Transport Infrastructure for Carbon Capture and Storage
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Transport Infrastructure for
Carbon Capture and Storage
WHITEPAPER ON REGIONAL INFRASTRUCTURE FOR MIDCENTURY DECARBONIZATION
Authored by
Elizabeth Abramson and Dane McFarlane
Great Plains Institute
Jeff Brown
University of Wyoming
REGIONAL
CARBON
CAPTURE
DEPLOYMENT
JUNE 2020 INITIATIVE
Table of Contents
Executive Summary ............................................................... i
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
Analytical Overview ................................................................ 1
Goals and Rationale
Study Approach
Summary of Findings
Full Discussion of Findings & Results
Approach, Data, and Tools ................................................. 15
Results ................................................................................. 22
Near- and Medium-Term Opportunities Scenario
High-Cost Sensitivity Scenario
Midcentury Decarbonization Scenario
Discussion of Findings ....................................................... 28
Conclusion ........................................................................... 37
Methodological Appendix....................................................... A1
Executive Summary
Analysis by the International Energy Agency in the future.4 Thus, this analysis sought to
(IEA) has determined that deployment of answer the question:
carbon capture technology is critical to
achieve midcentury US and global carbon What is the scale and design
reduction goals and temperature targets.1
necessary for regional CO2
Carbon capture enables power and industrial
transport infrastructure
sectors to reduce or eliminate carbon
emissions while protecting and creating high-
to meet US midcentury
wage employment. For key carbon-intensive decarbonization goals in the
industries such as steel and cement, significant industrial and power sectors?
CO2 emissions result from the mechanical or
chemical nature of the production process As seen in the maps included in this white
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
itself, regardless of the source of process paper, many of the industrial and power
energy. Industrial CO2 emissions account for facilities in the United States are located
33% of US stationary emissions.3 Carbon in regions without significant deep saline
capture is therefore an essential emissions or hydrocarbon geologic formations. Long
reduction tool for industries that are otherwise distance transport infrastructure can unlock
difficult to decarbonize even after switching to the economic potential for these facilities to
low-carbon electricity. IEA modeling estimates sell captured CO2 and earn tax credits for
that more than 28 billion tons of CO2 must be storage under Section 45Q. CO2 transport
captured globally from industrial processes infrastructure achieves beneficial economies
by 2060 in order to meet international of scale with higher volumes of CO2 delivered.
decarbonization goals and temperature Large trunk lines designed to carry CO2 from
targets.2 many facilities toward many storage sites
can achieve a lower transport cost over long
Infrastructure is needed on a significant scale distances than lines with capacity designed
to decarbonize the industrial and power for only one or a handful of capture projects.
sectors, even when accounting for aggressive Long-term, coordinated planning on regional
low-carbon and renewable energy adoption. In CO2 transport corridors will result in optimized,
addition to the economy-wide retrofit of carbon regional scale infrastructure that minimizes
capture equipment at industrial and power costs, land use, and construction requirements
facilities, regional scale transport infrastructure while maximizing decarbonization across
will be required to deliver captured CO2 to industrial and power sectors throughout the
sites of utilization and long-term storage. United States. This whitepaper presents
Previous work by the State Carbon Capture the results of a two-year modeling effort to
Work Group, an initiative facilitated by the identify such regional scale CO2 transport
Great Plains Institute, identified the limitations infrastructure that would serve existing facilities
of building CO2 transport infrastructure on and allow participation by new capture projects
a project-by-project basis and explored and facilities in the future.
the long-term benefit of “super-sizing” CO2
infrastructure to enable expanded capacity This analysis identified the most feasible
i
near- and medium-term opportunities for of anthropogenic CO2 based on near- and
deployment of carbon capture equipment at medium-term economics that include the
individual emitting facilities and focused on the Section 45Q tax credit. Cost estimates indicate
Western, Midwestern, Plains, and Gulf regions that beneficial economies of scale are achieved
of the US. The technological and economic via large shared trunk lines that reduce the per-
limitations of deploying carbon
capture at each emitting facility This whitepaper presents the results of
were considered. Los Alamos a two-year modeling effort to identify
National Laboratory's SimCCS
regional scale CO2 transport infrastructure
model was deployed to create
theoretical CO2 transport
that would serve existing facilities and
networks that minimized costs allow participation by new capture projects
and maximized storage while and facilities in the future.
protecting natural resources,
public lands, population centers, indigenous or ton cost of CO2 transport. Analysis indicated
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
tribal lands, and a variety of other geographic that smaller pipelines built for single projects,
factors. The scenarios presented here are or small feeder lines that connect individual
only for theoretical consideration across broad facilities, result in relatively higher per-ton
geographic areas and are not meant to identify transport costs along those segments. These
or proscribe the specific location of CO2 cost estimates were conducted using average
transport infrastructure. rates of return for capital investments and
show potential to enable capture at facilities
This process identified 1,517 45Q-eligible that have moderate to relatively high capture
facilities across the United States that emit cost through policies that provide low cost
a total of 2,352 million metric tons of CO2 financing or other support.
annually. This accounts for 89% of total US
stationary CO2 emissions.5 A facility-specific Further sensitivity studies revealed two
technical and financial screening then identified findings:
418 facilities as near- and medium-term
candidates for capture retrofit within the study First, that near-term potential currently exists
region. More detail on this facility selection for industrial sectors with relatively low costs of
process is included in the methodological capture (e.g. ethanol) to participate in a shared
appendix. These near- and medium-term transport corridor to sites of storage in Kansas,
facilities emit 797 million metric tons of CO2 per Oklahoma, and Texas.
year, of which 358 million metric tons can be
feasibly captured at relatively low cost under Second, that technical storage potential in
today’s policy context and with conservative deep saline formations nationwide offers a
economic assumptions. low-cost opportunity for local storage, pending
site-specific geological characterization, that
Using the SimCCS model, this analysis will allow full buildout to nearly any facility
identified a regional network of CO2 transport that qualifies for 45Q under currently defined
infrastructure that can achieve the capture, minimum thresholds for CO2 emissions.
delivery, and storage of nearly 300 million tons
iiOPPORTUNITIES FOR CARBON CAPTURE, STORAGE, AND
REGIONAL CO2 TRANSPORT INFRASTRUCTURE
This analysis identified 1,517 industrial and medium-term potential for carbon capture
power facilities throughout the United States retrofit under today’s policy landscape and
where stationary CO2 emissions are sufficient with conservative economic assumptions.
to meet minimum thresholds for the Section The quantity of capturable CO2 at optimized
45Q tax credit (100,000 metric tons per year capture costs from these near- and medium-
and 500,000 metric tons per year for industrial term facilities was estimated at approximately
and power facilities, respectively). These 358 million tons per year. The number of
facilities emit an approximate total of 2.3 billion facilities, quantity of emissions, and estimated
tons of CO2 annually. Of those that would theoretical cost of capture for each industrial
qualify for 45Q, 418 facilities met additional sector are listed in Table ii.
screening criteria to determine near- and
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
Figure i. Emitting facilities: 45Q Eligibility and near-term capture opportunities
NEAR- AND MEDIUM-TERM FACILITIES
REMAINING 45Q-ELIGIBLE FACILITIES
ALL INDUSTRIAL AND POWER FACILITIES
STUDY REGION
Figure authored by GPI based on
data from EPA FLIGHT 2018.
iiiTable i. 45Q-Qualifying facilities and emissions by industry
Share of
Number of 45Q-Eligible Biogenic Nitrous
Industry CO2 Methane
Facilities Facility CO2 Oxide
Emissions
Coal Power Plant 308 53.8% 1,269.6 0.3 3.0 6.2
Gas Power Plant 571 23.8% 565.4 0.7 0.4 0.4
Refineries 78 6.9% 163.3 - 0.6 0.4
Cement 135 3.7% 88.8 0.9 0.1 0.2
Hydrogen 57 2.7% 64.3 - 0.1 0.1
Steel 31 2.3% 54.0 - 0.2 -
Ethanol 173 1.3% 31.0 8.97 0.1 0.1
Ammonia 21 1.2% 25.1 0.0 0.0 4.1
Petrochemicals 30 1.1% 26.0 0.1 0.4 0.1
Metals, Minerals &
37 0.9% 19.5 - 0.4 -
Other
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
Gas Processing 40 0.9% 19.9 - 0.7 -
Chemicals 16 0.8% 8.7 - 0.0 10.4
Pulp & Paper 18 0.4% 7.8 25.5 2.4 0.1
Waste 2 0.1% 0.8 1.2 0.6 -
Grand Total 1,517 100% 2,344.2 29.3 9.1 22.1
All emissions are in million metric tons.
Table ii. Near- and medium-term facilities, capture targets, and cost estimates
Estimated Share of Total Average Range of Cost
Number of
Industry Capturable CO2 Capturable Estimated Cost Estimates
Facilities
mmt/year Estimate $/ton $/ton
Coal Power Plant 58 143.4 40.1% $56 $46 - $60
Gas Power Plant 60 67.9 19.0% $57 $53 - $63
Ethanol 150 50.6 14.1% $17 $12 - $30
Cement 45 32.7 9.1% $56 $40 - $75
Refineries 38 26.5 7.4% $56 $43 - $68
Steel 6 14.6 4.1% $59 $55 - $64
Hydrogen 34 14.4 4.0% $44 $36 - $57
Gas Processing 20 4.5 1.3% $14 $11 - $16
Petrochemicals 2 1.7 0.5% $59 $57 - $60
Ammonia 3 0.9 0.3% $17 $15 - $21
Chemicals 2 0.7 0.2% $30 $19 - $40
Grand Total 418 357.8 100.0% $39 $11 - 75
All emissions are in million metric tons.
ivFigure ii. Optimized transport network for economy-wide CO2 capture and storage
EOR FIELD WITH POTENTIAL
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
CO2 DEMAND
POTENTIAL SALINE
EMITTING FACILITIES INJECTION AREA
AMMONIA REGIONAL CO2 INFRASTRUCTURE
GAS POWER
(MODELED)
CEMENT PLANT Pipeline capacity (mtpa)
GAS PETROCHEMICALSREGIONAL
CARBON
CAPTURE
DEPLOYMENT
INITIATIVE
ABOUT THE REGIONAL CARBON CAPTURE DEPLOYMENT
INITIATIVE
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
The Regional Carbon Capture Deployment Initiative is a network of 25 states, and growing, that
work together to help ensure near-term deployment of carbon capture projects that will reduce
carbon emissions, benefit domestic energy and industrial production, and protect and create high-
wage jobs. The Initiative provides unique and valuable opportunities for governors, state officials,
legislators, and other stakeholders to engage at the state, regional, and national levels.
The Regional Carbon Capture Deployment Initiative is staffed by the Great Plains Institute (GPI) at
the invitation and direction of the State Carbon Capture Work Group.
CONTRIBUTORS
Many thanks to the following individuals for their significant contributions, input, and feedback in
this effort:
Richard Middleton Los Alamos National Laboratory
Sean Yaw Montana State University
Jeff Brown University of Wyoming
Jessi Wyatt Great Plains Institute
Mike Godec Advanced Resources International
Kevin Ellett Indiana University
Ryan Kammer Indiana University
Steve Carpenter Enhanced Oil Recovery Institute – University of Wyoming
The study authors also acknowledge numerous staff and faculty from the US Department
of Energy, National Energy Technology Laboratory, Los Alamos National Laboratory, Indiana
University, Princeton University, Massachusetts Institute of Technology, and industry and NGO
participants of the Regional Carbon Capture Deployment Initiative.
viACRONYM GUIDE
ARI – Advanced Resources International IPCC – Intergovernmental Panel on
45Q – Section 45Q Tax Credit for Climate Change
Carbon Oxide Sequestration kW – Kilowatt
CCS – Carbon capture & storage MT – Metric ton
CO2 – Carbon dioxide MMT – Million metric tons (also as mmt)
CRF – Capital recovery factor MTPA – Metric tons per annum
DOE – US Department of Energy MW – Megawatt
eGRID – EPA’s Emissions & Generation NATCARB – National Carbon Sequestration
Resource Integrated Database Database and Geographic
EIA – US Energy Information Information System
Administration NETL – National Energy Technology
EOR – Enhanced oil recovery Laboratory
EPA – US Environmental Protection O&M – Operations & maintenance
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
Agency SCO2T – Sequestration of CO2 Tool
FLIGHT – EPA's Facility Level Information on SMR – Steam Methane Reformer
GreenHouse gases Tool Ton – All instances of “ton” in this paper
GHG – Greenhouse gas are considered metric ton
IEA – International Energy Agency USGS – United States Geological Survey
EXECUTIVE SUMMARY
REFERENCES
1 International Energy Agency, 20 Years of Carbon
Capture and Storage: Accelerating Future Deployment
(2016).
2 International Energy Agency, Transforming Industry
through CCUS. May 2019. https://www.iea.org/re-
ports/transforming-industry-through-ccus
3 United States Environmental Protection Agency, Sum-
mary GHG Data 2016 (as of August 19, 2018), August
19, 2018, https://www.epa.gov/sites/production/
files/2018-10/ghgp_data_2016_8_19_2018.xlsx.
4 State CO2-EOR Deployment Work Group, 21st Century
Infrastructure. February 2017. https://www.betteren-
ergy.org/wp-content/uploads/2018/01/White_Pa-
per_21st_Century_Infrastructure_CO2_Pipelines_0.pdf
5 United States Environmental Protection Agency, Sum-
mary GHG Data 2016 (as of August 19, 2018), 2018.
6 National Energy Technology Laboratory. A Re-
view of the CO2 Pipeline Infrastructure in the U.S.
April 21, 2015. https://www.energy.gov/sites/prod/
files/2015/04/f22/QER%20Analysis%20-%20A%20
Review%20of%20the%20CO2%20Pipeline%20Infra-
structure%20in%20the%20U.S_0.pdf
viiAnalytical Overview
GOALS AND RATIONALE
Meeting decarbonization goals in the United Through the identification and assessment
States will require significant investment and of existing CO2 capture opportunities and
effort to retrofit carbon capture equipment on storage potential and location, as well as the
industrial and power operations where simply modeling of regional transport infrastructure,
switching to low-carbon energy sources will this analysis aimed to study the following
not address emissions from the chemical and research questions:
mechanical aspects of industrial production
processes. 1. What is the total potential for CO2 capture at
industrial and power facilities where capture
The United States has a vast abundance of retrofit is technically and economically
CO2 storage potential in geologic formations in feasible?
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
many areas throughout the country, including
in deep saline and petroleum basins. In 2. Where are the existing opportunities for safe,
many cases, it makes economic sense to secure, and long-term geologic CO2 storage
store captured CO2 in deep saline formations in deep saline formations and petroleum
within the vicinity of capture facilities. Where basins? Where are these areas in relation to
emissions occur in regions without significant capture opportunities?
geologic opportunity, however, CO2 transport
infrastructure is required to deliver captured 3. What is the scale and design required
CO2 to markets for utilization and storage. for regional CO2 transport infrastructure
to deliver CO2 from sources identified in
Under today’s policy context, which includes Question 1 to the markets and storage
the Section 45Q tax credit, it is already a locations identified in Question 2?
positive economic proposition in some areas Furthermore, what investment, scale, and
and industry sectors to finance regional CO2 planning are required to build regional CO2
transport infrastructure that will essentially transport infrastructure that enables the
be paid for through sales revenue and tax economy-wide capture of CO2 required by
credits. As nationwide efforts and investment in US midcentury decarbonization goals and
decarbonization continue toward midcentury, global temperature targets?
additional capture facilities will benefit
from regional transport infrastructure and STUDY APPROACH
storage locations for captured CO2. Regional
This analysis was conducted on the behalf
transport infrastructure that is planned and
of the Regional Carbon Capture Deployment
built to allow for additional future capacity will
Initiative through a collaboration of the
contribute to maximizing CO2 storage and
Great Plains Institute, Los Alamos National
minimizing transport costs, capital investment
Laboratory, Montana State University, Stanford
requirements, and land use impact.
University, Indiana University, the University
1of Wyoming Enhanced Oil Recovery Institute, Environmental Protection Agency’s (EPA)
and numerous others. Data, technical Greenhouse Gas Reporting Program were
support, and consultation were provided by collected using the Facility Level Information
Advanced Resourced International, Inc., the on GreenHouse Gases Tool (FLIGHT). FLIGHT
National Energy Technology Laboratory, and publishes emission levels for criteria pollutants
participants from a broad variety of industry specific to each applicable GHG Reporting
and nongovernmental organizations through Subpart activity, such as electricity generation,
the Regional Carbon Capture Deployment ammonia manufacturing, cement production,
Initiative. and iron and steel production, among others.3
Direct CO2 emission levels were used to
Nationwide storage potential in deep saline determine facility eligibility for Section 45Q tax
geologic formations was determined using credits for CO2 capture at minimum thresholds
the Sequestration of CO2 Tool (SCO2T), a of 100,000 tons and 500,000 tons per year for
reduced order model created by Los Alamos industrial and power facilities, respectively.4
National Laboratory and Indiana University
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
that integrates data from the US Department These 45Q-eligible facilities and their
of Energy’s National Carbon Sequestration process-specific emissions were compiled into
Database and Geographic Information System a database, against which a screening process
(NATCARB) Carbon Storage Atlas and United was applied based on facility operation,
States Geological Survey (USGS).1 SCO2T production, energy use, heat rate, and other
provides estimates for technical storage factors. This screening process was intended
potential, porosity, thickness, and theoretical to identify potential near- and medium-term
storage costs for each significant saline facilities that could participate in regional
formation across the US on a geographic grid CO2 transport infrastructure networks for
of 10 km2 cells. capture and delivery of CO2 under today’s
market and policy context. EPA’s Emissions
Potential demand for anthropogenic CO2 & Generation Resource Integrated Database
from existing enhanced oil recovery (EOR) (eGRID)5 provided unit- and generator-specific
operations was calculated by Advanced operational data and was supplemented by
Resources International, Inc. (ARI), according power plant information from the proprietary
to a proprietary model based on petroleum ABB Ability Velocity Suite.6
basin geology and historic operations.2 For
this analysis, average annual rates of purchase A meta-study and literature review of published
for CO2 at $20 per ton were estimated by capture costs, as well as capital, financing,
ARI for existing operations under two oil price and operation and maintenance costs for
scenarios, at $40 per barrel and $60 per capture equipment such as amine solvent units
barrel. For near- and medium-term scenarios, and compressor systems, was conducted to
this study relied on estimates based on the calculate theoretical capture costs based
more conservative $40 per barrel oil price on the emission quantity, operational patterns,
scenario. and energy costs of each facility. A detailed
description of screening process criteria
Stationary emissions from industrial and capture cost estimation can be found in
and power facilities published by the US the methodological appendix of this report.
2Average estimated capture costs for each Through an iterative process, a series of
industrial sector considered by this study are scenarios were constructed to explore the
published in the Summary of Findings section research questions outlined in the previous
on the following pages of this report. section of this report. These research
questions focus on identifying broad
Los Alamos National Laboratory’s SimCCS geographic corridors for regional CO2
model 7 was used to simulate optimized transport; modeling which facilities and
CO2 transport infrastructure to link cost segments of pipeline might break even or
effective sources of CO2 to locations of produce revenue within the existing and
potential economic demand for utilization near-term economic context; determining
and storage. SimCCS minimizes the cost how potential economic demand for CO2 at
of CO2 transport routes over a cost surface existing EOR operations and technical storage
based on numerous layers of geographic potential in nearby deep saline formations can
information and right-of-way concerns such as provide opportunities for CO2 capture retrofit;
urban areas, bodies of water, publicly-owned assessing the overall opportunity for carbon
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
lands and natural resources, indigenous capture and storage under the Section 45Q
or tribal lands, and existing infrastructure. tax credit; and finally, identifying the remaining
The physical and financial requirements of barriers and areas in need of support to fully
transport infrastructure were calculated and realize the potential for economy-wide capture
analyzed using the National Energy Technology and storage of CO2 to meet midcentury
Laboratory (NETL) CO2 Transport Cost Model, decarbonization goals.
which were also integrated into the cost
calculations of SimCCS.8
3SUMMARY OF FINDINGS
Capture Feasibility: Potential Sources of CO2
Each year, stationary power sources in the reported by the US EPA, 1,517 are likely
US emit nearly 2 billion metric tons of GHG eligible for the 45Q tax credit. These
emissions, while US industrial facilities emit 45Q-eligible facilities make up 89% of all
nearly 1 billion metric tons of GHG emissions. CO2 emissions from US power and industrial
Combined emissions from these power and facilities. This analysis identified 418 facilities
industrial facilities comprise roughly half of all as candidates for near- and medium-term
US GHG emissions.9 deployment, with the combined potential
to capture 358 million metric tons of CO2
Of the 6,586 power and industrial facilities emissions annually.
Table 3. Stationary emissions from US industrial and power facilities
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
Share of US
Number of Biogenic Nitrous
Industry Stationary CO2 CO2 Methane
Facilities CO2 Oxide
Emissions
Coal Power Plant 336 45% 1,270.6 0.4 3.0 6.2
Gas Power Plant 963 21% 581.3 0.9 0.5 0.4
Refineries 121 6% 171.3 0.0 0.7 0.4
Metals, Minerals &
1,511 5% 101.1 5.3 42.3 0.4
Other
Gas Processing 1,246 4% 88.9 0.2 9.9 0.1
Waste 1,225 4% 11.1 17.5 86.7 0.4
Cement 149 3% 90.4 0.9 0.1 0.2
Hydrogen 79 2% 66.2 - 0.1 0.1
Steel 82 2% 58.5 - 0.3 0.0
Chemicals 266 2% 30.4 0.7 0.1 13.1
Petrochemicals 61 2% 46.1 0.1 0.5 0.1
Pulp & Paper 225 2% 37.1 112.2 5.2 0.5
Other Power Plant 118 1% 36.4 9.2 0.2 0.2
Ethanol 181 1% 31.2 9.2 0.1 0.1
Ammonia 23 1% 25.21 - - 4.1
Grand Total 6,586 100% 2,645.8 147.9 149.5 26.2
All emissions are in million metric tons.
45Q-eligible facilities make up 89% of all CO2 emissions
from US power and industrial facilities. This analysis
identified 418 facilities as candidates for near- and
medium-term deployment, with the combined potential to
capture 358 million metric tons of CO2 emissions annually.
4Summary of Findings: 45Q Eligibility
Figure 3. 45Q-eligible facilities by industry and emissions
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
Emitting Facilities
METALS, MINERALS
AMMONIA ETHANOL & OTHER
GAS POWER
CEMENT PETROCHEMICALS
PLANT
GAS PULP &
CHEMICALS
PROCESSING PAPER
STEEL Figure authored by GPI based
COAL POWER
on data from EPA FLIGHT 2018.
HYDROGEN REFINERIES WASTE
PLANT
Table 4. 45Q-eligible facilities by industry and emissions
Share of
Number of Biogenic Nitrous
Industry 45Q-Eligible CO2 Methane
Facilities CO2 Oxide
Emissions
Coal Power Plant 308 53.8% 1,269.6 0.3 3.0 6.2
Gas Power Plant 571 23.8% 565.4 0.7 0.4 0.4
Refineries 78 6.9% 163.3 - 0.6 0.4
Cement 135 3.7% 88.8 0.9 0.1 0.2
Hydrogen 57 2.7% 64.3 - 0.1 0.1
Steel 31 2.3% 54.0 - 0.2 -
Ethanol 173 1.3% 31.0 8.97 0.1 0.1
Ammonia 21 1.2% 25.1 0.0 0.0 4.1
Petrochemicals 30 1.1% 26.0 0.1 0.4 0.1
Metals, Minerals &
37 0.9% 19.5 - 0.4 -
Other
Gas Processing 40 0.9% 19.9 - 0.7 -
Chemicals 16 0.8% 8.7 - 0.0 10.4
Pulp & Paper 18 0.4% 7.8 25.5 2.4 0.1
Waste 2 0.1% 0.8 1.2 0.6 -
Grand Total 1,517 100% 2,344.2 29.3 9.1 22.1
All emissions are in million metric tons.
5Summary of Findings: Near- and Medium-Term Potential Capture Retrofit
Figure 4. Identified near- and medium-term capture facilities within study region
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
Emitting Facilities
AMMONIA ETHANOL PETROCHEMICALS
GAS POWER
CEMENT REFINERIES
PLANT
GAS STEEL
CHEMICALS
PROCESSING Figure authored by GPI based
COAL POWER
PLANT HYDROGEN on data from EPA FLIGHT 2018.
Table 5. Identified near- and medium-term capture facilities
Average Share of Total
Number of Estimated
Industry Estimated Cost Capturable
Facilities Capturable CO2
$/ton Estimate
Coal Power Plant 58 $56 143.4 40.1%
Gas Power Plant 60 $57 67.9 19.0%
Ethanol 150 $17 50.6 14.1%
Cement 45 $56 32.7 9.1%
Refineries 38 $56 26.5 7.4%
Steel 6 $59 14.6 4.1%
Hydrogen 34 $44 14.4 4.0%
Gas Processing 20 $14 4.5 1.3%
Petrochemicals 2 $59 1.7 0.5%
Ammonia 3 $17 0.9 0.3%
Chemicals 2 $30 0.7 0.2%
Grand Total 418 $39 357.8 100.0%
All emissions are in million metric tons.
6This analysis included a literature review and optimizing cost of capture on a per ton
meta-study of published costs of capture basis. Table 6 reports the average and range
for a variety of industries and equipment of estimated capture costs calculated for
configurations. Unit- and process-specific this study. A full description of the sources,
emissions were identified to determine optimal equipment, capital financing scenarios,
capture quantities while minimizing overall and cost calculations can be found in the
capital investment requirements, thereby methodological appendix of this report.
Figure 5 & Table 6. Estimated capture cost per industry for near-term facilities in study area
$80
Average Range of Cost
Industry Estimated Cost Estimates
$70 $/ton $/ton
Gas Processing $14 $11 - $16
$60
Ethanol $17 $12 - $30
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
$50 Ammonia $17 $15 - $21
Chemicals $30 $19 - $40
$40 Hydrogen $44 $36 - $57
Refineries $56 $43 - $68
$30
Coal Power Plant $56 $46 - $60
$20 Cement $56 $40 - $75
Gas Power Plant $57 $53 - $63
$10 Steel $59 $55 - $64
Petrochemicals $59 $57 - $60
$0
ing
ol
nia
ls
n
s
nt
el
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Figure authored by GPI based on data from EPA FLIGHT 2018.
rie
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an
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7Figure 6. Estimated capture target and cost of capture per industry for near- and medium-
term capture opportunities in study area
CHEMICALS Figure authored by GPI based on
$19 - $40 data from EPA FLIGHT 2018.
AMMONIA
$15 - $21
PETROCHEMICALS
$57 - $60
1.7
14
MT
.4
14 MT
14
.6 GAS PROCESSING CO
MT
3.4
$11 - $16 AL
MT
HYDROGEN
$4
$36 - $57
6-
26.5 STEEL
$60
MT $55 - $64
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
REFINERIES
$43 - $68
CEMENT
32.7 MT $40 - $75
ET
NO
HA
6
3
L$ -$
50 12 53
- $3 E R$
.6 0 G AS PO W
MT
.9 MT
67
Each piece of the outer ring Potential capture amounts and
proportionally represents an range of estimated capture
individual facility in each sector costs in each sector
MT: Million metric tons CO2
8Summary of Findings: CO2 Storage Opportunities
Figure 7. Geologic deep saline formations and existing oil fields with CO2 storage potential
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
FIELD WITH TECHNICAL
POTENTIAL FOR EOR
SALINE FORMATION
EXISTING CO2
PIPELINE
Figure authored by GPI based on
data from ARI and NATCARB.
A total technical potential for storage in deep report focus on EOR operations and locations
saline formations of over 4.5 trillion metric within deep saline formations that present
tons was identified within the study region. feasible economics under today’s policy and
Meanwhile, existing EOR operations within market context, accounting for estimated
this same region may have the potential to costs of capture, the Section 45Q tax credit,
store over 500 million metric tons of CO2 transportation costs, injection and storage
per year, or over 10 billion metric tons over costs, the delivered price of CO2, and potential
20 years. These estimates refer to technical oil revenue. This study was not intended to
potential without consideration of costs and perform further geologic characterization of
economic feasibility. For modeling, this analysis deep saline formations to identify specific
did consider the likely market price of CO2 for injection sites. Local planning and geologic
utilization and storage by EOR, as well as the characterization must be performed to identify
estimated cost of injection, storage, and long- feasible injection sites within broader geologic
term monitoring in deep saline formations. formations.
The modeling scenarios presented in this
9Summary of Findings:
CO2 Transport Infrastructure for Economy-Wide Deployment
As outlined in the sections above, and detailed and international temperature targets, shared
in the methodological appendix of this paper, regional CO2 transport infrastructure will
this analysis identified near- and medium- minimize investment requirements, transport
term opportunities for capture at industrial costs, and land use. Los Alamos National
and power facilities along with likely geologic Laboratory’s SimCCS model was used to
storage opportunities in deep saline formations identify optimal regional scale transport
and existing EOR operations. To maximize networks that deliver CO2 from capture
CO2 capture and storage and approach the facilities to storage locations identified by this
scale needed for US decarbonization targets analysis, resulting in Figure 8.
Figure 8. Optimized transport network for economy-wide CO2 capture and storage
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
EOR FIELD WITH POTENTIAL
CO2 DEMAND
POTENTIAL SALINE
EMITTING FACILITIES INJECTION AREA
AMMONIA REGIONAL CO2 INFRASTRUCTURE
GAS POWER
(MODELED)
CEMENT PLANT Pipeline capacity (mtpa)
GAS PETROCHEMICALSSummary of Findings: Transport Costs
The NETL CO2 Transport Cost Model facilities had moderately high per-ton transport
was used to estimate capital investment, costs due to relatively lower volume (100,000
operational, and maintenance costs of each to 4 million metric tons per year).
segment of the transport network according to
its capacity and length. Costs were calculated Under current economic conditions, transport
at expected private sector rates of return on costs would ideally fall between $10 and $20
capital investment without additional support per ton in order for capture and storage to
or low-cost financing. economically break-even under Section 45Q.
The higher per-ton delivered cost of individual
As expected, costs on a per-ton basis are facility feeder lines indicates that shared or
much lower for large shared trunk lines that coordinated investment of CO2 transport
transport huge volumes of CO2 (more than infrastructure, and/or supportive policies
12 million metric tons per year), commonly such as low-cost financing, may be needed
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
achieving transport costs well below $10 per to achieve optimal regional scale transport
ton. Segments that transport between 4 and infrastructure that minimizes total system cost
12 million tons per year had estimated costs while maximizing economy-wide CO2 capture
generally between $10 and $20 per ton. Small and storage.
feeder lines that connect to individual capture
Figure 9. Relative transport cost of network segments
REGIONAL CO2 INFRASTRUCTURE (MODELED)
Estimated cost per ton transported
Cost Length
Very low
Low to moderate Range miles
Moderate to high
Pipeline capacity (million tons per year)
Very Low 18,006Summary of Findings: High-Cost Sensitivity Scenario
Achieving US economy-wide decarbonization with economic demand for CO2, or to store in
goals will likely require capital investment nearby saline formations at a cost (for injection,
across numerous sectors and industries. storage, and monitoring).
Analysis from the IPCC found that carbon
mitigation under the 2 degree C scenario The results of this high-cost sensitivity show
would cost 138% more if carbon capture two things: First, that there is immediate
were not included as an emissions reduction economic potential for geographically
strategy.10 As shown above, while CO2 concentrated, low-cost industrial sources
transport infrastructure does represent a in the Midwest (e.g., ethanol facilities) to
significant cost, the buildout of a shared aggregate their CO2 supply and deliver to
regional-scale transport network will minimize storage locations at petroleum basins in
the overall capital investment required. Kansas, Oklahoma, and Texas. Second,
in areas with sufficient storage potential in
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
To identify near-term opportunities for early deep saline formations, a variety of industries
stage buildout of this regional network, this with low and moderate capture costs have
study ran SimCCS in a strict economic pricing economic potential to claim Section 45Q tax
mode in which all infrastructure investment credits for local storage in nearby deep saline
must be paid for by the sale of CO2. Near- formations. This is also true for these same
term candidates for capture retrofit were industries in areas with storage potential
provided the option to invest in transport in petroleum basins, such as Louisiana,
infrastructure to reach distant EOR operations Oklahoma, Texas, and parts of the Rockies.
Figure 10. High-cost sensitivity with economic break-even
EOR FIELD WITH POTENTIAL
CO2 DEMAND
POTENTIAL SALINE
EMITTING FACILITIES INJECTION AREA
AMMONIA REGIONAL CO2 INFRASTRUCTURE
(MODELED)
GAS POWER
CEMENT Pipeline capacity (mtpa)
PLANT
GASSummary of Findings: Expansion of Storage in Deep Saline Formations
Based on the findings of the initial transport states, and various locations throughout the
network optimization modeling and the Rockies. This scenario achieved 669 million
following high-cost sensitivity model run, metric tons of CO2 capture and storage,
which identified additional economic potential enabled by saline storage for an expanded
for CO2 storage in deep saline formations set of 45Q-eligible facilities in addition to
nearby capture facilities, a final regional-scale the near- and medium-term facilities.
network scenario was modeled to optimize
capture and transport infrastructure for storage This study used geologic data for deep saline
at previously identified EOR operations and formations from NATCARB and the SCO2T
additional deep saline formations. saline storage database, as detailed in this
paper’s Study Approach section and the
This aggressive saline scenario, illustrated in Methodological Appendix. Further geologic
Figure 11, resulted in a regional CO2 transport characterization of deep saline formations
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
network similar to the initial scenario but with must be performed in order to identify actual
expanded storage in saline formations in the injection and storage sites within local areas.
eastern parts of the Midwest, Gulf Coast
Figure 11. Expanded storage in deep saline formations and petroleum basins
EOR FIELD WITH POTENTIAL
CO2 DEMAND
EMITTING FACILITIES POTENTIAL SALINE
INJECTION AREA
AMMONIA
REGIONAL CO2 INFRASTRUCTURE
CEMENT (MODELED)
GAS
Pipeline capacity (mtpa)
CHEMICALS
PROCESSINGFull Discussion of Findings and Results
US DECARBONIZATION GOALS AND POLICY CONTEXT
Analysis by the International Energy Agency key carbon-intensive industries such as steel
(IEA) has determined that deployment of and cement, significant CO2 emissions result
carbon capture technology is critical to achieve from the mechanical or chemical nature of the
midcentury US and global carbon reduction production process itself, regardless of the
and temperature targets.11 IEA’s modeling source of process energy. Carbon capture
estimates that more than 28 billion enables industrial sectors, which account for
tons of CO2 must be captured globally 33% of US stationary emissions, to reduce or
from industrial processes by 2060.12 eliminate carbon emissions while protecting
Decarbonizing the US and global economy and creating high-wage employment.14 Carbon
will require significant capital investment. capture is therefore an essential emissions
However, IPCC modeling suggests that reduction tool for industries that are otherwise
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
pursuing decarbonization would cost 138% difficult to decarbonize even after switching to
more without the use of carbon capture.13 For low-carbon electricity.
Figure 12. All major emitter facilities by industry and emissions
Emitting Facilities
GAS POWER PETROCHEMICALS
AMMONIA PLANT
GAS PULP &
CEMENT
PROCESSING PAPER
CHEMICALS HYDROGEN REFINERIES
COAL POWER METALS, MINERALS
PLANT STEEL
& OTHER
OTHER POWER
ETHANOL WASTE
PLANT
Figure authored by GPI based
on data from EPA FLIGHT 2018.
14Section 45Q Tax Credit an eligible project is ultimately used. Projects
Section 45Q of the US tax code provides storing CO2 geologically through EOR, and
a performance-based tax credit for carbon projects using CO2 or CO for other beneficial
capture projects that can be claimed when uses, such as converting carbon emissions
an eligible project has securely stored the into fuels, chemicals, or useful products like
captured carbon dioxide (CO2) in geologic concrete, generate $35 per ton of CO2 stored
formations, such as deep saline formations or utilized. Projects storing CO2 in other
and petroleum basins, or beneficially used geologic formations and not used in EOR
captured CO2 or its precursor carbon generate $50 per ton of CO2 stored.
monoxide (CO) as a feedstock to produce
fuels, chemicals, and products such as This analysis focused on industrial and power
concrete in a way that results in emissions facilities that would meet the minimum capture
reductions as defined by federal requirements. thresholds for eligibility. It is important to note
that eligible projects that begin construction
within six years of the
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
IEA’s modeling estimates that more than FUTURE Act’s enactment (i.e.,
28 billion tons of CO2 must be captured before January 1, 2024) can
globally from industrial processes by 2060. claim the credit for up to 12
years after being placed in
The availability of the newly expanded and service. This timeline underscores the urgency
reformed 45Q tax credit reduces the cost of this analysis, and of action on the part of
and risk to private capital of investing in the commercial entities and other stakeholders.
deployment of carbon capture technology
across a range of industries, including electric APPROACH, DATA, AND TOOLS
power generation, ethanol and fertilizer As summarized previously in this paper, this
production, natural gas processing, refining, analysis relied on data and tools available from
chemicals production, and the manufacture of federal institutions and national laboratories to
steel and cement. study power and industrial facility operations,
geologic storage potential, and CO2 transport
Eligibility is extended to three categories of routing and logistics.
carbon capture project, each with their own
threshold for eligibility: Projects capturing Power and Industrial Facilities:
carbon for a beneficial use other than EOR EPA FLIGHT and eGRID
are eligible if they capture between 25,000 Since 2010, the United States Environmental
500,000 metric tons of CO2/CO per year. All Protection Agency (EPA) Greenhouse Gas
other industrial facilities (other than electric Reporting Program (GHGRP) has collected
generating units), including direct air capture and published greenhouse gas emissions
are eligible if they capture at least 100,000 data from large emitting facilities, suppliers
metric tons of CO2/CO per year. Electric of fossil fuels, and industrial gases that result
generating units are eligible if they capture at in greenhouse gas (GHG) emissions when
least 500,000 metric tons of CO2/CO per year. used, and facilities that inject carbon dioxide
Meanwhile, the amount of credit generated underground. Sources whose emissions
is determined by how the CO2 captured from are equal to or surpass 25,000 metric tons
15of CO2 equivalent are required by law to Opportunities for Long-Term Storage
submit emissions data to the GHGRP. In of CO2: SCO2T Saline Data
total, EPA’s GHGRP gathers GHG data from The Sequestration of CO2 Tool (SCO2T),
over 8,000 facilities.15 This data is published created by Los Alamos National Laboratory
online as a resources called the EPA Facility and Indiana University, provided nation-wide
Level Information on Greenhouse Gases Tool assessment of geologic deep saline formations
(FLIGHT). for CO2 storage potential.19 SCO2T compiles
data from the USGS and the National Carbon
This analysis utilized EPA FLIGHT data Sequestration Database and Geographic
to provide detailed information about the Information System (NATCARB). NATCARB
emissions profile and other characteristics is administered by the US DOE’s National
of emitter facilities in order to assess each Energy Technology Laboratory and contains
emitter for potential carbon capture retrofit data provided by several Regional Carbon
viability. This analysis did not consider smaller Sequestration Partnerships (RCSP).
emitters that would not qualify for the 45Q
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
tax credit, nor facilities that would suffer SCO2T employs reduced-order models
scale diseconomies if application of capture to calculate physical characteristics and
technology were to be retrofitted. Direct CO2 engineering estimates for drilling, injection,
emission levels were used to determine facility and storage, such as well injection rate, CO2
eligibility for Section 45Q tax credits for CO2 plume area, and injection costs. A depiction
capture at minimum thresholds of 100,000 of SCO2T’s current data coverage (at the time
tons and 500,000 tons per year for industrial of writing) for 10 km2 grid-cells is provided
and power facilities, respectively.16 in Figure 13, which reports relative storage
potential for each geologic formation at each
These 45Q-eligible facilities and their process- cell. The location, annual injection potential,
specific emissions were compiled into a and estimated total injection and storage
database, against which a screening process cost from SCO2T were primary inputs into
was applied based on facility operation, the capture, storage, and transport modeling
production, energy use, heat rate, and other conducted for this analysis.
factors. This screening process was intended
to identify potential near- and medium-term
facilities that might feasibly participate in
regional CO2 transport infrastructure networks
for capture and delivery of CO2 under today’s
market and policy context. The full screening
methodology, criteria, and cost components
are provided in the appendix of this document.
EPA’s Emissions & Generation Resource
Integrated Database (eGRID)17 provided unit-
and generator-specific operational data and
was supplemented by power plant information
from the proprietary ABB Ability Velocity
Suite.18
16Figure 13: Relative CO2 storage potential by geologic formation and 10 km2 grid-cell
provided by SCO2T
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
Very Low Storage Cost
Figure authored by GPI
Low Storage Cost
based on data from
Moderate to High Storage Cost SCO2T and NATCARB.
Not yet characterized
Storage potential and economic criteria storage of tremendous amounts of CO2.
for CO2 injection at enhanced oil recovery Figure 13 shows that deep saline formations
operations was provided by the Advanced with CO2 storage potential exist throughout
Resources International, Inc. (ARI) proprietary large areas of the US. Once injected into a
Big Oil Fields Database.20 This
database contains detailed North American CO2 storage potential
information on over 6,000 oil is estimated to be as high as 22 trillion
reservoirs, accounting for over 75% metric tons, enough to store nearly
of all oil expected to be ultimately 3,500 years of US CO2 emissions.
produced in the US through primary
and secondary recovery processes. The saline formation, CO2 is secured by physical
database reports information on reservoir and chemical trapping mechanisms. The
volume, cumulative oil production to-date of IPCC reports that well-selected and managed
each reservoir, and remaining potential for geologic sites are likely to retain over 99% of
injection and storage of CO2. Reservoir-specific injected CO2 over 1,000 years. North American
data also includes key geologic properties and CO2 storage potential alone is estimated to
existing field infrastructure and activities that be as high as 22 trillion metric tons, which
could influence the performance of a CO2-EOR could store nearly 3,500 years of US CO2
project. emissions.21
Injection of CO2 into geologic reservoirs As demonstrated in Figure 14, many potential
provides an opportunity for the permanent candidates for carbon capture are co-located
17in areas of opportunity for geologic storage. scale infrastructure that will later be used by
This allows capture facilities to permanently expanded saline storage activity. While the
store CO2 with minimal transport and may existing Section 45Q tax policy creates the
even allow facilities to inject CO2 on or near opportunity for this, additional support or
their existing property. In contrast, many low cost financing may be required to plan
industrial and power facilities are located “supersized” CO2 transport infrastructure with
in areas without significant deep saline capacity to take on additional volumes in the
formations. Any effort to meet decarbonization future, rather than being fit for only a handful of
goals while maintaining production at these near-term projects.
facilities will likely need regional scale transport
infrastructure to unlock delivery markets and As shown in Figure 14, major US oil fields
economic value for captured CO2. are generally clustered in the Texas Gulf and
Permian Basin of Western Texas and stretch
The current Section 45Q tax policy provides up through the Western Plains and Northern
an incentive for long-term CO2 storage in Rockies. There are also notable clusters in and
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
both deep saline formations and hydrocarbon around Illinois, Ohio, and Michigan. Of these
basins where EOR operations utilize CO2. The oil fields, only some have sufficient demand for
US oil and gas industry has significant current CO2 to create feasible economic conditions to
EOR operations that utilize millions of tons of act as potential sites for CO2 storage through
naturally occurring CO2 per year from geologic, CO2-EOR. Oil fields where CO2 demand would
rather than anthropogenic, sources. With likely enable costs of transport and injection to
respect to EOR, Section 45Q can provide a break even or create a profit were selected as
two-fold benefit. Not only does the tax credit storage locations in our modeling scenarios.
create an incentive for EOR operators to Overall, large-scale storage in oil fields would
switch from geologic CO2 to anthropogenic require the establishment of sizeable trunk
CO2, it creates a market for source facilities corridors, connecting regions with many CO2
to deliver captured CO2. This is especially sources to regions with many oil fields and
helpful for potential source facilities located in other geologic sinks.
areas without nearby deep saline formations.
The combination of existing market demand
and additional supportive tax incentives for
the utilization of anthropogenic CO2 provides Maintaining industrial
near-term economic rationale to build regional production while meeting
infrastructure for the transport of CO2. decarbonization targets
Because CO2 storage in deep saline incurs will require regional scale
a cost for drilling, injection, and monitoring, transport infrastructure
it may be a difficult economic proposition to to unlock delivery markets
build dedicated transport infrastructure without and economic value for
the revenue from sales to EOR operations.
captured CO2.
Thus, the purchase of CO2 for existing EOR
operations can effectively finance regional-
18Figure 14. CO2 sources and oil fields with CO2 injection potential
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POWER
PLANT
EOR FIELD WITH
INDUSTRIAL
CO2 DEMAND > $20/TON
FACILITY
SALINE FORMATION
SIZE OF PLANT
EXISTING CO2
PIPELINE
Figure authored by GPI based
on results from NATCARB, EPA.
Table 7. Storage potential in saline formations and EOR operations in study focus states
State Saline EOR State Saline EOR
Alabama 274,909.7 - North Dakota 132,978.0 148.6
Arkansas 18,111.3 106.4 Nebraska 51,580.9 28.8
Colorado 123,441.8 163.2 New Mexico 122,968.2 515.4
Illinois 74,294.9 130 Ohio 8,801.0 119.4
Indiana 59,738.1 10.2 Oklahoma 73,191.0 1,322.6
Kansas 32,231.3 366.8 South Dakota 5,047.3 2.8
Kentucky 40,460.8 - Tennessee 1,468.3 -
Louisiana 660,992.5 1,096.2 Texas 1,372,789.7 4,875.4
Michigan 41,033.0 57.4 Utah 84,077.4 395.6
Mississippi 414,287.9 98 Wyoming 611,222.2 522.6
Montana 365,441.4 184.2 Table continued from previous
Million metric tons storage potential
19Pipeline Routing, Logistics, and GPI worked with Los Alamos researchers
Scenario Development: SimCCS to accurately incorporate cost components
SimCCS, created by Los Alamos National from NETL’s CO2 Transport Cost Model
Laboratory in collaboration with Indiana into SimCCS, allowing the model to use
University and Montana State University, is an comparative transport network cost estimates
open-source software tool for designing CO2 in real time while determining routes for CO2
capture, transport, and storage infrastructure. transport.
This analysis utilized SimCCS 2.0, which
was released in January 2018, to determine GPI also used the NETL CO2 Transport Cost
which power and industrial facilities would Model to calculate in-depth cost results and
participate in an optimized capture network, determine physical characteristics of CO2
which locations are best positioned for low transport segments generated by SimCCS.
cost injection and storage, and importantly, SimCCS reports the length and CO2 capacity
to find the most efficient network to connect of each pipeline, allowing the NETL model to
generate feasible diameters and a detailed
GREAT PLAINS INSTITUTE TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE
CO2 sources to sinks. SimCCS 2.0 integrates
economic and geospatial considerations and breakdown of investment required for capital
addresses critical parts of the CCS supply construction, materials, labor, operation, and
chain simultaneously, identifying key cost maintenance. The resulting cost per ton of
savings, revenue streams, and risks. SimCCS CO2 transported for each segment is a crucial
minimizes the cost of CO2 transport routes component in modeling the economics of
over a cost surface based on numerous CO2 capture, transport, and storage, as it
layers of geographic information and right-of- indicates the likely transport tariff that a seller
way concerns such as urban areas, bodies or buyer would need to pay in order to deliver
of water, publicly-owned lands and natural CO2 to storage locations. In general, cost per
resources, indigenous or tribal lands, and ton of CO2 transported decreased as pipeline
existing infrastructure. diameter increased, given that more CO2 could
be delivered with a greater-diameter pipeline.
To create an optimized pipeline network, the
model finds the shortest paths between all Regional CO2 Capture and Storage
source and storage locations, while minimizing Transport Networks
sharp angles in the routes and identifying the To optimize the design of a regional CO2
least expensive infrastructure to meet user- transport corridor suitable for economy-
specified capture goals. The model also allows wide deployment, a series of scenarios
users to project solutions across multiple time were devised that build out capture retrofits
periods, proposing early stage infrastructure over time at industrial and power facilities.
development to meet longer term capacity The datasets in Table 8 provided a range
needs. of configurations for input data in these
scenarios. The results from these scenarios
The US DOE’s NETL CO2 Transport were provided in the first summary section of
Cost Model was used to assess costs of this paper and are discussed in more detail in
transporting CO2 between sources and sinks.22 the following pages.
20Table 8. Primary input data sources per scenario
CAPTURE STORAGE TRANSPORT
Industrial and power Deep saline geologic
NEAR- AND MEDIUM-TERM
facilities within the study formations with estimated
region identified as injection and storage
near- or medium-term costs of less than $5 per
opportunities for capture metric ton.
retrofit. Data source: SCO2T, based
Data source: EPA on NATCARB, RCSP,
FLIGHT 2018 screened USGS.
for economic capture
opportunity. Petroleum basins: existing
operations with potential
demand for CO2 at oil
TRANSPORT INFRASTRUCTURE FOR CARBON CAPTURE AND STORAGE GREAT PLAINS INSTITUTE
prices of at least $40 per Trunk and feeder line
barrel. route optimization and
capacity determination
Data source: ARI 2018. performed by SimCCS.
Cost optimization and
calculation performed by
SimCCS based on costs
published in the NETL CO2
Transport Cost Model.
All US industrial and power Deep saline geologic
MIDCENTURY HORIZON
facilities with annual CO2 formations with estimated Further cost components
emissions that qualify for injection and storage and financing
45Q. costs of less than $5 per considerations calculated
Data source: EPA FLIGHT metric ton. by the NETL CO2 Transport
2018 screened for 45Q Data source: SCO2T, based Cost Model based on
threshold emission levels. on NATCARB, RCSP, SimCCS output.
USGS.
Petroleum basins: existing
operations with potential
demand for CO2 at oil
prices of at least $60 per
barrel.
Data source: ARI 2018.
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