Public Service Enterprise Group
Bank of America Merrill Lynch Power & Gas Leaders Conference
New York City
September 22, 2009
Forward-Looking Statement
Readers are cautioned that statements contained in this presentation about our and our subsidiaries' future performance, including future
revenues, earnings, strategies, prospects and all other statements that are not purely historical, are forward-looking statements for purposes of
the safe harbor provisions under The Private Securities Litigation Reform Act of 1995. Although we believe that our expectations are based on
reasonable assumptions, we can give no assurance they will be achieved. The results or events predicted in these statements may differ
materially from actual results or events. Factors which could cause results or events to differ from current expectations include, but are not
limited to:
Adverse changes in energy industry, law, policies and regulation, including market structures and rules, and reliability standards.
Any inability of our energy transmission and distribution businesses to obtain adequate and timely rate relief and regulatory approvals from
federal and state regulators.
Changes in federal and/or state environmental requirements that could increase our costs or limit operations of our generating units.
Changes in nuclear regulation and/or developments in the nuclear power industry generally, that could limit operations of our nuclear generating
units.
Actions or activities at one of our nuclear units that might adversely affect our ability to continue to operate that unit or other units at the same
site.
Any inability to balance our energy obligations, available supply and trading risks.
Any deterioration in our credit quality.
Availability of capital and credit at reasonable pricing terms and our ability to meet cash needs.
Any inability to realize anticipated tax benefits or retain tax credits.
Changes in the cost of or interruption in the supply of fuel and other commodities necessary to the operation of our generating units.
Delays or cost escalations in our construction and development activities.
Adverse investment performance of our decommissioning and defined benefit plan trust funds, and changes in discount rates and funding
requirements.
Changes in technology and increased customer conservation.
For further information, please refer to our Annual Report on Form 10-K, including Item 1A. Risk Factors, and subsequent reports on Form 10-Q
and Form 8-K filed with the Securities and Exchange Commission. These documents address in further detail our business, industry issues and
other factors that could cause actual results to differ materially from those indicated in this presentation. In addition, any forward-looking
statements included herein represent our estimates only as of today and should not be relied upon as representing our estimates as of any
subsequent date. While we may elect to update forward-looking statements from time to time, we specifically disclaim any obligation to do so,
even if our internal estimates change, unless otherwise required by applicable securities laws.
GAAP Disclaimer
PSEG presents Operating Earnings in addition to its Net Income reported
in accordance with accounting principles generally accepted in the United
States (GAAP). Operating Earnings is a non-GAAP financial measure that
differs from Net Income because it excludes the impact of the sale of
certain non-core domestic and international assets and material
impairments and lease-transaction-related charges. PSEG presents
Operating Earnings because management believes that it is appropriate
for investors to consider results excluding these items in addition to the
results reported in accordance with GAAP. PSEG believes that the non-
GAAP financial measure of Operating Earnings provides a consistent and
comparable measure of performance of its businesses to help
shareholders understand performance trends. This information is
not intended to be viewed as an alternative to GAAP information. The last
slide in this presentation includes a list of items excluded from Net Income
to reconcile to Operating Earnings, with a reference to that slide included
on each of the slides where the non-GAAP information appears.
PSEG - Review and Outlook
Caroline Dorsa
Executive Vice President and Chief Financial Officer
PSEG establishing a policy leadership position …
Electric and Gas
Delivery
Leveraged Leases and
Renewable Investments
Regional
Wholesale Energy
… in promoting a sustainable energy future.
PSE&G positioned to
meet NJ’s energy policy
and economic growth
objectives; rate base
growth of 13% to $9.9B
by 2011.
PSEG Power’s low-cost
baseload nuclear fleet
well-positioned in
carbon constrained
environment.
PSEG Energy Holdings
positioned to pursue
attractive renewable
generation opportunities.
Compressed Air Energy
Storage (CAES)
Solar
Offshore wind
Public Service Enterprise Group …
… an energy provider
meeting the needs of customers
and shareholders.
Meeting
Commitments
Delivering
Value Today
Positioned for
the Future
PSEG: Establishing a foundation…
Meeting Commitments
Achieved 2008 earnings targets
Operational excellence drove results
Sharpened business focus; international assets
sold
Balance sheet strengthened; credit outlook
improved
Attractive dividend growth rate
… and building a record that sets us apart.
YTD Operating Earnings by Subsidiary
$ 751
(9)
78
187
$ 495
2008
$ 800
(3)
40
166
$ 597
2009
Operating Earnings
Earnings per Share
(0.02)
(0.01)
Enterprise
$ 1.47
$ 1.58
Operating Earnings*
0.15
0.08
PSEG Energy Holdings
0.37
0.33
PSE&G
$ 0.97
$ 1.18
PSEG Power
2008
2009
$ millions (except EPS)
Six months ended June 30,
* See page 67 for Items excluded from Income from Continuing Operations to reconcile to Operating Earnings.
Low-cost portfolio
Regional focus in competitive, liquid
markets
Assets favorably located near
customers/load centers
Many units east of PJM
constraints
Southern NEPOOL/ Connecticut
Market knowledge and experience
to maximize the value of our assets
… with low cost plants, in good locations, within solid markets.
Power’s assets support commitments in a dynamic environment…
18%
45 %
9 %
27 %
Fuel Diversity
Coal
Gas
Oil
Nuclear
Pumped
Storage
1%
Energy Produced – 2008
53%
23%
23%
Pumped Storage
& Oil 1%
Nuclear
Coal
Gas
Total GWh: 55,300
Total MW: 13,576
PSEG Power’s focus on operational excellence…
… resulted in a record year of power generation.
53,617
53,197
55,292
30,000
40,000
50,000
60,000
96
91.4
92.6
50
75
100
31.8
35.8
42.6
0
25
50
Total Generation (GWh)
Nuclear Capacity
Factor (%)
Combined Cycle
Capacity Factor (%)
2007
2008
2007
2008
2006
2008
2006
2006
2007
Operated by PSEG Nuclear
PSEG Ownership: 100%
Technology:
Boiling Water Reactor
Total Capacity: 1,211MW
Owned Capacity: 1,211MW
License Expiration: 2026
August 2009: Filed for
20-year license extension
Operated by PSEG Nuclear
Ownership: PSEG - 57%,
Exelon – 43%
Technology:
Pressurized Water Reactor
Total Capacity: 2,345MW
Owned Capacity: 1,346MW
License Expiration: 2016 and
2020
August 2009: Filed for
20-year license
extension
Operated by Exelon
PSEG Ownership: 50%
Technology:
Boiling Water Reactor
Total Capacity: 2,224MW
Owned Capacity: 1,112MW
License Expiration: 2033
and 2034
Hope Creek
Salem Units 1 and 2
Peach Bottom
Units 2 and 3
Our five unit nuclear fleet …
… is a critical element of Power’s success.
Clear operational focus at Nuclear…
2006
Merger
termination
announced
PSEG Power
resumes
independent
operations of
Nuclear
Hope Creek
uprate
completed;
Salem steam
generator
replacement
… has driven improving results at PSEG Power.
2007
2008
2009
2010
Improvement
in capacity
factors;
application for
license
extensions at
Hope Creek
and Salem
Hope Creek –
Early Site
Permit
application for
new nuclear
Meeting
Commitments
Delivering
Value Today
Positioned for
the Future
Our nuclear performance has continued to improve…
79
80
97
94
92
97
96
96
97
96
97
2004
2005
2006
2007
2008
2009 Target
24.7
27.3
29.1
28.4
29.3
29.8
2004
2005
2006
2007
2008
2009 Target
INPO Index ( )
Highest capacity factor in the industry for Hope
Creek in 2008
Highest Nuclear output in Power’s history
2008 INPO Index for NJ Units of 92 would have
been 97, excluding planned Salem steam
generator replacement
Nuclear Generation Output ( )
(000’s GWH)
Forced Loss Rate ( )
(%)
3.1
2.1
0.6
0.7
0.6
0.6
0.6
0.6
1.0
0.7
2004
2005
2006
2007
2008
2009 Target
… as we maintain our relentless drive for excellence.
NJ Units
1st Quartile
NJ Units
1st Quartile
11.1
Salem’s benchmarking against the industry…
Indicator
Unit
2004
2005
2006
2007
2008
2009 PROJ
1
2
Industrial Safety (OSHA) 2-yr avg
1
2
1
0
2
0
0
1
2
Safety System Reliability
1
2
1
2
1
2
1
2
1
2
1
2
1
2
Production Cost (2-yr avg)
Fuel Reliability (Annual value)
CM Backlogs (Annual value)
1
4
1
1
1
0
1
2
7
0
1
2
2
0
Key
N/A
1st Quartile
2nd Quartile
3rd Quartile
4th Quartile
Forced Outages Annual value)
Significant Events (Annual value)
Emergency Diesel Generators (3-year avg)
Auxiliary Feedwater (3-year avg)
Safety Injection (3-year avg)
Chemistry Performance/Effectiveness Index (18mth)
Capacity Factor (2-yr avg)
Forced Loss Rate (2-yr avg)
Refueling Outage Duration (Annual value)
INPO Index (Annual value)
Collective Radiation Exposure (3-year avg)
Unplanned Scram Rate (per 7000 hrs)
… assured a constant striving for excellence.
Hope Creek’s performance against its peers has greatly improved…
… setting top quartile performance goals for 2009.
2004
2005
2006
2007
2008
2009 PROJ
INPO Index (not an average)
Industrial Safety (OSHA) 2-yr avg
Collective Radiation Exposure (3-yr avg)
Unplanned Scram Rate (per 7000 hrs)
Significant Events (annual value)
Safety System Reliability
Emergency Diesel Generators (3-year avg)
Residual Heat Removal (3-year avg)
High Pressure Coolant Injection (3-year avg)
Chemistry Performance/Effectiveness Index (18 mnth)
Capacity Factor (2-yr avg)
Forced Loss Rate (2-yr avg)
Refueling Outage Duration (annual value)
Production Cost (2-yr avg)
Fuel Reliability (annual value)
CM Backlogs (annual value)
Forced Outages (annual value)
3
3
0
2
0
2
Key
N/A
1st Quartile
2nd Quartile
3rd Quartile
4th Quartile
National carbon regulation …
… would benefit Power’s low carbon fleet.
The diversity of the portfolio makes Power well positioned to capture
value in a wide range of potential regulatory outcomes.
CO2 $/Ton Impact on PJM Prices and Power’s EBITDA
Illustration at $20 CO2:
(2008 Data)
55 TWh
x ~ $12 to $14/MWh
~ $660 – $770 M revenue
20M tons
x $20/ton
~ $400 M expense
The impact on
electric prices
moderates at higher
CO2 prices as:
-the fleet dispatch
changes, and
-the CO2 intensity of
the grid goes down.
$0
$100
$200
$300
$400
$500
$600
$700
$0
$10
$20
$30
$40
CO2 Price ($/ton)
$2.68
$3.00 - $3.25
$3.03
* See page 68 for Items excluded from Income from Continuing Operations to reconcile to Operating Earnings.
PSEG – 2009 guidance maintained …
… but, upper end a challenge.
PSEG – Delivering Value: Today and Tomorrow
Delivering
Value Today
Positioned for
the Future
Achieved 2008 earnings
targets
Operational excellence
drove results
Sharpened business focus;
international assets sold
Balance sheet
strengthened; credit
outlook improved
Attractive dividend growth
rate
2009 earnings guidance
represents continued
growth
Operational excellence
improving results
Core business
investments providing
attractive returns
Dividend increased – 6th
consecutive year; 102nd
year of paying an annual
dividend
Strong financial position
– credit metrics, liquidity
Balanced business mix
BGS: A demonstrated
mechanism for meeting
customer supply at market
prices for multi-year period
Federal and State policies
provide opportunities for
growth – Leadership position
in energy policy
T&D investments providing
growth with minimal rate
impact
Strong financial position and
cash flow provide flexibility in
volatile markets – No need to
issue equity
Meeting
Commitments
PSEG Power – Overview
Delivering
Value Today
Positioned for
the Future
Meeting
Commitments
Achieved 2008 earnings
targets
Improved operating
performance of generation
fleet
Environmental
commitments met
$1 Billion capital expense
on budget, met specs
Disciplined hedging
strategies have managed
earnings volatility and
reduced risk
2009 earnings guidance of
$1,170M - $1,245M reflects
impact of abnormally cool
weather
Continued Operational
Excellence Model (OEM)
implementation with
demonstrated
improvements at Fossil
Sustained, strong nuclear
performance
Successful multi-year
hedging strategy supported
by BGS, RPM in liquid
markets
Effective management of
costs and capital programs
to drive value
Low-cost, baseload
nuclear fleet benefits in
carbon constrained world
BET installation improves
operating capability of coal
fleet and enables a wide
variety of coals
Expansion opportunities
through existing
experience and
infrastructure, including
peaker bids
Strong free cash flow
PSEG Power - Delivering Value: Today and Tomorrow
… of serving full requirement load contracts, while maintaining
optionality under a variety of conditions.
Power’s assets along the dispatch curve reduce the risk…
X
X
Ancillary Revenue
X
X
X
X
Capacity Revenue
X
X
Energy Revenue
X
X
Dual Fuel
Baseload units
Load following units
Peaking units
Illustrative
Salem
Hope
Creek
Keystone
Conemaugh
Hudson 2
Linden 1,2
Burlington 8-9-11
Edison 1-2-3
Essex 10-11-12
Bergen 1
Sewaren 1-4
Hudson 1
Mercer1, 2
Bergen 2
Sewaren 6
Mercer 3
Kearny 10-11
Linden 5-8 / Essex 9
Burlington 12 / Kearny 12
Peach
Bottom
Bridgeport
New
Haven
Nuclear
Coal
Combined Cycle
Steam
Peaking
BEC
Yards
Creek
National Park
2003
2004
2005
2006
2007
2008
2009*
Increase in Full Requirements
Component Due to:
Increased Congestion (East/West Basis)
Increase in Capacity Markets/RPM
Volatility in Market Increases Risk
Premium
The recent successful completion of the seventh BGS auction...
Market Perspective – BGS Auction Results
… cushions the impact of volatile markets on customers.
Note: BGS prices reflect PSE&G Zone
Full Requirements
3 Year Average
Round the Clock
PJM West
Forward Energy
Price
$55.05
$65.41
~ $18
~ $21
$102.51
~ $32
$98.88
~ $41
~ $43
$111.50
~ $47
$103.72
$55.59
~ $21
Capacity
Load shape
Transmission
Congestion
Ancillary services
Risk premium
Green
$33 - $34
$36 - $37
$44 - $46
$67 - $70
$58-$60
$68 - $71
$56 - $58
*2009 RTC price was ~ $50/MWh at time of auction
-
2,000
4,000
6,000
8,000
10,000
12,000
-
2,000
4,000
6,000
8,000
10,000
12,000
Power’s output is sold forward…
… through full requirement contracts and other hedging transactions.
2009 2010 2011
2009 2010 2011
Nuclear
Coal
CC
Steam / Pk
Existing Hedges
Existing Loads+ Hedges
Existing Loads+ Hedges + Potential Future BGS
Total Fleet On-Peak Average MW
Total Fleet Off-Peak Average MW
$0
$20
$40
$60
$80
$100
2004
2005
2006
2007
2008
2009
Fwd*
2010
Fwd
2011
Fwd
Commodity prices have been volatile…
… but Power’s diverse asset portfolio and hedging strategy has
mitigated the effect of volatility, providing strong results.
Henry Hub NYMEX
($/MMBTU)
Western Hub RTC
($/MWh)
West Hub On Peak
($/MWh)
Central Appalachian Coal
($/Ton)
Note: Forward prices as of 8/27/09
$0
$20
$40
$60
$80
$100
$120
2004
2005
2006
2007
2008
2009
Fwd*
2010
Fwd
2011
Fwd
$0
$2
$4
$6
$8
$10
2004
2005
2006
2007
2008
2009
Fwd*
2010
Fwd
2011
Fwd
$0
$20
$40
$60
$80
$100
2004
2005
2006
2007
2008
2009
Fwd*
2010
Fwd
2011
Fwd
*Average of 8 historical months and 4 forward months
The effect of our hedging/forward sales strategy…
Power’s hedging strategy
secures pricing over a 2 - 3 year
future time horizon.
The 3 year BGS Auction period
has the effect of pulling forward
prices back.
… is to create a realized price that is a blend of prior and future pricing,
moderating volatility.
PJM West
PS Zone vs PJM West Basis
2009 realized
price
*
$0
$20
$40
$60
$80
$100
2004
2005
2006
2007
2008
2009 Fwd
2010 Fwd
2011 Fwd
*PJM West Average of 8 historical months and 4 forward months
-$10
$0
$10
$20
$30
$40
$50
2005
2006
2007
2008
2009
2010
2011
$0
$10
$20
$30
$40
$50
$60
$70
2005
2006
2007
2008
2009
2010
2011
Annual Average
Historical Monthly
Forecast
Spark and dark spreads …
PJM Western Hub Spark Spread (On-Peak – Henry Hub * 7.5 Heat Rate)
PJM Western Hub Dark Spread (RTC – Central Appalachian Coal * 10 Heat Rate)
… have declined near-term in response to weak demand.
Note: Forward prices as of 08/27/09
0%
25%
50%
75%
100%
2009
2010
2011
$40
$50
$60
$70
$80
$90
0%
25%
50%
75%
100%
2009
2010
2011
$0
$50
$100
$150
Power’s hedging program provides near-term stability from
market volatility…
… while remaining open to long-term market forces.
Estimated EPS impact of
$10/MWh PJM West around
the clock price change*
(~$2/mmbtu gas change)
Contracted Capacity
Estimated EPS impact of
$30/MW-day capacity
price change*
Price
(right
scale)
*As of June 2009; Assuming normal market commodity correlations and demand
Power has
contracted at
attractive prices,
which includes
locational basis
and load shaping
premium.
The pricing for
most of Power’s
capacity has been
fixed through May
2013, with the
completion of
auctions in PJM
and NE.
% sold
(left
scale)
$0.25 - $0.45
$0.10 - $0.20
$0.01 - $0.02
$0.00 - $0.01
$0.00 - $0.01
$0.00 - $0.01
Contracted Energy
Price
(right
scale)
% sold
(left
scale)
2012 / 2013 RPM Auction Results
PSEG Power’s assets are in
constrained zones, which
cleared at higher prices.
Power’s offer for 178MW of new
capacity was accepted by PJM.
Auction results reflect impact of
new transmission capability.
… Power expects to see continued strong margins from PJM’s
Reliability Pricing Model.
Through the new capacity construct, and pricing at auction
prices…
$185.00
PSEG North Zone
$16.46
$110.00
$174.29
$102.04
$111.92
$40.80
Rest of Pool
$133.37
$110.00
$174.29
191.32
MAAC
$139.73
$110.00
$174.29
$191.32
$148.80
$197.67
Eastern MAAC
2012 / 2013
2011 / 2012
2010 / 2011
2009 / 2010
2008 / 2009
2007 / 2008
PJM Zones
With nearly 1/3 of its capacity in PS North and nearly 2/3 of its capacity in
MAAC and EMAAC, Power’s assets in congested locations received higher
pricing in the 2012/2013 RPM Auction.
PJM Capacity Available to Receive Auction Pricing
0
2,000
4,000
6,000
8,000
10,000
12,000
07/08
08/09
09/10
10/11
11/12
12/13
2008 Operating
Earnings*
Energy
Capacity
Other Margin
Cost
2009 Guidance
… with visible sources of value to achieve this result.
Power’s commitment in 2009 reflects continued earnings
growth…
$1,107M
$1,170 -
$1,245M
$90 – 95M
($25 – 15M)
$38– 88M
O&M (pension)
Depreciation
Interest
Other
($40 – 30M)
Power’s 2008 Operating Earnings vs 2009 Guidance
Operations
Uprates
BGS
Recontracting
Fuel
More capacity
open to auction
BGSS
Other
$2,170M EBITDA $2,300 - $2,400M
* See page 68 for Items excluded from Income from Continuing Operations to reconcile to Operating Earnings.
… including market and operational factors.
Power’s earnings for 2010 will be subject to many influences…
$1,170 – $1,245M
Revenue/Margin
Nuclear output largely contracted
Dark Spread change of $5/MWh at
market – impact of $0.05-$0.10/share
Spark Spread change of $5/MWh at
market – impact of $0.05-$0.10/share
Capacity change of $30/MW-day –
impact of $0.00-$0.01/share
Operations
Operational excellence – 1% change in
nuclear capacity factor – impact of
$0.01-$0.03/share
O&M 1% change – impact of
~$0.01/share
Depreciation increase of ~$0.03/share
due to capital in service
2009 Guidance
2010+ Drivers
PSE&G - Review and Outlook
2008 earnings targets met
Transmission formula rate
treatment received from
FERC
Strong O&M control
Reduced Distribution capital
expenditures
National ReliabilityOne
Award winner
2009 earnings outlook
affected by abnormally cool
weather
Distribution base rate case
filed mid-2009
Transmission investment
increasing
New customer information
system implemented at end
of 1st quarter
Active participant in shaping
State energy policy
Prepared to meet NJ’s
stimulus and energy goals
Resolve Distribution base
rate case by mid-2010
Investment program
responsive to NJ’s
economic and energy-
related goals
Transmission formula rates
provide current return on
invested capital
Earnings growth in line with
capital investment
Continue to lead the nation
in electric reliability
PSE&G – Delivering Value: Today and Tomorrow
Delivering
Value Today
Positioned for
the Future
Meeting
Commitments
PSE&G regulatory strategy…
Earn authorized returns
Minimize regulatory lag
Support state energy goals
Maintain/enhance local relationships
…designed to support customer and shareholder requirements.
New Jersey Electric & Gas Rate Case*
Filed: May 29, 2009
Test Year: 2009**
51.2%
Equity Ratio
11.5%
Return on Equity
*New Jersey BPU decision anticipated within 9-12 months.
**Test year can be updated for known changes.
$2.4 billion
$3.8 billion
Rate Base
$96.9 million
$133.7 million
Increase
Gas
Electric
Request
Includes tracking mechanisms for capital expenditure and pension costs.
PSE&G’s current investment plan including the recently
approved NJ stimulus and EMP programs…
33%
52%
15%
0%
30%
4%
19%
47%
32%
17%
1%
50%
… now provides for growth in rate base of 13%.
PSE&G Rate Base
27%
23%
6%
44%
Electric Transmission
Electric Distribution
Gas Distribution
Energy Master Plan
2008
Rate Base $6.9B
Equity Ratio ~ 50%
2009
Rate Base $7.5B
Equity Ratio ~ 51%*
2010
Rate Base $8.8B
Equity Ratio ~ 51%*
2011
Rate Base $9.9B
Equity Ratio ~ 51%*
*Pending regulatory approval
Transmission Growth
PJM approved the $750M Susquehanna to
Roseland line in October 2007
Siting and permitting process underway
Incentives approved by FERC:
ROE: 12.93% (125 basis point adder)
100% CWIP in Rate Base
FERC approval of Sub-Transmission to
Transmission system reliability investments
represents about $340M through 2011, post-2011
~$60M per year
Total investment in PJM approved projects,
including Susquehanna to Roseland of $1.4B over
2009-2011
PJM approved the Branchburg-Roseland-Hudson
line in November 2008. Additional 500 kV
investments could further increase transmission
investment by approximately $1.0 -1.5B.
These opportunities will require substantial deployment of capital with siting
and permitting as the major challenges.
Branchburg
Roseland
Jefferson
New Freedom
Smithburg
Deans
MAPP
Hope Creek
Salem
Project
I-765
Interstate
Project
PSE&G implemented fully-forecasted formula rates with an 11.68%
base ROE, which provides attractive current return on investments.
2008 Regulatory Activities
A.
Solar Loan Program
($105M)
Approved April 2008
Up to 30MW
B.
Demand Response
($63M)
Filed August 2008. Decision
pending
Reduce demand by residential
and small commercial
customers by 150MW
C.
Carbon Abatement
Program ($47M)
Approved December 2008
Provides energy efficiency
programs
A
C
B
2009 Regulatory Activities
D.
Capital Economic Stimulus Infrastructure Investment
Program ($694M)
Filed January 2009, approved April 2009; 10.0% ROE
Accelerate capital investments to promote economic stimulus and
promote job growth in NJ
E.
Solar Loan Program – Phase II
Filed March 2009
F.
Electric and Gas Distribution base
rate case
Filed May 2009
G.
Energy Efficiency Economic Stimulus Program
($190M)
Approved July 2009
Promote job growth and stimulate NJ economy via energy
efficiency expenditures
H.
Solar 4 All ($515M)
Approved July 2009
80MW of utility-owned solar generation
D
E
G
H
I
2010 Regulatory Activities
I.
Resolve Electric and
Gas Distribution
base rate case
Normal BPU schedule would
have resolution of rate
proceeding by mid-2010
2011 will be first full year of
rate relief
2008
2009
2010
May
Dec
Dec
Jan
Jan
Jun
F
… with a manageable rate increase of 2% - 4% to customers.
$215M Filed
PSE&G is well positioned to respond to NJ’s needs…
18.5
0
2
4
6
8
10
12
14
16
18
20
PSE&G
Average
2011
Based on tariff rates in effect in March 2009.
… produces superior value to our electric and gas customers.
Electricity
(500kWh/month bill)
BGS
Delivery
Clauses
17.7
1.60
0.00
0.20
0.40
0.60
0.80
1.00
1.20
1.40
1.60
1.80
PSE&G
Average
2011
Gas
(100 therm/month bill)
BGSS
Delivery
Clauses
1.48
Source: Rates from PSE&G, NYPSC and PAPUC
1.53
BGSS
Delivery *
Clauses
BGS***
Delivery *
Clauses
Potential
Investments**
18.2
* Includes base rate increases
** Includes NJ stimulus filing (Capital and EEE), Solar 4 All and Solar II
Potential
Investments**
*** Assumes BGS/BGSS pricing remains constant
Combining operational excellence with prices comparable to
regional competitors …
2008 Operating
Earnings*
Weather
Transmission
Pension
Depreciation,
Interest and Other
2009 Guidance
$360M
$0 - 5M
$315 –
$335M
$5 - 10M
… increasing pension, depreciation and interest costs.
($40 - 35M)
($10 - 5M)
In 2009, controlling O&M helps to mitigate the effects of…
*See page 68 for Items excluded from Income from Continuing Operations to reconcile to Operating Earnings
PSE&G – Business Drivers
Operational excellence and effective cost
management
Distribution rate case should improve
2009 ROE’s of 8.0% - 8.8% to 9.0% - 9.5%
Addresses capital investment, O&M and
sales losses
1% change in Distribution rate case ROE for
2010 = ~$21M change in earnings
Transmission Investment under formula
rates. ROE ~ 11.7%
Capital Stimulus could provide an
additional 25 – 50 basis points to ROE
Energy Master Plan investments for
Energy Efficiency and Renewables could
provide an additional 5 – 10 basis points
to ROE if approved as planned.
A ±1% deviation in sales would result in a
±$15M change to margin revenues
$315 – $335M
2009 Guidance
2010+ Drivers
PSEG Energy Holdings -
Review and Outlook
PSEG Energy Holdings – Delivering Value: Today and Tomorrow
Exceeded 2008 earnings
targets
Strong 2008 Texas
performance well
above expectations
Stable earnings from
US contracted
generation assets
Sale of international
assets yielded $1.5B over
2007-2008
Proactively reserved for
potential LILO/SILO
liability
2009 earnings outlook
improved with lease
terminations
Achieving predictable
performance from
contracted US generation
assets
Improving Texas
operations via asset
management agreement
with PSEG Power
Redeemed approximately
$280M of Texas project
debt
Managing risk by limiting
growth in lease tax liability
Sufficient liquidity and
credit strength to fund
potential LILO/SILO liability
through cash, asset value
and debt capacity
Exploring opportunities to
optimize other U.S. assets
Pursuing attractive
renewable generation
opportunities
Compressed Air
Energy Storage
(CAES)
Solar
Offshore Wind
Meeting
Commitments
Delivering
Value Today
Positioned for
the Future
By reducing its investment in international assets …
… Holdings has decreased its risk profile and improved its
business focus.
$0.4
$0.5
$0.5
$0.8
$2.2
$1.4
$0.1
2004
2006
2008
2009 Projected*
PSEG Global Invested Capital
($ Billions)
$2.6B
$1.9B
$0.6B
$0.8B
*Investment Includes redemption of Texas debt in February 2009
International
Domestic
Texas assets are the major driver of PSEG Global’s business
results…
…PSEG Texas projected EBITDA reflects higher maintenance costs and
market uncertainty.
Strong 2008 performance from favorable market in Spring 2008
Looking ahead to 2009:
Uncertainty on gross margin impact from new wind additions
Operations and maintenance costs approximately $15M higher in 2009 than 2007 as
plants enter periods of major maintenance
Longer-term:
Continued uncertainty from wind
Positive impact from transmission build-up and potential unit mothballing by other
generators
60 – 70
35 – 45%
125 – 135
17%
4.0 - 5.0
2009
PSEG
Market
214
162
$186
Gross
Margin ($M)
147
47.9%
14%
9.0
2008
104
48.7%
15%
6.9
2007
$130
54.4%
16%
$6.7
2006
EBITDA*
($M)
Capacity
Factors
Reserve
Margin
Nat. Gas
Henry Hub Spot
($/mmBtu)
*Excluding Mark-to-Market Accounting effects
Holdings is focused on managing its financial risk.
Net Investment in lease portfolio of $0.4B*.
Book investment of $1.9B less deferred taxes of $1.5B
Reached agreement on termination of eight international leases for
$453M of cash, reducing the portfolio by $358M and reducing our
cash tax liability by $350 million
Sold PPN (20% interest in a 330MW CCGT in India) for
approximately book value, further reducing international investments
Redeemed $280M of non-recourse debt at Texas facilities;
repurchased $10M of Energy Holdings senior notes
September closing on exchange of $368M of Energy Holdings 8.50%
senior notes for PSEG Power 5.32% senior notes
Projected earnings for 2009 reflect the benefit of gains on the Lease terminations as
well as reduced LILO/SILO lease income pending IRS resolution.
* As of 6/30/09
2008 Operating
Earnings*
Texas Margin
and Major
Maintenance
Texas Project
Financing Paid
Off
Global
Contracted
Assets
Global Taxes
Interest & Other
Resources
Lease Sales /
Terminations,
Lease Income &
LILO/SILO
Interest
Resources
Interest, G&A,
Other & Taxes
2009 Guidance
PSEG Energy Holdings – 2009 Earnings Drivers
$99M
$40 – 65M
($60 - 50M)
($10 - 9M)
$14M
($14 - 12M)
$26 - 35M
($15 - 12M)
Holdings 2008 Operating Earnings vs 2009 Guidance
* See page 68 for Items excluded from Income from Continuing Operations to reconcile to Operating Earnings.
PSEG Energy Holdings – Business Drivers
$40 – 65M
2009 Guidance
2010+ Drivers
Sale of remaining international assets
(Book value $9M)
Continued defense of LILO/SILO lease
position with improved return post-
resolution
Focused management of domestic
contracted generation portfolio
Support of 2009 joint venture Energy
Storage & Power in efforts to license
CAES 2 technology
Pursuit of renewable development with
focus on Solar and Offshore Wind
Texas Spark Spread change of
±$5/MWh at market – impact of
approximately $0.03/share
Appendix
Strong operations and risk controls…
… position us to meet challenges of today’s market.
Asset optimization yielding
results
7th successful BGS auction validates
hedging strategy
RPM capacity auction supports asset
values in constrained areas
Power’s dispatch profile provides
operating flexibility
PSE&G focused on reliability and
meeting energy goals
Organization focused on controlling
costs
Challenge to meet the
upper end of our $3.00 -
$3.25 per share operating
earnings guidance.
Investment focus on projects
with attractive risk-adjusted
returns
Infrastructure
Energy Efficiency
Solar
$0.0
$1.0
$2.0
$3.0
Sources
Uses
PSEG Consolidated
2009E Sources and Uses
Cash Ops*
(Non-GAAP)
Shareholder
Dividend
Investment
(includes
Nuclear
Fuel)
Net Asset Sales
Internally generated cash in 2009 is expected to exceed
investment needs.
* Cash Ops (Non-GAAP) represents Cash Ops adjusted for securitization principal repayment, taxes associated with asset sales, and IRS deposits.
IRS Deposit
Net Financing
June 30, 2009 Capital Structure*
($ Billions)
45%
50%
55%
2007
2008
48%
50%
47%
50%
53%
2007
2008
PSE&G
Regulatory Equity Ratio
PSEG Consolidated
Total Debt to Total Capitalization
Our balance sheet has been strengthened …
… which provides us substantial financial flexibility.
*Excludes securitization and non-recourse debt
~$525M reduction in Net Debt
excluding PSE&G
~
~
Consolidated
PSE&G
Power
Holdings
Net Short Term Debt / (Investments)
0.0
0.3
-
-
Total Long-Term Debt
7.1
3.5
2.9
0.5
Preferred Stock
0.1
0.1
-
-
Common Equity
8.4
4.1
4.0
1.1
Total Capitalization
15.6
7.9
6.9
1.6
35%
40%
45%
50%
55%
2007
2008
2009E
20%
25%
30%
35%
2007
2008
2009E
PSEG
Funds from Operations / Total Debt
PSEG Power
Funds from Operations / Total Debt
Target Mid-20’s
~
~
Target Mid-30’s
~
~
We are meeting or exceeding key credit measures …
… maximizing financial flexibility in uncertain credit markets.
… continues 102-year history of paying common dividends.
70%
44%
Payout
Ratio
41% - 44%
43%
66%
63%
$1.10
$1.12
$1.33*
$1.17
$1.29
$1.14
2004
2005
2006
2007
2008
2009E
*Indicated annual dividend rate
Dividends per Share
Sixth consecutive annual increase in common dividend …
PSE&G’s investments in Energy Efficiency, Stimulus and Solar are
conditioned upon receiving reasonable rate treatment.
Future investments are weighted towards PSE&G and growth.
2009 - 2011 Capital Expenditures
$0
$500
$1,000
$1,500
$2,000
$2,500
2009
2010
2011
Power –
Sustainability
PSE&G -
Distribution
Infrastructure
Power – BET
Environmental
PSE&G -
Transmission
PSE&G - Other
Solar 4 All
Energy Efficiency
Solar II
(Pending approval)
Power –
Growth
PSEG leadership recognized
Named one
of the Most
Admired
Companies,
2007 & 2008
One of 139 companies
named to DJSI North
America and one of only
10 U.S. electric
companies included
Corporation of the year, 2007
One of the 12 best places to
work in NJ, 2009
One of the 400 best
big companies, 2008
PSE&G named America’s Most
Reliable Utility
3 of past 5 years
Mid-Atlantic Region
winner for the 7th straight year
Carbon Disclosure
Leadership Index 2008
2008
Balanced
Scorecard
Achievement
Award
Second year in a row
Operational excellence, financial strength and disciplined investment…
… position us well in today’s market.
Low payout ratio and strong balance sheet provide support
Is dividend secure?
Strong cash flow well in excess of PSE&G’s equity
requirements
Do you need equity?
Carbon friendly
Federal and State Policy initiatives support capital plans
Focus on regulated company growth moderates commodity
cyclicality
How is PSEG affected
by policy changes?
Multi-year hedging profile supported by core assets
Asset balance dampens relative fuel price volatility
Focused on reducing cost structure
What’s the impact of
commodity volatility?
PSE&G current/pending rate needs equal 2-4% impact
BGS supply generally priced at market
What is impact on
customer from capital
programs?
PSEG Position
Market’s Questions
Q2 2009 Earnings Summary
16
-
Discontinued Operations, Net of Tax
$ 0.61
$ 0.63
EPS from Operating Earnings*
(150)
311
Net Income
(166)
311
Income (Loss) from Continuing
Operations
(479)
(7)
Reconciling Items, Net of Tax
$ 313
$ 318
Operating Earnings
2008
2009
$ millions (except EPS)
Quarter ended June 30,
* See page 67 for Items excluded from Income from Continuing Operations to reconcile to Operating Earnings.
Q2 Operating Earnings by Subsidiary
$ 313
(4)
50
51
$ 216
2008
$ 318
1
36
43
$ 238
2009
Operating Earnings
Earnings per Share
(0.01)
-
Enterprise
$ 0.61
$ 0.63
Operating Earnings*
0.10
0.07
PSEG Energy Holdings
0.10
0.09
PSE&G
$ 0.42
$ 0.47
PSEG Power
2008
2009
$ millions (except EPS)
Quarter ended June 30,
* See page 67 for Items excluded from Income from Continuing Operations to reconcile to Operating Earnings.
PSEG Power – Generation Measures
* Includes figures for Pumped Storage
PSEG Power – Generation (GWh)
7,032
7,196
2,889
1,470
3,648
2,887
0
5,000
10,000
15,000
2008
2009
Quarter ended June 30,
Total Nuclear
Total Coal*
Total Oil & Natural Gas
13,569
11,553
14,296
15,014
6,546
4,149
6,426
5,510
0
10,000
20,000
30,000
2008
2009
Six months ended June 30,
27,268
24,673
$17.20
11,600
$199
35
164
117
47
2009
$36.50
13,600
$496
31
465
379
86
2008
Quarter ended June 30,
$ / MWh
Total Generation
(GWh)
Total Fuel Cost
Nuclear
Total Fossil
Oil & Gas
Coal
($ millions)
291
621
141
201
$20.40
$32.40
24,700
27,300
$503
$884
71
62
432
822
2009
2008
Six months ended June 30,
PSEG Power – Fuel Costs
The implementation of carbon will address the critical issue of global
warming…
~$12.00 - ~$14.00
100%
Total
$0.00
$0.00
0%
Nuclear
$4.80 - $3.60
$8.00
60%- 45%
Gas CC
$1.20 - $0.60
$12.00
10% - 5%
CTs
$6.00 - $10.00
$20.00
30% - 50%
Coal
Impact
$/MWh
On margin
(approximate)
Dispatch curve implication @ $20/ton*
By Fuel Type
$12.0
$18.0
$30.0
@$30
$8.0
$12.0
$20.0
@$20
$4.0
$6.0
$10.0
@$10
Price ($/MWh)
0.4
0.6
1.0
Carbon tons/MWh
CC
CTs
Coal
PSEG Power Generation by Fuel
… and activity continues in the direction of a national program.
*For illustration purposes – potential impact of CO2 on power prices with current dispatch – not an indication of net effect on income.
Energy Produced – 2008
53%
23%
23%
Nuclear
Coal
Gas
Total GWh: 55,300
Pumped Storage
& Oil 1%
The RGGI cap on CO2 emission shows that headroom exists …
200
190
180
170
160
150
140
130
2000
2002
2004
2006
2008
2010
2012
2014
2016
2018
CO2 Emissions vs. RGGI Cap
(Actuals through 2007)
Actual &
Forecast CO2
RGGI Cap
Actual
Projected
… compared to historical emission levels.
Affected Sources
Fossil-fired electric generating
units with a capacity of 25MW
and larger
Targets and Timing
Three-year compliance periods
with the first running from 2009-
2011
Stabilization of CO2 emissions at
recent levels through 2015
(~188 million tons per year)
Achieve a 10% reduction of CO2
emissions below recent levels by
2019
This translates into ~13%
reduction below 1990 levels or
~35% reduction from Business
as Usual (BAU) levels by 2020
Rate Mechanism
PSE&G proposes to recover the costs of the
program through an annual adjustment to electric
and gas rates which would not exceed 1%.
The cost of capital would be based on a capital
structure consisting of 51.2% common equity with a
return on common equity of 11.5% -- consistent
with the return allowed NJNG in its December 2008
base rate case decision.
Energy efficiency investment and savings
Investment Timeline
2009 – 2011 (18 months)
Category
Expenditure
Annual
Lifetime
Annual
Lifetime
Jobs
Residential
($ millions)
Whole House
$10
3,298
52,765
30,125
602,490
51
Multi-Family
19
6,223
99,574
56,848
1,136,960
49
9,521
152,339
86,973
1,739,450
100
Industrial & Commercial
Small Business
20
32,306
484,596
123,077
1,846,154
86
Muni/Local/State Government
25
31,878
478,170
153,846
2,307,692
107
Hospital Efficiency
68
128,640
1,929,600
1,315,337
19,730,061
292
Data Center
10
32,000
480,000
122,699
1,840,491
43
Tech Demo Sub-Program
12
18,947
284,210
192,000
2,880,000
52
Building
2
4,634
69,517
47,387
710,810
9
248,405
3,726,093
1,954,346
29,315,208
589
Admin Sales, Training, Evaluation, IT
24
TOTAL
$190
257,926
3,878,432
2,041,319
31,054,658
689
Savings (MWh)
Savings (Dtherms)
PSE&G Solar 4 All Program
Neighborhood Solar (40 megawatts) - $258.4M investment
Solar panels on utility poles and street lights in neighborhoods throughout
PSE&G’s service territory.
Centralized Solar (40 megawatts) – $256.1M investment
Solar systems on PSE&G land/buildings (25 megawatts).
Solar systems on 3rd Party sites (10 megawatts).
Solar systems on sites in UEZs (5 megawatts).
BPU approved a 10% ROE on its equity capital invested (47.4% common equity in its
capital structure). Return and capital structure will change when a new WACC is
established in a base rate case proceeding. Customer rate impact mitigated by
benefits associated with ITC and the value of electricity and Solar Renewable Energy
Certificates (SRECs) generated by the projects
Items Excluded from Income from Continuing Operations
to Reconcile to Operating Earnings
Please see Page 3 for an explanation of PSEG’s use of Operating Earnings as a non-GAAP financial measure and how
it differs from Net Income.
Pro-forma Adjustments, net of tax
2009
2008
2009
2008
Earnings Impact ($ Millions)
Gain (Loss) on Nuclear Decommissioning Trust (NDT) Fund Related Activity
17
$
(3)
$
(6)
$
(10)
$
Gain (Loss) on Mark-to-Market (MTM)
(24)
14
(39)
19
Lease Reserves
-
(490)
-
(490)
Premium on Bond Redemption
-
-
-
(1)
Total Pro-forma adjustments
(7)
$
(479)
$
(45)
$
(482)
$
Fully Diluted Average Shares Outstanding (in Millions)
507
509
507
509
Per Share Impact (Diluted)
Gain (Loss) on Nuclear Decommissioning Trust (NDT) Fund Related Activity
0.03
$
-
$
(0.01)
$
(0.02)
$
Gain (Loss) on Mark-to-Market (MTM)
(0.05)
0.03
(0.08)
0.04
Lease Reserves
-
(0.96)
-
(0.96)
Premium on Bond Redemption
-
-
-
-
Total Pro-forma adjustments
(0.02)
$
(0.93)
$
(0.09)
$
(0.94)
$
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
Reconciling Items Excluded from Continuing Operations to Compute Operating Earnings
(Unaudited)
June 30,
For the Quarters Ended
For the Six Months Ended
June 30,
Please see Page 3 for an explanation of PSEG’s use of Operating Earnings as a non-GAAP financial measure
and how it differs from Net Income.
Pro-forma Adjustments, net of tax
2008
2007
Earnings Impact (in Millions)
Asset Sales and Impairments:
Impairment of PPN
(9)
$
(2)
$
Impairment of Turboven
(4)
(7)
Loss on Sale of Chilquinta and Luz del Sur
-
(23)
Premium on Bond Redemption
(1)
(28)
Total Asset Sales and Impairments
(14)
(60)
Gain (Loss) on Nuclear Decommissioning Trust (NDT)
Fund Related Activity
(71)
12
Gain on Mark-to-Market (MTM)
16
10
Lease Reserves
(490)
-
Total Pro-forma to Operating Earnings
(559)
$
(38)
$
Fully Diluted Average Shares Outstanding (in Millions)
508
509
Per Share Impact (Diluted)
Asset Sales and Impairments:
Impairment of PPN
(0.02)
$
-
$
Impairment of Turboven
(0.01)
(0.01)
Loss on Sale of Chilquinta and Luz del Sur
-
(0.05)
Premium on Bond Redemption
-
(0.06)
Total Asset Sales and Impairments
(0.03)
(0.12)
Gain (Loss) on Nuclear Decommissioning Trust (NDT)
Fund Related Activity
(0.14)
0.02
Gain on Mark-to-Market (MTM)
0.03
0.02
Lease Reserves
(0.96)
-
Total Pro-forma to Operating Earnings
(1.10)
$
(0.08)
$
For the Twelve Months Ended
December 31,
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
Reconciling Items Excluded from Continuing Operations to Compute Operating Earnings
(Unaudited)
Items Excluded from Income from Continuing Operations to Reconcile to
Operating Earnings