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BUILDING A WORLD OF DIFFERENCE®
Planning for Growing Electric Planning for Growing Electric Generation DemandsGeneration Demands
Kansas Energy Council – Electric Subcommittee
March 12, 2008
BUILDING A WORLD OF DIFFERENCE®
2008 2
Topics
The Power Supply Planning Process
Conventional Power Supply Technologies
Renewable Technologies
Nuclear Developments
Summary
Questions and Answers
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2008 3
New Generation Planning Process
Projected Capacity /
Energy Needs
Analytically Optimal Plans
Prioritized Sites & Site Cost
Curves
Power Sales / Purchase Canidates
New Generator Sizing /
Technology Analysis
New Generator Siting Study
Market Assessment
Revenue Requirement and
Financial Analysis
Power Purchase / Sales
Negotiations
New Generator Supply Plan
Recommendations
Final Selected Site(s) and Supply Plan
Legend Planning Process Siting Process Financial Analysis Inputs to Planning Process Optimal Results
Start
Finish
In Parallel with a power market assessment and siting study. Usually also in parallel with DSM and existing generator life extension / retirement analysis
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Historical and Forecast Demand & Energy GrowthSample
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500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500A
ctua
l
Act
ual
Act
ual
Act
ual
For
ecas
t
For
ecas
t
For
ecas
t
For
ecas
t
For
ecas
t
1990 1995 2000 2005 2010 2015 2020 2025 2030
Year
Fo
rec
as
t A
nn
ua
l E
ne
rgy
, G
Wh
0
100
200
300
400
500
600
Fo
rec
as
t P
ea
k,
MW
Industrial Commercial Village West Residential City/County Borderline Losses Extreme Weather Peak Normal Weather Peak
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Load and Capability ForecastSample
0
50
100
150
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800
20
06
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Year
MW
WAP A 5 MW
CT #4, Gas & Oil 75 MW
CT #3, Oil 49 MW
CT #2, Oil 56 MW
CT #1, Gas 12 MW
Nearman #1 (BP U share) 174 - 232 MW
Quindaro #2, Gas 23 MW
Quindaro #2, Coal 95 MW
Quindaro #1, Coal 72 MW
Capacity Responsibility
P eak Demand
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Hourly Load Pattern Dictates Need for Various Generation Types
0
100
200
300
400
500
600
J F M A M J J A S O N D
MW
Lo
ad
% Time
Peaking
Intermediate
Baseload
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Conventional Generators
Renewable
Demand Side
Management
Power Supply Options
PurchasedPower
Nuclear
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$-
$50.00
$100.00
$150.00
$200.00
$250.00
$300.00
$350.00
$400.00
$450.00
$500.00
Fix
ed C
ost
in
$/k
W-y
ear
and
Var
iab
le C
ost
in $
/MW
h
Fixed Cost
Variable Cost
Comparative CostsConventional Generation ResourcesSample
600 MW PC 500 MW CC 150 MW CT
Baseload
Intermediate
Peaking
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Generation Resource ScreeningRepresentative Sample
20 Year Levelized Busbar Costs 2012 C/O Date
-
50
100
150
200
250
10% 20% 30% 40% 50% 60% 70% 80% 90% 100%
Capacity Factor
$/M
Wh
600 MW PC
CC 500
150 CT
solar
LFG
DFB
Wind
Nominal Rating
Solar and Wind technologies are not firm resources.
Assumes $6.80/MBtu gas in 2012 escalating at 4% per year and $1.45/MBtu coal escalating at 3% per year.
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Baseload Resource Screening with CO2 CostsRepresentative Sample
$-
$50.00
$100.00
$150.00
$200.00
$250.00
0 10 20 30 40 50 60
CO2 Price $/ton
Bu
sbar
Co
st $
/MW
h
SCPC
CC
Wind plus CC
Solar plus CC
Biomass
Note: Assumes biomass is CO2 neutral per the Intergovernmental Panel on Climate Change (IPCC).
Assumes $6.80/MBtu gas in 2012 escalating at 4% per year and $1.45/MBtu coal escalating at 3% per year.
BUILDING A WORLD OF DIFFERENCE®
Purchased Power or Power Sales OptionsRequire Analysis of Available Transmission CapacitySample
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New Generators Should Complement the Existing MixSample
Of 425 MW of firm capacity needed by 2011, up to 350 MW of new solely-owned coal capacity can be added while keeping coal and combined cycle in a least cost mix. The remaining 75 MW added should be peakers.
Load Duration Curve Screening-2011 Options
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Develop Alternative Power Supply Plans for Testing
Plan 1
CT – 2006 55 MW
1x1 CC – 2008 256 MW
250 MW Coal – 2010 250 MW
Retire Riverton 7, 8 in 2008
Plan 2
2 CTs – 2007 110 MW
2 CTs – 2009 110 MW
Large Coal – 2010 300 MW
Retire Riverton 7, 8 in 2008
Plan 3
CT – 2007 55 MW
CT – 2007 55 MW
Large Coal – 2010 400 MW
Retire Riverton 7, 8 in 2008
Plan 4
2 CTs – 2007 55 MW
2x1 CC – 2008 200 MW
Large Coal – 2010 200 MW
Retire Riverton 7, 8 in 2008
Plan 5
CT – 2006 55 MW
1x1 CC – 2008 256 MW
1x1 CC – 2010 256 MW
Retire Riverton 7, 8 in 2008
Sample
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Comparative Rate ImpactsCompare Plans Using Detailed Production Cost and Financial Models
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
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Year
Cu
mu
lati
ve In
crea
se %
210 MW CTs Plus 300MW Coal
55 MW CT Plus 500MW Combined Cycle
Sample
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Desirable Plans Minimize Revenue Requirements Under a Range of Risk ScenariosSample
Key Plans Sensitivity Cases
$45.00 $50.00 $55.00 $60.00 $65.00 $70.00 $75.00 $80.00 $85.00 $90.00
Levelized $/MWH
235 MW PC
135 of 235 MW PCCR2020
(Base Plan)
175 of 235 MW PC
175 of 235 MW PCCR2020
$65.88
$62.17
$62.84
$62.40
$63.24
116 of 232 MW CC
Capital
Spot Market
Carbon TaxNOx/SO2
Fuel Prce
Load Growth
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Consider Corporate Financial Impacts-AdverseImpacts on Bond Ratings Also Increase Revenue RequirementsSample
Co
ve
rag
e R
ati
o
0.00
0.50
1.00
1.50
2.00
2.50
3.00
3.50
4.00
4.50
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
Year
300 MW Owned Coal
300 MW Purchased Coal
300 MW Buy Back
Typical Target is 3 to 4.
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Selected Plan(s) Must Consider Lead Times
Air Permit
Studies and Conceptual Engineering
Permitting Preliminary Engineering
Cost Estimate Schedule
Detail Engineering and Procurement
Start Permitting and Preliminary
Engineering
Start Engineering and
Procurement Receive Air
Permit
Begin Construction
Construction
In Service
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Conventional Generators
Renewable
Power Supply Options
PurchasedPower
Nuclear
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Generation Technology OverviewConventional Generation
Simple Cycle Combustion Turbine (SCCT or CT)
Combined Cycle Combustion Turbine (CCCT)
Atmospheric Circulating Fluidized Bed (CFB)
Pulverized Coal (PC)
Integrated Gasification Combined Cycle (IGCC)
Nuclear
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Comparison of Conventional Technologies Simple Cycle Combustion Turbines
Description: Simple cycle combustion turbine generates power by compressing and heating
ambient air and then expanding those hot gases through a turbine which turns an electric generator.
Advantages: Low capital costs Short design and installation schedules Choice for peaking service with rapid
startup and modularity for ease of maintenance
High reliability and mature technology Disadvantages
Typically higher operations and maintenance costs than combined cycle units
Typically not used for baseload operation Sizes typically less than 300 MW High fuel costs
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Comparison of Conventional Technologies Combined Cycle Combustion Turbines
Description: Combined cycle combustion turbine generates power by compressing and heating
ambient air and then expanding those hot gases through a turbine which turns an electric generator. In addition, heat from the hot gases of combustion are captured in a heat recovery steam generator (HRSG) producing steam which is passed through a steam turbine generator.
Advantages: Low emissions Higher efficiency than SCCT
Disadvantages: Higher capital cost than SCCT Volatile natural gas prices Higher non-fuel O&M than coal units High fuel costs
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Conventional Technologies Pulverized Coal
Description: Pulverized coal is burned in a steam generator constructed of membrane waterwalls
and tube bundles which absorb the radiant heat of combustion producing steam that is fed into a steam turbine generator.
Advantages: Most mature coal burning technology More experience than any other power generation technology Very reliable and easy to operate and maintain Can accommodate up to 1,300 MW, and
economies of scale can result in low busbar costs
Low fuel cost Future units (advanced supercritical) higher
efficiency and lower GHG emissions Disadvantages:
Less fuel flexibility than CFB units More sensitive to fuel characteristics, slagging,
and fouling Siting and Permitting has become more difficult
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Comparison of Conventional Technologies Circulating Fluidized Bed (CFB)
Description: Combustion air is introduced through the bottom of the bed material normally
consisting of fuel, limestone, and ash. Heat generated from burning fuel produces steam which is fed into a steam turbine
generator. Advantages:
Ability to burn a wide variety of fuels – greater fuel diversity than PC Very reliable and easy to operate and maintain Slagging and fouling tendencies minimized
because of low combustion temperatures Disadvantages:
No units larger than 300 MW have been built Slightly higher operations and maintenance cost
than PC units Less suited for numerous startups and cycling
than PC units Typically less efficient than PC plants
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Comparison of Conventional Technologies Integrated Gasification Combined Cycle
Description: Fuel (petcoke, coal, or other solid fuel) converted to syngas then combusted in
modified gas turbines in a combined cycle power generation unit. Advantages:
Capability of operating at relatively low emissions compared to PC/CFB’s. Efficiencies comparable to supercritical PC technologies Costs associated with reducing Hg and
capturing CO2 emissions generally thought to be incrementally lower for IGCC than for CFB and PC technologies
Disadvantages: Capital costs, operating costs,
and availability Reliability lower than PC and CFB Startup and shutdown flaring reduces
emission benefits of IGCC over PC and CFB
To date, large-scale, U.S. based power producing IGCC plant not proven to be economically feasible without subsidization
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Comparison of Conventional Technologies Representative Emissions Levels
Constituent Unit PC CFB IGCC Combined Cycle
Fuel Coal Coal Coal Natural Gas
NOx
lb/MBtu 0.05 - 0.07 0.07 – 0.11 0.055 – 0.10 0.007-0.013
lb/MWh 0.55 0.85 0.68 0.07
SO2
lb/MBtu 0.06 – 0.1 0.04 – 0.13 0.015 – 0.045 0.0006
lb/MWh 0.74 0.80 0.27 0.004
PM/PM10
(filterable)
lb/MBtu 0.012 – 0.015 0.012 – 0.015 0.005 – 0.01 ~ 0.020 – 0.025
lb/MWh 0.12 0.13 0.07 0.15
CO2
lb/MBtu 205-220 205-220 205-220 117
lb/MWh 1950 1990 1910 810
Notes: Mercury regulation has recently been vacated. New permitting efforts will proceed on a case-by-case
basis. Air emissions based on 100 percent load. CO2 emissions are not currently regulated. IGCC is without CO2 capture and storage.
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Comparison of Conventional TechnologiesRepresentative Development Schedules
PC
SCCT
Years
CCCT
IGCC
Nuclear
2 4 6 8 10 12
Schedule and Costs Are Increasing
The schedules and costs of all technologies, including renewables, are being adversely impacted by the
current scarcity of labor and materials.
Units 5+
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Generation Technology OverviewRenewable Generation
Wind
Biomass
Landfill Gas
Solar
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Comparison of Renewable Technologies Wind
Description: Convert movement of air to electric power by means
of a rotating turbine and a generator Fastest growing energy source (+30% annually for
last 5 years) Project Sizes 1 to 300+ MW Cut-in wind speed: 8 mph WTG Specs: 1985 2007
Rotor: 15m 90mHub Height: 20m 80mRating: 50kW 2,000kW
Advantages: Clean generation technology
Disadvantages: Wind is an intermittent resource and capacity factors
range from 25 to 40 percent High capital costs, maintenance costs on the order of $35/kW-yr Capacity factor directly impacts economic performance Cannot be relied upon as firm capacity for peak power demands
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Comparison of Renewable Technologies Direct-fired Biomass
Description: Similar in operation to coal plants. By burning biomass,
pressurized steam is produced in boiler then expanded through a turbine. Biomass traditionally from direct combustion at pulp and paper mills, lumber mills, etc.
Prior to combustion in boiler, biomass fuel may require some processing to improve physical and chemical properties of feedstock. Stoker and fluidized bed combustion technologies are well proven.
6,500 MW of capacity installed in the U.S. Advantages:
Burn wide variety of fuels Carbon-neutral power generation (per IPCC) Biomass fuels contain little sulfur and trace amounts of toxic metals
Disadvantages: Capacities range up to 85 MW, average 20 MW Plant must be located at or within 50 to 75 miles from fuel source to be economically
feasible Lower heating values of fuels make biomass plants less efficient than coal plants
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Comparison of Renewable Technologies Biomass Co-firing
Description: Biomass and coal are co-fired in existing coal plants Two basic approaches to co-firing:
1. Blend fuels and feed together in coal processing equipment2. Separately processing and then injecting biomass
in boiler Advantages:
One of the most economical ways to burn biomass ($50–400/kW) Using Method 1: in a cyclone boiler, up to 10 percent of the
coal heat input could be replaced with biomass Using Method 2: in a PC boiler, 10 to 15 percent of coal heat input could be replaced
with biomass Disadvantages:
Disperse nature of feedstock and high associated transportation costs as in Direct-fired Biomass and Biomass IGCC
Limited capacity by amount of resource available Reduced plant capacity, boiler efficiency Ash contamination, increased O&M cost, boiler fouling/slagging, SCR catalyst
poisoning
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Comparison of Renewable Technologies Landfill Gas (LFG)
Description: LFG is produced by the decomposition of
the organic portion of waste stored in landfills. LFG primarily consists of methane which can be burned in reciprocating engines or small gas turbines.
Advantages: Burns gas that would otherwise be emitted
into the atmosphere as GHG Regarded as one of the more mature and
successful waste-to-energy technologies Disadvantages:
Power production from LFG typically less than 10 MW
Pretreatment of gas prior to combustion
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Comparison of Renewable Technologies Solar-Thermal Technologies
Description: Solar thermal technologies convert the sun’s energy
to electricity by capturing heat, producing steam and passes through a steam turbine.
Parabolic trough currently most prevalent technology. Advantages:
Appropriate for a wide range of intermediate and peaking applications
Clean generation technology Commercial solar thermal trough plants in California
currently generate more than 350 MW Thermal energy can be stored to allow for generation
when sun is not shining Disadvantages:
Large land to MW ratio Dependant on sunlight availability High capital cost
Parabolic Trough
Parabolic Dish
Central Receiver
Compact Linear Fresnel Reflector
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Nuclear Reactor Technology
Description: Inside a nuclear reactor, uranium atoms are bombarded by neutrons When a neutron is absorbed by a uranium atom, atom becomes unstable and splits, a
process known as fission Fission process generates heat in the reactor core and generated heat is transferred
to water which is circulated to the steam generator Electricity generated by applying steam to a turbine generator, much like coal-fired
power plants Advantages:
Virtually no emissions Relatively low fuel cost
Disadvantages: Obstacles related to public perception Capital costs Political risks Environmental issues
concerning disposal of spent fuel
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2005 Energy Policy Act Assists New Nuclear
Production Tax Credits 1.8¢ / kwh for 8 years up to $125 million annually per 1,000 MW
Requires COLA Submittal NLT 12/31/2008 & First Safety Concrete Pour NLT 1/1/2014
Loan Guarantees
Standby Support 100% for first two units up to $500 million each
50% for next four units up to $250 million each
Renewal of Price-Anderson Act
Continuation of Nuclear Power 2010 Program
Nuclear Decommissioning Tax Relief
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Nuclear Power 2010 Program
Nuclear Power 2010 Program is a Joint Government-Industry Cost Sharing Program That Will Pay up to Half of The Nuclear Industry’s Costs for Development of Generation III+ Technologies
Current Program Participants Include:
NuStart Energy LLC: AP1000 (Bellefonte)
Dominion Energy: ESBWR (North Anna)
BUILDING A WORLD OF DIFFERENCE®
2008 36
Other Changes for New Nuclear Construction
Regulatory Change to Single Step Licensing Process
Previous Generation Reactors Required Construction Permits and Operating License Hearings
New Generation III/III+ Reactors Obtaining SER As Generic Designs
Utility Submits COLA (Combined Operating License Application) for Site Specific Aspects of Project
Process Only Applies if Utility Uses Generic Designs- All Modifications Require USNRC Review
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2008 37
Status of Nuclear Industry
Technologies in Design Certification
Reactor Design Vendor
Approximate Capacity
(MWe)Reactor
Type NRC DC Status
US-EPR AREVA NP 1600 PWR Pre-Certification, Target 2009
US-APWR Mitsubishi 1700 PWR Undergoing Certification, Target 2011
AP-1000 Westinghouse 1117 PWR Certified (January 2006), Undergoing Update
ABWR GEH 1350 BWR Certified (May 1997)
ESBWR GEH 1520 BWR Undergoing Certification, Target 2010
BUILDING A WORLD OF DIFFERENCE®
2008 39
Limits to Foreign Ownership of Nuclear Generating Plants
Partial foreign ownership of a nuclear plant is not specifically prohibited by regulation - 100% foreign ownership is prohibited. The NRC reviews the makeup of the ownership as part of the license applications and makes a judgment regarding the ownership, considering whether the foreign component is just financial or the foreign component is acting as the licensee. A prior NRC ruling in the case of Amergen (PECO and British Energy) involved a 50-50 JV where PECO maintained the operating responsibility and BE was solely a financial vehicle. In this review, one of the main considerations by the NRC was the control of safety related activities (considered licensee activities) and that they be under the control of a US citizen. The NRC found it acceptable for the 50-50 ownership provided the day-to-day control of the plant and the licensee activities were under the control of the US entity. The same would hold true for Unistar, the EDF - Constellation JV.
Source: NRC SECY-98-252
BUILDING A WORLD OF DIFFERENCE®
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Summary / Conclusions
Generation additions are capital intensive and capital requirements have been increasing dramatically for all technologies
Electric generation has long-lead time requirements
Planning must consider rate-payers, stock holders, and Wall Street requirements
Planning must allow for all these factors
Recognition of risk and development of contingency plans
Value flexibility