in volumes of purchased power and (b) higher contracted prices of coal, natural gas and oil. These decreases were partially offset by (a) decreased natural gas and oil volumes and (b) lower contracted prices of purchased power.

(2)              See footnote (8) under “Six Months Ended June 30, 2006 Compared to Six Months Ended June 30, 2005 — Wholesale Energy Margins.”

 

Wholesale Energy Margins.

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

Open energy gross margin:

 

 

 

 

 

 

 

PJM Coal

 

$

246

 

$

191

 

$

55

(1)

MISO Coal

 

54

 

69

 

(15

)(2)

PJM/MISO Gas

 

7

 

18

 

(11

)

West

 

(2

)

(6

)

4

 

Other

 

(1

)

6

 

(7

)

Total

 

304

 

278

 

26

 

 

 

 

 

 

 

 

 

Other margin:

 

 

 

 

 

 

 

PJM Coal

 

17

 

21

 

(4

)

MISO Coal

 

4

 

5

 

(1

)

PJM/MISO Gas

 

13

 

15

 

(2

)

West

 

83

 

90

 

(7

)(3)

Other

 

52

 

49

 

3

 

Total

 

169

 

180

 

(11

)

 

 

 

 

 

 

 

 

Total open wholesale gross margin

 

473

 

458

 

15

 

 

 

 

 

 

 

 

 

Historical wholesale hedges

 

(209

)

(72

)

(137

)(4)

Net unrealized gains on energy derivatives

 

105

 

 

105

(5)

Changes in California-related receivables and reserves

 

 

2

 

(2

)

 

 

 

 

 

 

 

 

Wholesale energy gross margin

 

369

 

388

 

(19

)

Operation and maintenance

 

307

 

288

 

19

(6)

Bad debt expense

 

(3

)

 

(3

)

Total wholesale energy contribution margin

 

$

65

 

$

100

 

$

(35

)

 


(1)              Increase primarily due to (a) higher unit margins (higher market power prices and lower market coal costs), (b) increased commercial capacity factor driven by lower limitations in plant output caused by weather conditions and (c) full capacity at Seward in 2006 versus partial capacity in 2005.

(2)              Decrease primarily due to (a) lower unit margins (lower power prices partially offset by lower coal costs) and (b) lower economic generation due to weather.

(3)              Decrease due to Bighorn being under a power purchase agreement for only one month in 2006 compared to a full six months in 2005.

(4)              Increased loss primarily due to (a) $103 million impact of unwinding PJM power sales hedges in the fourth quarter of 2005 and (b) $67 million due to decreases in coal market prices combined with increases in coal contract prices. These losses were partially offset by $20 million on remaining power hedges due to lower hedged volumes, higher contract prices and higher market prices.

(5)              Increase primarily due to (a) $76 million higher unrealized gains in 2006 as compared to 2005 on positions entered to hedge the economics of our business operations, which receive mark-to-market accounting treatment and (b) $34 million reversal of previously recognized unrealized losses resulting from the settlement of positions during 2006 when compared to the same period in 2005. These gains were partially offset by $6 million in unrealized losses during 2006 due to a change in accounting estimate (see note 5 to our interim financial statements).

(6)              Increase primarily due to (a) $11 million increase in taxes other than income primarily due to the resolution of a potential tax liability in 2005 and (b) $3 million increase in planned outages and maintenance spending.

 

41



 

Other General and Administrative.

 

Legal costs

 

$

(13

)(1)

Salaries and benefits

 

5

 

Other, net

 

2

 

Net decrease in expense

 

$

(6

)

 


(1)              Decrease due to (a) $8 million settlement of shareholder class action lawsuits in 2005 and (b) $5 million of California litigation expenses in 2005.

 

Gains on Sales of Assets and Emission Allowances, Net. See note 13 to our interim financial statements.

 

Depreciation and Amortization.

 

Net accelerated depreciation on certain facilities due to early retirements

 

$

(18

)

Information system assets fully depreciated

 

(9

)

Decrease in amortization of emission allowances

 

(6

)(1)

Other, net

 

(8

)

Net decrease in expense

 

$

(41

)

 


(1)              Amortization of emission allowances was $18 million during the six months ended June 30, 2006 compared to $24 million for the same period during 2005. The decrease is primarily due to lower weighted average cost of allowances used in 2006 compared to the same period in 2005.

 

Income (Loss) of Equity Investments, Net. Income (loss) of equity investments increased $6 million primarily due to the sale of our interest in El Dorado Energy, LLC in July 2005 as we incurred a loss of $6 million from this investment during the six months ended June 30, 2005.

 

Other, Net. Other, net changed by $24 million during the six months ended June 30, 2006 compared to the same period in 2005 primarily due to a non-cash charge of $23 million in 2005 for the impairment of our investment in a communications services company. See note 18 to our consolidated financial statements in our Form 10-K.

 

Interest Expense.

 

Increase in outstanding debt

 

$

16

 

Higher interest rates

 

6

 

Other, net

 

(4

)

Net increase in expense

 

$

18

 

 

Interest Income.

 

Net margin deposits

 

$

9

 

Interest on California net receivables

 

(6

)

Other, net

 

1

 

Net increase in income

 

$

4

 

 

Income Tax Expense. See note 8 to our interim financial statements.

 

Discontinued Operations. See note 14 to our interim financial statements.

 

Liquidity and Capital Resources

 

During the six months ended June 30, 2006, we used $115 million in operating cash flows from continuing operations. Excluding the changes in margin deposits of $312 million and $159 million in payments relating to the western states and Cornerstone settlements (see notes 12 and 13 to our consolidated financial statements in our Form 10-K), we used $268 million in operating cash flows from continuing operations. In addition, we received $194 million of net proceeds from sales of emission allowances.

 

See “— Recent Events — Retail Credit Structure” for discussion about our contemplated new retail energy business credit structure.

 

42



 

In February and March 2006, we used net proceeds of $952 million relating to the sale of our New York plants to pay down debt. See note 14 to our interim financial statements.

 

As of July 31, 2006, we had total collateral postings of $1.8 billion, which is an $800 million decrease from December 31, 2005 due primarily to the liquidation of certain hedges. As of July 31, 2006, additional postings of $162 million could have been required by counterparties.

 

As of July 31, 2006, we had total available liquidity of $1.0 billion, comprised of $955 million in unused borrowing capacity under our senior secured revolver and $62 million of cash and cash equivalents.

 

We have updated our estimates for the construction and timing of emissions control projects for SO2 and NOx and mercury based on our commencement of plans to install wet flue gas desulphurization systems, or scrubbers, at two Pennsylvania plants and based on further studies and our analyses of and developments in regulation.  In total our capital expenditures for SO2 and NOx emission controls are now expected to range from $365 million to $640 million from 2006 through 2013.  Our capital expenditures for mercury compliance are expected to range from $35 million to $100 million through 2009.

 

The following table provides updated information (from amounts in our Form 10-K) about our estimated future capital requirements:

 

 

 

 

 

 

 

 

2006

 

2007

 

2008

 

 

 

 

 

 

 

 

 

(in millions)

 

Maintenance capital expenditures:

 

 

 

 

 

 

 

 

 

 

 

 

 

Retail energy

 

 

 

 

 

 

 

$

7

 

$

5

 

$

5

 

Wholesale energy (1)

 

 

 

 

 

 

 

67

 

102

 

63

 

Other operations

 

 

 

 

 

 

 

4

 

4

 

8

 

 

 

 

 

 

 

 

 

78

 

111

 

76

 

Environmental(2)

 

 

 

 

 

 

 

50

(3)

140

(4)

175

(5)

Construction of new generating facilities

 

 

 

 

 

 

 

1

 

 

 

Total capital expenditures

 

 

 

 

 

 

 

$

129

 

$

251

 

$

251

 

 


(1)     Excludes $7 million for the remainder of 2006 through 2011 for pre-existing environmental conditions and remediation, which have been accrued for in our consolidated balance sheet as of June 30, 2006.

(2)     We have estimated environmental capital expenditures of $110 million to $420 million for 2009 through 2013.

(3)     Of this amount, $8 million has been incurred through June 30, 2006.

(4)     We have estimated environmental capital expenditures of $140 million to $145 million for 2007 and have included the low end of the range in the table.

(5)     We have estimated environmental capital expenditures of $175 million to $205 million for 2008 and have included the low end of the range in the table.

 

See “Risk Factors” in Item 1A and “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources” in Item 7 of our Form 10-K.

 

Credit Risk

 

By extending credit to our counterparties, we are exposed to credit risk. As of June 30, 2006, our derivative assets and accounts receivable from our wholesale energy and ERCOT power supply counterparties, after taking into consideration netting within each contract and any master netting contracts with counterparties, are:

 

Credit Rating Equivalent

 

Exposure
Before
Collateral
(1)

 

Credit
Collateral
Held

 

Exposure
Net of Collateral

 

Number of
Counterparties
>10%

 

Net Exposure of
Counterparties
>10%

 

 

 

(dollars in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

Investment grade

 

$

165

 

$

40

 

$

125

 

 

$

 

Non-investment grade

 

592

 

 

592

 

2

 

587

 

No external ratings:

 

 

 

 

 

 

 

 

 

 

 

Internally rated – Investment grade

 

284

 

 

284

 

1

 

166

 

Internally rated – Non-investment grade

 

13

 

3

 

10

 

 

 

Total

 

$

1,054

 

$

43

 

$

1,011

 

3

 

$

753

 

 


(1)              The table excludes amounts related to contracts classified as “normal purchases and sales” and non-derivative contractual commitments that are not recorded in our consolidated balance sheets, except for any related accounts receivable. Such contractual commitments contain credit and economic risk if a counterparty does not perform. Nonperformance could have a material adverse impact on our future results of operations, financial condition and cash flows.

 

As of June 30, 2006, two non-investment grade counterparties and one investment grade counterparty represented 58% ($587 million) and 16% ($166 million), respectively, of our credit exposure, net of collateral. As of December 31, 2005, two non-investment grade counterparties and one investment grade counterparty represented 59% ($918 million) and 12% ($183 million), respectively, of our credit exposure, net of collateral. Since December 31, 2005, our credit exposure to non-investment grade counterparties decreased primarily due to changes in commodity prices and the settlement of certain contracts. There were no other counterparties representing greater than 10% of our net credit exposure.

 

Off-Balance Sheet Arrangements

 

As of June 30, 2006, we have no off-balance sheet arrangements.

 

43



 

Historical Cash Flows

 

Cash Flows — Operating Activities

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Operating income

 

$

150

 

$

259

 

$

(109

)

Depreciation and amortization

 

172

 

213

 

(41

)

Gains on sales of assets and emission allowances, net

 

(156

)

(24

)

(132

)

Net unrealized gains on energy derivatives

 

(75

)

(262

)

187

 

Western states and Cornerstone settlement payments

 

(159

)

 

(159

)

Margin deposits, net

 

312

(1)

(206

)(2)

518

 

Change in accounts and notes receivable and accounts payable, net

 

(100

)(3)

96

(4)

(196

)

Settlements of exchange transactions prior to contractual period(5)

 

(103

)

(4

)

(99

)

Net option premiums sold (purchased)

 

(31

)

56

 

(87

)

Interest payments

 

(189

)

(172

)

(17

)

Income tax (payments) net of refunds

 

(35

)

(18

)

(17

)

Other, net

 

99

 

6

 

93

 

Net cash used in continuing operations from operating activities

 

(115

)

(56

)

(59

)

Net cash provided by (used in) discontinued operations from operating activities

 

(37

)

28

 

(65

)

Net cash used in operating activities

 

$

(152

)

$

(28

)

$

(124

)

 


(1)              Change primarily due to a decrease in counterparty obligations partially offset by a decrease in net unrealized value of our broker accounts.

(2)              Change primarily due to decrease in net unrealized value of our broker accounts.

(3)              Change primarily due to (a) increased accounts receivable due to seasonality in our retail energy segment and (b) decreased accounts payable due to decreased gas purchases, partially offset by increased power purchases. These were partially offset by decreased accounts receivable due to decreased gas and power sales.

(4)              Change primarily due to (a) increased accounts payable as a result of increased power and gas purchases and (b) decreased accounts receivable due to decreased generation in our West region. These were partially offset by increased accounts receivable due to seasonality in our retail energy segment.

(5)              Represents exchange transactions financially settled within three business days prior to the contractual delivery month.

 

Cash Flows — Investing Activities

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Capital expenditures

 

$

(42

)

$

(33

)

$

(9

)

Proceeds from sales of assets, net

 

1

 

45

 

(44

)

Proceeds from sales of emission allowances

 

197

 

70

 

127

 

Purchases of emission allowances

 

(3

)

(89

)

86

 

Restricted cash

 

17

(1)

30

 

(13

)

Other, net

 

5

 

2

 

3

 

Net cash provided by continuing operations from investing activities

 

175

 

25

 

150

 

Net cash provided by discontinued operations from investing activities

 

968

 

21

 

947

 

Net cash provided by investing activities

 

$

1,143

 

$

46

 

$

1,097

 

 


(1)              Subsequent to the sale of the New York plants, Orion Power Holdings, Inc. is only able to distribute a portion of its cash to Reliant Energy, thus, its classification as restricted cash.

 

44



 

Cash Flows — Financing Activities

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

Change

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

Payments under senior secured term loans due 2010

 

$

(320

)(1)

$

(3

)

$

(317

)

Payments under REMA’s term loans

 

 

(28

)

28

 

Net borrowings under receivables facility

 

 

123

 

(123

)

Net payments on senior secured revolver due 2009

 

(60

)

(107

)

47

 

Proceeds from issuance of stock

 

10

 

14

 

(4

)

Other, net

 

(1

)

3

 

(4

)

Net cash provided by (used in) continuing operations from financing activities

 

(371

)

2

 

(373

)

Net cash used in discontinued operations from financing activities

 

(638

)(1)

 

(638

)

Net cash provided by (used in) financing activities

 

$

(1,009

)

$

2

 

$

(1,011

)

 


(1)              We used the net proceeds from the sale of our New York plants to pay down debt. See note 6 to our interim financial statements.

 

New Accounting Pronouncements, Significant Accounting Policies and Critical Accounting Estimates

 

New Accounting Pronouncements

 

See notes 2 and 8 to our interim financial statements.

 

Significant Accounting Policies

 

See note 2 to our consolidated financial statements in our Form 10-K.

 

Critical Accounting Estimates

 

See “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Accounting Estimates — New Accounting Pronouncements, Significant Accounting Policies and Critical Accounting Estimates — Critical Accounting Estimates” in Item 7 in our Form 10-K, note 2 to our consolidated financial statements in our Form 10-K and note 1 to our interim financial statements.

 

45



 

ITEM 3.          QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT NON-TRADING AND
TRADING ACTIVITIES AND RELATED MARKET RISKS

 

Market Risks and Risk Management

 

Our primary market risk exposure relates to fluctuations in commodity prices. See “Quantitative and Qualitative Disclosures About Non-Trading and Trading Activities and Related Market Risks” in Item 7A of our Form 10-K.

 

Non-Trading Market Risks

 

Commodity Price Risk

 

We assess the risk of our non-trading derivatives using a sensitivity analysis that measures the potential loss in fair value based on a hypothetical 10% movement in the underlying energy prices. The income (loss) impacts from our sensitivity analysis are:

 

As of

 

Market Prices

 

Fair Value of
Cash Flow Hedges

 

Earnings Impact of
Other Derivatives

 

Total Potential
Change in Fair Value

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

June 30, 2006

 

10% decrease

 

$

11

 

$

(198

)

$

(187

)

December 31, 2005

 

10% decrease

 

(19

)

(174

)

(193

)

 

As of June 30, 2006, the fair values of the contracts related to our net non-trading derivative assets and liabilities are:

 

Source of Fair Value

 

Twelve
Months
Ending
June 30,
2007

 

Remainder
of 2007

 

2008

 

2009

 

2010

 

2011 and
thereafter

 

Total fair
value

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Prices actively quoted

 

$

(328

)

$

(70

)

$

(154

)

$

7

 

$

1

 

$

 

$

(544

)

Prices provided by other external sources

 

142

 

114

 

72

 

(3

)

 

 

325

 

Prices based on models and other valuation methods

 

(27

)

(7

)

55

 

7

 

4

 

22

 

54

 

Total mark-to-market non- trading derivatives

 

(213

)

37

 

(27

)

11

 

5

 

22

 

(165

)

Cash flow hedges

 

(278

)

(69

)

(53

)

(28

)

(27

)

(39

)

(494

)

Total

 

$

(491

)

$

(32

)

$

(80

)

$

(17

)

$

(22

)

$

(17

)

$

(659

)

 

Interest Rate Risk

 

We assess interest rate risks using a sensitivity analysis that measures the potential change in our interest expense based on a hypothetical one percentage point movement in the underlying variable interest rate indices. If interest rates increased (decreased) one percentage point from their June 30, 2006 and December 31, 2005 levels, our annual interest expense would have increased (decreased) by $16 million and $18 million, respectively, and our annual interest expense, net of interest income, would not have changed significantly.

 

We estimated these amounts by considering the impact of hypothetical changes of interest rates on our variable-rate debt adjusted for:  cash and cash equivalents and net margin deposits outstanding at the respective balance sheet dates.

 

If interest rates decreased by one percentage point from their June 30, 2006 and December 31, 2005 levels, the fair market values of our fixed-rate debt would have increased by $196 million and $200 million, respectively.

 

46



 

Trading Market Risks

 

As of June 30, 2006, the fair values of the contracts related to our legacy trading positions and recorded as net derivative assets and liabilities are:

 

Source of Fair Value

 

Twelve
Months
Ending
June 30,
2007

 

Remainder
of 2007

 

2008

 

2009

 

2010

 

2011 and
thereafter

 

Total fair
value

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Prices actively quoted

 

$

(14

)

$

(19

)

$

(48

)

$

(15

)

$

 

$

 

$

(96

)

Prices provided by other external sources

 

19

 

19

 

55

 

16

 

 

 

109

 

Prices based on models and other valuation methods

 

(11

)

(2

)

(3

)

 

 

 

(16

)

Total

 

$

(6

)

$

(2

)

$

4

 

$

1

 

$

 

$

 

$

(3

)

 

Our consolidated realized and unrealized margins relating to these positions are (income (loss)):

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

2006

 

2005

 

 

 

(in millions)

 

 

 

 

 

 

 

 

 

 

 

Realized

 

$

 

$

4

 

$

(4

)

$

(12

)

Unrealized

 

 

(4

)

14

 

(4

)

Total

 

$

 

$

 

$

10

 

$

(16

)

 

An analysis of these net derivative assets and liabilities is:

 

 

 

Six Months Ended June 30,

 

 

 

2006

 

2005

 

 

 

(in millions)

 

 

 

 

 

 

 

Fair value of contracts outstanding, beginning of period

 

$

(20

)

$

26

 

Contracts realized or settled

 

(1

)(1)

11

(2)

Contracts transferred to non-trading

 

 

(4

)

Changes in valuation techniques

 

(8

)

 

Changes in fair values attributable to market price and other market changes

 

26

 

(18

)

Fair value of contracts outstanding, end of period

 

$

(3

)

$

15

 

 


(1)              Amount includes realized loss of $4 million offset by deferred settlements of $5 million.

(2)              Amount includes realized loss of $12 million offset by deferred settlements of $1 million.

 

The daily value-at-risk for most of our legacy trading positions is:

 

 

 

2006(1)

 

2005

 

 

 

(in millions)

 

 

 

 

 

 

 

As of June 30

 

$

2

 

$

1

 

Three months ended June 30:

 

 

 

 

 

Average

 

2

 

2

 

High

 

3

 

3

 

Low

 

2

 

1

 

Six months ended June 30:

 

 

 

 

 

Average

 

3

 

2

 

High

 

7

 

3

 

Low

 

2

 

 

 


(1)              The major parameters for calculating daily value-at-risk remain the same during 2006 as disclosed in “Quantitative and Qualitative Disclosures About Non-Trading and Trading Activities and Related Market Prices” in Item 7A of our Form 10-K.

 

47



 

ITEM 4.                 CONTROLS AND PROCEDURES

 

Evaluation of Disclosure Controls and Procedures

 

Our management, with the participation of our chief executive officer and chief financial officer, have evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934 (1934 Act)) as of June 30, 2006, the end of the period covered by this Form 10-Q. Based on this evaluation, our chief executive officer and chief financial officer concluded that, as of June 30, 2006, our disclosure controls and procedures were effective.

 

Changes in Internal Control Over Financial Reporting

 

There were no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the 1934 Act) during the period ended June 30, 2006, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

 

PART II.
OTHER INFORMATION

 

ITEM 1.          LEGAL PROCEEDINGS

 

See note 10 to our interim financial statements in this Form 10-Q.

 

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

 

In the second quarter of 2006, we issued 10,489 shares of unregistered common stock for warrants and 35,633 shares of unregistered common stock for $181,372 in cash pursuant to warrant exercises under an exemption pursuant to Section 4(2) of the Securities Act of 1933, as amended.

 

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

 

We held our annual meeting of our stockholders on May 19, 2006. Our stockholders voted on the following proposals:

 

1.               To elect three directors to our Board of Directors;

 

2.               To ratify the Audit Committee’s selection of KPMG LLP as our independent auditors for 2006; and

 

3.               To vote on a stockholder proposal requesting that the Board of Directors take action required to eliminate the classified structure of the Board.

 

The voting results were:

 

Joel V. Staff was re-elected to serve as a Class I director:

 

For

 

Withheld

 

240,444,248

 

37,519,508

 

 

Kirbyjon H. Caldwell was re-elected to serve as a Class I director:

 

For

 

Withheld

 

236,023,384

 

41,940,372

 

 

Steven L. Miller was re-elected to serve as a Class I director:

 

For

 

Withheld

 

236,261,143

 

41,702,613

 

 

48



 

The Audit Committee’s selection of KPMG LLP as our independent auditors for the fiscal year ended December 31, 2006 was ratified:

 

For

 

Against

 

Abstain

 

276,350,139

 

944,827

 

668,790

 

 

A non-binding stockholder proposal requesting that the Board of Directors take action required to eliminate the classified structure of the Board was approved:

 

For

 

Against

 

Abstain

 

189,931,143

 

15,307,448

 

4,822,707

 

 

There were 67,897,176 broker non-votes.

 

On April 18, 2006, we entered into a settlement agreement with a stockholder, Seneca Capital, L.P. Under the terms of the agreement, we agreed to appoint a representative of a substantial institutional shareholder to our board of directors by September 1, 2006.

 

ITEM 6.          EXHIBITS

 

Exhibits.

 

See Index of Exhibits.

 

49



 

SIGNATURE

 

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

 

 

 

RELIANT ENERGY, INC.

 

 

(Registrant)

 

 

 

 

 

 

August 8, 2006

 

By:

/s/ Thomas C. Livengood

 

 

 

 

 

  Thomas C. Livengood

 

 

Senior Vice President and Controller

 

 

(Duly Authorized Officer and Chief Accounting Officer)

 

 



 

INDEX OF EXHIBITS

 

Exhibits not incorporated by reference to a prior filing are designated by a cross (+); all exhibits not so designated are incorporated herein by reference to a prior filing as indicated. The exhibits with the asterisk symbol (*) are compensatory arrangements filed pursuant to Item 601(b)(10)(iii) of Regulation S-K.

 

Exhibit
Number

 

Document Description

 

Report or Registration
Statement

 

SEC File or
Registration
Number

 

Exhibit
Reference

 

 

 

 

 

 

 

 

 

 

 

3.1

 

 

Restated Certificate of Incorporation

 

Reliant Energy, Inc.’s Amendment No. 8 to Registration Statement on Form S-1 dated April 27, 2001

 

333-48038

 

3.1

 

 

 

 

 

 

 

 

 

 

 

 

3.2

 

 

Second Amended and Restated Bylaws

 

Reliant Energy, Inc.’s Current Report on Form 8-K dated September 21, 2004

 

1-16455

 

99.1

 

 

 

 

 

 

 

 

 

 

 

 

3.3

 

 

Certificate of Ownership and Merger Merging a Wholly-owned Subsidiary into Registrant Pursuant to Section 253 of the General Corporation Law of the State of Delaware, effective as of April 26, 2004

 

Reliant Energy, Inc.’s Current Report on Form 8-K dated April 26, 2004

 

1-16455

 

3.1

 

 

 

 

 

 

 

 

 

 

 

 

4.1

 

 

Registrant has omitted instruments with respect to long-term debt in an amount that does not exceed 10% of the registrant’s total assets and its subsidiaries on a consolidated basis and hereby undertakes to furnish a copy of any such agreement to the Securities and Exchange Commission upon request

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

*10.1

 

 

Form of 2002 Long-Term Incentive Plan Restricted Stock Award Agreement for Directors

 

Reliant Energy, Inc.’s Current Report on Form 8-K dated May 25, 2006

 

1-16455

 

10.1

 

 

 

 

 

 

 

 

 

 

 

 

10.2

 

 

Settlement Agreement between Reliant Energy, Inc. and Seneca Capital, L.P., dated as of April 18, 2006

 

Reliant Energy, Inc.’s Current Report on Form 8-K dated April 18, 2006

 

1-16455

 

10.1

 

 

 

 

 

 

 

 

 

 

 

 

10.2

 

 

Amendment No. 3 to Second Amended and Restated Credit and Guaranty Agreement among (i) Reliant Energy, Inc., as Borrower; (ii) the Other Loan Parties referred to therein, as Guarantors; (iii) the Lenders party thereto; and (iv) Bank of America, N.A., as Administrative Agent, dated as of May 17, 2006

 

Reliant Energy, Inc.’s Current Report on Form 8-K dated May 22, 2006

 

1-16455

 

10.1

 

 

 

 

 

 

 

 

 

 

 

 

10.3

 

 

Amendment No. 3 to Credit and Guaranty Agreement between (i) Reliant Energy, Inc., as Borrower; (ii) the Other Loan Parties, as Guarantors; (iii) the Other Lenders; and (iv) Deutsche Bank AG, New York Branch, as Administrative Agent, dated as of May 17, 2006

 

Reliant Energy, Inc.’s Current Report on Form 8-K dated May 22, 2006

 

1-16455

 

10.2

 

 

 

 

 

 

 

 

 

 

 

 

10.4

 

 

Amendment No. 4 to Second Amended and Restated Credit and Guaranty Agreement among (i) Reliant Energy, Inc., as Borrower; (ii) the Other Loan Parties referred to therein, as Guarantors; (iii) the Lenders party thereto; and (iv) Bank of America, N.A., as Administrative Agent, dated as of May 17, 2006

 

Reliant Energy, Inc.’s Current Report on Form 8-K dated May 22, 2006

 

1-16455

 

10.3

 

 

 

 

 

 

 

 

 

 

 

 

+31.1

 

 

Certification of the Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

+31.2

 

 

Certification of the Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

+32.1

 

 

Certification of Chief Executive Officer and Chief Financial Officer pursuant to Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

 

 

 

 

 

 

 

 



 

Exhibit
Number

 

Document Description

 

Report or Registration
Statement

 

SEC File or
Registration
Number

 

Exhibit
Reference

 

 

 

 

 

 

 

 

 

 

 

+99.1

 

 

Reliant Energy, Inc.’s note 12 to its consolidated financial statements in its Annual Report on Form 10-K for the year ended December 31, 2005

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

+99.2

 

 

Reliant Energy, Inc.’s note 10 to its unaudited interim financial statements in its Quarterly Report on Form 10-Q for the period ended March 31, 2006