x
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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¨
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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Entity
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Commission
File Number
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State of
Incorporation
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I.R.S. Employer
Identification No.
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Dynegy Inc.
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001-33443
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Delaware
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20-5653152
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Dynegy Holdings Inc.
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000-29311
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Delaware
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94-3248415
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1000 Louisiana, Suite 5800
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|||
Houston, Texas
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77002
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||
(Address of principal executive offices)
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(Zip Code)
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Dynegy Inc.
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Yes
x
No
¨
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Dynegy Holdings Inc.
|
Yes
x
No
¨
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Dynegy Inc.
|
Yes
x
No
¨
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Dynegy Holdings Inc.
|
Yes
¨
No
¨
|
Large accelerated filer
|
Accelerated filer
|
Non-accelerated filer
|
Smaller reporting company
|
|||||
(Do not check if a smaller reporting company)
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||||||||
Dynegy Inc.
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x
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¨
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¨
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¨
|
||||
Dynegy Holdings Inc.
|
¨
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¨
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x
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¨
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Dynegy Inc.
|
Yes
¨
No
x
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Dynegy Holdings Inc.
|
Yes
¨
No
x
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Page
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PART I. FINANCIAL INFORMATION
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Item 1.
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FINANCIAL STATEMENTS—DYNEGY INC. AND DYNEGY HOLDINGS INC.:
|
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4
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5
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6
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7
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8
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9
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10
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11
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12
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Item 2.
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33
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Item 3.
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53
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Item 4.
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54
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PART II. OTHER INFORMATION
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Item 1.
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55
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Item 1A.
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55
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Item 2.
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55
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Item 6.
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55
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ACES
APB
|
The American Clean Energy and Security Act of 2009
Accounting Principles Board
|
BACT
|
Best available control technology (air)
|
BART
|
Best available retrofit technology
|
BTA
|
Best technology available
|
Cal ISO
|
The California Independent System Operator
|
CARB
|
California Air Resources Board
|
CAA
|
Clean Air Act
|
CCA
|
Coal combustion ash
|
CCR
|
Coal combustion residuals
|
CDWR
|
California Department of Water Resources
|
CEC
|
California Energy Commission
|
CFTC
|
Commodity Futures Trading Commission
|
CO
2
|
Carbon Dioxide
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CRM
|
Our former customer risk management business segment
|
CUSA
|
Chevron U.S.A. Inc., a wholly owned subsidiary of Chevron Corporation
|
DHI
|
Dynegy Holdings Inc.
|
DMG
|
Dynegy Midwest Generation, Inc.
|
DMSLP
|
Dynegy Midstream Services L.P.
|
EPA
|
Environmental Protection Agency
|
FERC
|
Federal Energy Regulatory Commission
|
GAAP
|
Generally Accepted Accounting Principles of the United States of America
|
GEN
|
Our power generation business
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GEN-MW
|
Our power generation business - Midwest segment
|
GEN-NE
|
Our power generation business - Northeast segment
|
GEN-WE
|
Our power generation business - West segment
|
GHG
|
Greenhouse Gas
|
ICC
|
Illinois Commerce Commission
|
IMA
|
In-market asset availability
|
ISO
|
Independent System Operator
|
LNG
|
Liquefied natural gas
|
MISO
|
Midwest Independent Transmission Operator, Inc.
|
MMBtu
|
One million British thermal units
|
MW
|
Megawatts
|
MWh
|
Megawatt hour
|
NPDES
|
National Pollutant Discharge Elimination System
|
NRG
|
NRG Energy, Inc.
|
NYSDEC
|
New York State Department of Environmental Conservation
|
OAL
|
Office of Administrative Law
|
OTC
|
Over-the-counter
|
PJM
|
PJM Interconnection, LLC
|
PPEA
|
Plum Point Energy Associates, LLC
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PSD
|
Prevention of significant deterioration
|
PUHCA
|
Public Utility Holding Company Act of 1935, as amended
|
RCRA
|
Resource Conservation and Recovery Act
|
RGGI
|
Regional Greenhouse Gas Initiative
|
RMR
|
Reliability Must Run
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RSG
|
Revenue Sufficiency Guarantee
|
SCEA
|
Sandy Creek Energy Associates, LP
|
SCH
|
Sandy Creek Holdings LLC
|
SEC
|
U.S. Securities and Exchange Commission
|
SPDES
|
State Pollutant Discharge Elimination System
|
VaR
|
Value at Risk
|
VIE
|
Variable Interest Entity
|
June 30,
2010
|
December 31,
2009
|
|||||||
ASSETS
|
||||||||
Current Assets
|
||||||||
Cash and cash equivalents
|
$ | 282 | $ | 471 | ||||
Restricted cash and investments
|
87 | 78 | ||||||
Short-term investments
|
219 | 9 | ||||||
Accounts receivable, net of allowance for doubtful accounts of $36 and $22, respectively
|
198 | 212 | ||||||
Accounts receivable, affiliates
|
1 | 2 | ||||||
Inventory
|
136 | 141 | ||||||
Assets from risk-management activities
|
1,203 | 713 | ||||||
Deferred income taxes
|
7 | 6 | ||||||
Broker margin account
|
116 | 286 | ||||||
Prepayments and other current assets
|
110 | 120 | ||||||
Total Current Assets
|
2,359 | 2,038 | ||||||
Property, Plant and Equipment
|
8,610 | 9,071 | ||||||
Accumulated depreciation
|
(2,081 | ) | (1,954 | ) | ||||
Property, Plant and Equipment, Net
|
6,529 | 7,117 | ||||||
Other Assets
|
||||||||
Restricted cash and investments
|
859 | 877 | ||||||
Assets from risk-management activities
|
300 | 163 | ||||||
Intangible assets
|
165 | 380 | ||||||
Other long-term assets
|
384 | 378 | ||||||
Total Assets
|
$ | 10,596 | $ | 10,953 | ||||
LIABILITIES AND STOCKHOLDERS’ EQUITY
|
||||||||
Current Liabilities
|
||||||||
Accounts payable
|
$ | 138 | $ | 181 | ||||
Accounts payable, affiliates
|
8 | — | ||||||
Accrued interest
|
36 | 36 | ||||||
Accrued liabilities and other current liabilities
|
102 | 127 | ||||||
Liabilities from risk-management activities
|
1,133 | 696 | ||||||
Notes payable and current portion of long-term debt
|
146 | 807 | ||||||
Total Current Liabilities
|
1,563 | 1,847 | ||||||
Long-term debt
|
4,460 | 4,575 | ||||||
Long-term debt, affiliates
|
200 | 200 | ||||||
Long-Term Debt
|
4,660 | 4,775 | ||||||
Other Liabilities
|
||||||||
Liabilities from risk-management activities
|
362 | 213 | ||||||
Deferred income taxes
|
759 | 780 | ||||||
Other long-term liabilities
|
342 | 359 | ||||||
Total Liabilities
|
$ | 7,686 | $ | 7,974 | ||||
Commitments and Contingencies (Note 12)
|
||||||||
Stockholders’ Equity (Note 15)
|
||||||||
Common Stock, $0.01 par value, 420,000,000 shares authorized at June 30, 2010 and December 31, 2009, and 121,115,507 and 120,715,515 shares issued and outstanding at June 30, 2010 and December 31, 2009, respectively
|
1 | 1 | ||||||
Additional paid-in capital
|
6,062 | 6,061 | ||||||
Subscriptions receivable
|
(2 | ) | (2 | ) | ||||
Accumulated other comprehensive loss, net of tax
|
(71 | ) | (150 | ) | ||||
Accumulated deficit
|
(3,009 | ) | (2,937 | ) | ||||
Treasury stock, at cost, 627,607 and 557,677 shares at June 30, 2010 and December 31, 2009, respectively
|
(71 | ) | (71 | ) | ||||
Total Dynegy Inc. Stockholders’ Equity
|
2,910 | 2,902 | ||||||
Noncontrolling interests
|
— | 77 | ||||||
Total Stockholders’ Equity
|
2,910 | 2,979 | ||||||
Total Liabilities and Stockholders’ Equity
|
$ | 10,596 | $ | 10,953 |
Three Months Ended June 30,
|
Six Months Ended June 30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
Revenues
|
$ | 239 | $ | 450 | $ | 1,097 | $ | 1,354 | ||||||||
Cost of sales
|
(231 | ) | (263 | ) | (539 | ) | (641 | ) | ||||||||
Operating and maintenance expense, exclusive of depreciation shown separately below
|
(118 | ) | (137 | ) | (231 | ) | (252 | ) | ||||||||
Depreciation and amortization expense
|
(90 | ) | (89 | ) | (165 | ) | (175 | ) | ||||||||
Goodwill impairments
|
— | — | — | (433 | ) | |||||||||||
Impairment and other charges, exclusive of goodwill impairments shown separately above
|
(1 | ) | (387 | ) | (1 | ) | (387 | ) | ||||||||
General and administrative expenses
|
(28 | ) | (45 | ) | (59 | ) | (83 | ) | ||||||||
Operating income (loss)
|
(229 | ) | (471 | ) | 102 | (617 | ) | |||||||||
Earnings (losses) from unconsolidated investments
|
— | 13 | (34 | ) | 21 | |||||||||||
Interest expense
|
(91 | ) | (98 | ) | (180 | ) | (196 | ) | ||||||||
Other income and expense, net
|
1 | 4 | 2 | 8 | ||||||||||||
Loss from continuing operations before income taxes
|
(319 | ) | (552 | ) | (110 | ) | (784 | ) | ||||||||
Income tax benefit (Note 14)
|
128 | 204 | 63 | 113 | ||||||||||||
Loss from continuing operations
|
(191 | ) | (348 | ) | (47 | ) | (671 | ) | ||||||||
Income (loss) from discontinued operations, net of tax benefit of zero, $1, zero and $7, respectively (Note 2)
|
— | 2 | 1 | (12 | ) | |||||||||||
Net loss
|
(191 | ) | (346 | ) | (46 | ) | (683 | ) | ||||||||
Less: Net loss attributable to the noncontrolling interests
|
— | (1 | ) | — | (3 | ) | ||||||||||
Net loss attributable to Dynegy Inc.
|
$ | (191 | ) | $ | (345 | ) | $ | (46 | ) | $ | (680 | ) | ||||
Loss Per Share (Notes 11 and 15):
|
||||||||||||||||
Basic loss per share attributable to Dynegy Inc. common stockholders:
|
||||||||||||||||
Loss from continuing operations
|
$ | (1.59 | ) | $ | (2.06 | ) | $ | (0.39 | ) | $ | (3.98 | ) | ||||
Income (loss) from discontinued operations
|
— | 0.01 | 0.01 | (0.07 | ) | |||||||||||
Basic loss per share attributable to Dynegy Inc. common stockholders
|
$ | (1.59 | ) | $ | (2.05 | ) | $ | (0.38 | ) | $ | (4.05 | ) | ||||
Diluted loss per share attributable to Dynegy Inc. common stockholders:
|
||||||||||||||||
Loss from continuing operations
|
$ | (1.59 | ) | $ | (2.06 | ) | $ | (0.39 | ) | $ | (3.98 | ) | ||||
Income (loss) from discontinued operations
|
— | 0.01 | 0.01 | (0.07 | ) | |||||||||||
Diluted loss per share attributable to Dynegy Inc. common stockholders
|
$ | (1.59 | ) | $ | (2.05 | ) | $ | (0.38 | ) | $ | (4.05 | ) | ||||
Basic shares outstanding
|
120 | 168 | 120 | 168 | ||||||||||||
Diluted shares outstanding
|
121 | 169 | 121 | 169 |
Six Months Ended
June 30,
|
||||||||
2010
|
2009
|
|||||||
CASH FLOWS FROM OPERATING ACTIVITIES:
|
||||||||
Net loss
|
$ | (46 | ) | $ | (683 | ) | ||
Adjustments to reconcile net loss to net cash flows from operating activities:
|
||||||||
Depreciation and amortization
|
172 | 189 | ||||||
Goodwill impairments
|
— | 433 | ||||||
Impairment and other charges, exclusive of goodwill impairments shown separately above
|
1 | 410 | ||||||
(Earnings) losses from unconsolidated investments, net of cash distributions
|
34 | (21 | ) | |||||
Risk-management activities
|
8 | (65 | ) | |||||
Gain on sale of assets
|
— | (10 | ) | |||||
Deferred income taxes
|
(62 | ) | (129 | ) | ||||
Other
|
30 | 43 | ||||||
Changes in working capital:
|
||||||||
Accounts receivable
|
14 | 35 | ||||||
Inventory
|
3 | (9 | ) | |||||
Broker margin account
|
255 | (80 | ) | |||||
Prepayments and other assets
|
8 | (8 | ) | |||||
Accounts payable and accrued liabilities
|
(36 | ) | (13 | ) | ||||
Changes in non-current assets
|
(17 | ) | (38 | ) | ||||
Changes in non-current liabilities
|
4 | 6 | ||||||
Net cash provided by operating activities
|
368 | 60 | ||||||
CASH FLOWS FROM INVESTING ACTIVITIES:
|
||||||||
Capital expenditures
|
(201 | ) | (303 | ) | ||||
Unconsolidated investments
|
(15 | ) | 1 | |||||
Proceeds from asset sales, net
|
— | 105 | ||||||
Maturities of short-term investments
|
36 | 14 | ||||||
Purchases of short-term investments
|
(331 | ) | — | |||||
Increase in restricted cash and restricted investments
|
(10 | ) | (33 | ) | ||||
Other investing
|
— | 3 | ||||||
Net cash used in investing activities
|
(521 | ) | (213 | ) | ||||
CASH FLOWS FROM FINANCING ACTIVITIES:
|
||||||||
Proceeds from long-term borrowings, net of financing costs
|
(5 | ) | 54 | |||||
Repayments of borrowings
|
(31 | ) | — | |||||
Net cash (used in) provided by financing activities
|
(36 | ) | 54 | |||||
Net decrease in cash and cash equivalents
|
(189 | ) | (99 | ) | ||||
Cash and cash equivalents, beginning of period
|
471 | 693 | ||||||
Cash and cash equivalents, end of period
|
$ | 282 | $ | 594 | ||||
Other non-cash investing activity:
|
||||||||
Non-cash capital expenditures
|
$ | 6 | $ | 42 |
Three Months Ended
June 30,
|
||||||||
2010
|
2009
|
|||||||
Net loss
|
$ | (191 | ) | $ | (346 | ) | ||
Cash flow hedging activities, net:
|
||||||||
Unrealized mark-to-market gains arising during period, net
|
— | 81 | ||||||
Deferred losses on cash flow hedges, net
|
— | (3 | ) | |||||
Changes in cash flow hedging activities, net (net of tax expense of zero and $7, respectively)
|
— | 78 | ||||||
Amortization of unrecognized prior service cost and actuarial gain (net of tax (expense) benefit of $(1) and $2)
|
— | 3 | ||||||
Unconsolidated investments other comprehensive income, net (net of tax expense of zero and $2)
|
— | 5 | ||||||
Other comprehensive income, net of tax
|
— | 86 | ||||||
Comprehensive loss
|
(191 | ) | (260 | ) | ||||
Less: Comprehensive income attributable to the noncontrolling interests
|
— | 56 | ||||||
Comprehensive loss attributable to Dynegy Inc.
|
$ | (191 | ) | $ | (316 | ) |
Six Months Ended
June 30,
|
||||||||
2010
|
2009
|
|||||||
Net loss
|
$ | (46 | ) | $ | (683 | ) | ||
Cash flow hedging activities, net:
|
||||||||
Unrealized mark-to-market gains arising during period, net
|
— | 115 | ||||||
Deferred losses on cash flow hedges, net
|
— | (6 | ) | |||||
Changes in cash flow hedging activities, net (net of tax expense of zero and $16, respectively)
|
— | 109 | ||||||
Amortization of unrecognized prior service cost and actuarial gain (net of tax expense of $1 and $1)
|
2 | 2 | ||||||
Unconsolidated investments other comprehensive income, net (net of tax expense of zero and $4)
|
— | 6 | ||||||
Other comprehensive income, net of tax
|
2 | 117 | ||||||
Comprehensive loss
|
(44 | ) | (566 | ) | ||||
Less: Comprehensive income attributable to the noncontrolling interests
|
— | 82 | ||||||
Comprehensive loss attributable to Dynegy Inc.
|
$ | (44 | ) | $ | (648 | ) |
June 30,
2010
|
December 31,
2009
|
|||||||
ASSETS
|
||||||||
Current Assets
|
||||||||
Cash and cash equivalents
|
$ | 244 | $ | 419 | ||||
Restricted cash and investments
|
87 | 78 | ||||||
Short-term investments
|
204 | 8 | ||||||
Accounts receivable, net of allowance for doubtful accounts of $17 and $20, respectively
|
195 | 214 | ||||||
Accounts receivable, affiliates
|
1 | 2 | ||||||
Inventory
|
136 | 141 | ||||||
Assets from risk-management activities
|
1,203 | 713 | ||||||
Deferred income taxes
|
6 | 7 | ||||||
Broker margin account
|
116 | 286 | ||||||
Prepayments and other current assets
|
110 | 120 | ||||||
Total Current Assets
|
2,302 | 1,988 | ||||||
Property, Plant and Equipment
|
8,610 | 9,071 | ||||||
Accumulated depreciation
|
(2,081 | ) | (1,954 | ) | ||||
Property, Plant and Equipment, Net
|
6,529 | 7,117 | ||||||
Other Assets
|
||||||||
Restricted cash and investments
|
859 | 877 | ||||||
Assets from risk-management activities
|
300 | 163 | ||||||
Intangible assets
|
165 | 380 | ||||||
Other long-term assets
|
384 | 378 | ||||||
Total Assets
|
$ | 10,539 | $ | 10,903 | ||||
LIABILITIES AND STOCKHOLDERS’ EQUITY
|
||||||||
Current Liabilities
|
||||||||
Accounts payable
|
$ | 138 | $ | 181 | ||||
Accounts payable, affiliates
|
8 | — | ||||||
Accrued interest
|
36 | 36 | ||||||
Accrued liabilities and other current liabilities
|
102 | 128 | ||||||
Liabilities from risk-management activities
|
1,133 | 696 | ||||||
Notes payable and current portion of long-term debt
|
146 | 807 | ||||||
Total Current Liabilities
|
1,563 | 1,848 | ||||||
Long-term debt
|
4,460 | 4,575 | ||||||
Long-term debt, affiliates
|
200 | 200 | ||||||
Long-Term Debt
|
4,660 | 4,775 | ||||||
Other Liabilities
|
||||||||
Liabilities from risk-management activities
|
362 | 213 | ||||||
Deferred income taxes
|
685 | 704 | ||||||
Other long-term liabilities
|
342 | 360 | ||||||
Total Liabilities
|
7,612 | 7,900 | ||||||
Commitments and Contingencies (Note 12)
|
||||||||
Stockholders’ Equity
|
||||||||
Capital Stock, $1 par value, 1,000 shares authorized at June 30, 2010 and December 31, 2009
|
— | — | ||||||
Additional paid-in capital
|
5,135 | 5,135 | ||||||
Affiliate receivable
|
(777 | ) | (777 | ) | ||||
Accumulated other comprehensive loss, net of tax
|
(71 | ) | (150 | ) | ||||
Accumulated deficit
|
(1,360 | ) | (1,282 | ) | ||||
Total Dynegy Holdings Inc. Stockholder’s Equity
|
2,927 | 2,926 | ||||||
Noncontrolling interests
|
— | 77 | ||||||
Total Stockholders’ Equity
|
2,927 | 3,003 | ||||||
Total Liabilities and Stockholders’ Equity
|
$ | 10,539 | $ | 10,903 |
Three Months Ended June 30,
|
Six Months Ended June 30,
|
||||||||||||||
2010
|
2009
|
2010
|
2009
|
||||||||||||
Revenues
|
$ | 239 | $ | 450 | $ | 1,097 | $ | 1,354 | |||||||
Cost of sales
|
(231 | ) | (263 | ) | (539 | ) | (641 | ) | |||||||
Operating and maintenance expense, exclusive of depreciation
shown separately below
|
(118 | ) | (137 | ) | (231 | ) | (254 | ) | |||||||
Depreciation and amortization expense
|
(90 | ) | (89 | ) | (165 | ) | (175 | ) | |||||||
Goodwill impairments
|
— | — | — | (433 | ) | ||||||||||
Impairment and other charges, exclusive of goodwill impairments shown separately above
|
(1 | ) | (387 | ) | (1 | ) | (387 | ) | |||||||
General and administrative expenses
|
(28 | ) | (45 | ) | (59 | ) | (83 | ) | |||||||
Operating income (loss)
|
(229 | ) | (471 | ) | 102 | (619 | ) | ||||||||
Earnings (losses) from unconsolidated investments
|
— | 13 | (34 | ) | 20 | ||||||||||
Interest expense
|
(91 | ) | (98 | ) | (180 | ) | (196 | ) | |||||||
Other income and expense, net
|
1 | 3 | 2 | 7 | |||||||||||
Loss from continuing operations before income taxes
|
(319 | ) | (553 | ) | (110 | ) | (788 | ) | |||||||
Income tax benefit (Note 14)
|
128 | 205 | 56 | 117 | |||||||||||
Loss from continuing operations
|
(191 | ) | (348 | ) | (54 | ) | (671 | ) | |||||||
Income (loss) from discontinued operations, net of tax benefit of zero, $11, zero and $17, respectively (Note 2)
|
— | 12 | 1 | (2 | ) | ||||||||||
Net loss
|
(191 | ) | (336 | ) | (53 | ) | (673 | ) | |||||||
Less: Net loss attributable to the noncontrolling interests
|
— | (1 | ) | — | (3 | ) | |||||||||
Net loss attributable to Dynegy Holdings Inc.
|
$ | (191 | ) | $ | (335 | ) | $ | (53 | ) | $ | (670 | ) |
Six Months Ended
June 30,
|
||||||||
2010
|
2009
|
|||||||
CASH FLOWS FROM OPERATING ACTIVITIES:
|
||||||||
Net loss
|
$ | (53 | ) | $ | (673 | ) | ||
Adjustments to reconcile net loss to net cash flows from operating activities:
|
||||||||
Depreciation and amortization
|
172 | 189 | ||||||
Goodwill impairments
|
— | 433 | ||||||
Impairment and other charges, exclusive of goodwill impairments shown separately above
|
1 | 410 | ||||||
(Earnings) losses from unconsolidated investments, net of cash distributions
|
34 | (20 | ) | |||||
Risk-management activities
|
8 | (65 | ) | |||||
Gain on sale of assets, net
|
— | (10 | ) | |||||
Deferred income taxes
|
(55 | ) | (139 | ) | ||||
Other
|
27 | 43 | ||||||
Changes in working capital:
|
||||||||
Accounts receivable
|
19 | 35 | ||||||
Inventory
|
3 | (9 | ) | |||||
Broker margin account
|
255 | (80 | ) | |||||
Prepayments and other assets
|
8 | (8 | ) | |||||
Accounts payable and accrued liabilities
|
(37 | ) | 5 | |||||
Changes in non-current assets
|
(17 | ) | (38 | ) | ||||
Changes in non-current liabilities
|
4 | 7 | ||||||
Net cash provided by operating activities
|
369 | 80 | ||||||
CASH FLOWS FROM INVESTING ACTIVITIES:
|
||||||||
Capital expenditures
|
(201 | ) | (303 | ) | ||||
Unconsolidated investments
|
(15 | ) | — | |||||
Proceeds from asset sales, net
|
— | 105 | ||||||
Maturities of short-term investments
|
36 | 13 | ||||||
Purchases of short-term investments
|
(316 | ) | — | |||||
Increase in restricted cash and restricted investments
|
(10 | ) | (33 | ) | ||||
Affiliate transactions
|
(2 | ) | (3 | ) | ||||
Other investing
|
— | 3 | ||||||
Net cash used in investing activities
|
(508 | ) | (218 | ) | ||||
CASH FLOWS FROM FINANCING ACTIVITIES:
|
||||||||
Proceeds from long-term borrowings, net of financing costs
|
(5 | ) | 54 | |||||
Repayments of borrowings
|
(31 | ) | — | |||||
Dividend to affiliate
|
— | (175 | ) | |||||
Net cash used in financing activities
|
(36 | ) | (121 | ) | ||||
Net decrease in cash and cash equivalents
|
(175 | ) | (259 | ) | ||||
Cash and cash equivalents, beginning of period
|
419 | 670 | ||||||
Cash and cash equivalents, end of period
|
$ | 244 | $ | 411 | ||||
Other non-cash investing activity:
|
||||||||
Non-cash capital expenditures
|
$ | 6 | $ | 42 |
Three Months Ended
June 30,
|
||||||||
2010
|
2009
|
|||||||
Net loss
|
$ | (191 | ) | $ | (336 | ) | ||
Cash flow hedging activities, net:
|
||||||||
Unrealized mark-to-market gains arising during period, net
|
— | 81 | ||||||
Deferred losses on cash flow hedges, net
|
— | (3 | ) | |||||
Changes in cash flow hedging activities, net (net of tax expense of zero and $7, respectively)
|
— | 78 | ||||||
Amortization of unrecognized prior service cost and actuarial gain (net of tax (expense) benefit of $(1) and $2)
|
— | 3 | ||||||
Unconsolidated investments other comprehensive income, net (net of tax expense of zero and $2)
|
— | 5 | ||||||
Other comprehensive income, net of tax
|
— | 86 | ||||||
Comprehensive loss
|
(191 | ) | (250 | ) | ||||
Less: Comprehensive income attributable to the noncontrolling interests
|
— | 56 | ||||||
|
||||||||
Comprehensive loss attributable to Dynegy Holdings Inc.
|
$ | (191 | ) | $ | (306 | ) |
Six Months Ended
June 30,
|
||||||||
2010
|
2009
|
|||||||
Net loss
|
$ | (53 | ) | $ | (673 | ) | ||
Cash flow hedging activities, net:
|
||||||||
Unrealized mark-to-market gains arising during period, net
|
— | 115 | ||||||
Deferred losses on cash flow hedges, net
|
— | (6 | ) | |||||
Changes in cash flow hedging activities, net (net of tax expense of zero and $16, respectively)
|
— | 109 | ||||||
Amortization of unrecognized prior service cost and actuarial gain (net of tax expense of $1 and $1)
|
2 | 2 | ||||||
Unconsolidated investments other comprehensive income, net (net of tax expense of zero and $4)
|
— | 6 | ||||||
Other comprehensive income, net of tax
|
2 | 117 | ||||||
Comprehensive loss
|
(51 | ) | (556 | ) | ||||
Less: Comprehensive income attributable to the noncontrolling interests
|
— | 82 | ||||||
Comprehensive loss attributable to Dynegy Holdings Inc.
|
$ | (51 | ) | $ | (638 | ) |
Current assets
|
$ | 6 | ||
Property, plant and equipment, net
|
611 | |||
Intangible asset
|
190 | |||
Other non-current asset
|
20 | |||
Total assets
|
827 | |||
Current portion of long-term debt
|
744 | |||
Current liabilities
|
74 | |||
Noncontrolling interest
|
77 | |||
Accumulated other comprehensive loss
|
(157 | ) |
GEN-MW
|
GEN-WE
|
Total
|
||||||||||
(in millions)
|
||||||||||||
Three Months Ended June 30, 2009
|
||||||||||||
Revenues
|
$ | 2 | $ | 41 | $ | 43 | ||||||
Income (loss) from operations before taxes (1)
|
(17 | ) | 8 | (9 | ) | |||||||
Income (loss) from operations after taxes
|
(10 | ) | 6 | (4 | ) | |||||||
Gain on sale before taxes
|
— | 10 | 10 | |||||||||
Gain on sale after taxes
|
— | 6 | 6 | |||||||||
Six Months Ended June 30, 2010
|
||||||||||||
Revenues
|
$ | — | $ | — | $ | — | ||||||
Income from operations before taxes
|
— | 1 | 1 | |||||||||
Income from operations after taxes
|
— | 1 | 1 | |||||||||
Six Months Ended June 30, 2009
|
||||||||||||
Revenues
|
$ | 3 | $ | 42 | $ | 45 | ||||||
Loss from operations before taxes (2)
|
(23 | ) | (6 | ) | (29 | ) | ||||||
Loss from operations after taxes
|
(14 | ) | (4 | ) | (18 | ) | ||||||
Gain on sale before taxes
|
— | 10 | 10 | |||||||||
Gain on sale after taxes
|
— | 6 | 6 |
(1)
|
Includes $18 million of impairment charges related to our Bluegrass power generation facility in the GEN-MW segment.
|
(2)
|
Includes $23 million of impairment charges related to our Bluegrass power generation facility in the GEN-MW segment.
|
GEN-MW
|
GEN-WE
|
Total
|
||||||||||
(in millions)
|
||||||||||||
Three Months Ended June 30, 2009
|
||||||||||||
Revenues
|
$ | 2 | $ | 41 | $ | 43 | ||||||
Income (loss) from operations before taxes (1)
|
(17 | ) | 8 | (9 | ) | |||||||
Income (loss) from operations after taxes
|
(10 | ) | 10 | — | ||||||||
Gain on sale before taxes
|
— | 10 | 10 | |||||||||
Gain on sale after taxes
|
— | 12 | 12 | |||||||||
Six Months Ended June 30, 2010
|
||||||||||||
Revenues
|
$ | — | $ | — | $ | — | ||||||
Income from operations before taxes
|
— | 1 | 1 | |||||||||
Income from operations after taxes
|
— | 1 | 1 | |||||||||
Six Months Ended June 30, 2009
|
||||||||||||
Revenues
|
$ | 3 | $ | 42 | $ | 45 | ||||||
Loss from operations before taxes (2)
|
(23 | ) | (6 | ) | (29 | ) | ||||||
Loss from operations after taxes
|
(14 | ) | — | (14 | ) | |||||||
Gain on sale before taxes
|
— | 10 | 10 | |||||||||
Gain on sale after taxes
|
— | 12 | 12 |
(1)
|
Includes $18 million of impairment charges related to our Bluegrass power generation facility in the GEN-MW segment.
|
(2)
|
Includes $23 million of impairment charges related to our Bluegrass power generation facility in the GEN-MW segment.
|
Three Months Ended
June 30, 2009
|
||||||||
Dynegy Inc.
|
Dynegy Holdings Inc.
|
|||||||
(in millions)
|
||||||||
Loss from continuing operations
|
$ | (347 | ) | $ | (347 | ) | ||
Income from discontinued operations, net of tax benefit of $1 and $11, respectively
|
2 | 12 | ||||||
Net loss
|
$ | (345 | ) | $ | (335 | ) |
Six Months Ended
June 30, 2009
|
||||||||
Dynegy Inc.
|
Dynegy Holdings Inc.
|
|||||||
(in millions)
|
||||||||
Loss from continuing operations
|
$ | (668 | ) | $ | (668 | ) | ||
Loss from discontinued operations, net of tax benefit of $7 and $17, respectively
|
(12 | ) | (2 | ) | ||||
Net loss
|
$ | (680 | ) | $ | (670 | ) |
Controlling Interest
|
Noncontrolling Interests
|
Total
|
||||||||||
(in millions)
|
||||||||||||
December 31, 2008
|
$ | 4,515 | $ | (30 | ) | $ | 4,485 | |||||
Net loss
|
(680 | ) | (3 | ) | (683 | ) | ||||||
Other comprehensive income (loss), net of tax:
|
||||||||||||
Unrealized mark-to-market gains arising during period
|
25 | 90 | 115 | |||||||||
Reclassification of mark-to-market (gains) losses to earnings
|
(2 | ) | 2 | — | ||||||||
Deferred gains (losses) on cash flow hedges
|
1 | (7 | ) | (6 | ) | |||||||
Amortization of unrecognized prior service cost and actuarial gain
|
2 | — | 2 | |||||||||
Unconsolidated investments other comprehensive income
|
6 | — | 6 | |||||||||
Total other comprehensive income, net of tax
|
32 | 85 | 117 | |||||||||
Other equity activity:
|
||||||||||||
Options exercised
|
(1 | ) | — | (1 | ) | |||||||
Options and restricted stock granted
|
5 | — | 5 | |||||||||
401(k) plan and profit sharing stock
|
3 | — | 3 | |||||||||
Board of directors stock compensation
|
(2 | ) | — | (2 | ) | |||||||
June 30, 2009
|
$ | 3,872 | $ | 52 | $ | 3,924 |
Controlling Interest
|
Noncontrolling Interests
|
Total
|
||||||||||
(in millions)
|
||||||||||||
December 31, 2008
|
$ | 4,613 | $ | (30 | ) | $ | 4,583 | |||||
Net loss
|
(670 | ) | (3 | ) | (673 | ) | ||||||
Other comprehensive income (loss), net of tax:
|
||||||||||||
Unrealized mark-to-market gains arising during period
|
25 | 90 | 115 | |||||||||
Reclassification of mark-to-market (gains) losses to earnings
|
(2 | ) | 2 | — | ||||||||
Deferred gains (losses) on cash flow hedges
|
1 | (7 | ) | (6 | ) | |||||||
Amortization of unrecognized prior service cost and actuarial gain
|
2 | — | 2 | |||||||||
Unconsolidated investments other comprehensive income
|
6 | — | 6 | |||||||||
Total other comprehensive income, net of tax
|
32 | 85 | 117 | |||||||||
Other equity activity:
|
||||||||||||
Dividend to Dynegy
|
(175 | ) | — | (175 | ) | |||||||
Contribution from Dynegy
|
36 | — | 36 | |||||||||
June 30, 2009
|
$ | 3,836 | $ | 52 | $ | 3,888 |
Cost Basis
|
Gross Unrealized Gains
|
Gross Unrealized Losses
|
Fair Value
|
|||||||||||||
(in millions)
|
||||||||||||||||
Available for Sale investments:
|
||||||||||||||||
Commercial Paper
|
$ | 21 | $ | — | $ | — | $ | 21 | ||||||||
Certificates of Deposit
|
36 | — | — | 36 | ||||||||||||
Corporate Securities
|
22 | — | — | 22 | ||||||||||||
Non U.S. Government Securities
|
1 | — | — | 1 | ||||||||||||
U.S. Treasury and Government Securities (1)
|
210 | — | — | 210 | ||||||||||||
Total—DHI
|
$ | 290 | $ | — | $ | — | $ | 290 | ||||||||
Certificates of Deposit
|
3 | — | — | 3 | ||||||||||||
Corporate Securities
|
3 | — | — | 3 | ||||||||||||
U.S. Treasury and Government Securities
|
9 | — | — | 9 | ||||||||||||
Total—Dynegy
|
$ | 305 | $ | — | $ | — | $ | 305 |
(1)
|
Includes $86 million in Broker margin account on our consolidated balance sheets in support of transactions with our futures clearing manager
.
|
Contract Type
|
Hedge Designation
|
Quantity
|
Unit of Measure
|
Net Fair Value
|
|||||||
(in millions)
|
(in millions)
|
||||||||||
Commodity contracts:
|
|||||||||||
Electric energy (1)
|
Not designated
|
(93 | ) |
MW
|
$ | 261 | |||||
Natural gas (1)
|
Not designated
|
205 |
MMBtu
|
$ | (235 | ) | |||||
Heat rate derivatives
|
Not designated
|
(9)/77 |
MW/MMBtu
|
$ | (23 | ) | |||||
Other (2)
|
Not designated
|
2 |
Misc.
|
$ | 5 | ||||||
Interest rate contracts:
|
|||||||||||
Interest rate swaps
|
Fair value hedge
|
(25 | ) |
Dollars
|
$ | 1 | |||||
Interest rate swaps
|
Not designated
|
231 |
Dollars
|
$ | (10 | ) | |||||
Interest rate swaps
|
Not designated
|
(206 | ) |
Dollars
|
$ | 9 |
(1)
|
Mainly comprised of swaps, options and physical forwards.
|
(2)
|
Comprised of emissions, coal, crude oil, fuel oil options, swaps and physical forwards.
|
Derivatives Not Designated as Hedging
|
Location of Gain (Loss) Recognized in Income on
|
Amount of Gain (Loss) Recognized in Income on Derivatives for the
Three Months Ended June 30,
|
||||||||
Instruments
|
Derivatives
|
2010
|
2009
|
|||||||
(in millions)
|
||||||||||
Commodity contracts
|
Revenues
|
$ | (185 | ) | $ | 20 | ||||
Interest rate contracts
|
Interest expense
|
— | — |
Derivatives Not Designated as Hedging
|
Location of Gain (Loss) Recognized in Income on
|
Amount of Gain (Loss) Recognized in Income on Derivatives for the
Six Months Ended June 30,
|
||||||||
Instruments
|
Derivatives
|
2010
|
2009
|
|||||||
(in millions)
|
||||||||||
Commodity contracts
|
Revenues
|
$ | 140 | $ | 286 | |||||
Interest rate contracts
|
Interest expense
|
— | — |
Fair Value as of June 30, 2010
|
||||||||||||||||
Level 1
|
Level 2
|
Level 3
|
Total
|
|||||||||||||
(in millions)
|
||||||||||||||||
Assets:
|
||||||||||||||||
Assets from commodity risk management activities:
|
||||||||||||||||
Electricity derivatives
|
$ | — | $ | 711 | $ | 66 | $ | 777 | ||||||||
Natural gas derivatives
|
— | 680 | 5 | 685 | ||||||||||||
Heat rate derivatives
|
— | — | 7 | 7 | ||||||||||||
Other derivatives
|
— | 24 | — | 24 | ||||||||||||
Total assets from commodity risk management activities
|
$ | — | $ | 1,415 | $ | 78 | $ | 1,493 | ||||||||
Assets from interest rate swaps
|
— | 10 | — | 10 | ||||||||||||
Short-term investments:
|
||||||||||||||||
Commercial paper
|
— | 21 | — | 21 | ||||||||||||
Certificates of deposit
|
— | 36 | — | 36 | ||||||||||||
Corporate securities
|
— | 22 | — | 22 | ||||||||||||
Non U.S. government securities
|
— | 1 | — | 1 | ||||||||||||
U.S. Treasury and government securities (1)
|
— | 210 | — | 210 | ||||||||||||
Total—DHI short-term investments
|
$ | — | $ | 290 | $ | — | $ | 290 | ||||||||
Total—DHI
|
— | 1,715 | 78 | 1,793 | ||||||||||||
Short-term investments:
|
||||||||||||||||
Certificates of deposit
|
— | 3 | — | 3 | ||||||||||||
Corporate securities
|
— | 3 | — | 3 | ||||||||||||
U.S. Treasury and government securities
|
— | 9 | — | 9 | ||||||||||||
Total—Dynegy
|
$ | — | $ | 1,730 | $ | 78 | $ | 1,808 | ||||||||
Liabilities:
|
||||||||||||||||
Liabilities from commodity risk management activities:
|
||||||||||||||||
Electricity derivatives
|
$ | — | $ | (473 | ) | $ | (43 | ) | $ | (516 | ) | |||||
Natural gas derivatives
|
— | (920 | ) | — | (920 | ) | ||||||||||
Heat rate derivatives
|
— | — | (30 | ) | (30 | ) | ||||||||||
Other derivatives
|
— | (19 | ) | — | (19 | ) | ||||||||||
Total liabilities from commodity risk management activities
|
$ | — | $ | (1,412 | ) | $ | (73 | ) | $ | (1,485 | ) | |||||
Liabilities from interest rate swaps
|
— | (10 | ) | — | (10 | ) | ||||||||||
Total
|
$ | — | $ | (1,422 | ) | $ | (73 | ) | $ | (1,495 | ) |
(1)
|
Includes $86 million in Broker margin account on our consolidated balance sheets in
|
Fair Value as of December 31, 2009
|
||||||||||||||||
Level 1
|
Level 2
|
Level 3
|
Total
|
|||||||||||||
(in millions)
|
||||||||||||||||
Assets:
|
||||||||||||||||
Assets from commodity risk management activities:
|
||||||||||||||||
Electricity derivatives
|
$ | — | $ | 442 | $ | 57 | $ | 499 | ||||||||
Natural gas derivatives
|
— | 302 | 5 | 307 | ||||||||||||
Heat rate derivatives
|
— | — | 19 | 19 | ||||||||||||
Other derivatives
|
— | 36 | — | 36 | ||||||||||||
Total assets from commodity risk management activities
|
— | 780 | 81 | 861 | ||||||||||||
Assets from interest rate swaps
|
— | 15 | — | 15 | ||||||||||||
Other—DHI (1)
|
— | 8 | — | 8 | ||||||||||||
Total—DHI
|
— | 803 | 81 | 884 | ||||||||||||
Other—Dynegy (1)
|
— | 1 | — | 1 | ||||||||||||
Total—Dynegy
|
$ | — | $ | 804 | $ | 81 | $ | 885 | ||||||||
Liabilities:
|
||||||||||||||||
Liabilities from commodity risk management activities:
|
||||||||||||||||
Electricity derivatives
|
$ | — | $ | (361 | ) | $ | (51 | ) | $ | (412 | ) | |||||
Natural gas derivatives
|
— | (401 | ) | — | (401 | ) | ||||||||||
Heat rate derivatives
|
— | — | (2 | ) | (2 | ) | ||||||||||
Other derivatives
|
— | (29 | ) | — | (29 | ) | ||||||||||
Total liabilities from commodity risk management activities
|
— | (791 | ) | (53 | ) | (844 | ) | |||||||||
Liabilities from interest rate swaps
|
— | (15 | ) | (50 | ) | (65 | ) | |||||||||
Total
|
$ | — | $ | (806 | ) | $ | (103 | ) | $ | (909 | ) |
(1)
|
Other represents short-term investments and long-term investments.
|
Three Months Ended June 30, 2010
|
||||||||||||||||||||
Electricity Derivatives
|
Natural Gas Derivatives
|
Heat Rate Derivatives
|
Interest Rate Swaps
|
Total
|
||||||||||||||||
(in millions)
|
||||||||||||||||||||
Balance at March 31, 2010
|
$ | 70 | $ | 5 | $ | 20 | $ | — | $ | 95 | ||||||||||
Realized and unrealized gains (losses), net
|
(38 | ) | — | (27 | ) | — | (65 | ) | ||||||||||||
Purchases, issuances and settlements, net
|
(9 | ) | — | (16 | ) | — | (25 | ) | ||||||||||||
Balance at June 30, 2010
|
$ | 23 | $ | 5 | $ | (23 | ) | $ | — | $ | 5 | |||||||||
Unrealized losses relating to instruments still held as of June 30, 2010
|
$ | (31 | ) | $ | — | $ | (27 | ) | $ | — | $ | (58 | ) |
Six Months Ended June 30, 2010
|
||||||||||||||||||||
Electricity Derivatives
|
Natural Gas Derivatives
|
Heat Rate Derivatives
|
Interest Rate Swaps
|
Total
|
||||||||||||||||
(in millions)
|
||||||||||||||||||||
Balance at December 31, 2009
|
$ | 6 | $ | 5 | $ | 17 | $ | (50 | ) | $ | (22 | ) | ||||||||
Deconsolidation of Plum Point
|
— | — | — | 50 | 50 | |||||||||||||||
Realized and unrealized gains (losses), net
|
31 | — | (9 | ) | — | 22 | ||||||||||||||
Purchases, issuances and settlements, net
|
(14 | ) | — | (31 | ) | — | (45 | ) | ||||||||||||
Balance at June 30, 2010
|
$ | 23 | $ | 5 | $ | (23 | ) | $ | — | $ | 5 | |||||||||
Unrealized gains (losses) relating to instruments still held as of June 30, 2010
|
$ | 21 | $ | — | $ | (17 | ) | $ | — | $ | 4 |
Three Months Ended June 30, 2009
|
||||||||||||||||||||
Electricity Derivatives
|
Natural Gas Derivatives
|
Heat Rate Derivatives
|
Interest Rate Swaps
|
Total
|
||||||||||||||||
(in millions)
|
||||||||||||||||||||
Balance at March 31, 2009
|
$ | 1 | $ | 6 | $ | 26 | $ | — | $ | 33 | ||||||||||
Realized and unrealized gains (losses), net
|
5 | (1 | ) | 24 | — | 28 | ||||||||||||||
Purchases, issuances and settlements, net
|
(3 | ) | — | (15 | ) | — | (18 | ) | ||||||||||||
Balance at June 30, 2009
|
$ | 3 | $ | 5 | $ | 35 | $ | — | $ | 43 | ||||||||||
Unrealized gains (losses) relating to instruments still held as of June 30, 2009
|
$ | 4 | $ | (1 | ) | $ | 21 | $ | — | $ | 24 |
Six Months Ended June 30, 2009
|
||||||||||||||||||||
Electricity Derivatives
|
Natural Gas Derivatives
|
Heat Rate Derivatives
|
Interest Rate Swaps
|
Total
|
||||||||||||||||
(in millions)
|
||||||||||||||||||||
Balance at December 31, 2008
|
$ | 7 | $ | 7 | $ | 46 | $ | — | $ | 60 | ||||||||||
Realized and unrealized gains (losses), net
|
5 | (2 | ) | 20 | — | 23 | ||||||||||||||
Purchases, issuances and settlements, net
|
(9 | ) | — | (31 | ) | — | (40 | ) | ||||||||||||
Balance at June 30, 2009
|
$ | 3 | $ | 5 | $ | 35 | $ | — | $ | 43 | ||||||||||
Unrealized gains (losses) relating to instruments still held as of June 30, 2009
|
$ | (1 | ) | $ | (2 | ) | $ | 21 | $ | — | $ | 18 |
Fair Value Measurements as of June 30, 2009
|
||||||||||||||||||||
Level 1
|
Level 2
|
Level 3
|
Total
|
Total Losses
|
||||||||||||||||
(in millions)
|
||||||||||||||||||||
Assets/Liabilities:
|
||||||||||||||||||||
Goodwill
|
$ | — | $ | — | $ | — | $ | — | $ | (433 | ) | |||||||||
Assets held and used
|
— | — | 228 | 228 | (410 | ) | ||||||||||||||
Total
|
$ | — | $ | — | $ | 228 | $ | 228 | $ | (843 | ) |
June 30, 2010
|
December 31, 2009
|
|||||||||||||||
Carrying
Amount
|
Fair
Value
|
Carrying
Amount
|
Fair
Value
|
|||||||||||||
(in millions)
|
||||||||||||||||
Interest rate derivatives designated as fair value accounting hedges (1)
|
$ | 1 | $ | 1 | $ | 2 | $ | 2 | ||||||||
Interest rate derivatives not designated as accounting hedges (1)
|
(1 | ) | (1 | ) | (52 | ) | (52 | ) | ||||||||
Commodity-based derivative contracts not designated as accounting hedges (1)
|
8 | 8 | 17 | 17 | ||||||||||||
Term Loan B, due 2013
|
68 | 64 | 68 | 66 | ||||||||||||
Term Facility, floating rate due 2013
|
850 | 798 | 850 | 814 | ||||||||||||
Senior Notes and Debentures:
|
||||||||||||||||
6.875 percent due 2011
|
80 | 79 | 81 | 82 | ||||||||||||
8.75 percent due 2012
|
89 | 88 | 89 | 92 | ||||||||||||
7.5 percent due 2015 (2)
|
766 | 616 | 764 | 737 | ||||||||||||
8.375 percent due 2016 (3)
|
1,043 | 822 | 1,043 | 998 | ||||||||||||
7.125 percent due 2018
|
172 | 116 | 172 | 140 | ||||||||||||
7.75 percent due 2019
|
1,100 | 758 | 1,100 | 950 | ||||||||||||
7.625 percent due 2026
|
171 | 103 | 171 | 119 | ||||||||||||
Subordinated Debentures payable to affiliates, 8.316 percent, due 2027
|
200 | 108 | 200 | 107 | ||||||||||||
PPEA Credit Agreement Facility, floating rate, due 2010 (4)
|
— | — | 644 | 334 | ||||||||||||
PPEA Tax Exempt Bonds, floating rate, due 2036 (4)
|
— | — | 100 | 100 | ||||||||||||
Sithe Senior Notes, 9.0 percent due 2013 (5)
|
267 | 260 | 300 | 294 | ||||||||||||
Other—DHI (6)
|
290 | 290 | 8 | 8 | ||||||||||||
Other—Dynegy (7)
|
15 | 15 | 1 | 1 |
(1)
|
Included in both current and non-current assets and liabilities on the unaudited condensed consolidated balance sheets.
|
(2)
|
Includes unamortized discounts of $19 million and $21 million at June 30, 2010 and December 31, 2009, respectively.
|
(3)
|
Includes unamortized discounts of $4 million at June 30, 2010 and December 31, 2009.
|
(4)
|
As discussed in Note 1—Accounting Policies—Accounting Policies Adopted—Variable Interest Entities, effective January 1, 2010, we deconsolidated our investment in PPEA Holding, and as a result, PPEA’s debt is no longer included in our unaudited condensed consolidated balance sheets.
|
(5)
|
Includes unamortized premiums of $10 million and $13 million at June 30, 2010 and December 31, 2009, respectively.
|
(6)
|
Other represents short-term investments, including $86 million of short-term investments included in the Broker margin account.
|
(7)
|
Other represents short-term investments.
|
June 30,
2010
|
December 31,
2009
|
|||||||
(in millions)
|
||||||||
Cash flow hedging activities, net
|
$ | 3 | $ | (24 | ) | |||
Unrecognized prior service cost and actuarial loss, net
|
(57 | ) | (59 | ) | ||||
Accumulated other comprehensive loss—unconsolidated investments, net (1)
|
(17 | ) | — | |||||
Accumulated other comprehensive loss, net of tax
|
(71 | ) | (83 | ) | ||||
Less: Accumulated other comprehensive income attributable to the noncontrolling interests (1)
|
— | 67 | ||||||
Accumulated other comprehensive loss attributable to Dynegy and DHI, net of tax
|
$ | (71 | ) | $ | (150 | ) |
(1)
|
As discussed in Note 1—Accounting Policies—Accounting Policies Adopted—Variable Interest Entities, effective January 1, 2010, we deconsolidated our investment in PPEA Holding, and as a result, there are no longer any noncontrolling interests in any of our consolidated subsidiaries.
|
June 30,
2010
|
||||
(in millions)
|
||||
Unconsolidated investments
|
$ | — | ||
Accumulated other comprehensive loss, net of tax
|
17 |
Three Months Ended June 30, 2010
|
||||||||
Total
|
Equity Share
|
|||||||
(in millions)
|
||||||||
Revenues
|
$ | — | $ | — | ||||
Operating loss
|
(1 | ) | — | |||||
Net loss
|
(42 | ) | — |
Six Months Ended June 30, 2010
|
||||||||
Total
|
Equity Share
|
|||||||
(in millions)
|
||||||||
Revenues
|
$ | — | $ | — | ||||
Operating loss
|
(2 | ) | — | |||||
Net income (loss)
|
(33 | ) | 3 |
Three Months Ended
June 30,
|
Six Months Ended
June 30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
(in millions, except per share amounts)
|
||||||||||||||||
Loss from continuing operations
|
$ | (191 | ) | $ | (348 | ) | $ | (47 | ) | $ | (671 | ) | ||||
Less: Net loss attributable to the noncontrolling interests
|
— | (1 | ) | — | (3 | ) | ||||||||||
Loss from continuing operations attributable to Dynegy Inc. for basic and diluted loss per share
|
$ | (191 | ) | $ | (347 | ) | $ | (47 | ) | $ | (668 | ) | ||||
Basic weighted-average shares
|
120 | 168 | 120 | 168 | ||||||||||||
Effect of dilutive securities:
|
||||||||||||||||
Stock options and restricted stock
|
1 | 1 | 1 | 1 | ||||||||||||
Diluted weighted-average shares
|
121 | 169 | 121 | 169 | ||||||||||||
Loss per share from continuing operations attributable to Dynegy Inc.:
|
||||||||||||||||
Basic
|
$ | (1.59 | ) | $ | (2.06 | ) | $ | (0.39 | ) | $ | (3.98 | ) | ||||
Diluted (1)
|
$ | (1.59 | ) | $ | (2.06 | ) | $ | (0.39 | ) | $ | (3.98 | ) |
(1)
|
Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per-share amounts. Accordingly, Dynegy Inc. has utilized the basic shares outstanding amount to calculate both basic and diluted loss per share for the three and six months ended June 30, 2010 and 2009.
|
·
|
In February 2007, the Tennessee state court dismissed a class action on defendants’ motion. Plaintiffs appealed and, in October 2008, the appellate court reversed the dismissal. Thereafter, defendants appealed to the Tennessee Supreme Court which, in April 2010, reversed the appellate court ruling and dismissed all of plaintiffs’ claims. The decision is subject to appeal to the U.S. Supreme Court.
|
·
|
In February 2008, the United States District Court in Las Vegas, Nevada granted defendants’ motion for summary judgment in a Colorado class action and, ultimately, dismissed the case and all of plaintiffs’ claims. The decision is subject to appeal once the remaining defendants’ claims are adjudicated.
|
·
|
The remaining five cases, three of which seek class certification, are also pending in Nevada federal court. All of the cases contain similar claims that individually, and in conjunction with other energy companies, we engaged in an illegal scheme to inflate natural gas prices in four states by providing false information to natural gas index publications. In November 2009, following defendants’ motion for reconsideration, the court invited defendants to renew their motions for summary judgment, which were filed shortly thereafter. Now fully briefed, we await an order or further instruction from the court. In the interim, discovery and plaintiffs’ class certification motion are stayed.
|
·
|
Roseton SPDES Permit — In April 2005, the NYSDEC issued a Draft SPDES Permit renewal for the Roseton plant. The permit is opposed by environmental groups challenging the BTA determination. The hearing will be scheduled after the Commissioner rules on appeals of procedural matters. We believe that the petitioners’ claims lack merit and we plan to oppose those claims vigorously.
|
·
|
Moss Landing NPDES Permit — The California Regional Water Quality Control Board (“Water Board”) issued an NPDES permit for the Moss Landing power generating facility in 2000 that did not require closed cycle cooling. A local environmental group challenged the BTA determination of the permit. The Water Board’s decision was affirmed by the Superior Court in 2004 and by the Court of Appeals in 2007. The Supreme Court of California granted review in March 2008. The petitioner’s brief was filed in December 2009. We filed a motion to dismiss and our responsive brief in March 2010. The petitioner’s reply brief was filed in May 2010. Our motion to dismiss was denied in June 2010. In July 2010, the California Energy Commission filed an application for leave to file a brief in support of our argument challenging the jurisdiction of the Supreme Court. We believe that petitioner’s claims lack merit and we plan to continue to oppose those claims vigorously.
|
Pension Benefits
|
Other Benefits
|
|||||||||||||||
Three Months Ended June 30,
|
||||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
(in millions)
|
||||||||||||||||
Service cost benefits earned during period
|
$ | 3 | $ | 3 | $ | — | $ | — | ||||||||
Interest cost on projected benefit obligation
|
4 | 3 | 1 | 1 | ||||||||||||
Expected return on plan assets
|
(4 | ) | (4 | ) | — | — | ||||||||||
Recognized net actuarial loss
|
1 | 1 | — | — | ||||||||||||
Net periodic benefit cost
|
$ | 4 | $ | 3 | $ | 1 | $ | 1 |
Pension Benefits
|
Other Benefits
|
|||||||||||||||
Six Months Ended June 30,
|
||||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
(in millions)
|
||||||||||||||||
Service cost benefits earned during period
|
$ | 6 | $ | 6 | $ | 1 | $ | 1 | ||||||||
Interest cost on projected benefit obligation
|
7 | 6 | 2 | 2 | ||||||||||||
Expected return on plan assets
|
(8 | ) | (7 | ) | — | — | ||||||||||
Recognized net actuarial loss
|
2 | 2 | — | — | ||||||||||||
Net periodic benefit cost
|
$ | 7 | $ | 7 | $ | 3 | $ | 3 |
Three Months Ended
June 30,
|
Six Months Ended
June 30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
(in millions, except rates)
|
||||||||||||||||
Income tax benefit
|
$ | 128 | $ | 204 | $ | 63 | $ | 113 | ||||||||
Effective tax rate
|
40 | % | 37 | % | 57 | % | 14 | % |
Three Months Ended
June 30,
|
Six Months Ended
June 30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
(in millions, except rates)
|
||||||||||||||||
Income tax benefit
|
$ | 128 | $ | 205 | $ | 56 | $ | 117 | ||||||||
Effective tax rate
|
40 | % | 37 | % | 51 | % | 15 | % |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Unaffiliated revenues:
|
||||||||||||||||||||
Domestic
|
$ | 63 | $ | 71 | $ | 105 | $ | — | $ | 239 | ||||||||||
Total revenues
|
$ | 63 | $ | 71 | $ | 105 | $ | — | $ | 239 | ||||||||||
Depreciation and amortization
|
$ | (63 | ) | $ | (17 | ) | $ | (8 | ) | $ | (2 | ) | $ | (90 | ) | |||||
Impairment and other charges
|
— | — | (1 | ) | — | (1 | ) | |||||||||||||
Operating loss
|
$ | (165 | ) | $ | (9 | ) | $ | (26 | ) | $ | (29 | ) | $ | (229 | ) | |||||
Other items, net
|
— | — | — | 1 | 1 | |||||||||||||||
Interest expense
|
(91 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(319 | ) | ||||||||||||||||||
Income tax benefit
|
128 | |||||||||||||||||||
Net loss
|
$ | (191 | ) | |||||||||||||||||
Identifiable assets:
|
||||||||||||||||||||
Domestic
|
$ | 5,282 | $ | 2,112 | $ | 1,768 | $ | 1,410 | $ | 10,572 | ||||||||||
Other
|
— | — | — | 24 | 24 | |||||||||||||||
Total
|
$ | 5,282 | $ | 2,112 | $ | 1,768 | $ | 1,434 | $ | 10,596 | ||||||||||
Capital expenditures and investments in unconsolidated affiliates
|
$ | (108 | ) | $ | (2 | ) | $ | (2 | ) | $ | (3 | ) | $ | (115 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Unaffiliated revenues:
|
||||||||||||||||||||
Domestic
|
$ | 170 | $ | 100 | $ | 181 | $ | (1 | ) | $ | 450 | |||||||||
Total revenues
|
$ | 170 | $ | 100 | $ | 181 | $ | (1 | ) | $ | 450 | |||||||||
Depreciation and amortization
|
$ | (57 | ) | $ | (13 | ) | $ | (16 | ) | $ | (3 | ) | $ | (89 | ) | |||||
Impairment and other charges
|
— | — | (387 | ) | — | (387 | ) | |||||||||||||
Operating income (loss)
|
$ | (68 | ) | $ | 29 | $ | (382 | ) | $ | (50 | ) | $ | (471 | ) | ||||||
Earnings from unconsolidated investments
|
— | 13 | — | — | 13 | |||||||||||||||
Other items, net
|
— | 2 | — | 2 | 4 | |||||||||||||||
Interest expense
|
(98 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(552 | ) | ||||||||||||||||||
Income tax benefit
|
204 | |||||||||||||||||||
Loss from continuing operations
|
(348 | ) | ||||||||||||||||||
Income from discontinued operations, net of taxes
|
2 | |||||||||||||||||||
Net loss
|
(346 | ) | ||||||||||||||||||
Less: Net loss attributable to the noncontrolling interests
|
(1 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Inc.
|
$ | (345 | ) | |||||||||||||||||
Identifiable assets:
|
||||||||||||||||||||
Domestic
|
$ | 7,075 | $ | 2,946 | $ | 1,986 | $ | 1,514 | $ | 13,521 | ||||||||||
Other
|
— | — | — | 19 | 19 | |||||||||||||||
Total
|
$ | 7,075 | $ | 2,946 | $ | 1,986 | $ | 1,533 | $ | 13,540 | ||||||||||
Capital expenditures
|
$ | (146 | ) | $ | (7 | ) | $ | (11 | ) | $ | (1 | ) | $ | (165 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Unaffiliated revenues:
|
||||||||||||||||||||
Domestic
|
$ | 549 | $ | 214 | $ | 334 | $ | — | $ | 1,097 | ||||||||||
Total revenues
|
$ | 549 | $ | 214 | $ | 334 | $ | — | $ | 1,097 | ||||||||||
Depreciation and amortization
|
$ | (113 | ) | $ | (33 | ) | $ | (16 | ) | $ | (3 | ) | $ | (165 | ) | |||||
Impairment and other charges
|
— | — | (1 | ) | — | (1 | ) | |||||||||||||
Operating income (loss)
|
$ | 95 | $ | 36 | $ | 34 | $ | (63 | ) | $ | 102 | |||||||||
Losses from unconsolidated investments
|
(34 | ) | — | — | — | (34 | ) | |||||||||||||
Other items, net
|
— | — | 1 | 1 | 2 | |||||||||||||||
Interest expense
|
(180 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(110 | ) | ||||||||||||||||||
Income tax benefit
|
63 | |||||||||||||||||||
Loss from continuing operations
|
(47 | ) | ||||||||||||||||||
Income from discontinued operations, net of taxes
|
1 | |||||||||||||||||||
Net loss
|
$ | (46 | ) | |||||||||||||||||
Identifiable assets:
|
||||||||||||||||||||
Domestic
|
$ | 5,282 | $ | 2,112 | $ | 1,768 | $ | 1,410 | $ | 10,572 | ||||||||||
Other
|
— | — | — | 24 | 24 | |||||||||||||||
Total
|
$ | 5,282 | $ | 2,112 | $ | 1,768 | $ | 1,434 | $ | 10,596 | ||||||||||
Capital expenditures and investments in unconsolidated affiliates
|
$ | (197 | ) | $ | (10 | ) | $ | (5 | ) | $ | (4 | ) | $ | (216 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Unaffiliated revenues:
|
||||||||||||||||||||
Domestic
|
$ | 694 | $ | 183 | $ | 478 | $ | (1 | ) | $ | 1,354 | |||||||||
Total revenues
|
$ | 694 | $ | 183 | $ | 478 | $ | (1 | ) | $ | 1,354 | |||||||||
Depreciation and amortization
|
$ | (108 | ) | $ | (30 | ) | $ | (31 | ) | $ | (6 | ) | $ | (175 | ) | |||||
Goodwill impairments
|
(76 | ) | (260 | ) | (97 | ) | — | (433 | ) | |||||||||||
Impairments and other charges
|
— | — | (387 | ) | — | (387 | ) | |||||||||||||
Operating income (loss)
|
$ | 138 | $ | (243 | ) | $ | (425 | ) | $ | (87 | ) | $ | (617 | ) | ||||||
Earnings from unconsolidated investments
|
— | 20 | — | 1 | 21 | |||||||||||||||
Other items, net
|
2 | 2 | — | 4 | 8 | |||||||||||||||
Interest expense
|
(196 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(784 | ) | ||||||||||||||||||
Income tax benefit
|
113 | |||||||||||||||||||
Loss from continuing operations
|
(671 | ) | ||||||||||||||||||
Loss from discontinued operations, net of taxes
|
(12 | ) | ||||||||||||||||||
Net loss
|
(683 | ) | ||||||||||||||||||
Less: Net loss attributable to the noncontrolling interests
|
(3 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Inc.
|
$ | (680 | ) | |||||||||||||||||
Identifiable assets:
|
||||||||||||||||||||
Domestic
|
$ | 7,075 | $ | 2,946 | $ | 1,986 | $ | 1,514 | $ | 13,521 | ||||||||||
Other
|
— | — | — | 19 | 19 | |||||||||||||||
Total
|
$ | 7,075 | $ | 2,946 | $ | 1,986 | $ | 1,533 | $ | 13,540 | ||||||||||
Capital expenditures
|
$ | (274 | ) | $ | (8 | ) | $ | (18 | ) | $ | (3 | ) | $ | (303 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Unaffiliated revenues:
|
||||||||||||||||||||
Domestic
|
$ | 63 | $ | 71 | $ | 105 | $ | — | $ | 239 | ||||||||||
Total revenues
|
$ | 63 | $ | 71 | $ | 105 | $ | — | $ | 239 | ||||||||||
Depreciation and amortization
|
$ | (63 | ) | $ | (17 | ) | $ | (8 | ) | $ | (2 | ) | $ | (90 | ) | |||||
Impairment and other charges
|
— | — | (1 | ) | — | (1 | ) | |||||||||||||
Operating income (loss)
|
$ | (165 | ) | $ | (9 | ) | $ | (26 | ) | $ | (29 | ) | $ | (229 | ) | |||||
Other items, net
|
— | — | — | 1 | 1 | |||||||||||||||
Interest expense
|
(91 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(319 | ) | ||||||||||||||||||
Income tax benefit
|
128 | |||||||||||||||||||
Net loss
|
$ | (191 | ) | |||||||||||||||||
Identifiable assets:
|
||||||||||||||||||||
Domestic
|
$ | 5,282 | $ | 2,112 | $ | 1,768 | $ | 1,353 | $ | 10,515 | ||||||||||
Other
|
— | — | — | 24 | 24 | |||||||||||||||
Total
|
$ | 5,282 | $ | 2,112 | $ | 1,768 | $ | 1,377 | $ | 10,539 | ||||||||||
Capital expenditures and investments in unconsolidated affiliates
|
$ | (108 | ) | $ | (2 | ) | $ | (2 | ) | $ | (3 | ) | $ | (115 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Unaffiliated revenues:
|
||||||||||||||||||||
Domestic
|
$ | 170 | $ | 100 | $ | 181 | $ | (1 | ) | $ | 450 | |||||||||
Total revenues
|
$ | 170 | $ | 100 | $ | 181 | $ | (1 | ) | $ | 450 | |||||||||
Depreciation and amortization
|
$ | (57 | ) | $ | (13 | ) | $ | (16 | ) | $ | (3 | ) | $ | (89 | ) | |||||
Impairment and other charges
|
— | — | (387 | ) | — | (387 | ) | |||||||||||||
Operating income (loss)
|
$ | (68 | ) | $ | 29 | $ | (382 | ) | $ | (50 | ) | $ | (471 | ) | ||||||
Earnings from unconsolidated investments
|
— | 13 | — | — | 13 | |||||||||||||||
Other items, net
|
— | 2 | — | 1 | 3 | |||||||||||||||
Interest expense
|
(98 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(553 | ) | ||||||||||||||||||
Income tax benefit
|
205 | |||||||||||||||||||
Loss from continuing operations
|
(348 | ) | ||||||||||||||||||
Income from discontinued operations, net of taxes
|
12 | |||||||||||||||||||
Net loss
|
(336 | ) | ||||||||||||||||||
Less: Net loss attributable to the noncontrolling interests
|
(1 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Holdings Inc.
|
$ | (335 | ) | |||||||||||||||||
Identifiable assets:
|
||||||||||||||||||||
Domestic
|
$ | 7,075 | $ | 2,946 | $ | 1,986 | $ | 1,332 | $ | 13,339 | ||||||||||
Other
|
— | — | — | 19 | 19 | |||||||||||||||
Total
|
$ | 7,075 | $ | 2,946 | $ | 1,986 | $ | 1,351 | $ | 13,358 | ||||||||||
Capital expenditures
|
$ | (146 | ) | $ | (7 | ) | $ | (11 | ) | $ | (1 | ) | $ | (165 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Unaffiliated revenues:
|
||||||||||||||||||||
Domestic
|
$ | 549 | $ | 214 | $ | 334 | $ | — | $ | 1,097 | ||||||||||
Total revenues
|
$ | 549 | $ | 214 | $ | 334 | $ | — | $ | 1,097 | ||||||||||
Depreciation and amortization
|
$ | (113 | ) | $ | (33 | ) | $ | (16 | ) | $ | (3 | ) | $ | (165 | ) | |||||
Impairment and other charges
|
— | — | (1 | ) | — | (1 | ) | |||||||||||||
Operating income (loss)
|
$ | 95 | $ | 36 | $ | 34 | $ | (63 | ) | $ | 102 | |||||||||
Losses from unconsolidated investments
|
(34 | ) | — | — | — | (34 | ) | |||||||||||||
Other items, net
|
— | — | 1 | 1 | 2 | |||||||||||||||
Interest expense
|
(180 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(110 | ) | ||||||||||||||||||
Income tax benefit
|
56 | |||||||||||||||||||
Loss from continuing operations
|
(54 | ) | ||||||||||||||||||
Income from discontinued operations, net of taxes
|
1 | |||||||||||||||||||
Net loss.
|
$ | (53 | ) | |||||||||||||||||
Identifiable assets:
|
||||||||||||||||||||
Domestic
|
$ | 5,282 | $ | 2,112 | $ | 1,768 | $ | 1,353 | $ | 10,515 | ||||||||||
Other
|
— | — | — | 24 | 24 | |||||||||||||||
Total
|
$ | 5,282 | $ | 2,112 | $ | 1,768 | $ | 1,377 | $ | 10,539 | ||||||||||
Capital expenditures and investments in unconsolidated affiliates
|
$ | (197 | ) | $ | (10 | ) | $ | (5 | ) | $ | (4 | ) | $ | (216 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Unaffiliated revenues:
|
||||||||||||||||||||
Domestic
|
$ | 694 | $ | 183 | $ | 478 | $ | (1 | ) | $ | 1,354 | |||||||||
Total revenues
|
$ | 694 | $ | 183 | $ | 478 | $ | (1 | ) | $ | 1,354 | |||||||||
Depreciation and amortization
|
$ | (108 | ) | $ | (30 | ) | $ | (31 | ) | $ | (6 | ) | $ | (175 | ) | |||||
Goodwill impairments
|
(76 | ) | (260 | ) | (97 | ) | — | (433 | ) | |||||||||||
Impairments and other charges
|
— | — | (387 | ) | — | (387 | ) | |||||||||||||
Operating income (loss)
|
$ | 138 | $ | (243 | ) | $ | (425 | ) | $ | (89 | ) | $ | (619 | ) | ||||||
Earnings from unconsolidated investments
|
— | 20 | — | — | 20 | |||||||||||||||
Other items, net
|
2 | 2 | — | 3 | 7 | |||||||||||||||
Interest expense
|
(196 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(788 | ) | ||||||||||||||||||
Income tax benefit
|
117 | |||||||||||||||||||
Loss from continuing operations
|
(671 | ) | ||||||||||||||||||
Loss from discontinued operations, net of taxes
|
(2 | ) | ||||||||||||||||||
Net loss
|
(673 | ) | ||||||||||||||||||
Less: Net loss attributable to the noncontrolling interests
|
(3 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Holdings Inc.
|
$ | (670 | ) | |||||||||||||||||
Identifiable assets:
|
||||||||||||||||||||
Domestic
|
$ | 7,075 | $ | 2,946 | $ | 1,986 | $ | 1,332 | $ | 13,339 | ||||||||||
Other
|
— | — | — | 19 | 19 | |||||||||||||||
Total
|
$ | 7,075 | $ | 2,946 | $ | 1,986 | $ | 1,351 | $ | 13,358 | ||||||||||
Capital expenditures
|
$ | (274 | ) | $ | (8 | ) | $ | (18 | ) | $ | (3 | ) | $ | (303 | ) |
August 2,
2010
|
June 30,
2010
|
December 31, 2009
|
||||||||||
(in millions)
|
||||||||||||
Revolver capacity (1)
|
$ | 1,080 | $ | 1,080 | $ | 1,080 | ||||||
Borrowings against revolver capacity
|
— | — | — | |||||||||
Term letter of credit capacity, net of required reserves
|
825 | 825 | 825 | |||||||||
Plum Point letter of credit capacity (2)
|
— | — | 102 | |||||||||
Available contingent letter of credit facility capacity (3)
|
— | — | — | |||||||||
Outstanding letters of credit (2)
|
(461 | ) | (435 | ) | (536 | ) | ||||||
Unused capacity
|
1,444 | 1,470 | 1,471 | |||||||||
Cash—DHI
|
324 | 244 | 419 | |||||||||
Short-term investments—DHI (4)
|
222 | 204 | — | |||||||||
Total available liquidity—DHI
|
1,990 | 1,918 | 1,890 | |||||||||
Cash—Dynegy
|
38 | 38 | 52 | |||||||||
Short-term investments—Dynegy (4)
|
15 | 15 | — | |||||||||
Total available liquidity—Dynegy
|
$ | 2,043 | $ | 1,971 | $ | 1,942 |
(1)
|
We currently have a syndicate of lenders participating in the revolving portion of our Credit Facility with commitments ranging from $10 million to $165 million.
|
(2)
|
Reflects the reduction of $102 million of capacity and corresponding outstanding letters of credit as of March 31, 2010 due to the deconsolidation of PPEA Holding. Please read Note 1—Accounting Policies
—Accounting Policies Adopted—Variable Interest Entities for further discussion.
|
(3)
|
Under the terms of the Contingent LC Facility, up to $150 million of capacity can become available, contingent on changes in spark spreads and power prices for 2012 forward spark spreads and power prices.
|
(4)
|
We invest our available cash balances in certain investments permitted by our internal policies and external financing agreements. Please read Note 1—Accounting Policies—Short-Term Investments and Note 4—Investments for further discussion.
|
August 2,
2010
|
June 30,
2010
|
December 31,
2009
|
||||||||||
(in millions)
|
||||||||||||
By Business
:
|
||||||||||||
Generation
|
$ | 481 | $ | 459 | $ | 637 | ||||||
Other (1)
|
88 | 88 | 190 | |||||||||
Total
|
$ | 569 | $ | 547 | $ | 827 | ||||||
By Type
:
|
||||||||||||
Cash and short-term investments (2)
|
$ | 108 | $ | 112 | $ | 291 | ||||||
Letters of credit (1)
|
461 | 435 | 536 | |||||||||
Total
|
$ | 569 | $ | 547 | $ | 827 |
(1)
|
August 2, 2010 and June 30, 2010 reflect the reduction of $102 million of capacity and corresponding outstanding letters of credit due to the deconsolidation of PPEA Holding. Please read Note 1—Accounting Policies
—Accounting Policies Adopted—Variable Interest Entities for further discussion.
|
(2)
|
Includes Collateral included in Broker margin account on our consolidated balance sheets at August 2, 2010, June 30, 2010 and December 31, 2009, respectively, as well as other collateral postings included in Prepayments and other current assets.
|
For the Six Months Ended June 30,
|
||||||||
2010
|
2009
|
|||||||
(in millions)
|
||||||||
GEN-MW
|
$ | 182 | $ | 274 | ||||
GEN-WE
|
10 | 8 | ||||||
GEN-NE
|
5 | 18 | ||||||
Other
|
4 | 3 | ||||||
Total
|
$ | 201 | $ | 303 |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Revenues
|
$ | 63 | $ | 71 | $ | 105 | $ | — | $ | 239 | ||||||||||
Cost of sales
|
(110 | ) | (37 | ) | (84 | ) | — | (231 | ) | |||||||||||
Operating and maintenance expense, exclusive of depreciation and amortization expense shown separately below
|
(55 | ) | (26 | ) | (38 | ) | 1 | (118 | ) | |||||||||||
Depreciation and amortization expense
|
(63 | ) | (17 | ) | (8 | ) | (2 | ) | (90 | ) | ||||||||||
Impairment and other charges
|
— | — | (1 | ) | — | (1 | ) | |||||||||||||
General and administrative expense
|
— | — | — | (28 | ) | (28 | ) | |||||||||||||
Operating loss
|
$ | (165 | ) | $ | (9 | ) | $ | (26 | ) | $ | (29 | ) | $ | (229 | ) | |||||
Other items, net
|
— | — | — | 1 | 1 | |||||||||||||||
Interest expense
|
(91 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(319 | ) | ||||||||||||||||||
Income tax benefit
|
128 | |||||||||||||||||||
Net loss
|
$ | (191 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Revenues
|
$ | 170 | $ | 100 | $ | 181 | $ | (1 | ) | $ | 450 | |||||||||
Cost of sales
|
(120 | ) | (33 | ) | (110 | ) | — | (263 | ) | |||||||||||
Operating and maintenance expense, exclusive of depreciation and amortization expense shown separately below
|
(61 | ) | (25 | ) | (50 | ) | (1 | ) | (137 | ) | ||||||||||
Depreciation and amortization expense
|
(57 | ) | (13 | ) | (16 | ) | (3 | ) | (89 | ) | ||||||||||
Impairment and other charges
|
— | — | (387 | ) | — | (387 | ) | |||||||||||||
General and administrative expense
|
— | — | — | (45 | ) | (45 | ) | |||||||||||||
Operating income (loss)
|
$ | (68 | ) | $ | 29 | $ | (382 | ) | $ | (50 | ) | $ | (471 | ) | ||||||
Earnings from unconsolidated investments
|
— | 13 | — | — | 13 | |||||||||||||||
Other items, net
|
— | 2 | — | 2 | 4 | |||||||||||||||
Interest expense
|
(98 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(552 | ) | ||||||||||||||||||
Income tax benefit
|
204 | |||||||||||||||||||
Loss from continuing operations
|
(348 | ) | ||||||||||||||||||
Income from discontinued operations, net of taxes.
|
2 | |||||||||||||||||||
Net loss
|
(346 | ) | ||||||||||||||||||
Less: Net loss attributable to the noncontrolling interests
|
(1 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Inc.
|
$ | (345 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Revenues
|
$ | 63 | $ | 71 | $ | 105 | $ | — | $ | 239 | ||||||||||
Cost of sales
|
(110 | ) | (37 | ) | (84 | ) | — | (231 | ) | |||||||||||
Operating and maintenance expense, exclusive of depreciation and amortization expense shown separately below
|
(55 | ) | (26 | ) | (38 | ) | 1 | (118 | ) | |||||||||||
Depreciation and amortization expense
|
(63 | ) | (17 | ) | (8 | ) | (2 | ) | (90 | ) | ||||||||||
Impairment and other charges
|
— | — | (1 | ) | — | (1 | ) | |||||||||||||
General and administrative expense
|
— | — | — | (28 | ) | (28 | ) | |||||||||||||
Operating loss
|
$ | (165 | ) | $ | (9 | ) | $ | (26 | ) | $ | (29 | ) | $ | (229 | ) | |||||
Other items, net
|
— | — | — | 1 | 1 | |||||||||||||||
Interest expense
|
(91 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(319 | ) | ||||||||||||||||||
Income tax benefit
|
128 | |||||||||||||||||||
Net loss
|
$ | (191 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Revenues
|
$ | 170 | $ | 100 | $ | 181 | $ | (1 | ) | $ | 450 | |||||||||
Cost of sales
|
(120 | ) | (33 | ) | (110 | ) | — | (263 | ) | |||||||||||
Operating and maintenance expense, exclusive of depreciation and amortization expense shown separately below
|
(61 | ) | (25 | ) | (50 | ) | (1 | ) | (137 | ) | ||||||||||
Depreciation and amortization expense
|
(57 | ) | (13 | ) | (16 | ) | (3 | ) | (89 | ) | ||||||||||
Impairment and other charges
|
— | — | (387 | ) | — | (387 | ) | |||||||||||||
General and administrative expense
|
— | — | — | (45 | ) | (45 | ) | |||||||||||||
Operating income (loss)
|
$ | (68 | ) | $ | 29 | $ | (382 | ) | $ | (50 | ) | $ | (471 | ) | ||||||
Earnings from unconsolidated investments
|
— | 13 | — | — | 13 | |||||||||||||||
Other items, net
|
— | 2 | — | 1 | 3 | |||||||||||||||
Interest expense
|
(98 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(553 | ) | ||||||||||||||||||
Income tax benefit
|
205 | |||||||||||||||||||
Loss from continuing operations
|
(348 | ) | ||||||||||||||||||
Income from discontinued operations, net of taxes.
|
12 | |||||||||||||||||||
Net loss
|
(336 | ) | ||||||||||||||||||
Less: Net loss attributable to the noncontrolling interests
|
(1 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Holdings Inc.
|
$ | (335 | ) |
Three Months Ended
June 30,
|
||||||||
2010
|
2009
|
|||||||
GEN-MW
|
||||||||
Million Megawatt Hours Generated (1)
|
5.6 | 5.9 | ||||||
In Market Availability for Coal Fired Facilities (2)
|
83 | % | 92 | % | ||||
Average Capacity Factor for Combined Cycle Facilities (3)
|
25 | % | 28 | % | ||||
Average Quoted On-Peak Market Power Prices ($/MWh) (4):
|
||||||||
Cinergy (CIN Hub)
|
$ | 41 | $ | 34 | ||||
Commonwealth Edison (NI Hub)
|
$ | 40 | $ | 32 | ||||
PJM West
|
$ | 52 | $ | 40 | ||||
Average Market Spark Spreads ($/MWh) (5):
|
||||||||
PJM West
|
$ | 19 | $ | 12 | ||||
GEN-WE
|
||||||||
Million Megawatt Hours Generated (6) (7)
|
0.5 | 0.8 | ||||||
Average Capacity Factor for Combined Cycle Facilities (3)
|
17 | % | 23 | % | ||||
Average Quoted On-Peak Market Power Prices ($/MWh) (4):
|
||||||||
North Path 15 (NP 15)
|
$ | 36 | $ | 31 | ||||
Average Market Spark Spreads ($/MWh) (5):
|
||||||||
North Path 15 (NP 15)
|
$ | 2 | $ | 5 | ||||
GEN-NE
|
||||||||
Million Megawatt Hours Generated
|
1.6 | 2.1 | ||||||
In Market Availability for Coal Fired Facilities (2)
|
96 | % | 92 | % | ||||
Average Capacity Factor for Combined Cycle Facilities (3)
|
38 | % | 39 | % | ||||
Average Quoted On-Peak Market Power Prices ($/MWh) (4):
|
||||||||
New York—Zone G
|
$ | 53 | $ | 44 | ||||
New York—Zone A
|
$ | 41 | $ | 31 | ||||
Mass Hub
|
$ | 49 | $ | 39 | ||||
Average Market Spark Spreads ($/MWh) (5):
|
||||||||
New York—Zone A
|
$ | 7 | $ | 2 | ||||
Mass Hub
|
$ | 17 | $ | 11 | ||||
Fuel Oil
|
$ | (77 | ) | $ | (53 | ) | ||
Average natural gas price—Henry Hub ($/MMBtu) (8)
|
$ | 4.30 | $ | 3.69 |
|
(1)
|
Excludes less than 0.1 million MWh generated by our former Bluegrass power generation facility, which we sold on November 30, 2009 and is reported in discontinued operations, for the three months ended June 30, 2009.
|
|
(2)
|
Reflects the percentage of generation available during periods when market prices are such that these units could be profitably dispatched.
|
|
(3)
|
Reflects actual production as a percentage of available capacity. Excludes the Arizona power generation facilities which are reported as discontinued operations with respect to the GEN-WE segment for all periods presented. For the 2009 period presented, includes the Tilton, Rocky Road, Riverside and Renaissance power generation facilities with respect to the GEN-MW segment and the Bridgeport power generation facility with respect to the GEN-NE segment.
|
|
(4)
|
Reflects the average of day-ahead quoted prices for the periods presented and does not necessarily reflect prices we realize.
|
|
(5)
|
Reflects the simple average of the spark spread available to a 7.0 MMBtu/MWh heat rate generator selling power at day-ahead prices and buying delivered natural gas or fuel oil at a daily cash market price and does not reflect spark spreads available to us.
|
|
(6)
|
Includes our ownership percentage in the MWh generated by our GEN-WE investment in the Black Mountain power generation facility for the three months ended June 30, 2010 and 2009, respectively.
|
|
(7)
|
Excludes less than 0.5 million MWh generated by our Arizona power generation facilities, which we sold on November 30, 2009, and are reported in discontinued operations for the three months ended June 30, 2009.
|
|
(8)
|
Reflects the average of daily quoted prices for the periods presented and does not reflect costs incurred by us.
|
Three Months Ended June 30, 2009
|
||||||||||||||||||||
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
(in millions)
|
||||||||||||||||||||
Impairments
|
$ | — | $ | — | $ | (387 | ) | $ | — | $ | (387 | ) | ||||||||
Sandy Creek mark-to-market gains (1)
|
— | 15 | — | — | 15 | |||||||||||||||
Discontinued operations (2)
|
(17 | ) | 18 | — | — | 1 | ||||||||||||||
Total
|
$ | (17 | ) | $ | 33 | $ | (387 | ) | $ | — | $ | (371 | ) |
(1)
|
These mark-to-market gains represent our 50 percent share.
|
(2)
|
Discontinued operations includes an $18 million impairment for the Bluegrass power generation facility in GEN-MW and a gain of $10 million on the sale of the Heard County power generation facility in GEN-WE.
|
·
|
Mark-to-market losses – GEN-MW’s results for the three months ended June 30, 2010 included mark-to-market losses of $183 million related to forward sales and other derivative contracts, compared to $129 million of mark-to-market losses for the three months ended June 30, 2009. Of the $183 million in 2010 mark-to-market losses, $108 million related to positions that settled or will settle in 2010, and the remaining $75 million related to positions that will settle in 2011 and beyond;
|
·
|
Energy sales – GEN-MW’s results from energy sales, including both physical and financial transactions, decreased from $150 million for the three months ended June 30, 2009 to $109 million for the three months ended June 30, 2010. The contribution from physical transactions was higher primarily as a result of higher power prices at our coal-fired facilities and improved spark spreads at our combined cycle facilities, partially offset by more unplanned outages. However, these increases were more than offset by a reduced contribution from financial transactions; and
|
·
|
Decreased tolling/capacity revenues of $5 million – Tolling/capacity revenues decreased $9 million as a result of the sale of assets in the fourth quarter 2009 and $6 million primarily as a result of terminating our Kendall tolling contract. These decreases were partially offset by higher capacity revenues of $10 million due to additional capacity we were able to sell as a result of the termination of that toll.
|
·
|
Decreased operating and maintenance expenses – operating and maintenance expenses decreased from $61 million for the three months ended June 30, 2009 to $55 million for the three months ended June 30, 2010, primarily as a result of the sale of certain Midwest assets to LS Power in the fourth quarter 2009, as well as lower planned outage expenses.
|
·
|
Mark-to-market losses – GEN-WE’s results for the three months ended June 30, 2010 included mark-to-market losses of $27 million related to forward sales and other derivative contracts, compared to $10 million of mark-to-market gains for the three months ended June 30, 2009. Of the $27 million in 2010 mark-to-market losses, $13 million related to positions that settled or will settle in 2010, and the remaining $14 million related to positions that will settle in 2011 and beyond.
|
·
|
Energy sales – GEN-WE’s results from energy sales, including both physical and financial transactions, increased from $19 million for the three months ended June 30, 2009 to $25 million for the three months ended June 30, 2010. The contribution from physical transactions was lower primarily as a result of reduced spark spreads; however, this decrease was more than offset by increased contribution from financial transactions.
|
·
|
Mark-to-market losses – GEN-NE’s results for the three months ended June 30, 2010 included mark-to-market losses of $48 million related to forward sales and other derivative contracts, compared to gains of $8 million for the three months ended June 30, 2009. Of the $48 million in 2010 mark-to-market losses, $21 million related to positions that settled or will settle in 2010, and the remaining $27 million related to positions that will settle in 2011 and beyond.
|
·
|
Decreased operating and maintenance expenses – Operating and maintenance expenses decreased from $50 million for the three months ended June 30, 2009 to $38 million for the three months ended June 30, 2010 as a result of the sale of our Bridgeport facility in the fourth quarter 2009 and lower maintenance expenses;
|
·
|
A coal inventory write-down of approximately $8 million recorded during the second quarter 2009; and
|
·
|
Energy sales – GEN-NE’s results from energy sales, including both physical and financial transactions, increased from $17 million for the three months ended June 30, 2009 to $23 million for the three months ended June 30, 2010. The contribution from physical transactions increased primarily as a result of improved spark spreads and higher prices resulting from warmer weather, partially offset by the sale of our Bridgeport facility in the fourth quarter 2009. The contribution from financial transactions also increased.
|
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Revenues
|
$ | 549 | $ | 214 | $ | 334 | $ | — | $ | 1,097 | ||||||||||
Cost of sales
|
(237 | ) | (96 | ) | (206 | ) | — | (539 | ) | |||||||||||
Operating and maintenance expense, exclusive of depreciation and amortization expense shown separately below
|
(104 | ) | (49 | ) | (77 | ) | (1 | ) | (231 | ) | ||||||||||
Depreciation and amortization expense
|
(113 | ) | (33 | ) | (16 | ) | (3 | ) | (165 | ) | ||||||||||
Impairment and other charges
|
— | — | (1 | ) | — | (1 | ) | |||||||||||||
General and administrative expense
|
— | — | — | (59 | ) | (59 | ) | |||||||||||||
Operating income (loss)
|
$ | 95 | $ | 36 | $ | 34 | $ | (63 | ) | $ | 102 | |||||||||
Losses from unconsolidated investments
|
(34 | ) | — | — | — | (34 | ) | |||||||||||||
Other items, net
|
— | — | 1 | 1 | 2 | |||||||||||||||
Interest expense
|
(180 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(110 | ) | ||||||||||||||||||
Income tax benefit
|
63 | |||||||||||||||||||
Loss from continuing operations
|
(47 | ) | ||||||||||||||||||
Income from discontinued operations, net of taxes
|
1 | |||||||||||||||||||
Net loss
|
$ | (46 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Revenues
|
$ | 694 | $ | 183 | $ | 478 | $ | (1 | ) | $ | 1,354 | |||||||||
Cost of sales
|
(260 | ) | (85 | ) | (296 | ) | — | (641 | ) | |||||||||||
Operating and maintenance expense, exclusive of depreciation and amortization expense shown separately below
|
(112 | ) | (51 | ) | (92 | ) | 3 | (252 | ) | |||||||||||
Depreciation and amortization expense
|
(108 | ) | (30 | ) | (31 | ) | (6 | ) | (175 | ) | ||||||||||
Goodwill impairments
|
(76 | ) | (260 | ) | (97 | ) | — | (433 | ) | |||||||||||
Impairment and other charges, exclusive of goodwill impairments shown separately above
|
— | — | (387 | ) | — | (387 | ) | |||||||||||||
General and administrative expense
|
— | — | — | (83 | ) | (83 | ) | |||||||||||||
Operating income (loss)
|
$ | 138 | $ | (243 | ) | $ | (425 | ) | $ | (87 | ) | $ | (617 | ) | ||||||
Earnings from unconsolidated investments
|
— | 20 | — | 1 | 21 | |||||||||||||||
Other items, net
|
2 | 2 | — | 4 | 8 | |||||||||||||||
Interest expense
|
(196 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(784 | ) | ||||||||||||||||||
Income tax benefit
|
113 | |||||||||||||||||||
Loss from continuing operations
|
(671 | ) | ||||||||||||||||||
Loss from discontinued operations, net of taxes.
|
(12 | ) | ||||||||||||||||||
Net loss
|
(683 | ) | ||||||||||||||||||
Less: Net loss attributable to the noncontrolling interests
|
(3 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Inc.
|
$ | (680 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Revenues
|
$ | 549 | $ | 214 | $ | 334 | $ | — | $ | 1,097 | ||||||||||
Cost of sales
|
(237 | ) | (96 | ) | (206 | ) | — | (539 | ) | |||||||||||
Operating and maintenance expense, exclusive of depreciation and amortization expense shown separately below
|
(104 | ) | (49 | ) | (77 | ) | (1 | ) | (231 | ) | ||||||||||
Depreciation and amortization expense
|
(113 | ) | (33 | ) | (16 | ) | (3 | ) | (165 | ) | ||||||||||
Impairment and other charges
|
— | — | (1 | ) | — | (1 | ) | |||||||||||||
General and administrative expense
|
— | — | — | (59 | ) | (59 | ) | |||||||||||||
Operating income (loss)
|
$ | 95 | $ | 36 | $ | 34 | $ | (63 | ) | $ | 102 | |||||||||
Losses from unconsolidated investments
|
(34 | ) | — | — | — | (34 | ) | |||||||||||||
Other items, net
|
— | — | 1 | 1 | 2 | |||||||||||||||
Interest expense
|
(180 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(110 | ) | ||||||||||||||||||
Income tax benefit
|
56 | |||||||||||||||||||
Loss from continuing operations
|
(54 | ) | ||||||||||||||||||
Income from discontinued operations, net of taxes
|
1 | |||||||||||||||||||
Net loss
|
$ | (53 | ) |
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
Revenues
|
$ | 694 | $ | 183 | $ | 478 | $ | (1 | ) | $ | 1,354 | |||||||||
Cost of sales
|
(260 | ) | (85 | ) | (296 | ) | — | (641 | ) | |||||||||||
Operating and maintenance expense, exclusive of depreciation and amortization expense shown separately below
|
(112 | ) | (51 | ) | (92 | ) | 1 | (254 | ) | |||||||||||
Depreciation and amortization expense
|
(108 | ) | (30 | ) | (31 | ) | (6 | ) | (175 | ) | ||||||||||
Goodwill impairments
|
(76 | ) | (260 | ) | (97 | ) | — | (433 | ) | |||||||||||
Impairment and other charges, exclusive of goodwill impairments shown separately above
|
— | — | (387 | ) | — | (387 | ) | |||||||||||||
General and administrative expense
|
— | — | — | (83 | ) | (83 | ) | |||||||||||||
Operating income (loss)
|
$ | 138 | $ | (243 | ) | $ | (425 | ) | $ | (89 | ) | $ | (619 | ) | ||||||
Earnings from unconsolidated investments
|
— | 20 | — | — | 20 | |||||||||||||||
Other items, net
|
2 | 2 | — | 3 | 7 | |||||||||||||||
Interest expense
|
(196 | ) | ||||||||||||||||||
Loss from continuing operations before income taxes
|
(788 | ) | ||||||||||||||||||
Income tax benefit
|
117 | |||||||||||||||||||
Loss from continuing operations
|
(671 | ) | ||||||||||||||||||
Loss from discontinued operations, net of taxes.
|
(2 | ) | ||||||||||||||||||
Net loss
|
(673 | ) | ||||||||||||||||||
Less: Net loss attributable to the noncontrolling interests
|
(3 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Holdings Inc.
|
$ | (670 | ) |
Six Months Ended
June 30,
|
|||||||
2010
|
2009
|
||||||
GEN-MW
|
|||||||
Million Megawatt Hours Generated (1)
|
12.0 | 12.5 | |||||
In Market Availability for Coal Fired Facilities (2)
|
89 | % | 88 | % | |||
Average Capacity Factor for Combined Cycle Facilities (3)
|
20 | % | 29 | % | |||
Average Quoted On-Peak Market Power Prices ($/MWh) (4)
|
|||||||
Cinergy (CIN Hub)
|
$ | 42 | $ | 37 | |||
Commonwealth Edison (NI Hub)
|
$ | 41 | $ | 36 | |||
PJM West
|
$ | 52 | $ | 48 | |||
Average Market Spark Spreads ($/MWh) (5)
|
|||||||
PJM West
|
$ | 14 | $ | 12 | |||
GEN-WE
|
|||||||
Million Megawatt Hours Generated (6) (7)
|
1.9 | 2.3 | |||||
Average Capacity Factor for Combined Cycle Facilities (3)
|
38 | % | 38 | % | |||
Average Quoted On-Peak Market Power Prices ($/MWh) (4)
|
|||||||
North Path 15 (NP 15)
|
$ | 41 | $ | 36 | |||
Average Market Spark Spreads ($/MWh) (5)
|
|||||||
North Path 15 (NP 15)
|
$ | 5 | $ | 5 | |||
GEN-NE
|
|||||||
Million Megawatt Hours Generated
|
3.1 | 5.3 | |||||
In Market Availability for Coal Fired Facilities (2)
|
94 | % | 95 | % | |||
Average Capacity Factor for Combined Cycle Facilities (3)
|
33 | % | 44 | % | |||
Average Quoted On-Peak Market Power Prices ($/MWh) (4)
|
|||||||
New York—Zone G
|
$ | 55 | $ | 53 | |||
New York—Zone A
|
$ | 40 | $ | 39 | |||
Mass Hub
|
$ | 52 | $ | 49 | |||
Average Market Spark Spreads ($/MWh) (5)
|
|||||||
New York—Zone A
|
$ | 3 | $ | 6 | |||
Mass Hub
|
$ | 13 | $ | 11 | |||
Fuel Oil
|
$ | (74 | ) | $ | (31 | ) | |
Average natural gas price—Henry Hub ($/MMBtu) (8)
|
$ | 4.73 | $ | 4.13 |
(1)
|
Excludes approximately less than 0.1 million MWh generated by our Bluegrass power generation facility, which we sold on November 30, 2009 and is reported in discontinued operations, for the six months ended June 30, 2009.
|
(2)
|
Reflects the percentage of generation available during periods when market prices are such that these units could be profitably dispatched.
|
(3)
|
Reflects actual production as a percentage of available capacity. Excludes Arizona power generation facilities which are reported as discontinued operations with respect to the GEN-WE segment. For the 2009 period presented, includes the Tilton, Rocky Road, Riverside and Renaissance power generation facilities with respect to the GEN-MW segment and the Bridgeport power generation facility with respect to the GEN-NE segment.
|
(4)
|
Reflects the average of day-ahead quoted prices for the periods presented and does not necessarily reflect prices we realized.
|
(5)
|
Reflects the simple average of the spark spread available to a 7.0 MMBtu/MWh heat rate generator selling power at day-ahead prices and buying delivered natural gas or fuel oil at a daily cash market price and does not reflect spark spreads available to us.
|
(6)
|
Includes our ownership percentage in the MWh generated by our GEN-WE investment in the Black Mountain power generation facility for the six months ended June 30, 2010 and 2009, respectively.
|
(7)
|
Excludes less than 0.1 million MWh generated by the Heard County power generation facility, which we sold in April 2009 and is reported in discontinued operations, for the six months ended June, 30, 2009. Excludes approximately 0.5 million MWh generated by our Arizona power generation facilities, which we sold on November 30, 2009 and are reported in discontinued operations, for the six months ended June 30, 2009.
|
(8)
|
Reflects the average of daily quoted prices for the periods presented and does not reflect costs incurred by us.
|
Six Months Ended June 30, 2010
|
||||||||||||||||||||
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
(in millions)
|
||||||||||||||||||||
PPEA Holding impairment
|
$ | (37 | ) | $ | — | $ | — | $ | — | $ | (37 | ) | ||||||||
Taxes
|
— | — | — | 11 | 11 | |||||||||||||||
Total—DHI
|
(37 | ) | — | — | 11 | (26 | ) | |||||||||||||
Taxes
|
— | — | — | 5 | 5 | |||||||||||||||
Total—Dynegy
|
$ | (37 | ) | $ | — | $ | — | $ | 16 | $ | (21 | ) |
Six Months Ended June 30, 2009
|
||||||||||||||||||||
Power Generation
|
||||||||||||||||||||
GEN-MW
|
GEN-WE
|
GEN-NE
|
Other
|
Total
|
||||||||||||||||
(in millions)
|
||||||||||||||||||||
Impairments
|
$ | (76 | ) | $ | (260 | ) | $ | (484 | ) | $ | — | $ | (820 | ) | ||||||
Sandy Creek mark-to-market gains (1)
|
— | 25 | — | — | 25 | |||||||||||||||
Discontinued operations (2)
|
(23 | ) | 4 | — | — | (19 | ) | |||||||||||||
Taxes
|
— | — | — | (15 | ) | (15 | ) | |||||||||||||
Total—DHI
|
(99 | ) | (231 | ) | (484 | ) | (15 | ) | (829 | ) | ||||||||||
Taxes
|
— | — | — | (6 | ) | (6 | ) | |||||||||||||
Total—Dynegy
|
$ | (99 | ) | $ | (231 | ) | $ | (484 | ) | $ | (21 | ) | $ | (835 | ) |
(1)
|
These mark-to-market gains represent our 50 percent share.
|
(2)
|
Discontinued operations includes a $23 million impairment of the Bluegrass power generation facility in GEN-MW and a gain of $10 million on the sale of the Heard County power generation facility in GEN-WE.
|
·
|
Energy sales – GEN-MW’s results from energy sales, including both physical and financial transactions, decreased from $334 million for the six months ended June 30, 2009 to $241
million for the six months ended June 30, 2010. The contribution from physical transactions increased primarily as a result of higher power prices at our coal fired facilities and improved spark spreads at our combined cycle facilities, partially offset by more unplanned outages; however, these increases were more than offset by reduced contribution from financial transactions; and
|
·
|
Mark-to-market losses – GEN-MW’s results for the six months ended June 30, 2010 included mark-to-market losses of $4 million related to forward sales and other derivative contracts, compared to $40 million of mark-to-market gains for the six months ended June 30, 2009. Of the $4 million in 2010 mark-to-market losses, $34 million of losses related to positions that settled or will settle in 2010, partly offset by $30 million of gains related to positions that will settle in 2011 and beyond.
|
·
|
Increased tolling/capacity revenues of $17 million – Tolling revenues increased by $12 million primarily as a result of a termination fee received for exiting our Kendall tolling contract early. Capacity revenues also increased by $22 million due to previously contracted PJM capacity at higher prices than the prior year and additional capacity revenue from previously tolled power generation facilities. These increases were partially offset by a $17 million reduction in tolling/capacity revenues as a result of asset sales; and
|
·
|
Decreased operating and maintenance expenses – operating and maintenance expenses decreased from $112 million for the six months ended June 30, 2009 to $104 million for the six months ended June 30, 2010, primarily as a result of the sale of certain Midwest assets to LS Power in the fourth quarter 2009 as well as lower planned outage expenses.
|
·
|
Reduced mark-to-market losses – GEN-WE’s results for the six months ended June 30, 2010 included mark-to-market losses of $4 million related to forward sales and other derivative contracts, compared to $19 million of mark-to-market losses for the six months ended June 30, 2009. Of the $4 million in 2010 mark-to-market losses, $9 million in gains related to positions that settled or will settle in 2010, and was more than offset by $13 million in losses related to positions that will settle in 2011 and beyond; and
|
·
|
Energy sales – GEN-WE’s results from energy sales, including both physical and financial transactions, increased from $44 million for the six months ended June 30, 2009 to $52 million for the six months ended June 30, 2010. The contribution from physical transactions decreased primarily as a result of reduced spark spreads; however, this decrease was more than offset by increased contribution from financial transactions.
|
·
|
Reduced mark-to-market gains – GEN-NE’s results for the six months ended June 30, 2010 included mark-to-market gains of $3 million related to forward sales and other derivative contracts, compared to gains of $37 million for the six months ended June 30, 2009. Of the $3 million in 2010 mark-to-market gains, $6 million in gains related to positions that settled or will settle in 2010, and offset by $3 million in losses related to positions that will settle in 2011 and beyond;
|
·
|
Energy sales – GEN-NE’s results from energy sales, including both physical and financial transactions, decreased from $49 million for the six months ended June 30, 2009 to $38 million for the six months ended June 30, 2010. The contribution from physical tranactions decreased primarily as a result of weaker winter spark spreads and the sale of our Bridgeport facility in the fourth quarter 2009, partially offset by improved spark spreads and higher prices resulting from warmer weather in the second quarter as well as increased contribution from financial transactions;
|
·
|
Emissions sales – sales of emissions decreased by $10 million due to lower sale volumes and market prices of emissions credits in 2010; and
|
·
|
Decreased capacity revenues of $6 million – Capacity revenues decreased primarily due to an $11 million reduction in capacity revenue from the Bridgeport facility that was sold to LS Power in the fourth quarter 2009. This decrease was partially offset by increased capacity revenues at our other facilities due to slightly higher prices.
|
·
|
Decreased operating and maintenance expenses – Operating and maintenance expenses decreased from $92 million for the six months ended June 30, 2009 to $77 million for the six months ended June 30, 2010, primarily as a result of the sale of our Bridgeport facility in the fourth quarter 2009 and lower maintenance expenses; and
|
·
|
Coal inventory write-down of approximately $10 million recorded during the six months ended 2009.
|
As of and for the
Six Months Ended June 30, 2010
|
||||
(in millions)
|
||||
Balance Sheet Risk-Management Accounts
|
||||
Fair value of portfolio at December 31, 2009
|
$ | (33 | ) | |
Risk-management gains recognized through the income statement in the period, net
|
109 | |||
Cash received related to risk-management contracts settled in the period, net
|
(117 | ) | ||
Changes in fair value as a result of a change in valuation technique (1)
|
— | |||
Non-cash adjustments and other (2)
|
49 | |||
Fair value of portfolio at June 30, 2010
|
$ | 8 |
(1)
|
Our modeling methodology has been consistently applied.
|
(2)
|
Includes the reduction of $50 million of risk management activity as of January 1, 2010 due to the deconsolidation of PPEA Holding. Please read Note 1—Accounting Policies
—Accounting Policies Adopted—Variable Interest Entities for further discussion.
|
Total
|
2010
|
2011
|
2012
|
2013
|
2014
|
Thereafter
|
||||||||||||||||||||||
(in millions)
|
||||||||||||||||||||||||||||
Market quotations (1)
|
$ | 3 | $ | 26 | $ | 1 | $ | (24 | ) | $ | — | $ | — | $ | — | |||||||||||||
Prices based on models(2)(3)
|
5 | 17 | 7 | (22 | ) | — | 1 | 2 | ||||||||||||||||||||
Total
|
$ | 8 | $ | 43 | $ | 8 | $ | (46 | ) | $ | — | $ | 1 | $ | 2 |
(1)
|
Prices obtained from actively traded, liquid markets for commodities.
|
(2)
|
The market quotations and prices based on models categorization differs from the fair value accounting standards’ categories of Level 1, Level 2 and Level 3 due to the application of the different methodologies. Please see Note 6—Fair Value Measurements for further discussion.
|
(3)
|
The majority of the $17 million in 2010 is for instances where industry-standard models are used but the pricing inputs combine broker quotes for a liquid delivery hub with broker quotes for the price spread between the liquid delivery hub and the location under the contract. Therefore, the value is included in the prices based on models category.
|
·
|
the timing and anticipated benefits to be achieved through our 2010-2013 company-wide cost reduction program;
|
·
|
beliefs and assumptions relating to liquidity, available borrowing capacity and capital resources generally;
|
·
|
expectations regarding environmental matters, including costs of compliance, availability and adequacy of emission credits, and the impact of ongoing proceedings and potential regulations or changes to current regulations, including those relating to climate change, air emissions, cooling water intake structures, coal combustion byproducts, and other laws and regulations to which we are, or could become, subject;
|
·
|
beliefs about the overall economy, demand for power, commodity pricing and generation volumes;
|
·
|
anticipated liquidity in the regional power and fuel markets in which we transact, including the extent to which such liquidity could be affected by poor economic and financial market conditions or new regulations and any resulting impacts on financial institutions and other current and potential counterparties;
|
·
|
sufficiency of, access to and costs associated with coal, fuel oil and natural gas inventories and transportation thereof;
|
·
|
beliefs and assumptions about market competition, generation capacity and regional supply and demand characteristics of the wholesale power generation market, including the anticipation of higher market pricing over the longer term;
|
·
|
the possibility of further consolidation of the power generation industry and the impact of any such activity on Dynegy;
|
·
|
the beliefs and assumptions regarding our ability to enhance long-term value for stockholders;
|
·
|
the effectiveness of our strategies to capture opportunities presented by changes in commodity prices and to manage our exposure to energy price volatility;
|
·
|
beliefs and assumptions about weather and general economic conditions;
|
·
|
projected operating or financial results, including anticipated cash flows from operations, revenues and profitability;
|
·
|
expectations regarding our revolver capacity, credit facility compliance, financial covenants, collateral demands, capital expenditures, interest expense and other payments;
|
·
|
beliefs or expectations regarding the potential amendment, extension or refinancing of our Credit Facility, or the timing thereof;
|
·
|
our focus on safety and our ability to efficiently operate our assets so as to maximize our revenue generating opportunities and operating margins;
|
·
|
beliefs about the outcome of legal, regulatory, administrative and legislative matters; and
|
·
|
expectations and estimates regarding capital and maintenance expenditures, including the Midwest Consent Decree and its associated costs.
|
June 30,
2010
|
December 31,
2009
|
|||||||
(in millions)
|
||||||||
One day VaR—95 percent confidence level (1)
|
$ | 20 | $ | 41 | ||||
One day VaR—99 percent confidence level (1)
|
$ | 29 | $ | 57 | ||||
Average VaR for the year-to-date period—95 percent confidence level (1)
|
$ | 29 | $ | 34 |
(1)
|
The decrease in the June 30, 2010 VaR was primarily due to lower commodity price and historical volatility levels as compared to December 31, 2009.
|
Investment
Grade Quality
|
Non-Investment Grade Quality
|
Total
|
||||||||||
(in millions)
|
||||||||||||
Type of Business:
|
||||||||||||
Financial institutions
|
$ | 25 | $ | — | $ | 25 | ||||||
Utility and power generators
|
11 | — | 11 | |||||||||
Commercial, industrial and end users
|
1 | — | 1 | |||||||||
Oil and gas producers
|
2 | — | 2 | |||||||||
Total
|
$ | 39 | $ | — | $ | 39 |
June 30,
2010
|
December 31,
2009
|
|||||||
Fair value hedge interest rate swaps (in millions of U.S. dollars)
|
$ | 25 | $ | 25 | ||||
Fixed interest rate received on swaps (percent)
|
5.70 | 5.70 | ||||||
Interest rate risk-management contract (in millions of U.S. dollars) (1)
|
$ | 231 | $ | 784 | ||||
Fixed interest rate paid on swaps (percent)
|
5.35 | 5.33 | ||||||
Interest rate risk-management contract (in millions of U.S. dollars)
|
$ | 206 | $ | 206 | ||||
Fixed interest rate received on swaps (percent)
|
5.28 | 5.28 |
(1)
|
Reflects the reduction of $553 million of notional financial contract amounts due to the deconsolidation of PPEA Holding. Please read Note 1—Accounting Policies
—Accounting Policies Adopted—Variable Interest Entities for further discussion.
|
Period
|
(a)
Total Number of Shares
Purchased
|
(b)
Average
Price Paid
per Share
|
(c)
Total Number of Shares Purchased as Part of Publicly Announced Plans
or Programs
|
(d)
Maximum Number of Shares that May Yet Be Purchased Under the Plans or
Programs
|
||||||||||||
April 1-30
|
49,321 | $ | 6.25 | — | N/A | |||||||||||
May 1-31
|
104 | $ | 6.60 | — | N/A | |||||||||||
June 1-30
|
16 | $ | 6.25 | — | N/A | |||||||||||
Total
|
49,441 | $ | 6.25 | — | N/A |
Exhibit Number
|
Description
|
|
3.1
|
Dynegy’s Second Amended and Restated Certificate of Incorporation, amended as of May 21, 2010 (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K of Dynegy Inc. and Dynegy Holdings Inc. filed on May 25, 2010).
|
|
10.1
|
Dynegy Inc. 2010 Long Term Incentive Plan (incorporated by reference to Exhibit 4.1 to the Registration Statement on Form S-8 of Dynegy Inc. filed on May 26, 2010).
|
|
10.2
|
Facility and Security Agreement, executed May 21, 2010 (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K of Dynegy Inc. and Dynegy Holdings Inc. filed on May 25, 2010).
|
|
10.3
|
The Global Amendment to Equity-Based Compensation Agreements, executed on May 25, 2010 (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K of Dynegy Inc. and Dynegy Holdings Inc. filed on May 25, 2010).
|
|
*10.4
|
Second Amendment to the Dynegy Inc. Restoration Pension Plan, executed on July 2, 2010.
|
|
Chief Executive Officer Certification Pursuant to Rule 13a-14(a) and 15d-14(a), As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
||
*31.1(a)
|
Chief Executive Officer Certification Pursuant to Rule 13a-14(a) and 15d-14(a), As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
|
*31.2
|
Chief Financial Officer Certification Pursuant to Rule 13a-14(a) and 15d-14(a), As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
|
*31.2(a)
|
Chief Financial Officer Certification Pursuant to Rule 13a-14(a) and 15d-14(a), As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
|
†32.1
|
Chief Executive Officer Certification Pursuant to 18 United States Code Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
|
†32.1(a)
|
Chief Executive Officer Certification Pursuant to 18 United States Code Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
|
†32.2
|
Chief Financial Officer Certification Pursuant to 18 United States Code Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
|
†32.2(a)
|
Chief Financial Officer Certification Pursuant to 18 United States Code Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
|
**101.INS
|
XBRL Instance Document
|
|
**101.SCH
|
XBRL Taxonomy Extension Schema Document
|
|
**101.CAL
|
XBRL Taxonomy Extension Calculation Linkbase Document
|
|
**101.DEF
|
XBRL Taxonomy Extension Definition Linkbase Document
|
|
**101.LAB
|
XBRL Taxonomy Extension Label Linkbase Document
|
|
**101.PRE
|
XBRL Taxonomy Extension Presentation Linkbase Document
|
*
|
Filed herewith.
|
†
|
Pursuant to Securities and Exchange Commission Release No. 33-8238, this certification will be treated as “accompanying” this report and not “filed” as part of such report for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or the Exchange Act, or otherwise subject to the liability of Section 18 of the Exchange Act, and this certification will not be deemed to be incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Exchange Act.
|
**
|
XBRL information is furnished and not filed for purposes of Section 11 and 12 of the Securities Act of 1933 and Section 18 of the Securities Exchange Act of 193, and is not subject to liability under those sections, is not part of any registration statement or prospectus to which it relates and is not incorporated or deemed to be incorporated by reference into any registration statement, prospectus or other document.
|
DYNEGY INC.
|
||
Date: August 6, 2010
|
By:
|
/s/ H
OLLI
C
.
N
ICHOLS
|
Holli C. Nichols
Executive Vice President and Chief Financial Officer
(Duly Authorized Officer and Principal Financial Officer)
|
DYNEGY HOLDINGS INC.
|
||
Date: August 6, 2010
|
By:
|
/s/ H
OLLI
C
.
N
ICHOLS
|
Holli C. Nichols
Executive Vice President and Chief Financial Officer
(Duly Authorized Officer and Principal Financial Officer)
|
1.
|
Section 2.5 of the Plan shall be deleted, and the following Section 2.5 shall be substituted therefor:
|
2.
|
Capitalized terms used but not defined herein shall have the meanings attributed to such terms in the Plan.
|
3.
|
As amended hereby, the Plan is specifically ratified and reaffirmed.
|
By:
|
/s/ Julius Cox
|
|
|
Julius Cox,
Chairman of Benefit Plans Committee and VP of HR
|
I, Bruce A. Williamson, certify that:
|
1.
|
I have reviewed this report on Form 10-Q of Dynegy Inc.;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
(d)
|
Disclosed in this quarterly report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: August 6, 2010
|
By:
|
/s/ B
RUCE
A. W
ILLIAMSON
|
Bruce A. Williamson
Chairman of the Board, President and Chief Executive Officer
|
I, Bruce A. Williamson, certify that:
|
1.
|
I have reviewed this report on Form 10-Q of Dynegy Holdings Inc.;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
(d)
|
Disclosed in this quarterly report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: August 6, 2010
|
By:
|
/s/ B
RUCE
A. W
ILLIAMSON
|
Bruce A. Williamson
President and Chief Executive Officer
|
I, Holli C. Nichols, certify that:
|
1.
|
I have reviewed this report on Form 10-Q of Dynegy Inc.;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
(d)
|
Disclosed in this quarterly report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: August 6, 2010
|
By:
|
/s/ H
OLLI
C. N
ICHOLS
|
Holli C. Nichols
Executive Vice President and Chief Financial Officer
|
I, Holli C. Nichols, certify that:
|
1.
|
I have reviewed this report on Form 10-Q of Dynegy Holdings Inc.;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
(d)
|
Disclosed in this quarterly report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: August 6, 2010
|
By:
|
/s/ H
OLLI
C. N
ICHOLS
|
Holli C. Nichols
Executive Vice President and Chief Financial Officer
|
(1)
|
the Report fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company at the dates and for the periods indicated.
|
Date: August 6, 2010
|
By:
|
/s/ B
RUCE
A. W
ILLIAMSON
|
Bruce A. Williamson
Chairman of the Board, President and Chief Executive Officer
|
(1)
|
the Report fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company at the dates and for the periods indicated.
|
Date: August 6, 2010
|
By:
|
/s/ B
RUCE
A. W
ILLIAMSON
|
Bruce A. Williamson
President and Chief Executive Officer
|
(1)
|
the Report fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company at the dates and for the periods indicated.
|
Date: August 6, 2010
|
By:
|
/s/ H
OLLI
C
.
N
ICHOLS
|
|
Holli C. Nichols
Executive Vice President and Chief Financial Officer
|
(1)
|
the Report fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company at the dates and for the periods indicated.
|
Date: August 6, 2010
|
By:
|
/s/ H
OLLI
C
.
N
ICHOLS
|
|
Holli C. Nichols
Executive Vice President and Chief Financial Officer
|