Attached files
| file | filename |
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| 8-K - FORM 8-K - PUBLIC SERVICE ENTERPRISE GROUP INC | d77337d8k.htm |
| EX-99.1 - EX-99.1 - PUBLIC SERVICE ENTERPRISE GROUP INC | d77337dex991.htm |
 EXHIBIT 99 We have the energy to make things better … for you, for our investors and for our stakeholders. |
 Forward-Looking Statement 2 Certain of the matters discussed in this report about our and our subsidiaries' future performance, including, without
limitation, future revenues, earnings, strategies, prospects, consequences and all other statements that are not purely historical constitute “forward-looking statements” within the
meaning of the Private Securities Litigation Reform Act of 1995. Such forward-looking statements are subject to risks and uncertainties, which could cause actual results to differ materially from those
anticipated. Such statements are based on management's beliefs as well as assumptions made by and information currently available to management. When used herein, the words “anticipate,”
“intend,” “estimate,” “believe,” “expect,” “plan,” “should,” “hypothetical,” “potential,” “forecast,” “project,” variations of such words and similar expressions are
intended to identify forward-looking statements. Factors that may cause actual results to differ are often presented with the forward-looking statements themselves. Other factors that could cause actual results to differ
materially from those contemplated in any forward-looking statements made by us herein are discussed in filings we make with the United States Securities and Exchange Commission (SEC), including our
Annual Report on Form 10-K and subsequent reports on Form 10-Q and Form 8-K and available on our website: http://www.pseg.com. These factors include, but are not limited to: • adverse changes in the demand for or the price of the capacity and energy that we sell into wholesale electricity markets, • adverse changes in energy industry law, policies and regulation, including market structures and transmission planning, • any inability of our transmission and distribution businesses to obtain adequate and timely rate relief and regulatory
approvals from federal and state regulators, • changes in federal and state environmental regulations and enforcement that could increase our costs or limit our
operations, • changes in nuclear regulation and/or general developments in the nuclear power industry, including various impacts from
any accidents or incidents experienced at our facilities or by others in the industry, that could limit operations of our nuclear generating units, • actions or activities at one of our nuclear units located on a multi-unit site that might adversely affect our ability
to continue to operate that unit or other units located at the same site, • any inability to manage our energy obligations, available supply and risks, • adverse outcomes of any legal, regulatory or other proceeding, settlement, investigation or claim applicable to us and/or
the energy industry, • any deterioration in our credit quality or the credit quality of our counterparties, • availability of capital and credit at commercially reasonable terms and conditions and our ability to meet cash needs, • changes in the cost of, or interruption in the supply of, fuel and other commodities necessary to the operation of our
generating units, • delays in receipt of necessary permits and approvals for our construction and development activities, • delays or unforeseen cost escalations in our construction and development activities, • any inability to achieve, or continue to sustain, our expected levels of operating performance, • any equipment failures, accidents, severe weather events or other incidents that impact our ability to provide safe and
reliable service to our customers, and any inability to obtain sufficient insurance coverage or recover proceeds of insurance with respect to such events, • acts of terrorism, cybersecurity attacks or intrusions that could adversely impact our businesses, • increases in competition in energy supply markets as well as for transmission projects, • any inability to realize anticipated tax benefits or retain tax credits, • challenges associated with recruitment and/or retention of a qualified workforce, • adverse performance of our decommissioning and defined benefit plan trust fund investments and changes in funding
requirements, • changes in technology, such as distributed generation and micro grids, and greater reliance on these technologies, and • changes in customer behaviors, including increases in energy efficiency, net-metering and demand response. All of the forward-looking statements made in this report are qualified by these cautionary statements and we cannot
assure you that the results or developments anticipated by management will be realized or even if realized, will have the expected consequences to, or effects on, us or our business prospects,
financial condition or results of operations. Readers are cautioned not to place undue reliance on these forward-looking statements in making any investment decision. Forward-looking
statements made in this report apply only as of the date of this report. While we may elect to update forward-looking statements from time to time, we specifically disclaim any obligation to do so,
even if internal estimates change, unless otherwise required by applicable securities laws.
The forward-looking statements contained in this report are
intended to qualify for the safe harbor provisions of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended.
|
 3 GAAP Disclaimer These materials and other financial releases can be found on the pseg.com
website under the investor tab, or at
http://investor.pseg.com/ PSEG presents Operating
Earnings and Adjusted Earnings Before Interest, Taxes, Depreciation and Amortization (EBITDA) in addition to its Income from Continuing Operations/Net Income reported in
accordance with accounting principles generally accepted in the
United States (GAAP). Operating Earnings and
Adjusted EBITDA are non-GAAP financial measures that differ from Income from Continuing Operations/Net Income. Operating Earnings exclude gains or losses associated with Nuclear
Decommissioning Trust (NDT), Mark-to-Market (MTM)
accounting, and other material one-time items. 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.
PSEG is presenting Adjusted EBITDA because it provides investors
with additional information to compare our
business performance to other companies and understand
performance trends. Adjusted EBITDA excludes the
same items as our Operating Earnings measure as well as income tax expense, interest expense, depreciation and amortization and major maintenance expense costs at Power’s fossil generation facilities.
This
information
is
not
intended
to
be
viewed
as
an
alternative
to
GAAP
information.
The
last
three
slides
in
this presentation (Slides A, B and C) include a list of items
excluded from Income from Continuing
Operations/Net Income to reconcile to Operating Earnings and
Adjusted EBITDA with a reference to that slide
included on each of the slides where the non-GAAP
information appears. |
 PSEG OVERVIEW CHAIRMAN, PRESIDENT AND CHIEF EXECUTIVE OFFICER Ralph Izzo EXECUTIVE VICE PRESIDENT AND CHIEF FINANCIAL OFFICER Daniel Cregg |
 Operational Excellence: Maintaining
reliability and improving performance as we
control costs in low price environment
Financial
Strength:
Strong
financial
position
supports investment program and dividend
growth
Disciplined Investment:
• Balanced business mix • Robust pipeline of opportunities Results: • Project 3 rd year of EPS growth • Increased rate of dividend growth • Best in class utility growth rate • Addition of efficient CCGT capacity enhances market position • Upside potential from power markets DISCIPLINED INVESTMENT DISCIPLINED INVESTMENT OPERATIONAL EXCELLENCE OPERATIONAL EXCELLENCE FINANCIAL STRENGTH FINANCIAL STRENGTH ENGAGED WORKFORCE ENGAGED WORKFORCE PSEG’s Strategy Investment program delivering results 5 |
 Two complementary businesses A stable platform, each with growth opportunities Strategy: Investment program enhances competitive position with addition of efficient CCGT capacity Value Proposition: Provides substantial
free cash flow in current environment and
upside from market rule improvements
Assets $12B
Operating Earnings $642M
Regional Competitive Generation
Strategy:
Investments aligned with public
policy and customer needs
Value
Proposition:
A
$12
billion
infrastructure
program
–
focused
on
transmission
–
produces
double-digit
rate
base growth through 2019
Assets $22B
Operating Earnings
$725M
Electric
& Gas Delivery
and Transmission
2014
2014
6
PSE&G AND POWER DO NOT ADD TO TOTAL DUE TO PARENT AND PSEG
LONG ISLAND ACTIVITY. SEE SLIDE A FOR ITEMS EXCLUDED FROM INCOME FROM CONTINUING
OPERATIONS/NET INCOME TO RECONCILE TO OPERATING
EARNINGS. ASSETS AND OPERATING EARNINGS ARE FOR THE YEAR ENDED 12/31/2014. |
 Delivering on commitments and realizing growth Operational Excellence PSE&G: Mid-Atlantic Reliability Award (14 th consecutive year), top ranked among eastern electric and gas utilities in business customer satisfaction PSEG Power: Record output from combined cycle units PSEG Long Island: Demonstrated management and integration capability through a successful transition in first year PSEG: Cost-control benefits continue Financial Strength Updated operating earnings guidance for 2015 to $2.85-$2.95 per share from $2.80-$2.95 per share Cash flows and business mix support strong credit ratings and ability to fully fund robust investment pipeline without issuing new equity
Increased rate of
dividend growth in 2015
Disciplined
Investment
PSE&G
Capital program = double digit rate base growth over 5-year
period (2015-2019) with increased investment
in Transmission; Electric and Gas distribution;
and Gas System Modernization Program
Power:
Keys
&
Sewaren
CCGTs,
uprates,
PennEast
Pipeline,
and
Solar
Source
7 |
 Robust pipeline of investment opportunities supports >20% growth in capital spending over the period
2015E -
2019E*: $15.6 Billion
2010 –
2014: $12.6 Billion
PSE&G Total
$9.8B
PSE&G Total
$11.8B
PSEG Capital Spending
Power Total***
$3.6B
8
Power Total***
$2.7B
*INCLUDES ALL PLANNED SPENDING. **ENERGY STRONG EXCLUDES RISK
AND CONTINGENCY. ***POWER CAPITAL SPENDING EXCLUDES
NUCLEAR FUEL. ****INCLUDES PENNEAST PIPELINE EQUITY
INVESTMENT OF $0.1B. E=ESTIMATE. DATA AS OF OCTOBER 30, 2015. |
 9 Balance sheet strength supports capital allocation Timeframe Actions taken 2010 – 2014: Transformed business mix • Applied $12.6 billion towards investments • Improved credit ratings • Monetized Energy Holdings’ portfolio • Strong balance sheet sustained during period of low power
prices, while increasing the dividend
2015
–
Forward:
Strong financial
position supports
continued growth
• Increased rate of dividend growth in 2015 • $15.6 billion investment program through 2019 • Gas System Modernization Program settlement of ~ $900 million of capital investment through 2019 • Financial capability supports further expansion of the current capital plan |
 PSE&G’s investment program Meeting public policy goals and customer needs PSE&G Rate Base and Operating Earnings* *SEE SLIDE A FOR ITEMS EXCLUDED FROM INCOME FROM CONTINUING OPERATIONS/
NET INCOME TO RECONCILE TO OPERATING EARNINGS.
2009-2014
Operating
EPS
CAGR: 18%
10 |
 11 Containing customer bills while investing in the system • PSE&G customers’ combined electric and gas bills declined 23% over the period.
• Low gas prices drove rate decreases; in addition, gas customers received
bill credits of ~$400 in total from 2012 through 2014.
Gas
Electric
PSE&G Typical Residential Customer Bills*
*FOR ALL YEARS THE BILLING ASSUMES 7,200 KWH FOR ELECTRIC AND
1,010 THERMS FOR GAS ANNUALLY. E = ESTIMATE |
 12 PSE&G’s robust capital investment pipeline drives double-digit rate base growth through 2019 E=ESTIMATE PSE&G Capital Projects • Planned capital spend supports high single digit earnings growth at PSE&G through 2017 • Transmission expected to grow to >50% of rate base in 2019 • Seeking to broaden platform to expand energy efficiency and other investments |
 13 PSEG Power increased capital spending by $1.5 billion with addition of new generating capacity focused
on improving efficiency and reliability
*BASED ON CURRENTLY KNOWN AND QUANTIFIABLE ENVIRONMENTAL
REQUIREMENTS. E=ESTIMATE. (Peach
Bottom EPU, AGP, Solar) |
 14 Power’s fleet has the desired attributes to be
successful in today’s and tomorrow’s
market •
Largest nuclear site in the
eastern U.S. and ownership in large, fully scrubbed coal facilities at Keystone and Conemaugh provide economies of
scale that enhance energy margins in current low
market, and provide for upside potential if prices improve. • Dual fuel peakers meet reliability criteria in
capacity markets and provide option value in energy market. Opportunity exists to repower peakers that do not meet NJ HEDD environmental regulations.
• Combined cycle units Keys and Sewaren, expected to be operational in 2018, will
enhance emissions performance and have a combined average heat rate of approximately 6,800.
Economic Drivers
Outlook
Combined
Cycle
Nuclear
Scrubbed
Coal
Peakers
Renewable
Energy Margins
Low natural gas and energy
prices
Robust portfolio of gas
pipeline contracts
n/a
n/a
Capacity Markets
Tightened
rules proposed for
capacity performance
n/a
Environmental
Regulations
Tighter air emissions
standards
Location
Assets in well-designed
markets, premium regions
Opportunities on brownfield
sites
n/a
3.3
3.7
2.4
2.3
0.1
4.7
3.8
2.4
1.8
0.1
• • • • • • *AS OF AUGUST 2015 APPROXIMATELY 1.3 GW UNDER DEVELOPMENT - KEYS AND SEWAREN CCGT UNITS, WHICH
ARE TARGETED TO GO INTO SERVICE IN 2018 ALONG
WITH RETIREMENT OF OLDER SEWAREN UNITS 2015
-
PSEG
Power
Total
Capacity
11.8
GW
2018
-
PSEG
Power
Total
Capacity
12.8
GW
* |
 15 Operating Earnings Disciplined investment program and focus on operational excellence have supported growth Power’s diverse fuel mix and dispatch flexibility continue to generate strong earnings and free cash flow in low price environment PSE&G’s investment program has driven double digit compound annual earnings growth since 2010 Operating Earnings* Contribution by Subsidiary ** ** *SEE SLIDE A FOR ITEMS EXCLUDED FROM INCOME FROM CONTINUING OPERATIONS/
NET INCOME TO RECONCILE TO OPERATING EARNINGS. E=ESTIMATE
** 2015 PERCENTS USE MIDPOINT OF UPDATED EARNINGS GUIDANCE AS OF OCTOBER 30, 2015. |
 16 Power – Growing value by improving market rules
and developing investment opportunities
Value
Source
Opportunities and Actions Taken
• PJM’s Capacity market – 2014 limits on demand response and August 2015 Capacity Performance auction • Demand response treatment at U.S. Courts / FERC • Energy price formation at FERC • Increasing air quality standards via Federal and State regulations Our footprint provides growth opportunities • Nuclear and Combined Cycle plant uprates adding capacity • New build Keys CCGT in SWMAAC* (MD) and Sewaren 7 in EMAAC* • Brownfield expansions at existing sites New peakers built at New Haven and Kearny sites Continue to explore further opportunities • PennEast pipeline - equity investment and gas portfolio enhancement • ~152 MW** of utility-scale solar, with significant project pipeline • Continue to seek opportunities to expand the fleet * SWMAAC = SOUTHWEST MID-ATLANTIC AREA COUNCIL \EMAAC = EASTERN MID-ATLANTIC AREA COUNCIL
LOCATIONAL
DELIVERABILITY AREA WITHIN PJM. **PROJECT SIZE IN
MEGAWATTS SHOWN IN DC (DIRECT CURRENT), AC EQUIVALENT IS 115 MW. Improving rules will better recognize value of our fleet |
 17 PSEG Annual Dividend An increased dividend growth rate with potential for consistent and
sustainable growth given our business mix and financial
position Payout Ratio
50%
58%
56%
54%
54%*
*2015E PAYOUT RATIO REFLECTS THE MIDPOINT OF UPDATED OPERATING
EARNINGS GUIDANCE AS OF 10/30/2015. E=ESTIMATE
2011-2015 CAGR: 3.3%
PSEG Annual Dividend Rate
|
 18 Focus areas over business plan horizon PSE&G • Operational excellence and cost control • • Regulatory framework • Continue to develop incremental growth opportunities PSEG Power • Operational excellence and cost control SWMAAC* and Sewaren 7 CCGT in EMAAC* Zones • • PSEG Long Island • *SWMAAC = SOUTHWEST MID-ATLANTIC AREA COUNCIL/EMAAC = EASTERN MID-ATLANTIC AREA COUNCIL
LOCATIONAL DELIVERABILITY AREA WITHIN PJM.
Capital program execution
– Transmission, Energy Strong and GSMP program
Timely construction of new growth
opportunities – Keys Energy Center CCGT in Monitor and shape market rules - Capacity markets and environmental regulations Continue execution – Integration and achievement of performance metrics Strong performance at Nuclear and Fossil to maximize fleet value in dynamic markets • |
 19 PSEG’s Value Proposition • A stable platform with predictable earnings and a robust investment pipeline • • • PSE&G – Best in class utility performance and growth profile PSEG Power – Repositioning fleet to enhance efficiency
and reliability in the current market environment Strong balance sheet – Supports strong credit rating,
growth objectives and the potential for consistent and
sustainable dividend growth |
 PSE&G |
 21 PSE&G strategy Building a sustainable platform that balances reliability, customer rates and public policy to ensure growth at reasonable returns DISCIPLINED INVESTMENT OPERATIONAL EXCELLENCE FINANCIAL STRENGTH ENGAGED WORKFORCE |
 22 PSE&G is the largest electric and gas distribution and
transmission utility company in New Jersey
Electric
Gas
Customers
Growth (2010 –
2014)
2.2 Million
0.3%
1.8 Million
0.3%
2014 Electric Sales and Gas Sold and Transported
40,737 GWh
2,628M
Therms*
Projected
Annual
Load
Growth
(2015
–
2017)**
1.1%
0.5%
Projected Annual Load Growth
Transmission
(2015
–
2017)
0.9%
Sales Mix
Residential
32%
60%
Commercial
58%
36%
Industrial
10%
4%
Transmission
Electric
Gas
Approved Rate of Return***
11.68% ROE
10.3% ROE
10.3% ROE
Renewables & Energy
2009-June 2015
Total Program
Plan
Total
Investment
thru
June
2015
Solar Loan Capacity
83 MW
178.5 MW
$250M
Solar 4 All Capacity
100 MW
125 MW
$527M
EE Annual Electric savings
206 GWh
~250 GWh
EE Annual Gas savings
6.5 M Therms
~10 M Therms
* GAS FIRM ONLY
SALES. ** ESTIMATED ANNUAL
GROWTH PER YEAR, ASSUMES NORMAL WEATHER.
*** SOME PROJECTS APPROVED FOR SPECIFIC ROE.
Efficiency Approved Programs |
 23 Mid-Atlantic ReliabilityOne award winner for 14 years in a row |
 24 PSE&G’s service and reliability is being recognized by customers |
 25 PSE&G plans to invest $11.8B over the
next five years
PSE&G’s Capital Expenditures*
*INCLUDES AFUDC.
E=ESTIMATE. Distribution
34%
Other
Transmission
32%
Major
Transmission
Incentive
Projects
24%
Solar/Energy
Efficiency
10%
$9.8B
Distribution
40%
Other
Transmission
45%
Major
Transmission
Incentive
Projects
13%
Solar/Energy
Efficiency
2%
$11.8B
2015-2019E
2010-2014 |
 26 PSE&G’s major Transmission projects have been completed on schedule and on budget Major Transmission Investments Project Roster Approved ROE Inclusion of CWIP in Rate Base 100% Recovery of Costs Due to Abandonment Estimate Up To ($ Millions) Expected In-service Date Susquehanna-Roseland 12.93% $790 Completed North Central Reliability 11.68% $390 Completed Burlington–Camden 230kV 11.68% $399 Completed Mickleton–Gloucester–Camden 230kV 11.68% $435 Completed |
 27 A robust pipeline of Transmission investments focus on reliability improvements and replacement
of aging infrastructure
*
PJM ESTIMATE
Project Roster
Approved
ROE
Program
Description
Estimate
Up To
($ Millions)
Expected
In-service
Date
Northeast Grid Reliability
11.93%
PJM baseline project
receiving CWIP in rate base
treatment
$975
Jun ‘15 –
Dec ‘16
Bergen—Linden Corridor 345kV
11.68%
PJM baseline project
receiving CWIP in rate base
treatment
$1,200
June
2018
PJM Regional Transmission
Expansion
Plan
(RTEP)
–
multiple
projects
11.68%
PJM mandated system
reliability projects
$1,900
Various
69kV
Upgrade
–
multiple
projects
11.68%
Upgrade of 26kV to 69kV
$1,500
Various
Transmission
Lifecycle
–
multiple
projects
11.68%
Replacement of aging
infrastructure
$1,100
Various
Transmission Hardening–
multiple projects
11.68%
Reliability projects focused
on system resiliency
$650
Various
Artificial Island
11.68%
PJM Baseline Project
$110-$130*
2019* |
 28 Major Transmission programs focus on
reliability and replacing aging infrastructure
• PJM’s Regional Transmission Expansion Plan (RTEP) identifies system
enhancements needed for reliability
• 69kV system upgrades improve system reliability and provide capacity
for future growth
• Transmission Lifecycle is an ongoing program to manage transmission
asset life to maintain and improve system integrity and
reliability •
Transmission Hardening projects focus on increasing system
resiliency |
 29 PSE&G is successfully executing on Energy Strong with ~$440M deployed Program Approved Flood Mitigation $620M $83M Electric Contingency Reconfiguration $100M $53M Electric Advanced Technology $100M $42M Gas Utilization Pressure Cast Iron (UPCI) $350M $252M Gas Metering & Regulating (M&R) $50M $7M TOTAL $1,220M $437M Spend thru Sept 2015 |
 30 PSE&G has successfully worked with regulators to develop multiple solutions for New
Jersey’s energy and economic
development goals •
Solar Loan I
–
2008
• Solar Loan II – 2009 • Solar 4 All – 2009 • Solar Loan III – 2013 • Solar 4 All Ext – 2013 RENEWABLES creative solutions to install solar generation • Carbon Abatement – 2008 • Demand Response – 2009 • Energy Efficiency (EE) – 2009 • EE Extension – 2011 • EE Extension II – 2015 ENERGY EFFICIENCY assisting customers with controlling energy usage • NJ Capital Infrastructure Program 1 (CIP 1) – 2009 • NJ Capital Infrastructure Program 2 (CIP 2) – 2011 • Energy Strong – 2014 DISTRIBUTION improving electric and gas delivery infrastructure To date we have invested over $2B in the above programs Over $1B ahead in Energy Strong, Energy Efficiency Ext II and Solar programs Gas System (GSMP) settlement increases investment by ~$900M through 2019 |
 31 Extension of PSE&G’s award winning
Energy Efficiency program
• Energy Efficiency Extension II approved by the BPU in April 2015 will
extend the investment and time frame for three previously
approved programs already in the marketplace,
allowing PSE&G to factor in lessons learned
and balance policy issues •
$95M of rate base investment approved at an ROE of
9.75% •
Extends existing programs, two of which have sizable waiting
lists: •
Hospitals
• Multifamily • Direct install – government, non-profit, and small business • Allows PSE&G to leverage past investments in people, capabilities,
systems and processes |
 32 Settlement reached on Gas System Modernization Program for ~$900 million over three years • Agreement in principle reached with Staff of the NJBPU and the Division of Rate Counsel • GSMP is the next phase of a long-term, cast iron and unprotected steel replacement strategy • Three-year program with total capital investment of $905 million, beginning January 2016 The program provides for investment of $650M recovered through a clause similar to the Energy Strong program – with a 9.75% ROE Additional capital investment of $255M to be recovered in rate case scheduled to be filed by November 2017 |
 Traditional Recovery Mechanisms Distribution Base Rates FERC Formula Rates Transmission PSE&G continues to receive contemporaneous/ formula rate recovery on ~70% of its investment program Clause Recovery Mechanisms Energy Strong / GSMP / Infrastructure / Solar / Energy Efficiency E = ESTIMATE. DATA AS OF SEPTEMBER 2015. 20% 56% 24% 2010-2014 PSE&G Capital Spending by Recovery Method $9.8B 15% 57% 28% 2015-2019E PSE&G Capital by Recovery Method $11.8B 33 |
 34 Cost control actions taken:
• PSE&G is utilizing the Lean Six Sigma discipline to achieve costs savings and process
improvements
• Conducted organizational reviews resulting in streamlining of processes through
restructuring
• Continued focus on vendor and inventory practices ensuring maximum value
• Successful management of pension 2009 to 2015 CAGR = 0.3% PSE&G O&M Expense E=ESTIMATE PSE&G has controlled costs through process improvements and will continue to drive future efficiencies $0 $500 $1,000 $1,500 2009 2010 2011 2012 2013 2014 2015E |
 35 PSE&G’s 2015 operating earnings expected to benefit from increased investment in Transmission
*SEE SLIDE A FOR ITEMS EXCLUDED
FROM NET INCOME TO RECONCILE TO OPERATING EARNINGS. E =ESTIMATE. **UPDATED GUIDANCE ON OCTOBER 30, 2015.
$612
$725
2013
2014
2015 Guidance
PSE&G Operating Earnings*
($ Millions)
$785
–
$805E** |
 PSEG LONG ISLAND |
 37 PSEG Long Island is focused on improving customer service and reliability
• Provide best-in-class customer service, including building on our new
Call Center Technology platform to better serve our
customers •
According to J.D. Power, in 2014 PSEG Long Island showed the
most improvement in overall customer satisfaction
of any large electric utility, anywhere in the
nation •
Work to maintain industry-leading service
reliability •
Improve every aspect of the storm response process
• Leveraged our new Outage Management System to improve storm logistics
and outage coordination
• Contributed $0.02* to PSEG’s earnings per share in 2014, as expected
* EXCLUDES THE ENERGY RESOURCES & TRADE CONTRACT, WHICH
WILL BE INCLUDED IN PSEG POWER’S RESULTS. |
 PSEG POWER |
 39 PSEG Power strategy Excellence in operating our units safely, reliably, cost- competitively and in an environmentally, responsible manner DISCIPLINED INVESTMENT OPERATIONAL EXCELLENCE FINANCIAL STRENGTH ENGAGED WORKFORCE |
 40 PSEG Power creating value by responding
to changing markets and regulations
Safety/Environmental Focus
Fleet Diversity/Efficiency Focus
Financial/Economic
Focus
Regulatory Focus
• Nuclear units have performed well • Hope Creek recorded its second highest output in its history • Fleet diversity across the dispatch curve and fuel types provide flexibility to meet changing market conditions • Bergen 1 & 2 and Linden 1 individually, and the CCGT fleet in total, set generation records in 2014 • Kearny 13 & 14 have shown increasing output in each year since start-up • Getting the most out of existing fleet • Locational advantage • O&M control programs have delivered a CAGR of 2.6% between 2009 and 2015 • Sites offer competitive advantage for expansion • Strong regulatory performance • Industry leadership in the changing business environment |
 41 Financial Strength Disciplined Investment Operational Excellence • Maximize value of existing generating plants through implementation of the Operational Excellence Model (OEM) • Workforce engagement and development • Deliver on Business Plan Commitments • Maintain competitive markets and improve constituent communication on issues important to Power • Successfully complete the Advanced Gas Path (AGP) uprates • Seek new opportunities in target markets (PJM, ISO-NE, NYISO) • Develop our renewables business (solar) • Maintain new nuclear option by successfully managing the Early Site Permit (ESP) process PSEG Power Delivering on priorities •
OEM implemented and
achieving measures • Resource sharing program between Nuclear & Fossil • Exceeded earnings guidance in 2014 • Ongoing effort in key markets showing success • Successful court outcome against subsidized generation • Accelerated schedule for AGP to maximize opportunity • LIPA contract for fuel and generation dispatch began January 1, 2015 • Solar Source’s portfolio is 152 MW DC • Nuclear ESP is expected in 2016 • New build Keys CCGT in Maryland and Sewaren 7 in New Jersey – both targeted in-service 2018 |
 42 PSEG Power met 2014’s challenges Storm and weather challenges • All of the generation sites affected by SuperStorm Sandy were restored to service by mid-2014, with ongoing repairs • Cold weather extremes created a challenging operating environment, but also presented opportunities Market challenges • Transmission (outages and build outs) and gas markets resulted in pressure on basis • Lower gas cost impacted dark spread pressuring coal unit dispatch • Load impacted by economy Value delivered • Expedited return from storm outages, restored margin opportunities • High availability when needed • Flexibility of portfolio captured real- time basis opportunities • Captured value through coal/gas switching, unit flexibility • Management of gas assets benefited customers and fleet • Achieved fuel cost savings |
 43 PSEG Power has generating assets in three competitive markets • Assets located near load centers • Low cost portfolio Fuel flexibility with gas cost advantage • Positioned to benefit from volatility in real-time markets • Readiness for capacity performance (CP) in PJM • Sites suitable for expansion ISO New England New Haven Bridgeport Bethlehem Energy Center (Albany) Conemaugh Keystone Peach Bottom Bergen Kearny Essex Sewaren Linden Mercer Burlington Hudson Hope Creek Salem Yards Creek New York ISO PJM Keys (Site) |
 44 PSEG Power value advantaged by asset diversity, fuel flexibility and location Fuel Diversity* Total MW: 13,146 Energy Produced* Total GWh: 54,162 Energy Market Served*
Total MW: 13,146
44%
22%
34%
Load Following
Peaking
Base load
Gas
Pumped
Storage
Nuclear
Oil
Coal**
Gas
Pumped
Storage
Nuclear
Oil
Coal**
46%
28%
18%
7%
1%
*YEAR END 2014 DATA, EXCLUDES SOLAR AND KALAELOA.
**INCLUDES NEW JERSEY UNITS THAT FUEL SWITCH TO GAS.
|
 45 Power’s PJM assets along the dispatch curve reduce
the risk of serving full requirement load contracts and can take
advantage of volatile market
conditions Energy Revenue
X X X Capacity Revenue X X X Ancillary Revenue X X Dual Fuel X X • Base Load ensures cash flow certainty • Load Following provides ability to serve load shape • Readiness for Capacity Performance (CP) • Keys & Sewaren 7 to be added to dispatch in 2018E • Peaking takes advantage of real-time prices and reduces operational risk • Dual fuel capability at 87% of load following and peaking units Illustrative Salem Hope Creek Keystone Conemaugh Hudson 2 Linden 1,2 Bergen 1 Mercer 1, 2 Bergen 2 Peach Bottom Essex 9 Sewaren 1-4 Burlington 12 Yards Creek Base Load Units Peaking Units Load Following Units Kearny 12-13-14 Nuclear Coal Coal/Gas Combined Cycle Steam Combustion Turbine / Pumped Storage Linden 5-8 POST - HEDD E = ESTIMATE |
 46 PSEG Power will improve diversity and efficiency as
we invest in the fleet
2014
2018
Oil
Pumped Storage
HEDD
Other gas
Peakers
AGP/PB EPU
CCGT
Coal
Nuclear
• Maintain fuel diversity • Maintain load-serving capability • Maintain low cost structure • Environmental improvement • Peach Bottom (PB) uprate • Advanced Gas Path (AGP) • Combined cycle units Keys and Sewaren 7 operational in 2018 Objective 2015 2018 13,146 MW 12,800 MW Fuel Diversity 57 - 59 TWh 54 TWh E E=ESTIMATE. 2014 2018 Oil, Other gas, HEDD, Pumped storage Peakers AGP/PB EPU CCGT Coal Nuclear Energy Produced E |
 47 0.5 0.6 0.7 0.8 0.9 1.0 8,500 9,000 9,500 10,000 10,500 Heat Rate NOx + SO2 2014 2018E PSEG Power’s fleet will experience
heat rate and emissions improvements
• AGP (Advanced Gas Path) investments • Other Efficiency improvements • HEDD retirements • Keys/Sewaren Combined Cycle Development (2018) E = ESTIMATE |
 48 PSEG Power’s fleet is among the lowest
emitting in the industry
0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000 90,000 10,000 20,000 30,000 40,000 50,000 60,000 70,000 2006 2007 2008 2009 2010 2011 2012 2013 2014 Generation SO2 NOx • Mercury reduced 80% across the timeframe above • More efficient testing and improved operational flexibility through utilization of Continuous
Emission Monitoring System testing
SO2 |
 49 PSEG Power Nuclear is a critical element of our
success Hope Creek
• Operated by PSEG Nuclear • PSEG Ownership: 100% • Technology: Boiling Water Reactor • Total Capacity: 1,178 MW • Owned Capacity: 1,178 MW • License Expiration: 2046 • Next Refueling Fall 2016 Salem Units 1 and 2 • Operated by PSEG Nuclear • PSEG Ownership: 57% • Technology: Pressurized Water Reactor • Total Capacity: 2,307 MW • Owned Capacity: 1,324 MW • License Expiration: 2036 and 2040 • Next Refueling Unit 1 – Spring 2016 Unit 2 -- Fall 2015 Peach Bottom Units 2 and 3 • Operated by Exelon • PSEG Ownership: 50% • Technology: Boiling Water Reactor • Total Capacity: 2,242 MW • Owned Capacity: 1,121 MW • License Expiration: 2033 and 2034 • Next Refueling Unit 2 - Spring 2016 Unit 3 - Fall 2015 • Uprate: 130 MW (PS Share) Unit 2 - March 2015 Unit 3 - 2016 |
 50 PSEG Power Nuclear has competitive
advantages •
Continued strong nuclear operations
• Nuclear excellence program • Top quartile of cost performance/MWh Brought security services in-house • Significant earnings contributor • Recruitment of the best new and experienced talent, and attractive training program • Fukushima action plan in response to NRC staff review FLEX* plan submitted with implementation underway • Peach Bottom extended power uprate, 130 MW Power’s share, scheduled in service 2015/2016 • Active and influential participation at INPO, NEI, EPRI, USA Alliance *STRATEGY KNOWN AS THE “DIVERSE AND FLEXIBLE MITIGATION CAPABILITY” OR FLEX, ADDRESSES
RECOMMENDATIONS OF THE NUCLEAR REGULATORY COMMISSION’S
FUKUSHIMA TASK FORCE. |
 51 7,200 7,300 7,400 7,500 7,600 7,700 7,800 2008 2009 2010 2011 2012 2013 2014 PSEG Power initiatives result in
continuing improvement in combined cycle heat rate
AGP projected efficiency
improvement 2015-2018
2018E* E= ESTIMATE. *The weighted average Combined Cycle Operating Heat Rate in 2018, with the addition of
Sewaren 7 and Keys Energy Center, will be approximately
7,250 |
 52 PSEG Power CCGT/Fossil initiatives
Actions Taken to Create Value
Capacity
• New Keys CCGT 755MW online in 2018 adds geographic diversity to fleet • Sewaren 7 CCGT 540 MW online in 2018 improves fleet efficiency
• Advanced Gas Path (AGP) investments 2014 through 2018 to provide additional efficient capacity, heat rate improvements • New lower cost gas line at BEC with Dominion Performance • EPRI efficiency initiatives • GE initiatives for large data analytic • Consolidation of unit testing • Auto tuning software Maintenance • Ongoing outage efficiency improvement • Improvements to reliability • Central fleet monitoring and diagnostic center |
 53 PSEG Power developing 1,300 MW of new, efficient CCGT capacity in MD and NJ PJM *SWMAAC = SOUTHWEST/EMAAC = EASTERN MID-ATLANTIC AREA COUNCIL
LOCATIONAL DELIVERABILITY AREA WITHIN PJM.
SEWAREN 7 SITE
KEYS ENERGY
CENTER SITE
• Construction of 755 MW Keys Energy Center to begin this Fall on a new, natural gas fired power plant in Maryland (SWMAAC*) at an estimated cost of $825 to $875 million • Power cleared a new 540 MW CCGT unit, Sewaren 7 located in New Jersey (EMAAC*), in the recent 2018/2019 RPM auction; the new unit is expected to cost $625 to $675 million and will replace the older Sewaren units upon completion • Both Keys and Sewaren 7 are targeted to be in-service in 2018 |
 54 PSEG Power’s Growth Investments Site Project Estimate ($ millions) Benefits Status Maryland Keys 755 MW CCGT $825 - $875 Geographic diversity within PJM; highly efficient gas fired unit in SWMAAC 2018E Sewaren Unit 7, 540 MW CCGT $625- $675 Improved efficiency and reliability; increase in capacity 2018E Peach Bottom Peach Bottom EPU (2014 – 2015) $417 Increased capacity: 130 MW PB2 May 2015, PB3 in 2016 Linden/ Bergen/ BEC Advanced Gas Path Uprates (AGP): Linden -- 63 MW Bergen -- 31 MW BEC -- 58 MW $120 Increased capacity and improved heat rate: ~152 MW capacity increase ~1.2% heat rate improvement Completed: Linden (2014) Bergen (2015) Planned: BEC 2017/2018E Various Interim ISA’s* No cost Increased capacity: 69 MW Completed Eastern PA to Mercer, NJ PennEast Pipeline $119 Estimated Earnings in 2019: $13 million Underway Total Increased Capacity – 1,132 MW **
* INTERCONNECTION SERVICE
AGREEMENTS. E = ESTIMATE. **NET OF PLANNED RETIREMENTS. |
 55 PSEG Solar Source owns ~152 MW of solar facilities with long term contracted revenues* *PROJECT SIZE IN MEGAWATTS SHOWN IN DC (DIRECT CURRENT). E = ESTIMATE
Shasta A & Shasta B
California (2 x 2 MW)
COD March 2014
Polycrystalline -
single axis
Investment $13 million
20 year PPAs with PG&E
Hackettstown (Mars)
New Jersey (2 MW)
COD September 2009
Thin film panels –
fixed tilt
Investment $13 million
15 year PPA with Mars, Inc.
Wyandot
Ohio (12 MW)
COD May 2010
Thin film panels –
fixed tilt
Investment $44 million
20 year PPA with AEP
JEA
Florida (15 MW)
COD September 2010
Thin film panels –
fixed tilt
Investment $59 million
30 year PPA with JEA
Queen Creek
Arizona (25 MW)
COD October 2012
Polycrystalline -
single axis
Investment $75 million
20 year PPA with SRP
Milford
Delaware (15 MW)
COD December 2012
Polycrystalline -
fixed tilt
Investment $47 million
20 year PPA with DEMEC
Badger I
Arizona (19 MW)
COD November 2013
Polycrystalline –
single axis
Investment $48 million
30 year PPA with APS
Newman
Texas (13 MW)
COD December 2014
Polycrystalline -
single axis
Investment $22 million
30 year PPA with El Paso Elec.
Whitcomb (Essex Junction)
Vermont (4 MW)
COD October 2014
Polycrystalline –
fixed tilt
Investment $10 million
25 year PPA with VT Electric
Power Producers, Inc.
Rockfish (Waldorf)
Maryland (13 MW)
COD July 2015
Polycrystalline -
single axis
Investment $22 million
20 year PPA with SMECO
Columbia
California (25.5 MW)
COD October 2015 Polycrystalline – fixed tilt Investment $55 million 20 year PPA with PG&E Whitethorn California (4 MW) COD March 2016 E Polycrystalline – fixed tilt Investment $8 million 20 year PPA with WAPA Power Producers, Inc. |
 56 Gas Asset Optimization Large wholesale provider to PSE&G and others Storage capacity of approximately 75 Bcf (in the Gulf and market regions)
Firm transportation of 1.3 Bcf/day on seven
pipelines Off-system sales margins shared with
residential customers Commercial & Industrial
customers (C&I) Weather and price
volatility Ancillary Services
LIPA fuel and energy dispatch management
PSEG Power has other attractive
sources of revenues to round out a robust
portfolio, in addition to energy and capacity |
 57 PSEG Power is an established leader within the industry INPO • National Nuclear Accrediting Board NEI • Communications Advisory Committee • Board of Directors • Board of Directors Executive Committee • Emergency Preparedness Working Group • Security Working Group • Fukushima Response Steering Committee • Joint Information System Task Force • Nuclear Strategic Issues Advisory Committee Steering Group EPRI • Chairman Nuclear Power Council • Executive Committee Nuclear Power Council BWR Owners Group • Vice Chair of the Executive Oversight Committee Utilities Service Alliance (USA) Fleet • Chair EPSA • Executive committee member UWAG • Chair of the Cooling Systems Committee PJM/NY/ISO-NE • Member of various Committees at PJM • Chairman & Vice-Chair of the Supplier Sector of the New
England Power Pool (NEPOOL)
• Chair of the PJM Power Providers Board • Board member & member of the board’s Executive
Committee of Independent Power Producers of New York
(IPPNY)
EEI
• Member of water resources subcommittee National Coal Council • Member of Executive Committee |
 58 Developing People to drive operational excellence
and to optimize the workforce
• Succession planning and development planning • Recent CNO retirement & succession was part of the plan
• Training & development of employees • Rotational assignments for key leaders in PSEG Power • Outreach programs • Employee engagement • Shared resources between Fossil and Nuclear (outage support)
• Diversity & inclusion |
 59 Cost control actions taken:
• Fossil plant assessment • CCGT material condition assessment • Vendor contract renegotiations • Nuclear security services brought in- house to control costs • Nuclear maintenance productivity study • Nuclear outage efficiency initiative • Materials management 2009 to 2015 CAGR = 2.6% Power O&M Expense* *EXCLUDES IMPACTS FROM STORM RECOVERY COSTS. E=ESTIMATE
PSEG Power’s
focus on costs
has resulted in moderate
increase in O&M for
seven years
$0 $500 $1,000 $1,500 2009 2010 2011 2012 2013 2014 2015E |
 60 Power’s 2015 operating earnings maintain solid performance Power Operating Earnings* ($ Millions) 2013 2014 2015 Guidance $710 $642 $620 – $650E** 2015 Observations • Increase in average hedge price for energy helps mitigate reset in capacity price and volume *SEE SLIDE A FOR ITEMS EXCLUDED FROM NET INCOME TO RECONCILE TO OPERATING EARNINGS. E =
ESTIMATE. ** UPDATED GUIDANCE ON OCTOBER 30,
2015. |
 PSEG POWER ER&T PSEG POWER |
 Market Review: Winter Z6 gas prices retain seasonal volatility;
spark spreads have continued to be robust in PJM
2015 YTD Z6
PJM West vs. PS Zone Spark Spreads (2013-2018)
2015-2018 Z6
62
FORWARDS AS OF OCTOBER 28, 2015
|
 ANNUAL FORWARD BASIS TO PJM-WEST AS OF OCTOBER 28, 2015.
E = YTD ACTUAL PLUS FORWARD; F =
FORWARD Power
Basis
in
Eastern
PJM:
Expected
to
be
volatile
and
negative on an annual basis for 2015 and 2016
PS Zone RTC Basis to PJM West
Electric Basis is negative however it is viewed to be
stabilizing and turning back to positive within 2
years due to: •
Export of ~18 bcf/day of gas which will significantly
strengthen regional gas prices •
Easing of transmission constraints in
Virginia/Maryland •
Construction of significant new gas-fired generation in
VA/MD 63 |
 64 Market Review: PSEG’s extensive gas asset portfolio
gives unparalleled access to Marcellus Shale gas
• PSEG Power maintains a robust portfolio of pipeline and storage assets in the Mid-Atlantic • PSEG Power’s gas for generation was ~100 BCF in 2014, of which >60% was supplied by Shale gas • PSEG Power procured over 400 BCF in 2014 with ~75% going to PSE&G’s utility gas customers • When gas is surplus to customer needs, PSEG Power sells surplus to others; margins from such sales benefit PSE&G gas customers and PSEG Power Eastern PA Shale Western PA Shale Gulf Coast Delivered Gas 40% 20% 6% 34% Power’s Gas for Generation in 2014 |
 Market Review: New pipelines will move significant quantities of
Marcellus gas out of the region by 2018
New pipeline investment is expected to increase takeaway
capacity from the low cost Marcellus/Utica shale
and reduce regional surpluses and increase gas prices by 2018 New England 3.4 bcf/d Southeast 6.4 bcf/d Midwest 5.9 bcf/d Gulf Coast 3.1 bcf/d NJ/NY 1.4 bcf/d Pipeline capacity grows significantly by 2018 Historical and Expected Marcellus Production 65 2010 2011 2012 2013 2014 2015 2016 2017 2018 0 5 10 15 20 25 30 |
 Northeast Portfolio: New York and New England
New England (972 MW)
• Small but dynamic market • Significant improvement in market construct • High volatility due to extreme (winter) weather
conditions
• Significant siting and permitting challenges • Gas pipeline infrastructure poses supply
challenges/opportunity
New York (774 MW)
• Single state ISO • Investment in new lateral to connect to the Dominion pipeline at Bethlehem Energy Center (BEC) allows for access to fuel supply from Marcellus • Long Island Power Authority Fuel Management Contract 66 |
 67 PSEG Power acting as an agent for LIPA began January 2015 • Performing ISO bidding for LIPA’s 6,000 MWs of generation/tolls • Procuring natural gas and oil for the majority of these assets • Scheduling two DC transmission cables (ISO-NE and PJM) into Long Island • Entering into financial hedges to reduce LIPA customer’s price volatility This relationship has provided PSEG Power: • Additional experience in Eastern NY and Connecticut markets • Bigger natural gas footprint • Fee-based services contract Northeast Portfolio: Expanding our footprint with PSEG Long Island
38%
36%
16%
7%
3%
LIPA Capacity (6,163 MW)
Steam
Combustion Turbine
Cables
Combined Cycle
Resource Recovery,
Pumped Storage, Solar |
 68 … Recent capacity auctions provide for growth in capacity revenue into 2019
Capacity Market Pricing:
~98% of Power’s PJM fleet that cleared the 2018/2019 RPM auction met the new CP standards
*PSEG POWER’S AVERAGE PRICES AND CLEARED CAPACITY (MW)
REFLECT BASE AND INCREMENTAL AUCTIONS. DELIVERY
YEAR RUNS FROM JUNE 1 TO MAY 31 OF THE NEXT CALENDAR YEAR. + INCLUDES CP TRANSITION AUCTION RESULTS FOR ‘16/’17 AND ‘17/’18
AS OF SEPTEMBER 10, 2015.
2018/2019
RPM
Auction
Highlights
• Cleared new 540 MW Sewaren 7
CCGT • EMAAC
separated • CP reflects cost to
meet new performance obligation •
CP construct favors portfolio approach
68
2015 / 2016*
2016 / 2017*+
2017 / 2018+
2018 / 2019
Power’s Average
Prices*($/MW-day)
$168
$172
$177
$215
RTO Prices
($/MW-day)
$136
$59
$120
$165/$150
(CP/Base)
Power’s Cleared
Capacity (MW)
8,750
8,700
8,700
8,650
Calendar Year
2016
2017
2018
Through 5/31/19
Capacity Revenues
$542
$555
$631
$281
Delivery Year
PJM Capacity Revenues ($ Millions)
RPM – Auction Results |
 NJ default service provides Power the ability to
forward hedge generation and protect energy
basis Capacity
Load shape
Transmission
Congestion
Ancillary
services
Risk premium
Green
BGS sales account for approximately 20% of our forward portfolio
of hedges 3 Year Average
Round the Clock
PJM West
Forward Energy
Price
$/MWH; BGS PRICES REFLECT PSE&G ZONE; RESULTS FOR
2013-2015 ARE THE NEW BLENDED PRICES BEGINNING JUNE 1, 2015. 2011 2012 2013 2014 2015 $94.30 $83.88 ~ $46 $92.18
~ $48
~ $53
~ $59
$97.39 $45 - $47 $39 - $40 $37 - $38 $38 - $39 ~ $62 $37 - $38 $99.54
69 |
 70 Hedging strategy: designed to protect gross margin while leveraging the portfolio Oct-Dec 2015 2016 2017 Volume TWh 9 36 36 Base Load % Hedged 100% 100% 55-60% (Nuclear and Base Load Coal) Price $/MWh $52 $51 $49 Volume TWh 4 19 19 Intermediate Coal, Combined % Hedged 35-40% 0% 0% Cycle, Peaking Price $/MWh $52 - - - - Volume TWh 12** 55-57 55-57 Total % Hedged 80-85% 65-70% 35-40% Price $/MWh $52 $51 $49 HEDGE PERCENTAGES AND PRICES AS OF SEPTEMBER 30, 2015. REVENUES OF FULL REQUIREMENT LOAD DEALS BASED ON CONTRACT PRICE,
INCLUDING RENEWABLE ENERGY CREDITS, ANCILLARY, AND TRANSMISSION
COMPONENTS BUT EXCLUDING CAPACITY. HEDGES INCLUDE POSITIONS WITH MTM ACCOUNTING TREATMENT AND OPTIONS. EXCLUDES SOLAR AND KALAELOA. **VOLUMES REFLECT ROUNDING. |
 71 Regulatory Framework: Significant reforms implemented and
new rules being promulgated to improve energy and capacity market
designs ISSUE /POLICY
OUTCOME
PJM
CAPACITY
• Higher payments for enhanced reliability (Capacity Performance)
• Tighter performance obligations for Demand Response ENERGY • FERC directed improvements to energy price formation: • 5 minute settlement (FERC Notice of Proposed Rulemaking)
• Developing day-ahead hourly offers/real-time reoffers in Q4 2016
ISO-NE
CAPACITY
• Implemented two settlement capacity market (Pay for Performance) • Higher prices in recent auction better reflect tight supply conditions in concert with implementation of sloped demand curve in FCA 9
• Supply and demand near equilibrium • Zonal demand curves expected in FCA 11 ENERGY • Implemented day-ahead hourly offers/real-time reoffers in Q4 2014
• Reserve market prices better reflect scarcity prices • 5 minute settlement expected implementation Q1 2017 NYISO CAPACITY • New Capacity Zone (LHV) leads to more accurate price signals • FERC directed NYISO to develop RMR Rules in place of NYPSC rules
ENERGY
• Improvement in price formation during reserve shortage conditions FEDERAL DEMAND RESPONSE • FERC v. EPSA before Supreme Court and national implications • DC Circuit RICE NESHAPs decision affecting diesel engines pending CAPACITY • Supreme Court to review Maryland subsidized generation case ENVIRONMENTAL REGULATIONS • HEDD, CPP, HAPS/MACT will lead to tightening of supply in 2015+ timeframe |
 PSEG Power’s Value Proposition • Re-positioning fleet to improve efficiency and reliability in attractive
markets
• Advantaged by low cost structure, fuel diversity and dispatch flexibility
• Value add from strong gas supply capability • Significant drive by regulatory bodies to improve market constructs
• Low capital requirements to meet enhanced performance standards
• Organic growth opportunities to increase nuclear and combined cycle
generation
• Hedging strategy is responsive to changing market dynamics, providing
attractive returns and free cash flow
72 |
 PSEG FINANCIAL REVIEW & OUTLOOK |
 74 Strong financial position to support our business initiatives 2014 Financial Position Strong 2014 earnings growth Exceeded earnings guidance Executed major PSE&G capital program Strong balance sheet with no long term Parent debt Solid credit metrics 2015 and Beyond Third year of anticipated positive earnings growth in 2015
Controlled O&M growth
Balance Sheet and Cash Flow support investment program
without equity issuance Substantial additional
investment capacity Growth in PSE&G
investments with contemporaneous/formula rate returns and new Power investment Consistent and strong cash flow from both Power and PSE&G
Potential for consistent and sustainable dividend growth
|
 PSEG 2015 Updated Guidance for Operating Income – by Subsidiary, and PSEG Power Adjusted EBITDA $ millions (except EPS) 2015E 2014 PSE&G $785 - $805 $725 PSEG Power $620 - $650 $642 PSEG Enterprise/Other $40 - $45 $33 Operating Earnings*
$1,445 -
$1,500
$1,400
Earnings per Share
$2.85 -
$2.95E
$2.76
PSEG Power Adjusted EBITDA**
$ millions (except EPS)
2015E
2014
PSEG Power
$1,545 -
$1,595
$1,584
* SEE SLIDE A FOR ITEMS EXCLUDED FROM NET INCOME TO
RECONCILE TO OPERATING EARNINGS; INCLUDES THE FINANCIAL IMPACT FROM MARK-TO-MARKET POSITIONS WITH FORWARD DELIVERY MONTHS.
** SEE SLIDE B FOR A RECONCILIATION OF ADJUSTED EBITDA TO
OPERATING EARNINGS AND NET INCOME. E = ESTIMATE. 75 Anticipates Another Year of Growth in Operating Earnings |
 PSEG 2015– 2019E Capital Expenditures (1) PSEG growth spend
represents ~75% of total investment Power & Other Maintenance PSE&G Distribution Maintenance Power Growth PSE&G Transmission Growth PSE&G Distribution Growth PSEG Planned Spend Maintenance ~$3.8B (1) INCLUDES AFUDC AND IDC, GAS SYSTEM MODERNIZATION PROGRAM, KEYS ENERGY CENTER, SEWAREN, PENNEAST
76
~$1.6B ~$2.2B ~$2.2B ~$2.8B ~$6.8B ~$15.6B Planned Growth Investment ~$11.8B PIPELINE EQUITY INVESTMENT OF~$0.1B IS INCLUDED IN POWER GROWTH. E = ESTIMATE.
|
 2014 – 2017E Rate Base CAGR Growth of ~13% Distribution Transmission PSE&G’s Capital Program drives
double-digit growth in rate base through 2019 ~$11.4B ~$16.5B ~$6.9B ~$4.5B ~$2.2B ~$9.8B ~$3.1B ~$9.4B Rate Base Growth ~$0.5B 2014 Rate Base Planned 2017E Rate Base Planned 2019E Rate Base ~$2.0B ~$8.9B ~$7.6B ~$19.2B 2014 – 2019E Rate Base CAGR Growth of ~11% Rate Base Growth E = ESTIMATE INCLUDES GAS SYSTEM MODERNIZATION PROGRAM 77 |
 Continuing our track record of 5 year double digit rate base growth leading to high single-digit growth in
earnings through 2017
2010 –
2015E
PSE&G 5 Year Rate Base CAGR
2011 –
2016E
2012 –
2017E
2013 –
2018E
2014 –
2019E
~11%
~13%
~12%
~10%
~11%
E = ESTIMATE
INCLUDES GAS SYSTEM MODERNIZATION PROGRAM
78 |
 79 PSEG 2015 - 2019E Sources and Uses PSE&G Cash from Ops (1) PSE&G Cash Investment I N C L U D E S K E Y S E N E R G Y C E N T E R , S E W A R E N , G A S S Y S T E M M O D E R N I Z A T I O N P R O G R A M ( 1 ) P S E & G C A S H F R O M O P E R A T I O N S A D J U S T S F O R S E C U R I T I Z A T I O N P R I N C I P A L R E P A Y M E N T S O F ~ $ 2 6 0 M F R O M 2 0 1 5 – 2 0 1 9 ( 2 ) O T H E R C A S H F L O W I N C L U D E S P S E G L I, H O L D I N G S N E T C A S H F L O W , I N V E S T E D C A S H , A N D P A R E N T S H O R T – T E R M D E B T ( 3 ) P O W E R C A S H I N V E S T M E N T I N C L U D E S N U C L E A R F U E L A N D EM I S S I O N PU R C H A S E S E = E S T I M A T E S. PSE&G Net Debt Shareholder Dividend Power Cash from Ops Power Net Debt Parent Long-Term Debt Power Cash Investment (3) Utilizing financial strength to issue debt
at the parent level in support of growth
Other
Cash
Flow
(2)
Sources
Uses |
 80 0% 10% 20% 30% 40% 50% 60% 70% Power’s key credit metric remains strong providing opportunity for incremental investment* 2015-2017E Average Increased contribution to earnings from the more stable regulated business Power’s annual Cash From Operations and Funds From Operations average approximately $1.3+ B over the 2015 to 2017 period supported by: – Capacity Revenues – Hedged Generation – O&M Control Financial strength can be used to pursue future growth in both businesses beyond current plans 2013 2014 PSEG Power Funds from Operations / Debt *INCLUDES KEYS ENERGY CENTER, SEWAREN. E= ESTIMATE |
 Substantial Investment Capacity to pursue
additional growth without the need for equity*
$0.0
$3.0
Power
Parent
Total
($ Billions)
Power
PSEG
Estimate
~ 50%
~27%
Minimum
Threshold
30%
~20%
*INCLUDES KEYS ENERGY CENTER, SEWAREN, GAS SYSTEM MODERNIZATION
PROGRAM. E= ESTIMATE Our incremental
investment capacity can support growth at both
PSE&G and Power
81
Total Incremental Investment Capacity
through 2017
Average Funds from Operations /Debt
2015 -
2017 |
 PSEG’s longer-term outlook is influenced by Power’s
hedge position and increased investment at PSE&G
2015E
**
2016E
Each $0.75/mcf Change in Natural Gas
Each $2/MWh Change in Spark Spread
Each $5/MWh Change in Dark Spread
Each 1% Change in Nuclear Capacity Factor
Segment EPS Drivers
Each $100 Million of Incremental Investment
Each 1% Change in Sales
Electric
Gas
Each 1% Change in O&M
Each 10 basis point Change in Distribution ROE
Each 10 basis point Change in Transmission ROE
$0.01
$0.01
$0.01
$0.01
$0.01
$0.01
$0.03-$0.06
$0.04
$0.04
$0.01
$0.01-$0.02
$0.02
$0.01
$0.01
$0.01
$0.01
$0.01
$0.01
$0.01
$0.01
Sensitivities derived from typical annual market variability*
* Estimated annual variability approximating one
standard deviation based on 2011–2013 historical data and forward curve estimates applied to Power’s open positions. **Jul-Dec 2015. E = ESTIMATE. M = MILLION YE = YEAR-END
POWER EARNINGS SENSITIVITIES UPDATED FOR 2015 BGS AUCTION AND
12/31/14 PRICE CURVES.
2015E
2016E
2017E
$0.10-$0.13
$0.04
$0.04
$0.01
$0.01
$0.01
$0.01
$0.01
$0.01
$0.01
2017E
Each 1% Change in 2015 Rate of Return on Pension Assets
Each 15 basis point Change in 2015 Year-End
Discount Rate Estimated Change in Actuarial
Assumptions PSEG 2015 pension expense of $55M
based on YE 2014 discount rate of 4.2% and 2015 expected rate of return on pension assets of 8%. As of 9/30/15, pension expense in 2016 was estimated to increase by $0.02-$0.03 per share. This will be updated at YE and managed as
part of overall O&M. 2016E
($0.01)
$0.01
$0.02
Pension
Expense
82 |
 PSE&G EPS Annual Dividend Per Share 2011 – 2015 CAGR: 3.3% Potential for consistent and sustainable dividend growth given significant contribution from regulated
earnings and Power’s strong free cash flow
Payout
Ratio
50%
58%
56%
54%
54%
(1)
$1.37
$1.42
$1.44
$1.48
$1.56
$0.60
$0.80
$1.00
$1.20
$1.40
$1.60
2011
2012
2013
2014
2015E
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S
T
I
M
A
T
E.
$1.55 -$1.58
5.4% increase
PSE&G
Earnings
Guidance
83 |
 PSEG Summary • Continued third year of anticipated positive earnings trend in 2015 with
updated operating earnings guidance of $2.85 to $2.95 per
share •
Continued
5
straight
year
of
expected
double
digit,
5-year
growth
in
rate
base
• Anticipated high single digit earnings growth at PSE&G on a three-year basis
from 2014 to 2017, driven by transmission investments and
planned programs •
Power’s continued focus on operational excellence, market
expertise and financial strength delivers value in
current price environment •
Power realigning its portfolio with new, efficient CCGT
investments in MD and NJ •
Strong Balance Sheet and Cash Flow support PSE&G’s
capital program and Power’s new investment
opportunities without the need for equity •
Our $0.08 per share dividend increase for 2015 is consistent
with our long history of returning cash to the
shareholder through the common dividend, with
potential for consistent and sustainable growth
th
84 |
 PSE&G APPENDIX 85 |
 PSE&G provides high reliability at below
average cost which creates superior value to
customers SAIDI
=
SYSTEM
AVERAGE
INTERRUPTION
DURATION
INDEX,
A
MEASURE
OF
AVERAGE
OUTAGE
DURATION
FOR
ALL
CUSTOMERS
SERVED,
EXCLUDING
MAJOR
EVENTS.
SOURCES:
PSE&G
PEER
PANEL
STUDY,
FIRST
QUARTILE
BENCHMARK
STUDY
AND
VARIOUS
REGULATORY REPORTS..
86 |
 PSE&G prioritizes public safety while maintaining value to customers LEAK RESPONSE RATE = PERCENTAGE OF UTILITY RESPONSES TO REPORTED LEAKS WITHIN ONE HOUR. SOURCES: PSE&G PEER PANEL STUDY AND AGA BENCHMARK STUDY. 87 |
 PSEG POWER AND ER&T APPENDIX 88 |
 Nuclear fuel needs have been hedged through
2017
Anticipated Nuclear Fuel Cost
Hedged $0 $5 $10 2015 2016 2017 89 |
 Capacity Price per RPM Auction for PSEG Zone Capacity Price per BGS Tranche 2015-2016 166 $
Three Year Average ($/MW-day)
$173
2016-2017
177
$
Average MW per Tranche (varies by
EDC) 111
2017-2018
175
$
Days per Year
365
Average Capacity Price ($/MW-day)
173
$
Average Capacity Cost per Tranche
7,007,656
$
MWh per Tranche
Average MW per Tranche (varies by EDC)
111
Hours per Year 8,768 Load Factor
(varies by EDC) ~37%
MWh per Tranche, approx.
355,000
Capacity Cost per MWh 20 $
The full requirements BGS rate recognizes the forward PJM capacity market price 90 |
 PSEG FINANCIAL APPENDIX 91 |
 Year to Date Operating Earnings by Subsidiary Operating Earnings Earnings per Share $ millions (except EPS) 2015 2014 2015 2014 PSE&G $ 631 $ 565 $ 1.24 $ 1.11 PSEG Power 558 551 1.10 1.09 PSEG Enterprise/Other 32 37 0.07 0.07 Operating Earnings* $ 1,221 $ 1,153 $ 2.41 $ 2.27 Nine months ended September 30 •SEE SLIDE B FOR ITEMS EXCLUDED FROM NET INCOME TO RECONCILE TO OPERATING EARNINGS.
92 |
 PSEG EPS Reconciliation – YTD 2015 versus YTD 2014 $2.27 0.13 0.01 $2.41 0.00 0.50 1.00 1.50 2.00 2.50 YTD 2015 Operating Earnings* YTD 2014 Operating Earnings* Re-Contracting, Market Pricing, and Lower Cost to Serve 0.22 Gas Send Out and Fixed Cost Recovery 0.04 Higher Volume 0.02 Capacity (0.21) O&M (0.05) D&A (0.01) PSEG Power** Transmission 0.10 Electric Volume, Weather, Demand and Other Revenue 0.05 Gas Volume and Demand 0.02 Pension and Other O&M (0.03) Taxes & Other (0.01) PSE&G ** * SEE SLIDE B FOR ITEMS EXCLUDED FROM NET INCOME TO RECONCILE TO OPERATING EARNINGS.
**
PRIOR QUARTER RESULTS FOR RECONCILING ITEMS MAY NOT ADD TO
YEAR-TO-DATE (YTD) TOTALS DUE TO ROUNDING.
Revenue growth supported EPS increase
93 |
 PSEG Power’s Adjusted EBITDA – Q3 2015, YTD and Full-Year 2015 Guidance Three Months Ended September 30, Nine Months (YTD) Ended September 30, Full-Year 2015 Guidance ($ in millions) 2015 2014 2015 2014 Low High Operating Earnings** $170 $171 $558 $551 $620 $650 Add: Fossil Major Maintenance, pre-tax 10 10 111 117 115 115 Depreciation & Amortization, pre-tax 76 71 228 217 305 305 Interest Expense, pre-tax 30 31 93 91 125 125 Income Taxes 115 103 338 337 380 400 Adjusted EBITDA $401 $386 $1,328 $1,313 $1,545E $1,595E PSEG Power - Adjusted EBITDA* * SEE SLIDE C FOR A RECONCILIATION OF ADJUSTED EBITDA TO OPERATING EARNINGS AND NET INCOME.
E = ESTIMATE. ** SEE SLIDE B FOR ITEMS
EXCLUDED FROM NET INCOME TO RECONCILE TO OPERATING EARNINGS; INCLUDES THE FINANCIAL IMPACT FROM MARK-TO-MARKET POSITIONS WITH FORWARD DELIVERY MONTHS.
94 |
 September 30, 2015 $ Billions PSEG PSE&G Power Cash and Cash Equivalents $0.3 $0.0 $0.0 Short Term Debt $0.0 $0.0 N/A Long Term Debt (1) 9.2 6.6 2.5 Common Equity 12.9 7.4 5.8 Total Capitalization $22.1 $14.0 $8.4 Total Debt / Capitalization 42% 47% 30% PSE&G Regulated Equity Ratio (2) 52.5% Our balance sheet remains strong (1)INCLUDES L-T DEBT DUE WITHIN 1 YEAR; EXCLUDES SECURITIZATION DEBT OF $68 MILLION AND NON-RECOURSE DEBT OF $7
MILLION. (2)REGULATED EQUITY RATIO INCLUDES
CUSTOMER DEPOSITS OF ~$97 MILLION AND EXCLUDES SHORT-TERM DEBT. 95 |
 PSEG Liquidity as of September 30,
2015 Expiration
Total Available Company Facility Date Facility Usage Liquidity ($Millions) PSE&G 5-year Credit Facility Apr-20 $600 (A) $34 $566 PSEG Money Pool 5-Year Credit Facility (Power) Apr-19 $1,600 $201 $1,399 5-Year Credit Facility (Power) Apr-20 $1,000 (B) $14 $986 5-year Credit Facility (PSEG) Apr-19 $500 $10 $490 5-year Credit Facility (PSEG) Apr-20 $500 (C) $0 $500 Total Money Pool $3,600 $225 $3,375 Total $4,200 $259 $3,941 $227 (A) PSE&G facility will be reduced by $29 million in April 2016, and $14 million in March 2018.
PSE&G ST Investment
$0 (B) Power facility will be reduced by $48 million in April 2016, and $24 million in March 2018.
Total Liquidity Available
$4,168 (C) PSEG facility will be reduced by $23 million in April 2016, and $12 million in March 2018.
Total Money Pool Liquidity Available
$3,602 PSEG / Power PSEG Money Pool ST Investment 96 |
 PSEG Energy Holdings Investment Portfolio Equipment Investment Balance *
at 9/30/15
($millions)
Merchant Energy Leases
NRG REMA
Keystone, Conemaugh & Shawville (PA)
3 coal-fired plants (1,162 equity MW)
$ 355
NRG Energy, Inc. / Midwest Gen**
Powerton & Joliet Generating Stations
(IL) 2 coal-fired generating facilities (1,640 equity MW)
$ 218
Regulated Energy Leases
Merrill Creek
Reservoir in NJ (PECO, MetEd, Delmarva Power &
Light) $ 152
Grand Gulf
Nuclear station in Mississippi (175 equity MW)
$ 14
Real Estate Leveraged Leases
GM Renaissance Center; Wal-Marts
$ 57
Real Estate Operating Leases
Office
Towers,
Shopping
Centers
-
28
properties
$ 34
Generation Legacy Assets
GWF (in wind down stage), GSOE
$ 1
Other
Land
$ 5
Total Holdings Investments
$836
* BOOK BALANCE EXCLUDING DEFERRED TAX
ACCOUNTS **EME AND ITS SUBSIDIARIES FILED CHAPTER
11 BANKRUPTCY ON 12/17/2012. EME WAS ACQUIRED BY
NRG ON APRIL 1 2014. 97
|
 Items Excluded from Income from Continuing Operations/Net Income to Reconcile to Operating Earnings PLEASE SEE PAGE 3 FOR AN EXPLANATION OF PSEG’S USE OF OPERATING EARNINGS AS A NON-GAAP FINANCIAL MEASURE AND HOW
IT DIFFERS FROM NET INCOME.
2014 2013 2012 2011 2010 2009 Earnings Impact ($ Millions) Operating Earnings 1,400 $ 1,309 $ 1,236 $ 1,389 $ 1,584 $ 1,567 $ Gain (Loss) on Nuclear Decommissioning Trust (NDT) Fund Related Activity (PSEG Power) 68 40 52 50 46 9 Gain (Loss) on Mark-to-Market (MTM) (a) (PSEG Power) 66 (74) (10) 107 (1) (11) Lease Transaction Activity (PSEG Enterprise/Other) - - 36 (173) - 29 Storm O&M (PSEG Power) (16) (32) (39) - - - Market Transition Charge Refund (PSE&G) - - - - (72) - Gain (Loss) on Asset Sales and Impairments (PSEG Enterprise/Other) - - - 34 - - Income from Continuing Operations 1,518 $ 1,243 $ 1,275 $ 1,407 $ 1,557 $ 1,594 $ Discontinued Operations - - - 96 7 (2) Net Income 1,518 $ 1,243 $ 1,275 $ 1,503 $ 1,564 $ 1,592 $ Fully Diluted Average Shares Outstanding (in Millions) 508 508 507 507 507 507 Per Share Impact (Diluted) Operating Earnings 2.76 $ 2.58 $ 2.44 $ 2.74 $ 3.12 $ 3.09 $ Gain (Loss) on NDT Fund Related Activity (PSEG Power) 0.13 0.08 0.10 0.10 0.09 0.02 Gain (Loss) on MTM (a) (PSEG Power) 0.13 (0.14) (0.02) 0.21 - (0.02) Lease Transaction Activity (PSEG Enterprise/Other) - - 0.07 (0.34) - 0.05 Storm O&M (PSEG Power) (0.03) (0.07) (0.08) - - - Market Transition Charge Refund (PSE&G) - - - - (0.14) - Gain (Loss) on Asset Sales and Impairments (PSEG Enterprise/Other) - - - 0.06 - - Income from Continuing Operations 2.99 $ 2.45 $ 2.51 $ 2.77 $ 3.07 $ 3.14 $ Discontinued Operations - - - 0.19 0.01 - Net Income 2.99 $ 2.45 $ 2.51 $ 2.96 $ 3.08 $ 3.14 $ (Unaudited) For the Year Ended December 31, PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED Reconciling Items, net of tax (a) Includes the financial impact from positions with forward delivery months.
A |
 Items Excluded from Income from Continuing Operations/Net Income to Reconcile to Operating Earnings PLEASE SEE PAGE 3 FOR AN EXPLANATION OF PSEG’S USE OF OPERATING EARNINGS AND ADJUSTED EBITDA AS NON-GAAP
FINANCIAL MEASURES AND HOW THEY DIFFER FROM NET
INCOME. B
2015 2014 2015 2014 2014 2013 Operating Earnings 403 $ 393 $ 1,221 $ 1,153 $ 1,400 $ 1,309 $ Gain (Loss) on Nuclear Decommissioning Trust (NDT) Fund Related Activity (PSEG Power) (14) 17 (11) 40 68 40 Gain (Loss) on Mark-to-Market (MTM) (PSEG Power) (a) 50 36 58 (138) 66 (74) Storm O&M, net of insurance recoveries (PSEG Power) - (2) 102 (13) (16) (32) Net Income 439 $ 444 $ 1,370 $ 1,042 $ 1,518 $ 1,243 $ Fully Diluted Average Shares Outstanding (in Millions) 508 507 508 507 508 508 Operating Earnings 0.80 $ 0.77 $ 2.41 $ 2.27 $ 2.76 $ 2.58 $ Gain (Loss) on NDT Fund Related Activity (PSEG Power) (0.02) 0.04 (0.02) 0.08 0.13 0.08 Gain (Loss) on MTM (PSEG Power) (a) 0.09 0.07 0.11 (0.27) 0.13 (0.14) Storm O&M, net of insurance recoveries (PSEG Power) - (0.01) 0.20 (0.03) (0.03) (0.07) Net Income 0.87 $ 0.87 $ 2.70 $ 2.05 $ 2.99 $ 2.45 $ (a) Includes the financial impact from positions with forward delivery months. ($ Per Share Impact - Diluted, Unaudited) ($ Millions, Unaudited) PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED Reconciling Items, net of tax Three Months Ended Year Ended Consolidated Operating Earnings Reconciliation Nine Months Ended December 31, September 30, September 30, |
 Items Excluded from Net Income to Reconcile to Operating Earnings and Adjusted EBITDA 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.
C |