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![Page 1: Getting to 2050 CFA Society Presentation October 25, 2011 San Francisco, CA Ren Orans, Managing Partner Energy and Environmental Economics, Inc. Pathways.](https://reader035.fdocuments.in/reader035/viewer/2022070410/56649eb35503460f94bba2de/html5/thumbnails/1.jpg)
Getting to 2050
CFA Society PresentationOctober 25, 2011San Francisco, CA
Ren Orans, Managing PartnerEnergy and Environmental Economics, Inc.
Pathways to Deep Reductions in GHG Emissions
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Agenda
Climate Change-Why Should I Care?
No Question we have a Monumental Task Ahead
Achievable through Wedges?
Electrification is Key!
Duke Power Example
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Energy and Environmental Economics, Inc.
San Francisco-based consulting firm since 1989
Deep expertise in electricity sector
Experienced in linking technical-economic analysis to policy decision-making and public process
Skilled at placing near term energy choices in long-term, transformational perspective
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The Climate Challenge
Climate stabilization (at 450 ppm CO2e) requires global emissions to stop growing by 2015, and to fall 50 – 80% below 2000 levels by 2050
Reducing GHGs will mitigate climate change impacts, but temps will increase no matter what we do today
Source: Intergovernmental Panel on Climate Change, Climate Change 2007: Synthesis Report
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Climate Change-Why Should I Care?
Economic Costs- Costs between 1 and 4 percent of GDP in 2050
Investment in Mitigation-Requires huge investment in new Infrastructure.
• Upfront investments are about 3 times economic costs which amounts to about $10 trillion over next 20 years.
Adaptation-What is left over after mitigation, might be something on the order of $100 Billion per year.
• This also introduces a tremendous financing opportunity to mitigate, account for and insure against residual adaptation costs.
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National GHG targets developing in the absence of an int’l framework
Governing Body
Source/Declaration Legally binding?
Greenhouse Gas Emissions Reduction Target
G8 G8 Hokkaido Toyako Summit
No 50% below current levels by 2050
Australia Carbon Pollution Reduction Scheme
No 60% below 2000 levels by 2050
European Union
European Parliament Legislative Resolution, 17 December 2008
Yes 20% reduction from 1990 levels by 2020 (goal of 60% to 80% below 1990 levels by 2050 in developed countries)
United Kingdom
Climate Change Act of 2008
Yes 80% below 1990 levels by 2050
United States
Obama administration policy goal, various legislative proposals
Proposal only
80% reduction by 2050
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U.S. Federal Proposals Call for Deep Cuts in GHG Emissions by 2050
Source: Pew Center on Global Climate Change, www.pewclimate.org
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U.S. States with GHG Targets
Arizona 2000 levels by 2020
50% below 2000 by 2040
California 1990 levels by 2020
80% below 1990 by 2050
Colorado 20% below 2005 by 2020 80% below 2005 by 2050
RGGI states
10% below 1990 by 2020
Florida 2000 levels by 2017, 1990 levels by 2025, and 80% below 1990 levels by 2050
Hawaii 1990 levels by 2020
Minnesota 15% below 2005 by 2015
30% below 2005 by 2025
80% below 2005 by 2050
Oregon 10% below 1990 by 2020
75% below 1990 by 2050
Source: Pew Center on Global Climate Change, www.pewclimate.org
Example states – not full list
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California’s GHG Strategy
AB 32: 1990 levels by 2020
• 80% of reductions to come from regulations
• 33% RPS by 2020
• Energy efficiency
• Combined heat and power
• Light-duty vehicle emissions performance standards
• Low-carbon fuel standard for vehicles
• 20% of reductions to come from regional cap and trade
• Western Climate Initiative
Executive Order S-3-05: 80% below 1990 by 2050
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California 2050 Study
Key question
• What does California need to do to meet the 2050 GHG reduction goal?
Infrastructure modeling approach
• Multi-sector, stock roll-over model• Integrated electricity grid dispatch
algorithms• Use standard projections of CA
population, economic growth• Consistent w/ AB32 Scoping Plan
Independent study sponsored by Hydrogen Energy International (HEI)
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California’s Big Step ForwardAssembly Bill 32
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700
1990 1994 1998 2002 2006 2010 2014 2018 2022 2026 2030 2034 2038 2042 2046 2050
Mill
ion
met
ric to
nnes
CO
2e
Today
2020 Goal under AB32
2050 GoalExecutive order
Business as usual projection
Transportation
Electricity
Industry
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Greenhouse Gas Savings for 2050
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200
300
400
500
600
700
800
900
1990 2000 2010 2020 2030 2040 2050
Year
MM
t C
O2e
Conservation & Behavior Change
Energy Efficiency: Transportation
Energy Efficiency: Buildings andIndustrial
PV Rooftops
Low Carbon Biofuels
Electrification: Transportation
Low Carbon Generation
Mitigation of Non-Fuel/Non-CO2 GHGs
Remaining CO2e
Source: Energy and Environmental Economics, Inc 2009
Greenhouse Gas Reductions in California
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Emissions Reductions by Source
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1990 2000 2010 2020 2030 2040 2050
Year
MM
t C
O2e
Non-Fuel/Non CO2 GHGs
Diesel & Other transport fuels
Gasoline
Fuel - Industrial & Agriculture
Fuel - Residential & Commercial
Electricity - Transportation
Electricity - Non-transport
Baseline
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Behavioral Change Technological Change
Types of Change
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1990 2000 2010 2020 2030 2040 2050
Re
sid
en
tia
l Ho
me
s (
Mill
ion
s)
Year
New Homes
Retrofit Homes
Homes with Historic Energy Demand
Conservation & Energy Efficiency
“Smart Growth” 10% reduction in vehicle miles traveled relative to baseline
Unprecedented levels of energy efficiency
Transition to zero net energy homes by 2020
Extensive retrofits of existing buildings
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2008 2050 Baseline 2050 CompliantCase
Bill
ion
s o
f g
allo
ns
Conservation
Efficiency
Electrification
BioJet Fuel
Biodiesel
Ethanol
Jet Fuel
Diesel
Gasoline
Low-Carbon Biofuels
100% of California's biomass feedstock for ethanol plus 7% of US feedstocks (DOE EIA 2007)
Feedstocks include Ag Residues, Grasses and Forest Trimmings
7% assumes a distribution proportional to fuel consumption across all 48 States
Assumes 1.8 billion gallons per year of algal biodiesel and bio-jet fuel
Sufficient to meet 25% of biodiesel and 10% of bio-jet fuel demand in 2050 compliant case
California Biofuel Availability
Eliminate consumption of gasoline by 2050 replacing it with some mix of low-carbon electricity and low-carbon fuels
Aggressive biofuel assumptions don’t meet all transportation energy needs – biofuels likely to become premium fuel
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Electrification & Electricity Demand
Electricity demand could nearly double by 2050
Increase in demand driven by electric vehicles
Nearly all electricity must be from low-carbon generation
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1990 2000 2010 2020 2030 2040 2050
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Ele
ctr
ic D
em
an
d a
t th
e G
en
era
tor
(GW
h)
Transportation
Petroleum & Agriculture
Industrial
Commercial
Residential
Baseline
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Electrification and Loads
“Flat” load profile in 2050 Compliant case“Peaky” demand in 2050 Baseline
2050 Baseline Case 2050 Compliant Case
High levels of energy efficiency help to decrease demand and flatten the demand profile
Off-peak electric vehicle “smart charging” & electrification will flatten load shape, increase overall demand & need for baseload generation
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Low-Carbon Generation
1. High Renewable Case 2. High Nuclear Case
3. High CCS Case 4. Blended Case
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Investments to decarbonize electricity are significant in all low-carbon cases
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tme
nt
(Bill
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20
08
$)
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Generation Capacity in 2050
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Na
me
pla
te C
ap
ac
ity
(G
W)
Gas CT
Biomass
Geothermal
Solar Thermal
Solar PV
Wind
Nuclear
Storage - 4 Hour
Gas w/ CCS
Coal w/ CCS
Coal
Combined Cycle
Hydro
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Technology Wish List
EfficiencyZero net energy buildingsExtensive building retrofits
ElectrificationBatteries for electric vehiclesSmart charging for electric vehicles
BiofuelsZero carbon ethanolZero carbon algal fuels
Zero Carbon GenCarbon capture and storageLarge scale energy storageNuclear waste storage
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Retail Rates, Risk and Greenhouse Gas Reductions
Example fromDuke Energy Carolinas
E3 Case Study
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Duke Energy Carolinas
Duke Energy Carolinas is focused on coal and nuclear:
1. Energy efficiency and conservation
2. Transition away from coal power
3. Transition from natural gas power renewables
4. Electrification of fossil fuel uses
Source: Duke Energy Carolinas, 2010 Integrated Resource Plan
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Investment Decision Timeline
Power plant investments made today have 20 – 40 year lifetime at minimum
Only one to two investment cycles before 2050, when goal is to have a decarbonized energy system
To what degree should utilities tolerate ratepayer risk of future emissions abatement costs?
Solar Nuclear Carbon capture & storage
Wind
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Duke Energy Carolinas Case Study
Scenario Description 1. Business-as-usual, no CO2
price
Modeled roughly after Duke Carolinas 2010 Integrated Resource Plan, assumes no carbon abatement costs
2. Business-as-usual, w/ CO2
price
Same as #1, but includes moderate carbon abatement costs
3. Coal retirement
Same as #2, including CO2 cost, but coal is replaced with natural
gas fired generation
4. Low risk electrification
Same as #3, but assumes a high penetration of electric vehicles. New loads are served with new natural gas-fired generation. Scenario also assumes off-peak charging of electric vehicles. Electrification does not increase RPS compliance costs. Utility receives 100% of the GHG savings credits achieved in transportation sector from electric vehicles
5. High risk electrification
Same as #4, but assumes uncontrolled charging of electric vehicles. Scenario assumes electrification increases the cost of decarbonizing the utility generation portfolio to meet the RPS, and provides no utility credit for GHG savings achieved in transportation sector from electric vehicles
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Duke Energy Carolinas Case Study
E3 developed five scenarios for 2011 – 2030
Scenarios test variations in generation mix & vehicle electrification assumptions
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Purchases
Natural gas
Renewables
Hydro
Coal
Nuclear
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Duke Energy Carolinas Case Study
Assume retired coal is replaced with natural gas
Assume new electrification loads are met with natural gas
-10,000
-5,000
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Cha
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apac
ity
Rela
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to 2
010
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)
Natural gas
Renewables
Hydro
Coal
Nuclear
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Scenario Results:Greenhouse Gas Emissions
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60
2009 2012 2015 2018 2021 2024 2027 2030
Net
Uti
lity
Emis
sion
s (M
MT
CO2)
High-risk Electrification CaseBAU CaseCoal Retirement CaseLow-risk Electrification Case
Emissions are nearly flat in BAU scenario
Emissions risk or benefit from electric vehicles
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$0.00
$0.04
$0.08
$0.12
2009 2012 2015 2018 2021 2024 2027 2030
Real
201
0 $/
kWh
High Risk Electrification
BAU
Low Risk Electrification
BAU Without Carbon Price
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Scenario Results:Retail Rate Impacts
Low risk case: rate impacts are lower than BAU largely because of CO2 cost savings credited from vehicle electrification
High-risk case: If utilities do not receive emissions savings credit from electric vehicle, rate impacts are high
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Ratepayer Risk & Electrification
Electrification & natural gas pathway can be:
• Lower cost for customers;
• Lower risk (for ratepayers and/or shareholders); and
• Lower emissions than BAU coal and nukes pathway.
Done wrong, electrification represents an emissions and cost risk to utilities
Electrification is unlikely to achieve high penetrations without concerted policy efforts and support of electric utilities
• Current federal incentives for EVs unlikely encourage the market transformation and breakthroughs that are needed
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Summary of Challenges and Opportunities
GHG reductions pose a substantial financing challenge
• Initially mitigation in both power, buildings and transportation sectors
Utilities and larger customers should account for and possibly hedge against emissions abatement risk and cost
• Similar to sinking fund for disposal of nuclear waste
• Lack of policy does not translate to zero future costs
Electrification is key to mitigation challenge
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Thank You
Ren OransEnergy and Environmental Economics, Inc.101 Montgomery Street, Suite 1600San Francisco, CA 94104
(415) [email protected]
Presentation Available at:http://ethree.com/documents/E3_2050_CFA_25Oct11.ppt