Form 425

 

Filed by Mirant Corporation

Pursuant to Rule 425 under the Securities Act of 1933

and deemed filed pursuant to Rule 14a-12

of the Securities Exchange Act of 1934, as amended

Subject Company: Mirant Corporation

(Commission File No. 001-16107)

Cautionary Language Regarding Forward-Looking Statements

Some of the statements included herein involve forward-looking information. Mirant cautions that these statements involve known and unknown risks and that there can be no assurance that such results will occur. There are various important factors that could cause actual results to differ materially from those indicated in the forward-looking statements, such as, but not limited to, legislative and regulatory initiatives regarding deregulation, regulation or restructuring of the industry of generating, transmitting and distributing electricity (the “electricity industry”); changes in state, federal and other regulations affecting the electricity industry (including rate and other regulations); changes in, or changes in the application of, environmental and other laws and regulations to which Mirant and its subsidiaries and affiliates are or could become subject; the failure of Mirant’s plants to perform as expected, including outages for unscheduled maintenance or repair; environmental regulations that restrict Mirant’s ability or render it uneconomic to operate its plants, including regulations related to the emission of CO2 and other greenhouse gases; increased regulation that limits Mirant’s access to adequate water supplies and landfill options needed to support power generation or that increases the costs of cooling water and handling, transporting and disposing off-site of ash and other byproducts; changes in market conditions, including developments in the supply, demand, volume and pricing of electricity and other commodities in the energy markets, including efforts to reduce demand for electricity and to encourage the development of renewable sources of electricity, and the extent and timing of the entry of additional competition in our markets; continued poor economic and financial market conditions, including impacts on financial institutions and other current and potential counterparties and negative impacts on liquidity in the power and fuel markets in which Mirant and its subsidiaries hedge and transact; increased credit standards, margin requirements, market volatility or other market conditions that could increase Mirant’s obligations to post collateral beyond amounts that are expected, including additional collateral costs associated with over-the-counter hedging activities as a result of new or proposed rules and regulations governing derivative financial instruments, including those resulting from the Dodd-Frank Wall Street Reform and Consumer Protection Act; Mirant’s inability to access effectively the over-the-counter and exchange-based commodity markets or changes in commodity market conditions and liquidity, including as a result of new or proposed rules and regulations governing derivative financial instruments, including those resulting from the Dodd-Frank Wall Street Reform and Consumer Protection Act, which may affect Mirant’s ability to engage in asset management, proprietary trading and fuel oil management activities as expected, or result in material gains or losses from open positions; deterioration in the financial condition of Mirant’s counterparties and the failure of such parties to pay amounts owed to Mirant or to perform obligations or services due to Mirant beyond collateral posted; hazards customary to the power generation industry and the possibility that Mirant may not have adequate insurance to cover losses resulting from such hazards or the inability of Mirant’s insurers to provide agreed upon coverage; the expected


timing and likelihood of completion of the proposed merger with RRI Energy, including the timing, receipt and terms and conditions of required, governmental and regulatory approvals that may reduce anticipated benefits or cause the parties to abandon the merger; the diversion of management’s time and attention from our ongoing business during the time we are seeking to complete the merger; the ability to maintain relationships with employees, customers and suppliers; the ability to integrate successfully the businesses and realize cost savings and any other synergies; and the risk that credit ratings of the combined company or its subsidiaries may be different from what the companies expect; price mitigation strategies employed by ISOs or RTOs that reduce Mirant’s revenue and may result in a failure to compensate Mirant’s generating units adequately for all of their costs; changes in the rules used to calculate capacity, energy and ancillary services payments; legal and political challenges to the rules used to calculate capacity, energy and ancillary services payments; volatility in Mirant’s gross margin as a result of Mirant’s accounting for derivative financial instruments used in its asset management, proprietary trading and fuel oil management activities and volatility in its cash flow from operations resulting from working capital requirements, including collateral, to support its asset management, proprietary trading and fuel oil management activities; Mirant’s ability to enter into intermediate and long-term contracts to sell power or to hedge our future expected generation of power, and to obtain adequate supply and delivery of fuel for its generating facilities, at Mirant’s required specifications and on terms and prices acceptable to it; the failure to utilize new or advancements in power generation technologies; the inability of Mirant’s operating subsidiaries to generate sufficient cash flow to support its operations; the potential limitation or loss of Mirant’s net operating losses notwithstanding a continuation of its stockholder rights plan; Mirant’s ability to borrow additional funds and access capital markets; strikes, union activity or labor unrest; Mirant’s ability to obtain or develop capable leaders and its ability to retain or replace the services of key employees; weather and other natural phenomena, including hurricanes and earthquakes; the cost and availability of emissions allowances; curtailment of operations and reduced prices for electricity resulting from transmission constraints; Mirant’s ability to execute its business plan in California, including entering into new tolling arrangements in respect of its existing generating facilities; Mirant’s ability to execute its development plan in respect of its Marsh Landing generating facility, including obtaining the permits necessary for construction and operation of the generating facility and completing the construction of the generating facility by mid-2013; the ability of Mirant Marsh Landing to meet the conditions to draw under the Marsh Landing credit agreement; the ability of lenders under the Marsh Landing credit facility to fund the Marsh Landing credit agreement; Mirant’s relative lack of geographic diversification of revenue sources resulting in concentrated exposure to the Mirant Mid-Atlantic market; the ability of lenders under Mirant North America’s revolving credit facility to perform their obligations; war, terrorist activities, cyberterrorism and inadequate cybersecurity, or the occurrence of a catastrophic loss; the failure to provide a safe working environment for Mirant’s employees and visitors thereby increasing Mirant’s exposure to additional liability, loss of productive time, other costs, and a damaged reputation; Mirant’s consolidated indebtedness and the possibility that Mirant or its subsidiaries may incur additional indebtedness in the future; restrictions on the ability of Mirant’s subsidiaries to pay dividends, make distributions or otherwise transfer funds to Mirant, including restrictions on Mirant North America contained in its financing agreements and restrictions on Mirant Mid-Atlantic contained in its leveraged lease documents, which may affect Mirant’s ability to access the cash flows of those subsidiaries to make debt service and other


payments; the failure to comply with, or monitor provisions of Mirant’s loan agreements and debt may lead to a breach and, if not remedied, result in an event of default thereunder, which would limit access to needed capital and damage Mirant’s reputation and relationships with financial institutions; and the disposition of the pending litigation described in Mirant’s Form 10-Q for the quarter ended September 30, 2010, filed with the Securities and Exchange Commission.

Mirant undertakes no obligation to update publicly or revise any forward-looking statements to reflect events or circumstances that may arise. The foregoing review of factors that could cause Mirant’s actual results to differ materially from those contemplated in the forward-looking statements included in this news release should be considered in connection with information regarding risks and uncertainties that may affect Mirant’s future results included in Mirant’s filings with the Securities and Exchange Commission at www.sec.gov.

Additional Information and Where To Find It

In connection with the proposed merger between RRI Energy and Mirant, RRI Energy filed with the SEC a registration statement on Form S-4 that includes a joint proxy statement of RRI Energy and Mirant and that also constitutes a prospectus of RRI Energy. The registration statement was declared effective by the SEC on September 13, 2010. RRI Energy and Mirant urge investors and shareholders to read the registration statement, and any other relevant documents filed with the SEC, including the joint proxy statement/prospectus that is a part of the registration statement, because they contain important information. You may obtain copies of all documents filed with the SEC regarding this transaction, free of charge, at the SEC’s website (www.sec.gov). You may also obtain these documents, free of charge, from RRI Energy’s website (www.rrienergy.com) under the tab “Investor Relations” and then under the heading “Company Filings” and from Mirant’s website (www.mirant.com) under the tab “Investor Relations” and then under the heading “SEC Filings.”


Dickerson  Generating Station
Mirant Corporation
Third Quarter 2010 Earnings Results
November 5, 2010


2
Forward-Looking Statements
This
presentation
may
contain
statements,
estimates
or
projections
that
constitute
“forward-looking
statements”
as
defined
under
U.S.
federal
securities
laws.
In
some
cases,
one
can
identify
forward-looking
statements
by
terminology
such
as
“will,”
“expect,”
“plan,”
“lead,”
“project”
or
the
negative
of
these
terms
or
other
comparable
terminology.
Forward-looking
statements
are
subject
to
certain
risks
and
uncertainties
that
could
cause
actual
results
to
differ
materially
from
Mirant’s
historical
experience
and
our
present
expectations
or
projections.
These
risks
include,
but
are
not
limited
to:
(i)
legislative
and
regulatory
initiatives
relating
to
the
electric
utility
industry;
(ii)
changes
in,
or
changes
in
the
application
of,
environmental
or
other
laws;
(iii)
failure
of
our
assets
to
perform
as
expected,
including
due
to
outages
for
unscheduled
maintenance
or
repair;
(iv)
changes
in
market
conditions
or
the
entry
of
additional
competition
in
our
markets;
(v)
the
expected
timing
and
likelihood
of
completion
of
the
proposed
merger
with
RRI
Energy,
including
the
timing,
receipt
and
terms
and
conditions
of
required
governmental
and
regulatory
approvals
that
may
reduce
anticipated
benefits
or
cause
the
parties
to
abandon
the
merger;
the
diversion
of
management’s
time
and
attention
from
our
ongoing
business
during
the
time
we
are
seeking
to
complete
the
merger;
the
ability
to
maintain
relationships
with
employees,
customers
and
suppliers;
the
ability
to
integrate
successfully
the
businesses
and
realize
cost
savings
and
any
other
synergies;
and
the
risk
that
credit
ratings
of
the
combined
company
or
its
subsidiaries
may
be
different
from
what
the
companies
expect;
and
(vi)
those
factors
contained
in
our
periodic
reports
filed
with
the
SEC,
including
in
our
Quarterly
Report
on
Form
10-Q
for
the
period
ended
September
30,
2010.
The
forward-looking
information
in
this
document
is
given
as
of
this
date
only,
and
Mirant
assumes
no
duty
to
update
this
information.
Safe Harbor Statement


3
Additional
Information
and
Where
To
Find
It
In
connection
with
the
proposed
merger
between
RRI
Energy
and
Mirant,
RRI
Energy
filed
with
the
SEC
a
registration
statement
on
Form
S-4
that
includes
a
joint
proxy
statement
of
RRI
Energy
and
Mirant
and
that
also
constitutes
a
prospectus
of
RRI
Energy.
The
registration
statement
was
declared
effective
by
the
SEC
on
September
13,
2010.
RRI
Energy
and
Mirant
urge
investors
and
shareholders
to
read
the
registration
statement,
and
any
other
relevant
documents
filed
with
the
SEC,
including
the
joint
proxy
statement/prospectus
that
is
a
part
of
the
registration
statement,
because
they
contain
important
information.
You
may
obtain
copies
of
all
documents
filed
with
the
SEC
regarding
this
transaction,
free
of
charge,
at
the
SEC’s
website
(www.sec.gov).
You
may
also
obtain
these
documents,
free
of
charge,
from
RRI
Energy’s
website
(www.rrienergy.com)
under
the
tab
“Investor
Relations”
and
then
under
the
heading
“Company
Filings”
and
from
Mirant’s
website
(www.mirant.com)
under
the
tab
“Investor
Relations”
and
then
under
the
heading
“SEC
Filings.”
Non-GAAP
Financial
Information
The
following
presentation
includes
certain
“non-GAAP
financial
measures”
as
defined
in
Regulation
G
under
the
Securities
Exchange
Act
of
1934.
A
schedule
is
attached
hereto
and
is
posted
on
the
Company’s
website
at
mirant.com
(in
the
Investor
Relations
-
Presentations
section)
that
reconciles
the
non-GAAP
financial
measures
included
in
the
following
presentation
to
the
most
directly
comparable
financial
measures
calculated
and
presented
in
accordance
with
Generally
Accepted
Accounting
Principles.
In
addition,
the
Company
has
included
a
more
detailed
description
of
each
of
the
non-GAAP
financial
measures
used
in
this
presentation,
together
with
a
discussion
of
the
usefulness
and
purpose
of
these
measures
as
Exhibit
99.2
to
the
Company’s
Current
Report
on
Form
8-K
furnished
to
the
SEC
with
its
earnings
press
release.
Safe Harbor Statement


4
GenOn
Energy –
Merger Update
Mirant and RRI Energy stockholders approved on October 25, 2010
the proposals related to their proposed merger
Entered into agreements on September 20, 2010 for revolving credit
facility and merger related financings
$788 million five-year revolving credit facility
$700 million seven-year term loan
$675 million of 9.5% senior unsecured notes due 2018
$550 million of 9.875% senior unsecured notes due 2020
Merger remains subject to Hart-Scott-Rodino
clearance by the 
Department of Justice
Merger expected to close by the end of 2010
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


5
Financial Highlights
($millions)
In Q3, change in Adjusted EBITDA principally attributable to
-
Lower realized value of hedges
-
Lower energy gross margins from proprietary trading activities
-
Lower contracted and capacity revenues
-
Higher operating costs primarily because of scrubbers installed in
December 2009 and the Montgomery County, Maryland CO2 levy
imposed on our Dickerson generating facility beginning in May 2010
Higher energy gross margins from generation
Adjusted EBITDA
190
311
501
706
Q3
9 Months
2010
2009
2010
2009
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


6
1.45
1.01
1.15
0.50
0.34
0
3.35
2.34
2.21
1.24
1.01
1.08
0.00
0.50
1.00
1.50
2.00
2.50
3.00
3.50
4.00
2004
2005
2006
2007
2008
2009
YTD 2010
Operations Highlights
Mirant’s safety incident rates remain at low levels
Commercial Availability, the percent of maximum achievable energy gross
margin that was realized in the period, remains at a high level
Commercial Availability
Safety Incident Rates
Lost Time Incident Rate
Lost Time EEI Top Quartile Benchmark
Recordable Incident Rate
Recordable EEI Top Quartile Benchmark
0.34
0.80
84%
87%
89%
88%
80%
85%
90%
95%
100%
2007
2008
2009
YTD 2010
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


7
Market Update Since August
Near term (2010 and 2011)
Natural gas prices decreased and currently trade around $4.30/mmBtu for 2011
Power prices in PJM decreased but heat rates expanded as power prices
declined less than natural gas prices
Northern Appalachian coal prices were relatively unchanged and trade around
$64/ton for 2011
Dark spreads declined
Longer term (2012 –
2015)
Natural gas prices decreased and currently trade in a range of $5.00 to
$5.80/mmBtu
Power prices in PJM decreased but heat rates expanded as power prices
declined less than natural gas prices
Northern Appalachian coal prices were unchanged and are quoted in a range of
$66–
$75/ton
Dark spreads declined
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


8
Electricity Markets
Reserve Margins
Forecasted reserve margins incorporate the latest information from each ISO
Eastern markets are forecasted to tighten because little generation is being built
Source:  Mirant forecasts
8%
12%
16%
20%
24%
28%
32%
36%
40%
2010
2011
2012
2013
2014
New York East
N.California
PJM East
New England
PJM RTO (ex. COMED)
Target Reserve range
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


9
Hedge Levels
Based on Expected Total Generation
Aggregate
Baseload
Coal
1.
Positions as of October 12, 2010
Shaded boxes represent net additions to prior guidance
2.
2010 represents period between November and December
3.
Power hedges include hedges with both power and natural gas
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


10
Marsh Landing Generating Station
(760 MW)
Total project costs are expected to be approximately $700 million including capital costs
and financing fees
Directed Kiewit to commence engineering and procurement
Construction expected to begin in late 2010 and to be completed by mid-2013
Received approval of PPA with PG&E
and all necessary permits to commence
construction
$650 million project financing closed on
October 8, 2010
Includes $500 million construction
and term loan and $150 million of
letter of credit facilities
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


11
Pittsburg Generating Station
Mirant
entered
into
a
new
tolling
agreement
with
PG&E
on
October
28,
2010
to provide electricity from Pittsburg units 5, 6, and 7
Agreement is for total capacity of 1,159 MW for three years
commencing January 1, 2011
Includes options for PG&E to extend agreements for each of 2014
and 2015
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


12
Financial Results
(millions, except per share amounts)
9 Months
2010
2009
2010
2009
Net income
254
$   
55
$     
398
$   
598
$   
Unrealized (gains) losses on derivatives
(167)
   
174
     
(179)
   
(66)
     
Bankruptcy charges and legal contingencies
(1)
       
-
         
-
         
(62)
     
Postretirement benefit curtailment gain
-
         
-
         
(37)
     
-
         
Other
-
         
9
         
11
14
       
Adjusted net income
86
238
193
484
Interest, taxes, depreciation & amortization
104
73
       
308
222
Adjusted EBITDA
190
$   
311
$   
501
$   
706
$   
Diluted weighted average shares outstanding
146
     
146
     
146
     
145
     
Earnings per share:
Net income
1.74
$  
0.38
$  
2.73
$  
4.12
$  
Adjusted net income
0.59
$  
1.63
$  
1.32
$  
3.34
$  
Q3
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


13
Realized Gross Margin
(millions)
Operational
Performance
-
Cash
Generation
-
Prudent
Growth
Q3 2010
Q3 2009
YTD 2010
YTD 2009
Energy
171
72
377
254
Contracted & Capacity
135
147
415
418
Realized Value of Hedges
55
247
202
507
Total Realized Gross Margin
361
466
994
1,179
$361
$466
$994
$1,179
$0
$200
$400
$600
$800
$1,000
$1,200
$1,400


14
Adjusted Free Cash Flow
(millions, except per share amounts)
2010
2009
2010
2009
Net cash provided by operating activities
193
$   
342
$      
343
$      
726
$      
     Bankruptcy claim payments
-
          
-
            
-
            
1
            
     Emission allowance sales proceeds
-
          
3
            
3
            
20
          
     Capitalized interest
-
          
(2)
          
(3)
          
(35)
        
Adjusted net cash provided by operating activities
193
     
343
        
343
        
712
        
Capital expenditures, excluding capitalized interest
(54)
      
(128)
      
(211)
(473)
Adjusted free cash flow
139
     
215
        
132
        
239
        
     MD Healthy Air Act capital expenditures
32
       
88
          
109
        
336
        
     Marsh Landing capital expenditures and working capital
82
       
16
          
84
          
16
          
Adjusted free cash flow (w/o MD HAA & Marsh Landing)
253
$   
319
$      
325
$      
591
$      
     Diluted weighted average shares outstanding
146
     
146
        
146
        
145
        
Adjusted free cash flow per share (w/o MD HAA & Marsh Landing)
1.73
$  
2.18
$     
2.23
$     
4.08
$     
9 Months
Q3
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


15
Consolidated Debt and Liquidity
(millions)
Debt
$        2,561
Cash and cash equivalents
Mirant Corporation
1,421
$       
Mirant Americas Generation
19
              
Mirant North America
245
            
Mirant Mid-Atlantic
273
            
Other
31
              
Total cash and cash equivalents
1,989
         
Less restricted and reserved
(11)
             
Available cash & cash equivalents
1,978
         
Revolver & LC availability
712
            
Total available liquidity
2,690
$       
September 30, 2010
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


16
Capital Expenditures
(millions)
Maryland Healthy Air Act spending prior to 2010 totaled approximately $1.405 billion
Normalized
maintenance
CapEx
of
$50
million
to
$60
million
per
year
Other environmental expenditures include the amounts deposited in escrow for control of
small dust particles as part of the Potomac River agreement
Operational
Performance
-
Cash
Generation
-
Prudent
Growth
2010
1
2011
Environmental
Maryland Healthy Air Act
176
$     
93
$       
Other
7
24
Maintenance
103
47
Construction
Marsh Landing Generating Station
37
180
Other
24
51
Other
12
12
Total
Capital
Expenditures
2
359
$     
407
$     
1
Includes actuals
for January through September
2
Excludes capitalized interest unrelated to the Marsh Landing project financing
Forecast


17
Takeaways
Creation of GenOn
Energy will deliver significant value to stockholders
Hedging cushioned Mirant in Q3 2010 from the effects of relatively low
commodity prices
Eastern markets are forecasted to tighten because little generation is
being built
Mirant completed financing for the Marsh Landing generating facility
and directed Kiewit to commence engineering and procurement
Construction is expected to begin in late 2010
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


Dickerson  Generating Station
Appendix


19
Federal NOL Status
Mirant’s estimated Federal NOL balance at December 31, 2009 was $2.7 billion
An
“ownership
change”
requires
Mirant
to
reset
the
limitation
that
determines
how much annual taxable income may be offset by its NOLs
in future years
An ownership change occurs if there is an increase of more than 50 percentage
points in the ownership of Mirant stock held by large Mirant shareholders from
the date of a previous ownership change
New limitation depends on Mirant stock value on the ownership change date
and an interest rate determined by the IRS
We expect that Mirant will experience an “ownership change”
for federal
income tax purposes  on the closing date of the proposed merger with RRI
Energy
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


20
Federal NOL Status (Cont.)
Assuming the shares of Mirant and RRI Energy are at or near current prices on the
closing date of the proposed merger and both companies experience an ownership
change, Mirant expects that
The combined company, GenOn
Energy, will be unable to use any pre merger NOLs
for the first 5 years following the merger
Thereafter, assuming sufficient taxable income, GenOn
will be able to use
approximately $100MM –
$125MM per year of pre merger NOLs
until such NOLs
expire
Based on current commodity price forecasts, Mirant expects that GenOn
Energy
will pay only federal Alternative Minimum Tax and certain state income taxes during
the 5 years immediately following the merger
Mirant’s Board of Directors has extended its stockholder rights plan and the plan
was approved at its 2010 Annual Meeting of Stockholders held on May 6, 2010
There is no assurance that the stockholder rights plan will prevent an ownership
change prior to the closing date of the proposed merger
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


21
Additional Hedge Information
1
Projected as of October 12, 2010
2
Power hedges include hedges with both power and natural gas
3
Realized Value of Hedges are nominal values and do not include certain adjustments required under fair value accounting
($millions)
Q3
2010
Q3
2009
YTD
2010
YTD
2009
2010
2011
2012
2013
2014
Power
2
59
$   
285
234
608
362
289
208
193
189
Fuel
(4)
      
(38)
    
(32)
    
(101)
  
(34)
    
(23)
    
(33)
   
1
       
1
       
Realized Value of Hedges
55
$   
247
202
507
328
266
175
194
190
Projected
1,3
Actual
Operational
Performance
-
Cash
Generation
-
Prudent
Growth
Nov-Dec 2010
2011
2012
2013
2.37
$         
2.74
$         
2.99
$         
2.74
$         
Average contract price of hedged coal before delivery
($/mmBtu)


22
Quarterly Generation by Dispatch Type
Net MW
Net MWh
Generated
EAF (%) (1)
Net Capacity
Factor (%)
Net MW
Net MWh
Generated
EAF (%) (1)
Net Capacity
Factor (%)
Baseload
MidAtlantic
2,729
4,060,219
91.6
67.1
2,765
3,400,766
87.4
55.7
Northeast
238
399,732
94.5
82.7
238
377,785
95.0
78.1
California
0
0
0
0
Total Baseload
2,967
4,459,951
91.8
68.3
3,003
3,778,551
88.0
57.3
Intermediate
MidAtlantic
1,400
733,421
71.2
24.8
1,400
194,192
53.1
6.6
Northeast
2,265
324,013
85.1
6.5
2,265
111,191
93.4
2.2
California
2,191
254,390
99.9
5.3
2,191
457,168
99.3
9.5
Total Intermediate
5,856
1,311,824
87.5
10.3
5,856
762,551
86.3
6.0
Peaking
MidAtlantic
1,065
120,092
95.3
5.1
1,065
27,772
99.5
1.2
Northeast
32
4,796
100.0
6.8
32
2,012
99.8
2.9
California
156
(235)
98.7
0.0
156
1,484
99.5
0.4
Total Peaking
1,253
124,653
95.8
4.5
1,253
31,268
99.5
1.1
Total Mirant
10,076
5,896,428
89.8
26.7
10,112
4,572,370
88.4
20.7
(1) Equivalent Availability Factor - the total hours a unit is available in a period minus the sum of all full and partial outage equivalent
expressed as a percent of all hours in a period.
Generation by Dispatch Type
Third Quarter 2010
Third Quarter 2009
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


23
Year to Date Generation by Dispatch Type
Net MW
Net MWh
Generated
EAF (%) (1)
Net Capacity
Factor (%)
Net MW
Net MWh
Generated
EAF (%) (1)
Net Capacity
Factor (%)
Baseload
MidAtlantic
2,729
11,094,303
82.2
62.0
2,765
10,568,142
84.9
58.3
Northeast
238
1,119,425
93.2
74.4
238
1,076,030
91.4
71.6
California
0
0
0
0
Total Baseload
2,967
12,213,728
83.0
62.9
3,003
11,644,172
85.4
59.3
Intermediate
MidAtlantic
1,400
1,065,311
53.6
11.9
1,400
333,372
41.9
3.7
Northeast
2,265
382,168
86.2
2.6
2,265
682,781
86.5
4.6
California
2,191
466,242
92.4
3.3
2,191
846,415
86.4
5.9
Total Intermediate
5,856
1,913,721
80.9
5.0
5,856
1,862,568
76.0
4.9
Peaking
MidAtlantic
1,065
190,146
92.2
2.6
1,065
63,284
94.9
0.9
Northeast
32
6,123
92.7
2.9
32
2,381
98.7
1.1
California
156
(823)
97.7
0.0
156
1,986
89.1
0.2
Total Peaking
1,253
195,446
92.9
2.3
1,253
67,651
94.3
0.8
Total Mirant
10,076
14,322,895
83.1
21.6
10,112
13,574,391
81.2
20.5
(1) Equivalent Availability Factor - the total hours a unit is available in a period minus the sum of all full and partial outage equivalent
expressed as a percent of all hours in a period.
Generation by Dispatch Type
YTD 2010
YTD 2009
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


24
Equivalent Forced Outage Rate (EFOR)
EFOR  =
Forced Outage Hours
Forced Outage Hours + Service Hours
2010
2009
2010
2009
Mid-Atlantic Baseload Coal
4%
8%
5%
9%
Q3
YTD
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


25
Mirant Operations
10,076 MW
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


26
Development Opportunities
760 MW Marsh Landing Generating Station will commence
commercial operations in mid-2013
Potential to add 1,700 –
2,700 MWs
of capacity
California
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


27
Share Count
(millions)
Weighted average shares outstanding - basic
146
145
145
145
Effect of dilutive securities
0
1
1
0
Weighted average shares outstanding - diluted
146
146
146
145
Shares outstanding at quarter end - basic
146
145
146
145
Effect of dilutive securities
0
1
0
1
Shares outstanding at end of quarter - diluted
146
146
146
146
Three
Three
Nine
Nine
Months Ending
September 30, 2009
Months Ending
Months Ending
Months Ending
September 30, 2010
September 30, 2009
September 30, 2010
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


28
Regulation G Reconciliation
Operational
Performance
-
Cash
Generation
-
Prudent
Growth
(in millions except per share)
Per
Share
1
Per
Share
1
Net Income
254
$       
1.74
$        
55
$      
0.38
$        
Unrealized losses (gains)
(167)
(1.14)
174
1.19
Impairment losses
-
-
14
0.10
Lower of cost or market inventory adjustments, net
(7)
(0.05)
(6)
(0.04)
Merger-related costs
8
0.06
-
-
Other
(2)
(0.02)
1
-
Adjusted Net Income
86
$         
0.59
$        
238
$    
1.63
$        
Provision for income taxes
-
3
Interest expense, net
51
33
Depreciation and amortization
53
37
Adjusted EBITDA
190
$       
311
$    
Table 1
Net Income to Adjusted Net Income and Adjusted EBITDA
Quarter Ending
Quarter Ending
September 30, 2010
September 30, 2009
1
Per share amounts for 2010 and 2009 are based on diluted weighted average shares outstanding of 146 million.


29
Regulation G Reconciliation
Operational
Performance
-
Cash
Generation
-
Prudent
Growth
(in millions except per share)
Per
Share
1
Per
Share
1
Net Income
398
$     
2.73
$        
598
$   
4.12
$        
Unrealized gains
(179)
(1.23)
(66)
(0.45)
Bankruptcy charges and legal contingencies
-
-
(62)
(0.43)
Severance and bonus plan for dispositions
-
-
13
0.09
Impairment losses
-
-
14
0.10
Lower of cost or market inventory adjustments, net
(1)
(0.01)
(17)
(0.12)
Postretirement benefit curtailment gain
(37)
(0.25)
-
-
Merger-related costs
13
0.09
-
-
Other
(1)
(0.01)
4
0.03
Adjusted Net Income
193
$     
1.32
$        
484
$   
3.34
$        
Provision for income taxes
1
11
Interest expense, net
150
102
Depreciation and amortization
157
109
Adjusted EBITDA
501
$     
706
$   
1
Per
share
amounts
for
2010
are
based
on
diluted
weighted
average
shares
outstanding
of
146
million.
Per
share
amounts
for
2009
are
based
on
diluted
weighted
average
shares
outstanding
of
145
million.
Table 2
Net Income to Adjusted Net Income and Adjusted EBITDA
Year to Date
Year to Date
September 30, 2010
September 30, 2009


30
Regulation G Reconciliation
(in millions )
Mid-
Atlantic
Northeast
California
Other
Operations
Eliminations
Total
Net Income (Loss)
319
$      
(3)
$          
11
$          
(73)
$           
-
$                
254
$      
Unrealized losses (gains)
(179)
       
2
               
-
               
10
               
-
                  
(167)
       
Bankruptcy charges and legal contingencies
-
             
-
               
(1)
             
-
                 
-
                  
(1)
           
Lower of cost or market inventory adjustments, net
(4)
           
-
               
-
               
(3)
                
-
                  
(7)
           
Merger-related costs
-
             
-
               
-
               
8
                 
-
                  
8
             
Gains on sales of assets (excluding emissions allowances), net
-
             
(1)
             
-
               
-
                 
-
                  
(1)
           
Adjusted Net Income (Loss)
136
$      
(2)
$          
10
$          
(58)
$           
-
$                
86
$        
Provision (benefit) for income taxes
(1)
           
-
               
-
               
1
                 
-
                  
-
             
Interest expense, net
1
             
-
               
(1)
             
51
               
-
                  
51
          
Depreciation and amortization
36
          
5
               
8
               
4
                 
-
                  
53
          
Adjusted EBITDA
172
$      
3
$             
17
$          
(2)
$              
-
$                
190
$      
Table 3
Adjusted Net Income (Loss) and Adjusted EBITDA
Quarter Ending September 30, 2010
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


31
Regulation G Reconciliation
(in millions )
Mid-
Atlantic
Northeast
California
Other
Operations
Eliminations
Total
Net Income (Loss)
525
$      
(17)
$        
17
$          
(127)
$         
-
$                
398
$      
Unrealized losses (gains)
(208)
       
16
             
-
               
13
               
-
                  
(179)
       
Bankruptcy charges and legal contingencies
-
             
-
               
(1)
             
1
                 
-
                  
-
             
Lower of cost or market inventory adjustments, net
(3)
           
-
               
-
               
2
                 
-
                  
(1)
           
Postretirement benefit curtailment gain
-
             
-
               
-
               
(37)
              
-
                  
(37)
         
Merger-related costs
-
             
-
               
-
               
13
               
-
                  
13
          
Gains on sales of assets (excluding emissions allowances), net
-
             
(1)
             
-
               
-
                 
-
                  
(1)
           
Adjusted Net Income (Loss)
314
$      
(2)
$          
16
$          
(135)
$         
-
$                
193
$      
Provision (benefit) for income taxes
(1)
           
-
               
-
               
2
                 
-
                  
1
             
Interest expense, net
2
             
1
               
(1)
             
148
             
-
                  
150
        
Depreciation and amortization
105
        
17
             
23
             
12
               
-
                  
157
        
Adjusted EBITDA
420
$      
16
$          
38
$          
27
$             
-
$                
501
$      
Table 4
Adjusted Net Income (Loss) and Adjusted EBITDA
Year to Date September 30, 2010
Continuing Operations
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


32
Regulation G Reconciliation
(in millions )
Mid-
Atlantic
Northeast
California
Other
Operations
Eliminations
Total
Net Income (Loss)
86
$        
5
$             
(5)
$           
(31)
$           
-
$                  
55
$       
Unrealized losses (gains)
124
        
26
             
-
                
24
               
-
                    
174
       
Impairment losses
-
              
-
               
14
              
-
                 
-
                    
14
         
Generating facility shut down costs
-
              
1
               
-
                
-
                 
-
                    
1
           
Lower of cost or market inventory adjustments, net
(4)
           
-
               
-
                
(2)
                
-
                    
(6)
          
Adjusted Net Income (Loss)
206
$      
32
$          
9
$              
(9)
$              
-
$                  
238
$     
Provision for income taxes
-
              
-
               
-
                
3
                 
-
                    
3
           
Interest expense, net
-
              
-
               
1
                
32
               
-
                    
33
         
Depreciation and amortization
25
          
4
               
5
                
3
                 
-
                    
37
         
Adjusted EBITDA
231
$      
36
$          
15
$           
29
$             
-
$                  
311
$     
Table 5
Adjusted Net Income (Loss) and Adjusted EBITDA
Quarter Ending September 30, 2009
Continuing Operations
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


33
Regulation G Reconciliation
(in millions )
Mid-
Atlantic
Northeast
California
Other
Operations
Eliminations
Total
Net Income (Loss)
604
$      
40
$          
(2)
$           
(45)
$           
1
$                  
598
$     
Unrealized losses (gains)
(119)
       
(20)
           
-
                
73
               
-
                    
(66)
        
Bankruptcy charges and legal contingencies
-
              
-
               
-
                
(62)
              
-
                    
(62)
        
Severance and bonus plan for dispositions
-
              
-
               
-
                
13
               
-
                    
13
         
Impairment losses
-
              
-
               
14
              
-
                 
-
                    
14
         
Generating facility shut down costs
-
              
4
               
-
                
-
                 
-
                    
4
           
Lower of cost or market inventory adjustments, net
3
             
(1)
              
1
                
(20)
              
-
                    
(17)
        
Adjusted Net Income (Loss)
488
$      
23
$          
13
$           
(41)
$           
1
$                  
484
$     
Provision for income taxes
-
              
-
               
-
                
11
               
-
                    
11
         
Interest expense, net
2
             
-
               
2
                
98
               
-
                    
102
       
Depreciation and amortization
73
          
13
             
15
              
8
                 
-
                    
109
       
Adjusted EBITDA
563
$      
36
$          
30
$           
76
$             
1
$                  
706
$     
Table 6
Adjusted Net Income (Loss) and Adjusted EBITDA
Year to Date September 30, 2009
Continuing Operations
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


34
Regulation G Reconciliation
(in millions)
Mid-Atlantic
Northeast
California
Other
Operations
Eliminations
Total       
Energy
151
$               
14
$        
-
$           
6
$              
-
$                
171
$             
Contracted & capacity
83
                   
20
          
32
          
-
                 
-
                  
135
               
Incremental realized value of hedges
58
                   
(3)
           
-
              
-
                 
-
                  
55
                 
Realized gross margin
292
                 
31
          
32
          
6
                
-
                  
361
               
Unrealized gross margin
179
                 
(2)
           
-
              
(10)
             
-
                  
167
               
Gross margin
471
$               
29
$        
32
$        
(4)
$             
-
$                
528
$             
(in millions)
Mid-Atlantic
Northeast
California
Other
Operations
Eliminations
Total       
Energy
33
$                 
3
$          
-
$           
36
$           
-
$                
72
$               
Contracted & capacity
90
                   
24
          
33
          
-
                 
-
                  
147
               
Incremental realized value of hedges
214
                 
33
          
-
              
-
                 
-
                  
247
               
Realized gross margin
337
                 
60
          
33
          
36
              
-
                  
466
               
Unrealized gross margin
(124)
                
(26)
         
-
              
(24)
             
-
                  
(174)
              
Gross margin
213
$               
34
$        
33
$        
12
$           
-
$                
292
$             
Gross Margin
Quarter Ending September 30, 2010
Table 7
Quarter Ending September 30, 2009
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


35
Regulation G Reconciliation
(in millions)
Mid-Atlantic
Northeast
California
Other
Operations
Eliminations
Total       
Energy
321
$               
15
$        
-
$           
41
$           
-
$                
377
$             
Contracted & capacity
257
                 
67
          
91
          
-
                 
-
                  
415
               
Incremental realized value of hedges
189
                 
13
          
-
              
-
                 
-
                  
202
               
Realized gross margin
767
                 
95
          
91
          
41
              
-
                  
994
               
Unrealized gross margin
208
                 
(16)
         
-
              
(13)
             
-
                  
179
               
Gross margin
975
$               
79
$        
91
$        
28
$           
-
$                
1,173
$         
(in millions)
Mid-Atlantic
Northeast
California
Other
Operations
Eliminations
Total       
Energy
124
$               
21
$        
-
$           
112
$         
(3)
$              
254
$             
Contracted & capacity
261
                 
68
          
89
          
-
                 
-
                  
418
               
Incremental realized value of hedges
473
                 
34
          
-
              
-
                 
-
                  
507
               
Realized gross margin
858
                 
123
        
89
          
112
           
(3)
                
1,179
           
Unrealized gross margin
119
                 
20
          
-
              
(73)
             
-
                  
66
                 
Gross margin
977
$               
143
$      
89
$        
39
$           
(3)
$              
1,245
$         
Table 8
Gross Margin
Year to Date September 30, 2010
Year to Date September 30, 2009
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


36
Regulation G Reconciliation
(in millions)
Gross margin
528
$                         
292
$                         
Unrealized gross margin
(167)
                          
174
                           
Lower of cost or market inventory adjustments, net
(7)
                              
(6)
                              
Adjusted gross margin
354
                           
460
                           
Operations and maintenance expenses
(172)
                          
(154)
                          
Bankruptcy charges and legal contingencies
-
                                
-
                                
Merger-related costs
8
                               
-
                                
Generating facility shut down costs
-
                                
1
                               
Adjusted operations and maintenance expenses
(164)
                          
(153)
                          
Gain on sales of emissions allowances, net
-
                                
3
                               
Other income (expense), net
-
                                
1
                               
Adjusted EBITDA
190
$                         
311
$                         
Table 9
Gross Margin to Adjusted EBITDA
Quarter  Ending
Quarter  Ending
September 30, 2010
September 30, 2009
Operational
Performance
-
Cash
Generation
-
Prudent
Growth


37
Regulation G Reconciliation
(in millions)
Gross margin
1,173
$                      
1,245
$                          
Unrealized gross margin
(179)
                          
(66)
                                
Lower of cost or market inventory adjustments, net
(1)
                              
(17)
                                
Adjusted gross margin
993
                           
1,162
                            
Operations and maintenance expenses
(470)
                          
(430)
                              
Bankruptcy charges and legal contingencies
-
                                
(62)
                                
Severance and bonus plan for dispositions
-
                                
13
                                 
Merger-related costs
13
                             
-
                                    
Postretirement benefit curtailment gain
(37)
                            
-
                                    
Generating facility shut down costs
-
                                
4
                                   
Adjusted operations and maintenance expenses
(494)
                          
(475)
                              
Gain on sales of emissions allowances, net
3
                               
20
                                 
Other expense, net
(1)
                              
(1)
                                  
Adjusted EBITDA
501
$                         
706
$                             
Table 10
Gross Margin to Adjusted EBITDA
Year to Date
Year to Date
September 30, 2010
September 30, 2009
Operational
Performance
-
Cash
Generation
-
Prudent
Growth