global energy solutions summit · 2020. 4. 17. · • multi-stakeholder initiatives are important...
TRANSCRIPT
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GLOBAL ENERGY SOLUTIONS SUMMIT
March 28 to 29, 2019Location (Embassy of Canada, 501 Pennsylvania Ave NW)
Washington, DC
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GLOBAL ENERGY SOLUTIONS SUMMIT
Welcome to Day 2: Carbon Capture, Utilization and
Storage (CCUS)
Rachel McCormick
Counsellor and Head
Energy and Environment Section,
The Embassy of Canada
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GLOBAL ENERGY SOLUTIONS SUMMIT
CCUS Opening Keynote
Hon. Bronwyn Eyre
Minister of Energy and Resources
Saskatchewan
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GLOBAL ENERGY SOLUTIONS SUMMIT
State of the CCUS Market
Samantha McCulloch
Head, CCUS Unit
International Energy
Agency
Jeff Erikson
General Manager –
Client Engagement
Global CCS Institute
Trude Sundset
CEO
Gassnova
Sarah Forbes
Scientist
Office of Fossil
Energy, U.S.
Department of Energy
John Harju
Vice President for Strategic
Partnerships
University of North Dakota’s
Energy and Environmental
Research Center (EERC)
Robert Niven
CEO
CarbonCure
MODERATOR
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IEA 2019. All rights reserved.
Global Energy Solutions Summit:
CCUS Roundtable
Samantha McCulloch
Head of CCUS
29th March 2019
IEA
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6IEA 2019. All rights reserved.
Global energy demand last year grew by 2.3%, the fastest pace this decade, an exceptional performance
driven by a robust global economy, weather conditions and moderate energy prices.
2018 – a remarkable year for energy
Annual change in global primary energy demand, 2011-18
100
200
300
400
2011 2012 2013 2014 2015 2016 2017 2018
Mtoe
Coal
Oil
Gas
Nuclear
Renewables
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7IEA 2019. All rights reserved.
Higher demand for fossil fuels drove up global CO2 emissions for a second year after a brief hiatus.
Increases in efficiency, renewables, coal-to-gas switching and nuclear avoided 640 Mt of CO2 emissions.
Annual change in global energy-related CO2 emissions, 2014-2018
Energy-related CO2 emissions hit a record high…
- 200
0
200
400
600
2014 2015 2016 2017 2018
MtCO2
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8IEA 2019. All rights reserved.
..led by coal in power generation in Asia
Emissions from coal continue to rise, driven by increasing coal use mostly for power generation in Asia.
CCUS is a critical solution and is showing signs of a revival.
Global energy-related CO2 emissions, 1990-2018
5
10
15
20
25
30
35
1990 2000 2010 2018
GtCO2
Other
Other coal use
Coal-fired power
generation
Coal
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9IEA 2019. All rights reserved.
www.iea.orgIEA
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1.4 millionSchool Climate strikes
Photo: NRK
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Technology Centre Mongstad
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CCS Infrastructure
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CCUS Projects Map
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GLOBAL ENERGY SOLUTIONS SUMMIT
Intermission
Join Us On
Twitter!
#WeTheStates
Join Us On
Twitter!
#WeTheStates
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GLOBAL ENERGY SOLUTIONS SUMMIT
Case Study on Boundary Dam Project
Beth Hardy
Vice President, Strategy & Stakeholder Relations
International CCS Knowledge Centre
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C. Beth Hardy, VP Strategy & Stakeholder Relations
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Our Organization
Mandate:Advance the understanding and use of CCS as a means of managing greenhouse gas emissions
Sponsored jointly by global resource leader, BHP and CCS pioneer, SaskPower
Sharing lessons learned from hands-on operations ensures for experienced-based decision making
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Large Scale Deployment (Boundary Dam 3)
Operational & Policy Understandings
Second Generation Application
Trends & Gaps for Large-Scale Deployment
Driving Future Opportunities
Our Story for CCS
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Carbon Capture and Storage Initiatives
E X E C U T I V E S T R A T E G I C
P L A N N I N G S E S S I O N
L EA R N I N G S TA R T S H E R ET H E W O R L D ’ S 1 S T I N T EG R AT E D L A R G E S C A L E P O S T - C O M B U S T I O NC C S FAC I L I T Y
BOUNDARY DAM
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Large Scale Deployment (Boundary Dam 3)
• Post-combustion chosen from several studies
• CCS on coal-fired power operating since 2014
• Projected 90% capture rate & 30 yr life extension
• Initial investment = approximately CDN$1.5 billion
• CO2 is used for EOR or sequestered at Aquistore
CCS at Boundary Dam Power Stationallowed for long-term production of
over 110 MW of clean, base-load electricityin a fully integrated and full chain process
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Overview of BD3 Project
The project consisted of two major parts:
Refurbishment included a complete replacement of the steam turbine and generator, which were at their end of life.
Capture involves taking out other components before the amine removes the CO2.
• Design deficiencies and construction quality issues had to be managed, as well as amine issues.
• Trend of higher capture rate and reduced outages over time
• Has captured & stored over 2Mt
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Comparing Costs
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Operational Understandings: Exceeding Federal Regulations
The project consisted of two major parts:
Refurbishment included a complete replacement of the steam turbine and generator, which were at their end of life.
Capture involves taking out other components before the amine removes the CO2.
• Design deficiencies and construction quality issues had to be managed, as well as amine issues.
• Trend of higher capture rate and reduced outages over time
• Has captured & stored over 2Mt
*Name plate capacity
CLE
AN
ER1100 t/GWh = Lignite Coal Plant
550-500 = Current Natural Gas Plant
420 = Canadian Regulations on Coal Plant
375-400 = New Natural Gas Plant
300-325 = Wind (with peakers)
120-140 = CCS on Boundary Dam 3*
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Capture plant has been reliable
Power plant maintenance resulted in no CO2 production
NOT CAPTURE PLANT RELATED
INITIAL OPERATION
Learning about amines
MAXIMUM CAPACITY HIT: 3240 t/dayBetter operations.
What’s next for Boundary Dam CCS?• Improve efficiency and reliability• Reduce operation & maintenance costs• Increase capacity
Performance: Reliability
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“Real world” considerations for using CCS are important.
We must COLLABORATE -Not just talk about collaborating.
• Stimulate development• Bring down costs• Promote greater knowledge exchange
Operational Understandings: Sharing Lessons Learned
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H I G H L I G H T S O F F EA S I B I L I T Y S T U D Y:• D e s i g n e d t o c a p t u r e 2 M t• 6 7 % c o s t r e d u c t i o n ( p e r t o n n e C O 2 )• C a n c a p t u r e u p t o 9 7 % a n d i n t e g r a t e s w e l l w i t h r e n e w a b l e s
SECOND GENERATION DESIGNSASKPOWER SHAND POWER STATION
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About the Shand Feasibility Study
Feasibility Study evaluates the economics of a CCS retrofit & life extension on 300MW
coal fired power plant in Saskatchewan
• Projected capture capacity of 2Mt/yr
• Capital cost to be 67% less per tonne of CO2 captured
• Cost of capture at $45US/t CO2
• Capture rate can reach up to 97% with reduced load (i.e. renewables on grid)
• Fly ash sales can further reduce CO2
(potential 125,000t CO2/yr reduced)Carbon neutral?
HOW DID COSTS COME DOWN?
• Lessons learned from building and operating BD3
• Construction at a larger scale using extensive modularization
• Integration of the bigger unit’s steam cycle
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Second Generation Application to Coal and Other Sources
• IPCC’s 5th Assessment Report: median increase in mitigation cost is 138% without CCS
• Almost all IPCC 1.5oC pathway scenarios include CCS
CCS technology is proven;so de-risked deployment can occur
• Reliable and affordable energy with reduced emissions are imperative for energy security.
• Implementation of CCS can:o allow existing generating assets to operate cleanly ando aid to decarbonize industrial emissions.
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Information on this slide is sourced from International Energy Agency, Energy Technology Perspectives 2017
Iron & Steel28%
Cement27%
Chemicals and petrochemicals
13%
Aluminium3%
Pulp & Paper3%
Other Industry26%
Direct industrial CO2 emissions (2014)Industrial CO2 emissions represent 24% of global
CO2 emissions at 8.3 Gt CO2 (2014)
• Lessons learns from operational experience at Boundary Dam CCS Facility and findings from the Shand CCS Feasibility Study can be applied to other industrial sources of emissions
• Size and layout considerations / integration are key considerations
• Costs can be saved with CO2 infrastructure hubs, cost recovery with EOR, modularization and byproduct sales decisions
• Optimization is still required for particular flue gas characteristics to save operating costs
Second Generation Application to Industrial Emissions
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Driving Future Opportunities
Cooperative Approaches:• Multi-stakeholder initiatives are important to drive development• Government funding goes farther when leveraged with private funding• Don’t reinvent the wheel!
Business Case:• Account for economic considerations and energy security issues• Find value in by-products• Use enhanced oil recovery & align with oil companies where possible
Reduce Administrative Burden:• Build on existing regulations as much as possible• Create flexible enforcement regulations
Incentives & Financing:• Enable support for first-movers• Create a variety of financial incentives for projects• Drive policy parity with other clean energy technology (ex. subsidies)• Multilateral Development Bank involvement is critical for Asia
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For more information pleasevisit our website at:
Thank You Contact us by email:
Don’t forget to follow us on Twitter
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GLOBAL ENERGY SOLUTIONS SUMMIT
Trivia & Transition
Join Us On
Twitter!
#WeTheStates
Join Us On
Twitter!
#WeTheStates
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GLOBAL ENERGY SOLUTIONS SUMMIT
Training Session: Workforce Development for Emerging Energy Technologies
CCS Bridge to a Cleaner Future
International Brotherhood of Boilermakers
https://vimeo.com/278701159
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GLOBAL ENERGY SOLUTIONS SUMMIT
Opportunities & Next Steps: State & International
Perspectives on CCUS
Jeff Bobeck
Director of Energy
Policy Engagement
Center for Climate and
Energy Solutions
Shannon Angielski
Executive Director
Carbon Utilization
Research Council
Adam Schafer
Policy Director
Office of Montana
Governor Steve
Bullock
Brad Crabtree
Vice President, Carbon
Management
Great Plains Institute
Jason Lanclos
Director, Technology
Assessment Division
Louisiana State Energy
Office
Chris Romans
Executive Director
Energy Advance
Center
MODERATOR
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• Co-convened by former Governor Matt Mead (R-WY) and Governor Steve Bullock (D-MT). Staffed by Great Plains Institute.
• Launched in 2015:• Officials from 15 states*
• Leading industry and NGO stakeholders and experts
• Objectives: • Help policymakers better understand
states’ potential for carbon capture,
CO2-EOR and other storage and utilization;
• Recommend state and federal strategies and policies;
• Support implementation of policy recommendations and project deployment.
*State participation varies and includes governors’ staff, cabinet secretaries, utility commissioners and agency and commission staff.
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Growing State Support for Carbon Capture
Year Organization Resolution Highlights
2015 Western Governor’s Association Recognizes economic and environmental benefits of carbon capture and CO2-EOR; called on Congress to extend and strengthen the federal Sec. 45Q tax credit.
2015 Southern States Energy Board Emphasizes need for federal incentives and state policymeasures.
2016 National Association of Regulatory Utility Commissioners
Highlights economic, energy production and carbon mitigation benefits, and the importance of state and federal action.
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Four Major Work Group Deliverables To Date
• Putting the Puzzle Together: State and Federal Policy Drivers for Growing America’s Carbon Capture and CO2-EOR Industry
• 21st Century Energy Infrastructure: Policy Recommendations for Development of American CO2 Pipeline Networks
• Electricity Market Design and Carbon Capture Technology: The Opportunities and the Challenges
• Capturing and Utilizing CO2 from Ethanol: Adding Economic Value and Jobs to Rural Economies and Communities While Reducing Emissions
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Regional Cooperation to Support Carbon Capture & CO2 Pipeline Infrastructure Deployment
• Development of two cooperative regional efforts to harness the federal 45Q tax credit for deployment:
oWestern and Midwestern regions.
oFormer Governor Mead invited 17 governors to have their states participate.
oGovernors Mead and Bullock announced Regional Deployment Initiative in Jackson Hole, WY in June 2018, together with officials from other states.
oState Carbon Capture Work Group coordinating effort.
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Three-Phased Approach to Fostering Project Deployment
• Baseline mapping of sources and sinks;
• Preliminary cost analysis; and
• Pipeline modeling.
Phase I (complete)
• Convened state officials and stakeholders to launch Initiative in Midwestern and Western regions.
Phase II (complete)
• Modeling and planning to support project deployment.
• Identification of additional state and federal policies to close remaining cost gaps for projects.
Phase III (underway)
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Objectives in 2019
• Prioritize key carbon capture and CO2 pipeline project opportunities revealed in the modeling.
• Determine cost gaps, where applicable, for priority projects after accounting for federal 45Q tax credit.
• Identify state policies to help close cost gaps.
• Engage stakeholders, policymakers and media to marshal support for projects to meet 45Q timeline of beginning construction by end of 2023.
• Prepare for 2020 state legislative sessions.
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2016
Regional Deployment Corridors
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October
2018
Texas Interconnection
Petro-chem/NG Refining
Electricity
Ethanol
Cement
EOR Sink
Modeling Regional CO2 Pipeline
Infrastructure Networks
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NATCARB Saline Formations
EOR vs Storage
Decent
Good
Great
Storage Capacity
Source: NATCARB 2016
Figure authored by GPI
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GLOBAL ENERGY SOLUTIONS SUMMIT
Opportunities & Next Steps: State & International
Perspectives on CCUS
Jeff Bobeck
Director of Energy
Policy Engagement
Center for Climate and
Energy Solutions
Shannon Angielski
Executive Director
Carbon Utilization
Research Council
Adam Schafer
Policy Director
Office of Montana
Governor Steve
Bullock
Brad Crabtree
Vice President, Carbon
Management
Great Plains Institute
Jason Lanclos
Director, Technology
Assessment Division
Louisiana State Energy
Office
Chris Romans
Executive Director
Energy Advance
Center
MODERATOR
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GLOBAL ENERGY SOLUTIONS SUMMIT
Lunch and Keynote on the Future of CCUS
Julio Friedmann
Senior Research Scholar at the Center for Global Energy Policy
Columbia University
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The essential nature of CCS and CO2 removal:
convergence of policy, technology & commerce
Dr. S. Julio Friedmann
Senior Research Scholar, Center for Global Energy Policy
March 529, 2019
@CarbonWrangler
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A few key points
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CCS and CO2 removal are required to hit key targets• Mitigation: CCS is required to achieve 2°C (IPCC, IEA, UNEP)• Additional mitigation: CO2 removal (CDR) is required to achieve 1.5°C• Critically important for heavy industry & “hard to mitigate” sections
Tech gets better• Like solar, wind, LEDs, batteries – we know the recipe• Dramatic cost reductions within 5-7 years
Policy is needed• Should focus on creating markets for carbon products and services• Lots of policy options: C Tax not required
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Already at 95% lock-in. All IPCC pathways 2ºC or less require CCS
IEA: World Energy Outlook 2018
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Operating
Under construction
Advanced planning
Industrial project
Power project
Estimated storage worldwide: ~10 trillion tons
18 operating plants, storing ~30 Mtons CO2 each year
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The world, especially North America, has plenty of storage
2.5-21.8 trillion tons (median ~8.5 trillion tons) North America
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The market today (Unsubsidized LCOE – Lazard 2018)
Copyright 2018 Lazard
This study has been prepared by Lazard for general informational purposes only, and it is not intended to be, and should not be construed as, financial or
other advice. No part of this material may be copied, photocopied or duplicated in any form by any means or redistributed without the prior consent of Lazard.
x
Alternative Energy
Conventional
x
$160
$81
$73
$40
$36
$98
$103
$71
$29
$152
$112
$60
$41
$267
$170
$145
$46
$44
$181
$152
$111
$56
$206
$189
$143
$74
$0 $50 $100 $150 $200 $250 $300 $350
Solar PV—Rooftop Residential
Solar PV—Rooftop C&I
Solar PV—Community
Solar PV—Crystalline Utility Scale
Solar PV—Thin Film Utility Scale
Solar Thermal Tower with Storage
Fuel Cell
Geothermal
Wind
Gas Peaking
Nuclear
Coal
Gas Combined Cycle
Levelized Cost ($/MWh)
(2)
(2)
(6)
$92(3)
(4)
L A Z A R D ’ S L E V E L I Z E D C O S T O F E N E R G Y A N A L Y S I S — V E R S I O N 1 2 . 0
Source: Lazard estimates.
Note: Here and throughout this presentation, unless otherwise indicated, the analysis assumes 60% debt at 8% interest rate and 40% equity at 12% cost. Please see page titled “Levelized Cost of Energy Comparison—Sensitivity to
Cost of Capital” for cost of capital sensitivities.
(1) Such observation does not take into account other factors that would also have a potentially significant effect on the results contained herein, but have not been examined in the scope of this analysis. These additional factors,
among others, could include: import tariffs; capacity value vs. energy value; stranded costs related to distributed generation or otherwise; network upgrade, transmission, congestion or other integration-related costs; significant
permitting or other development costs, unless otherwise noted; and costs of complying with various environmental regulations (e.g., carbon emissions offsets or emissions control systems). This analysis also does not address
potential social and environmental externalities, including, for example, the social costs and rate consequences for those who cannot afford distribution generation solutions, as well as the long-term residual and societal
consequences of various conventional generation technologies that are difficult to measure (e.g., nuclear waste disposal, airborne pollutants, greenhouse gases, etc.).
(2) Unless otherwise indicated herein, the low end represents a single-axis tracking system and the high end represents a fixed-tilt design.
(3) Represents the estimated implied midpoint of the LCOE of offshore wind, assuming a capital cost range of approximately $2.25 – $3.80 per watt.
(4) Unless otherwise indicated, the analysis herein does not reflect decommissioning costs or the potential economic impacts of federal loan guarantees or other subsidies.
(5) Represents the midpoint of the marginal cost of operating fully depreciated coal and nuclear facilities, inclusive of decommissioning costs for nuclear facilities. Analysis assumes that the salvage value for a decommissioned coal
plant is equivalent to the decommissioning and site restoration costs. Inputs are derived from a benchmark of operating, fully depreciated coal and nuclear assets across the U.S. Capacity factors, fuel, variable and fixed operating
expenses are based on upper and lower quartile estimates derived from Lazard’s research. Please see page titled “Levelized Cost of Energy Comparison—Alternative Energy versus Marginal Cost of Selected Existing
Conventional Generation” for additional details.
(6) Unless otherwise indicated, the analysis herein reflects average of Northern Appalachian Upper Ohio River Barge and Pittsburgh Seam Rail coal. High end incorporates 90% carbon capture and compression. Does not include
cost of transportation and storage.
Levelized Cost of Energy Comparison—Unsubsidized Analysis
$28(5)
$36(5)
Certain Alternative Energy generation technologies are cost-competitive with conventional generation technologies under certain circumstances(1)
2
Red bars: Range of 90% CCS for new plants
Red diamond: median retrofit for coal on supercritical coal plant with local storage
Green bar: projected costs for NetPower, unsubsidized
Green star: project costs for NetPower, unsubsized Nth of a kind OR 1st of a kind with 45Q
Green diamonds: PV + battery storage
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• 100% CO2 stream, at pressure• Produces water• Nth plant: ~price parity to NGCC• Can ramp up & down• Addl. potential revenues
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• Solid sorbent + 3D printing• Very low capital costs• Nth plant: ~$30/t CO2
• Modular design• New CEO• Can ramp up and down
• Molten carbonate “afterburner”• Produces extra power• Nth plant: unclear• High efficiency, modular design• Partnership with ExxonMobil & Southern Co.• Can ramp up & down
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Policies options are required for market design and scaling
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Policies to spur investment
• Tax credits (45Q, ITC & PTC, bonus depreciation, economic activity zones)
• Other financial incentives (private activity bonds, MLP)
Policies to spur markets
• Procurements (e.g., low-C building materials)
• Clean Energy Standards & Low-C Fuel Standards
• Critical infrastructure investments
• Carbon tax/cap & trade
Policies to spur innovation
• RD&D investment (Mission Innovation)
• Loan-program office
• Life-cycle assessments & performance standards
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FUTURE Act is now law (45Q tax credit reform)
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CA SB100: 100% Clean Energy Portfolio Standard by 2045EO B-55-18: 100% decarbonized by 2045, net removal after
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Federal R&D Programs: Unprecedented funding
Office of Fossil Energy: $727M totalClean Coal and Carbon Management
Maintains carbon capture and advanced cycle programs
Maintains carbon storage, including CarbonSAFE assessments
Maintains CO2 Utilization, possibly expands
Office of Energy Efficiency and Renewable Energy: $2.3B
Bioenergy Technology Office (BETO)• CO2 to products program (including algae and biochemicals)• Engineered Carbon Reduction Report (Rewiring C Economy)
DOE Loan program Office• Sustained current advanced fossil budget• Added $2B authorities for rural cooperatives
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Carbon dioxide removal (CDR) essential for meeting climate goals
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• CDR is additional and complementary to conventional mitigation
“All pathways that limit global warming to 1.5°C with limited or no overshoot project the use of carbon dioxide removal (CDR) on the order of 100–1000 GtCO2 over the 21st century.“ – IPCC 1.5°C Report (2018)
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National Academies: Natural Solutions + BECCS not enough
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National Academies, 2018
https://nas-sites.org/dels/studies/cdr/
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Generation Engine: turning CO2 to fuel: Carbon Engineering & GreyrockSquamish, British Columbia
This will improve
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Third new species: Air-CO2 for fun and profitGlobal Thermostat, Alabama
This will improve
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GLOBAL ENERGY SOLUTIONS SUMMIT
Closing Remarks & Thank You
Sue Gander
Division Director
Environment, Energy &
Transportation,
National Governors Association
Thank You to the Summit Planning Team
NGA Embassy of Australia
Jessica Rackley Sarah Storey
Abigail Hunter Anthony Orford
Meredith Jones
Embassy of Canada Embassy of Denmark
Aaron Annable Jeppe Mathias Helsted
Dan Abele James Glennie
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GLOBAL ENERGY SOLUTIONS SUMMIT
Closing Remarks
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