1. Jarad Daniels
Office of Clean Coal & Carbon Management
Thursday 19th June 2014
U.S. CCS Policy

2. President’s Climate Action Plan:
Three overarching themes
Mitigation (Emissions Reduction)
• ALL OF THE ABOVE
• Efficiency, Renewables, Nuclear, Gas
• Coal with CCS/CCUS
Adaptation and Resilience
• Smart, reliable grid
• Key infrastructure investments
International Partnerships
• China and Asia
• Coordinated Intl. Efforts
2
Once in a Generation Opportunity to Build

3. 3
Effects of Market Realities
on the “All of Above” Strategy
• Regardless of EPA Greenhouse Gas
regulations, the Energy Information
Administration (EIA) projects that no new
coal-fired generation will be built in the US in
the foreseeable future.
• The expansion of shale gas production in the
U.S. has led to lower natural gas prices,
challenging the cost-competitiveness of coal-
fired power generation.

4. 4
Electric Utility Sector & EPA Regs
Issue Federal Regulation/Compliance
Air SOx & NOx crossing
state lines
Cross-State Air Pollution Rule (CSAPR)
finalized 7.7.2011; 12.30.2011, DC Circuit stay of
CSAPR (CAIR in effect); 8.21.2012, DC Circuit
decision vacating CSAPR; SCOTUS overturned, EPA
Review Pending
Compliance: Unknown
Mercury and
Hazardous Air
Pollutants (HAPs)
Mercury and Air Toxics Standards (MATS) Rule for
Electric Generation Units
finalized 12.16.2011
Compliance: ~2015
GHG emissions GHG New Source Performance Standards (NSPS)
new rule proposed 9.20.2013
Existing GHG Regulation
proposed rule delivered 6.2014; final rule expected
6.2015 (under Presidential Memorandum)
Waste Coal Combustion
Residuals (e.g., coal
ash, boiler slag)
Coal Combustion Residuals (CCR) Rule
proposed rule 6.10.2010; schedule for final rule
expected 1.2014 (court memorandum)
Compliance: Unknown
Water Cooling Water Intake
Structures – impact
on aquatic life
CWA §316(b) Rule
proposed rule 4.20.2011; final rule delivered
5.2014 (settlement agreement)
Compliance: Within 8 Years
Surface water
discharges; Surface
impoundments
Steam Electric Effluent Limitations Guidelines
proposed rule expected 11.2012; final rule
expected 5.22.2014 (settlement agreement)
Compliance: Unknown
 Near-term (through 2015-2016)
Compliance Horizon for EPA
regulations may create potential
localized reliability issues
 Local reliability issues can be
managed with timely notice and
coordination on retirement and
retrofit decisions
 States and regions will play a
valuable role in addressing EPA
regulation impacts
 Non-transmission alternatives can
help alleviate reliability impacts
when/where available
 EPA regulations are only one aspect
impacting the future of our
electricity system

5. 5
2011 2012 2013 2014 2015 2016 20212010
For Reliability
Critical Units
Technically in Effect
(conditional)
316(b)
Final Rule
5.2014
Compliance within 8 years of effective date
Eff Guide
Final Rule
5.22.2014
Eff Guide
Prop Rule
6.7.2013
316(b)
Prop Rule
4.20.2011
MATS
Final Rule
12.16.2011
Compliance within 3 years of effective date +
1 add’l year if granted by permitting authority
MATS
Prop Rule
3.16.2011
CSAPR
Final Rule
7.7.2011
CSAPR
Prop Rule
4.26.2010
EGU GHG
NSPS
Final Rule
2013-2014*
EGU GHG
NSPS
Prop Rule
3.27.2012
CCR
Final Rule
2014??
Compliance Currently Unknown
PROPOSED: Subtitle D – 6 months; Subtitle C – state decision
CCR
Prop Rule
6.21.2010
Compliance Currently Unknown
•CSAPR: 4.29.2014 opinion vacating CSAPR overturned by Supreme Court; EPA is reviewing the opinion
•MATS: EPA Enforcement Policy Memorandum; Presidential Memorandum; FERC Policy Statement
•EPA finalized its reconsideration of MATS for new sources on 3.28.2013; only impacts new sources to be built in the future.
EPA Regs Compliance Horizon
CAIR in effect; CSAPR Compliance Currently Unknown; pending SCOTUS review
* PM directs EPA to issue new proposed EGU GHG NSPS by 9.20.2013 and
a final rule “in a timely fashion after considering all public comments,
as appropriate”
EGU GHG
NSPS
Prop Rule #2
9.20.2013
Complaince, 2018- 2030+
Existing
EGU GHG
Final Rule
6.2015*
Existing
EGU GHG
Prop Rule
6.2014*
* PM directs EPA to issue proposed existing source
EGU GHG rule by 6.2014 and a final rule by 6.2015.

6. 6
Clean Air Act - 111(b)
New Source Performance Standards (NSPS) for Greenhouse Gases (GHGs) from new fossil
sources, burning at least 50% coal or 50% natural gas
Coal-Fired Units: less than 1,100 lbs CO2/MWh
Reference: New Super Critical: 1,800-2,000 lbs CO2/MWh
Coal may comply with ~ 40% capture
Gas NGCC:1,000 lbs CO2/MWh
Gas simple cycle 1,100 CO2/MWh
- Compliance is on a 12 month rolling basis
- Captured CO2 may be sent for geologic storage
- EOR may be used with appropriate reporting
Timeline:
Proposed Regulation: November, 2013
Final Regulation expected November 2014 – January 2015 (1 year after proposal)
Note: 111(b) must be final before 111(d) is final!

7. 7
Clean Air Act - 111(d): Summary
Approach:
1.) Develop Building Blocks to guide emission reductions
2.) Set state targets for 2030
3.) Request State implementation plans by 2016-2017
4.) Gradual reduction over 12 years, with binding cap in 2030
EPA defines the “best system” as the Electricity system as a whole. Therefore,
new non-emitting sources can be used
EPA is seeking to provide as much flexibility to states as possible to develop
individual plans
Published concurrently with Modified source rule (Modified sources under
111(b). Note that this counts as a precursor to 111(d) regulations, as does the
New Source Performance Standards, also under 111(b)
111(d) has only been used 5 times before for smaller rules. This is new legal
territory for EPA.

8. 8
111(d): Building Blocks
Approach: EPA Developed 4 “Building blocks”
1.) 6% Improvement in Coal Plant Heat Rate (4% from “Best
practices”, 2% from Equipment Improvements
2.) Increase existing NGCC capacity factors to 70%
3.) Expanding new, less carbon – intensive generating capacity
(Renewables, New Nuclear, and credit for retaining existing
nuclear)
4.) Demand Side Energy Efficiency
- Building blocks are calculated on a per-state basis.
- States DO NOT have to use the 4 building blocks above.
- Building blocks set the state emission rate; State Implementation Plan can
determine how best to meet the emission rate.
- 2012 Baseline Year

9. 9
CO2 emission rate =
CO2 emissions from all affected fossil fuel EGUs
Generation from affected fossil fuel EGUs +
New RE Generation +
Generation from new and “preserved” NE +
Cumulative MWh saved from demand side EE
State Implementation Plans:
- SIPs due in June, 2016, unless states opt in to a multi-state approach
- Multi-State Plans due in June, 2017.
- Plans will be evaluated based on 4 criteria:
- Enforceable Measures
- Emission Performance
- Quantifiable and Verifiable Emission Performance
- Reporting and Corrective Action
EPA will be publishing guidelines to aid states in developing SIPs
111(d): Emission Rates and SIPs

10. 10
Draft Rule: 2 June 2014
Final NSPS: November 2014 – January 2015
Final Rule: June, 2015 (Per President’s Directive)
State Plans: June, 2016
Multi State Plans: June, 2017
Initial Reductions: 2018
SIPs shall set interim goals to assess performance over the time period from
2018-2030.
Binding State Goals: 2030; 3-year rolling average thereafter.
111(d): Timeframes:

11. 11
Cross-Cutting Research
Crosscutting technology development program
Major Goals: 2016: advance 2nd gen materials, sensors, modeling technologies to
applied programs
2020: develop distributed communication sensor networks
(transformational tech.)
CO2 Storage
Safe, permanent storage of CO2 from power and industry
Major Goals: 2020: technologies and tools available to measure and account for 99%
of injected CO2
2020: CCS best practices and protocols completed based upon RCSP
Phase III activities
CO2 Capture and Compression
Cost effective capture for new and existing plants
Major Goals: 2016: complete 2nd gen field tests (~1.0 MW scale)
2020: complete 2nd gen pilot tests (10 to 25 MW)
2025: complete transformational tech. field tests (~ 1.0 MW)
Office of Clean Coal: Program Summary
Advanced Energy Systems
Gasification, Adv Turbines, Adv Combustion, CBTL, and fuel cells
Major Goals: 2016: Complete Warm Gas Cleanup demo.
2025: 20-30% Reduction in Combined Cycle Capital Cost (2nd gen)
2025: Advanced combustion ready for pilot scale operation

12. 12
Carbon Capture
Sub-program is focused on the development of post-combustion and pre-
combustion CO2 capture technology for new and existing industrial and power-
producing plants
The National Carbon Capture Center
in Wilsonville, Alabama
FY 2015 Request: $77.0 Million
• Post-Combustion Capture Systems
(65.0 Million)
• Pre-Combustion Capture Systems
(12.0 Million)

13. 13
Carbon Storage
Sub-program advances safe, cost-effective and
permanent geologic storage of CO2
FY 2015 Request: $80.1 Million
• Storage Infrastructure (Regional Carbon Sequestration Partnerships)
(60.1 Million)
• Geologic Storage Technologies
(8.5 Million)
• Monitoring, Verification, Accounting and Assessment
(4.5 Million)
• Focus Area for Carbon Sequestration Science
(7.0 Million)
Regional Carbon Sequestration Partnerships

14. 14
Advanced Energy Systems
Sub-program focuses on improving the efficiency of coal-based power systems,
enabling affordable CO2 capture, increasing plant availability, and maintaining the
highest environmental standards
FY 2015 Request: $51.0 Million
• Advanced Combustion Systems
(15.0 Million)
• Gasification Systems
(22.0 Million)
• Hydrogen Turbines
(11.0 Million)
• Solid Oxide Fuel Cells
(3.0 Million)

15. 15
Cross-Cutting Research
Development of new materials, catalysts, instrumentation and sensors,
and advanced computer systems that will be used in future power plants
and energy systems
FY 2015 Request: $35.3 Million
• Plant Optimization Technologies
(7.0 Million)
• Coal Utilization Science
(23.5 Million)
• University Training and Research
(2.75 Million)
• Energy Analyses
(0.85 Million)
• International Activities
(1.1 Million)

16. 16
CCS & Power Systems Funding
FY 2013 - 2015
($ in thousands)
FY 2013
FY 2014
Enacted
FY 2015
Request
Carbon Capture
Post-Combustion
Natural Gas CCS Prize
Pre-Combustion
Total, Carbon Capture
51,336
0
12,389
63,725
80,000
0
12,000
92,000
65,000
0
12,000
77,000
Carbon Storage
Storage Infrastructure (Regional Carbon Sequestration Partnerships)
Geological Storage
Monitoring, Verification, Accounting and Assessment
Carbon Use and Reuse
Focus Area for Carbon Sequestration Science
Total, Carbon Storage
76,961
13,845
6,229
719
8,991
106,745
71,866
16,300
10,000
800
9,800
108,766
60,084
8,500
4,500
0
7,000
80,084
Advanced Energy Systems
Advanced Combustion Systems
Gasification Systems
Hydrogen Turbines
Coal and Coal Biomass to Liquids
Solid Oxide Fuel Cells
Total, Advanced Energy Systems
14,790
36,051
13,866
4,621
23,110
92,438
18,500
36,000
15,000
5,000
25,000
99,500
15,000
22,000
11,000
0
3,000
51,000
Cross-cutting Research
Plant Optimization Technologies
Coal Utilization Science
Energy Analyses
University Training and Research
International Activities
Total, Cross-cutting Research
12,629
23,293
4,711
3,699
1,286
45,618
17,025
19,000
950
3,600
1,350
41,925
7,042
23,550
850
2,750
1,100
35,292
NETL Coal Research and
Development
NETL Coal Research and Development
Total, NETL Coal Research and Development
33,338
33,338
50,011
50,011 34,031
Total, CCS & Power Systems 341,864 392,202 277,407
16

17. 17
Fossil Energy Budget: 2015:
$205,000
1,600
19,950
15,580
Research
and
Development
CCS Demonstrations
Natural Gas Carbon Capture & Storage
CCS & Power Systems
Carbon Capture
Carbon Storage
Advanced Energy Systems
Cross-cutting Research
NETL Coal R&D
Total CCS & Power Systems
Oil & Natural Gas Technologies
Petroleum
Reserves
Other R&D/Prog. Direction/Mgmt.Support
Total, Research and Development
(Dollars in Thousands)
FY2015
25,000
77,000
80,084
51,000
35,292
34,031
$302,407
$35,000
$138,093
$475,500
Request
Total Fossil Energy Budget $711,030
Strategic Petroleum Reserve
Northeast Home Heating Oil Reserve*
Naval Petroleum Reserves/RMOTC
Elk Hills School Land Fund
Rescission of CCT Prior Year Funds ($6,600)

18. 18
DOE CCUS Demonstration Projects
CCPI
FutureGen
ICCS (Area I)
Hydrogen Energy California
IGCC with EOR
$408 Million - DOE
$4.0 Billion - Total
Summit Texas Clean Energy
IGCC with EOR
$450 Million - DOE
$1.7 Billion - Total
NRG Energy
Post Combustion with CO2
Capture with EOR
$167 Million – DOE
$339 Million - Total
Air Products
CO2 Capture from Steam
Methane Reformers with EOR
$284 Million - DOE
$431 Million - Total
Leucadia
CO2 Capture from Methanol
with EOR
$261 Million - DOE
$436 Million - Total
Archer Daniels Midland
CO2 Capture from Ethanol w/ saline storage
$141 Million - DOE
$208 Million - Total
FutureGen 2.0
Oxy-combustion with CO2 capture
and saline storage
$1.0 Billion - DOE
$1.3 Billion - Total
Southern Company Services
IGCC-Transport Gasifier w/CO2 pipeline
$270 Million - DOE
$2.67 Billion - Total
Focus – Large-scale commercial demonstration of CCUS integrated with
coal power generation and industrial sources.

19. 19
Southern Company Services
Advanced IGCC with CO2 Capture
Plant SitePlant Site
Status
 Plant construction >85% complete;>5,100
construction workers on site
 CO2 off-take agreements signed
 Lignite mine under development
 Combustion turbine startup: Aug 2013
 Roll Steam Turbine: Oct 2013
 Gasifier heat-up: June 2014
Key Dates
 Project Awarded: January 2006
 Project moved to MS: December 2008
 Construction: July 2010
 NEPA ROD: August 2010
 Operations: Nov/Dec 2014
• Kemper County, MS
• 582 MWe (net) IGCC: 2 Gasifiers, 2 Siemens
Combustion Turbines, 1 Toshiba Steam Turbine
• Mississippi Lignite Fuel
• ~67% CO2 capture (Selexol® process)
3,000,000 tons CO2/year
• EOR Denbury Onshore LLC, Treetop Midstream
Services LLC
• Total Project: $4.3 Billion
DOE Share: $270 Million (7%)
DOE Reimbursement to date: $248 Million

20. 20
Southern Company Services
Advanced IGCC with CO2 Capture
Remaining Issues/Concerns:
 There are few remaining challenges for the Kemper project to overcome, but none of them are
anticipated to preclude the plant from operating as planned.
 Portions of the plant are presently being tested and full operations is expected to start in early 2015.
 Litigation was filed by the Sierra Club on the Certificate of Public Convenience and Necessity. The
issue is before the Mississippi State Supreme Court.
 Mississippi Power Company (MPC) has increased estimated plant costs several times over the past
year. MPC will not seek to recover these increases from customers.

21. 21
21
Kemper County, MS
Southern Co., 2010

22. 22
22

23. 23
Archer Daniels Midland
CO2 Capture from Biofuel Plant
• Decatur, IL
• CO2 is a by-product (>99% purity) from production of
fuel grade ethanol via anaerobic fermentation
• Up to 90% CO2 capture; dehydration (via tri-ethylene
glycol) and compression – ~900,000 tonnes CO2 /year
• Sequestration in Mt. Simon Sandstone saline reservoir
• Total Project: $208 Million
DOE Share: $141 Million (68%)
DOE Reimbursement to date: $75 Million
Key Dates
 Phase 2 selection: Jun 15, 2010
 FEED Complete: Apr 2011
 NEPA FONSI: Apr 2011
 Construction start: May 2011
 UIC Class VI Injection Well Permit: Aug 2014
 Sequestration start: Feb 2015
Status
 Construction ~55% complete
 UIC Class VI permit submitted: Jul 2011
 Two monitoring wells drilled: Nov 2012
 Commissioning compression and dehydration:
began in July 2013

24. 24
Archer Daniels Midland
CO2 Capture from Biofuel Plant
Remaining Issues/Concerns:
 The ADM draft permitting process for the first UIC Class VI CO2 injection well permit is on track.
 The permitting process may continue through August 2014 to get the final permit. Any delay would
impact the injection well drilling schedule.

25. 25
Decatur, IL
ADM 2013
Compression FacilityCO2 Pipe to Injection Well

26. 26
ADM - Project Monitoring Photos (June 2013)
Soil Gas and CO2 Flux
Networks
Shallow Groundwater
Sampling

27. 27
ADM - Project Photos (June 2013)
Four Compressor Train Compressor & Auxiliaries
Dehydration System 8” High Pressure transmission Line

28. 28
Air Products & Chemicals
Steam Methane Reforming with CO2 Capture
• Port Arthur, TX (Hydrogen plant at Valero Refinery)
• 90%+ CO2 capture (Vacuum Swing Adsorption) from 2
steam-methane reformers (SMRs) yielding ~925,000
tonnes CO2/year
• ~30 MWe cogeneration unit to supply makeup steam
to SMRs and operate VSA and compression equipment
• CO2 to Denbury for EOR - West Hastings oilfield
• Total Project: $431 Million
DOE Share: $284 Million (66%)
DOE Reimbursement to date: $266 Million
Key Dates
 Phase 2 selection: Jun 15, 2010
 FEED complete: Nov 2010
 Permit By Rule (PBR) and Standard Air
Permits issued: May 2011
 NEPA FONSI: Jul 2011
 Construction start: Aug 2011
 Operation start: Dec 2012
Status
 PA-1 initiated operation: Mar 3, 2013
 PA-2 initiated operation: Dec 16, 2012
– Operating continuously since Dec 31, 2012
– Full capacity achieved: April 2013
– Total CO2 delivered: 922K tons (Mar 2014)
 Final MVA report submitted: Feb 2013

29. Air Products & Chemicals
Steam Methane Reforming with CO2 Capture
Remaining Issues/Concerns:
 APCI is currently operating and there are no present issues of concern with this project.
 The project reached 1,000,000 metric tons of contained CO2 in the mid-April 2014 timeframe.
 APCI has requested a 2-year no-cost time extension beyond September 30, 2015 to provide
additional operational data.

30. VSA VesselsVSA Vessels
Co-Gen Unit
Blowers
CO2 Compressor &
TEG Unit CO2 Surge
Tanks
Existing SMR
Air Products and Chemicals, Inc. - Port Arthur 2

31. 31
0
500
1000
1500
2000
2500
3000
3500
4000
HECA FutureGen 2.0 Archer Daniels
Midland
Summit TX
Clean Energy
NRG Energy Air Products Leucadia Southern
Company
TotalProjectCost(MillionsofDollars($))
DOE CCUS Demonstration Projects
Funding Sources
DOE Funding Industry Funding

32. 32
Texas Clean Energy Project
A breakdown of the financing
Project Details
• Advanced Integrated Gasification Combined Cycle
• Poly-generation with Enhanced Oil Recovery
• 90% CO2 capture ~ 2.7 million tons of CO2 per year
• CO2 used for EOR in the Permian Basin oilfields
Project Funding
• Foreign Investment
• MOU signed by representatives of Summit, Sinopec Engineering Group, and The Export-Import Band of
China
• Pending a possible $ 1 billion foreign investment Sinopec Engineering Group and China’s state-
owned Export-Import Bank (Chexim)
• Total Funding Breakdown
• $ 1.3 billion in debt financing in the form of bonds and bank loans
• $ 845 million from equity and tax equity
• $ 450 million in DOE Clean Coal Power Initiative funding
• Federal Tax Incentives – Long-term benefits totaling $1.49 billion
• $ 313 million – Advanced Coal Program Investment Tax Credit
• $ 253 million – Total available Carbon Sequestration Tax Credits over the first 10 years
• $ 925 million – estimated MACRS accelerated depreciation tax benefits over the first 5 years
Plant Production Details
• 400 MW of gross power
• 160 MW net available for sale to the power grid.
• 2.2 million tons of CO2 per year for EOR
• 720 thousand tons of Urea per year

33. 33
Loan Program Office Project Development Financing
LPO Advanced Fossil Energy Solicitation
$8 billion in loan guarantees
CARBON CAPTURE
• From traditional coal or NG generation
• Saline formations or EOR
ADVANCED RESOURCE DEVELOPMENT
• ECBM, UCG, novel oil and gas drilling
• Use of co-produced waste gases vs. flaring
LOW CARBON POWER SYSTEMS
• Oxycombustion, chemical looping
• Syngas-, H2, or NG-based fuel cells
EFFICIENCY IMPROVEMENTS
• CHP and waste-heat recovery
• High-T or high-efficiency cycles

34. 34
Funding CCS Projects in the United States…
American Reinvestment and Recovery Act (ARRA):
- $ 1 Billion, FutureGen 2.0
- $ 1.52 Billion, Industrial CCS Applications
- $ 800 Million, CCPI Round 3 Expansion
- $ 100 Million, Training, Research, and Program Direction
U.S. DOE Office of Fossil Energy
- $ 25 Million, requested for Natural Gas CCS demonstration in FY 2015
Loan Guarantees
$8 Billion available for Advanced Fossil Projects
- Will guarantee up to 80% of the project cost
- First round of applications submitted April, 2014
Tax Credits:
At least 500,000 metric tons per tax year captured and used for:
(1) $20 per metric ton of carbon dioxide which is - (A) captured by the taxpayer at a qualified
facility, and (B) disposed of in secure geological storage (Saline Formations)
(2) $10 per metric ton of qualified carbon dioxide which is—(A) captured by the taxpayer at a
qualified facility, (B) used by the taxpayer as a tertiary injectant in a qualified enhanced oil or
natural gas recovery project, and (C) disposed of by the taxpayer in a secure geological
storage.

35. 35
Carbon Sequestration
Leadership Forum (CSLF)
• A ministerial-level international climate change
initiative focused on the development of improved,
cost effective CCS.
• Comprised of 23 members representing 22 countries
and the European Commission.
• CSLF member countries represent over 60% of the
world’s population and over 70% of man-made CO2
emissions, world energy production and consumption,
and world GDP.

36. 36
Carbon Sequestration Leadership Forum
The CSLF aims to:
– Share information on CCS
Projects, policy initiatives and
legal and regulatory
developments in member
countries;
– Build the capacity for CCS in
the developing country CSLF
Members;
– Explore methods for financing
CCS projects, including in
developing countries, and;
– Develop global roadmaps for
research, development and
demonstration of CCS
technologies.

37. 37
Global challenge global progress:
new global solutions still required
Key unit of innovation – global engines of discovery
Uthmaniyah (KSA)
Lula (BRA)
Quest (CAN) Mongstad (NOR)
ESI (UAE)
Gorgon (AUS)
GreenGen (PRC)
We just need more projects and more information

38. China: necessary and equal partner
• Global leader and driver
– In coal use, production, &
imports
– In CO2 emissions
– In boiler and gasifier
construction
– In renewable loading and
production
• Technically advanced
– Gasification technology and use
– USC-PC; developing A-USC cycles
– Advanced modeling &
simulation
• Global economic powerhouse
38

39. 39
US-China CERC: Premier bi-lateral R&D platform
This work performed under the auspices of the U.S. Department of Energy by Lawrence
Livermore National Laboratory under Contract DE-AC52-07NA27344
Active as of Oct. 2010
Joint R&D platform for efficient
buildings, efficient vehicles, and
clean coal plus CCUS
•Carbon sequestration tech. &
practice
• Capture technology and
engineering
• Coal Conversion and CO2
utilization
Large industrial projects as part
of R&D platform
Technical management plan
(with IP protections) signed
Sept. 2011

40. 40
U.S.-China Climate Change Working Group
• Five cooperative initiative were launched after
the April 2013 visit to China by Secretary Kerry:
1. Carbon Capture Utilization and Storage
2. Smart Grid
3. Emission reduction from heavy-duty & other vehicles
4. Collecting and managing GHG emission data
5. Energy efficiency in building & industry
• CCUS initiative focus on partnering new China
CCUS demonstration projects in EOR and water
production with their U.S. counterparts.