TECHNICAL REPORTSTATE OF THE ART:CCS TECHNOLOGIES 2022

NOUMAN MIRZA, Ph.D
Consultant - CCS Technologies
DAVID KEARNS, Ph.D
Principal Consultant - CCS Technologies

CONTENTS
FOREWORD

4

CAPTURE

6

AIR LIQUIDE8

AIR PRODUCTS

16

AKER CARBON CAPTURE

20

AXENS

24

C-CAPTURE

28

CARBON ENGINEERING

32

CARBON CLEAN

34

CO2 CAPSOL38DECARBONTEK42

ENTROPY44

HONEYWELL

46

IHI

50

LEILAC GROUP (CALIX)

54

SAIPEM

56

SHELL

60

SVANTE

70

TRANSPORT74

K-LINE

76

KNCC

78

MAN

82

SVANEHOJ84

TORISHIMA86

STORAGE90

DRIL-QUIP

92

MAXTUBE

94

FULL VALUE CHAIN

98

BAKER HUGHES102

CAPTICO2122

CARBFIX124

CHEVRON

128

JCCS

132

LINDE

136

NOV

148

SCHLUMBERGER

152

SICK

156

Carbon Capture and Storage (CCS) has emerged as
an indispensable tool in humanity’s efforts to combat
climate change and reach its goal of net-zero emissions.
Industries as diverse as cement, iron and steel, chemicals,
natural gas and electricity generation can benefit from theability of CCS to cut industrial CO2 emissions deeply.
CCS is also moving into carbon dioxide removal (CDR)
in applications such as Direct Air Capture (DAC) andBioenergy with CCS (BECCS), drawing down historical
CO2 emissions from the atmosphere.
The CCS sector has been growing at an unprecedented
rate in recent years, and that growth is only accelerating.
The increased dependence of global plans for net-zeroon CCS means that the economic performance of CCS is
becoming increasingly important.

CCS is happening now, and the technology is ready topurchase today. This inaugural Technology Compendium
is intended to showcase the breadth and depth ofcommercially-available CCS technologies worldwide.
Contributions to this Compendium have come from someof the world’s most prominent technology providers, aswell as promising emerging firms.
David T. Kearns, PhD.
Principal – CCS Technologies
Global CCS InstituteMay 2022

Technology development will be a significant driver of
improved economics for CCS. Higher energy efficiency,
reduced variable operating costs, capital cost reductions,and plant performance improvements, enabled by newtechnologies, are meeting the demand for improved CO2
capture system performance, transport system costs, andCO2 storage options.

Acknowledgements
We are grateful for the contributions and support of all the technology companies who have contributed to thispublication.
Thank you to Dr Nouman Mirza for his invaluable editing and coordination of this report.
Special mentions also go to Bruno Gerrits, Christina Staib, Erin Billeri, Yasuo Murakami and Kazuko Miyashita of the
Global CCS Institute for their efforts and support.

4

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACTFOREWORDCAPTURE

CONTACTAMINE SOLUTIONS, RECTISOL™, AND RECTICAP™

AIR LIQUIDEEmail:

gas-treatment@airliquide.com
hydrogen-syngas@airliquide.com

Web:

www.engineering-airliquide.com

DESCRIPTIONSUMMARY
Air Liquide Engineering & Construction (Air Liquide
E&C) also engineers solvent-based technologies suchas amine to capture CO2 from synthesis gas or flue gas.
Through long term partnerships with the key amine licenseproviders, Air Liquide has installed 80+ units and benefits
from its long-term operational experience of amine units.
Considered as the industrial base case, amine technology
can deliver high purity gaseous CO2 (99+%) at low pressure,which can be combined with Cryocap™ XLL. For CO2
capture on flue gases with low CO2 concentration (below10%), amine technology remains the most competitive
solution, provided the availability of large amounts ofexcess steam or high grade heat. Air Liquide Engineering& Construction is also offering proprietary technologies forCO2 capture from synthesis gas (Rectisol, Recticap).

BENEFITS

8•

Fully referenced in all applicable scales and different applications•

Process uses inexpensive, available and chemically stable solvent•

Technology provides low operating costs and high availability•

Process configuration can be tailored to optimize CapEx and OpEx

STATE OF THE ART: CCS TECHNOLOGIES 2022

Acid Gas Removal – Amine Wash

Rectisol™

The process configuration and solvent selection will betailored according to feedstock and sweet gas application.
Air Liquide E&C can offer very energy-efficient processes
such as the BASF OASE® purple or OASE® yellow as wellas other proprietary or generic amines for pipeline orliquefied natural gas specifications. This process presents
the advantage of very low hydrocarbon co-absorption.
With selective processes, deep H2S removal with low tomoderate CO2 co-absorption can be achieved for pipeline
specifications. Capacity is up to 1,500,000 Nm³/h per train.

Harmful acid gases contained in raw gases from any
gasification are removed by absorption with a physicalsolvent (cold methanol). Rectisol™ is the leading process
when it comes to the purification of gasification-based
syngas for catalytic applications (production of SNG,
methanol, ammonia, or Fischer-Tropsch) as well ashydrogen and syngas for power production. Using
inexpensive solvent in combination with optimized heat
integration, the Rectisol™ process has extremely low
operating costs and high availability.

CO2 Removal from Flue Gas (3-25% CO2) - Amine Wash

Key Figures

Trace components such as particles and SOx are handled
in the upstream pretreatment. Air Liquide offers energy
efficient solutions with highly stable, low maintenancesolvents based on proprietary second-generation amines.
CO2 capture rates of up to 95% can be reached irrespectiveof the feed’s CO2 content, and CO2 product specificationsof up to >99.9%. Capacities are up to 1,500,000 Nm³/h
feed per train, and up to 4,000 tpd CO2 per train.

•

50,000 - 1,000,000 Nm³/hr per train (feed gas)•Special setups for removal of mercaptans, metal
carbonyls and BTX available•

Accumulation of all harmful contaminants within theacid gas to be safely processed in an SRU

CO2 Removal from Syngas - Amine Wash
Air Liquide E&C offers very energy-efficient processes
such as BASF OASE® white. The process configuration
will be tailored according to treated gas requirements
and CO2 product specification as well as optimized CapEx
and OpEx. The process can be heat-integrated with the
upstream gas generation. CO2 specifications in the treatedgas of < 20 ppm are achievable, making this process ideal
for CO2 removal upstream of any coldbox or ammonia
process. CO2 capture rates from syngas of >99% can beachieved to produce a decarbonized hydrogen product.
Since the process has a very low co-absorption even at
higher feed gas pressures, CO2 product specifications with
CO2 > 99% are achievable.

Recticap™
Recticap™ is AL-Lurgi´s Rectisol™ tailored for carbon
capture from natural gas reforming to produce low-cost
blue hydrogen in large capacities (>300,000 kNm³/hr)
at moderate to high pressures (>25 bar). In contrast toa Rectisol™, Recticap™ removes only CO₂ from the raw
hydrogen/syngas and has a simplified process setup with
reduced capital expenditures. The solution allows up to>95% CO2 capture from syngas. Dry CO2 capture-ready at>98.5% purity is achievable.

CONTACTCRYOCAP™ XLL (LARGE CO2 LIQUEFACTION)

AIR LIQUIDEEmail:

cryocap@airliquide.com

Web:

www.engineering-airliquide.com

DESCRIPTION
The Cryocap™ XLL process is proposed as an industrial
solution to compress, liquefy, and purify the raw CO₂
stream resulting from upstream units. The CO₂ feed gas
is compressed in the feed/recycle compressor, dried at anintermediate pressure and then compressed again. The
compressed gas is cooled down and then routed to thecold process. In the cold process, the high-pressure, dry
CO₂ is cooled down and split into various streams. Oneof these streams is purified by distillation in the Stripping
Column to produce liquid CO₂ product, which is routed
to the unit’s battery limits. The remaining streams are
expanded to different levels and vaporized in the mainheat exchanger, providing the refrigeration load required
for the liquefaction of CO₂. Once vaporized, these streams
are recycled at ambient temperature to the feed/recycle
compressor. This configuration makes it possible to handle
the compression of the feed gas and the refrigeration witha single compressor (so called self-refrigerated cycle).

SUMMARY
Air Liquide Engineering and Construction has developed
Cryocap™ XLL, which is specifically designed to liquefy
large volumes of CO2. The solution allows aggregationof CO₂ from various emitters utilizing possibly different
types of carbon capture technologies. On top of liquefying
CO₂, Cryocap™ XLL also allows the removal of moistureand other compounds (such as O₂) to meet CO₂ sinkspecifications. The technology has been developed forlarge scale and is able to reduce specific power for CO₂
liquefaction by 40% compared to existing small scale CO₂liquefier used for industrial merchant application.

BENEFITS•

HSE-Friendly•

Custom plant: flexible design•

Moisture and other light compounds (O₂, N₂…) removal•High compactness•

Low specific energy•

Cost efficiency

10

STATE OF THE ART: CCS TECHNOLOGIES 2022

The technology is especially suited for CO₂ industrial
hubs and basins where the CO₂ needs to be transported
via ships, trucks, or trains. Cryocap™ XLL is a HSE-friendly
solution that does not involve the use of any toxic or
flammable external refrigerant (such as ammonia orpropane). As a single compressor is used for both the feed
and the cycle, it is also a very compact and cost-effective
solution.

Key Figures•

800 to 10,000+ tpd•

Custom plant: flexible design•

Liquefies CO₂ at ambient temperature•

5-25€/t CO₂ liquefied•

Very low OpEx: 30-130 kWh/t CO₂•

HSE-friendly (CO₂ cycle)

Reference Examples•

2020 - Industrial FEED for 7000 tpd in Belgium(Antwerp@C)

CONTACTCRYOCAP™ (H2, FG, OXY, STEEL, NG)

AIR LIQUIDE

solutions to meet and exceed customer expectations interms of efficiency, safety, reliability and competitivenessto achieve energy transition goals. As a top technology
provider with a longstanding experience in Engineering,
Procurement, and Construction (EPC), we cover the entire

Email:

cryocap@airliquide.com

Web:

www.engineering-airliquide.com

project life-cycle: license engineering services/proprietaryequipment, high-end engineering & design capabilities,
and project management & execution services. In addition,
we also offer efficient customer services through ourworldwide set-up.

BENEFITS
The entire Cryocap™ suite was designed to address thechallenges experienced from traditional capture solutions.
Our customers value the following Cryocap™ features:

SUMMARY
Air Liquide has been designing gas separation
technologies for more than 100 years, and has leveraged
its industrial demonstration units on power plants, steel
blast furnaces, and H2 production plants to develop
the Cryocap™ product line. Cryocap™ is a proprietary
technological innovation for CO2 capture that is uniquein the world, and uses a cryogenic process (involving
low temperatures to separate gases). Cryocap™ can beadapted to specific applications combining a variety of
Air Liquide technologies. Customers can reduce their CO2
emissions by up to 98% and have the possibility to valorise
other molecules contained in the feed gas (e.g. CO andH2). Cryocap™ technology is the most environment-friendly
technology and available to service customers looking to
reduce the carbon footprint of their production facilities.
Driven by innovation and the need to decarbonize carbon
intensive processes, Cryocap™ reference examples dateback to 2005 and the product line has since been selected
for multiple engineering studies, pre-Front End Engineering& Design (pre-FEED), FEED, and implementation acrossfour continents for a diverse set of industries. To further
showcase its innovative and efficient design in CO2
capture, Cryocap™ has resulted in several patent filings, hasbeen awarded by the 2021 EU Innovation Fund throughseveral projects, and has also been selected for FEED
study by US DOE for industrial capture projects.

12

STATE OF THE ART: CCS TECHNOLOGIES 2022

Our portfolio of cryogenic technologies includes:
•
•
•
•
•

•

Minimizes overall carbon footprint: the technologies
run mainly on electricity (negligible steam), which
maximizes the CO2 avoided by reduced indirect CO2
emissions, high CO2 recovery (90 - 95%, and up to 98%
with Cryocap™ Oxy and Cryocap™ H2)•

High intrinsic process efficiency: the technology bricks
are used within their optimum range•

Safety and environment-friendly: solvent-free, and no
toxic or flammable gases used

Cryocap™ H2 for hydrogen production: Steam Methane
Reformer (SMR), AutoThermal Reforming (ATR), or
Partial Oxidation (POX)
Cryocap™ FG for flue gases (optimal: >15% CO2 drybasis)
Cryocap™ Oxy for oxy combustion
Cryocap™ Steel for steel production
Cryocap™ NG for acid natural gas fields

The first industrial deployment of this technology was
made in Port-Jerome, France (Cryocap™ H2), at the largest
SMR Hydrogen production unit operated by Air Liquide.
Since its startup in H1 2015, the plant has proven a highly
reliable operation with zero impact on SMR availability, andcaptures 0.1 Mtpa CO2 from an existing SMR while boosting
H2 production. Moreover, 300 tpd of liquid CO2 is produced
at food grade quality and sold on the market primarily forthe beverage industry. Port Jerome is one of the 4 sites in
Europe able to produce Hydrogen certified low carbon. It
has been integrated as a pilot site for the project “CertifHy”,
the first Guarantee of Origin (GO) platform for green andlow-carbon hydrogen.
Air Liquide Engineering & Construction (E&C) has always
been committed to innovation by improving its vast
portfolio of patented technologies and customized•

Match the end specifications: all Cryocap™ produce
either high pressure gaseous or liquid CO2 at marginal
extra cost and can meet the most stringent CO2
specifications (up to 99.9% purity)•

Favour synergies and optimize space: 1-step capture
and liquefaction for any stream containing >15% CO2(dry basis), very compact solutions with flexible layout
configuration and simplified infrastructure compared to
steam-based solutions•

Improve productivity: for some applications (H2 andsteel), installing our product improves the efficiencyof the original process or enable the co-productionof valuable molecules (e.g. Cryocap™ H2 increases H2
production by 20%)DESCRIPTION
Cryocap™ H2
Based on its extensive experience in hydrogen production
units, Air Liquide E&C has developed a technology capableof capturing the CO₂ emitted during hydrogen production(by SMR or ATR or POX). This proprietary technology is the
subject of several patents and allows our customers to makesignificant cost reductions. On top of capturing and liquefying
the CO₂ in one step, it is the only technology that can
reduce CO₂ emissions during the production process whileboosting hydrogen production by 13 - 20%. It has the lowest
cost on the market for CO₂ capture in hydrogen production

units (especially compared to activated MDEA), and can beadapted to existing and future hydrogen production units.
The technology uses cryogenic purification to separate
CO₂ from Pressure Swing Adsorption (PSA) offgas,
containing typically 40-50 vol.% CO₂. The PSA offgas iscompressed, dried and sent to a cryogenic unit, where
the CO₂ is separated from the other components by a
combination of partial condensation and distillation. A
pure and pressurized CO₂ flow is produced from the cold
process. The non-condensed gases are recycled througha membrane system to recover H₂ and CO₂. Residual gas

CONTACTCRYOCAP™ (H2, FG, OXY, STEEL, NG)

AIR LIQUIDEEmail:

cryocap@airliquide.com

Web:

www.engineering-airliquide.com

DESCRIPTION CONT.
is sent to the burners of H₂ production plant. The CO₂
product is compressed up to supercritical pressure orliquefied and stored in liquid storage. Liquid CO₂ can also
be directly withdrawn from the cold process at marginal
costs. The CO₂ can be then liquefied and purified to
be used and meet CO₂ specifications of local industrial
markets (agri-food and water treatment etc.). Cryocap™ H₂
can be installed for greenfield and brownfield H₂ plants.
Key Figures
•
•
•
•
•
•

Capacity: 300 - 5,000 tpd
Hydrogen production: increase of 13 - 20%
Avoided CO₂ cost reduction: up to 40% compared to
MDEA
OpEx + CapEx: - 30-50 €/tCO₂ captured
Gaseous or liquid CO₂More than 98% of CO₂ recovery from syngas

Main Applications•

H2 production (SMR or ATR)

It is compressed and then sent to a cold process. There, theCO₂ is recovered by the combination of partial condensationand distillation, which allow the removal of various elements
such as O₂, Ar, N₂, NO and CO. The CO₂ product iscompressed, condensed and pumped up to supercriticalpressure or directly produced as liquid. The pressurized
nitrogen from the PSA is expanded to recover energy.
Key Figures
•
•
•
•
•
•
•

Main Applications•

Reference Examples•••

2012 - Industrial CCU EPC for 300 tpd in France
2019 - Industrial CCS pre-FEED in EU (Air Liquide SMR)
2020 - Industrial CCS FEED in Belgium (Air Liquide SMR)

Cryocap™ FG
Air Liquide developed a dedicated capture technology inorder to address low-hanging fruits of high-concentrated
sources: industrial flue gases. Many high CO₂-emitting
industries have concentrated sources of CO₂ emissionsof above 15%, such as hydrogen production with SMR,
cement and lime production, blast furnaces in hot metal
production, and FCC in refineries. These high-concentrated
sources are estimated to represent around 50% of the
global industrial direct emissions. Additionally, Cryocap™
FG is not only a CO₂ capture technology, but can alsosignificantly abate NOx emissions from flue gas and deliver
on-spec liquid CO₂ product at its battery limits, thereby
reducing the number of process units and interfaces, andincreasing the level of overall optimization and reliability.
Cryocap™ FG is a separation process based on the combinationof adsorption and cryogenic separation. The flue gas isfirst compressed, dried and sent to a PSA (Pressure Swing
Adsorption). The PSA pre-concentrates the CO₂ in the offgas.

14

STATE OF THE ART: CCS TECHNOLOGIES 2022

Capacity: 300 – 10,000 tpd
PSA-assisted CO₂ condensation
Compressors, PSA and cryo process can be located in
two different plots
Smart impurities management (high NOx)
40 to 80 €/tCO₂ captured
Gaseous or liquid CO₂
CO₂ capture rate: up to 95%
Flue gases or off gases with CO₂ content ≥ 15% (SMR,
cement/lime, steel blast furnace, refineries (FCC), coal/biomass power plant, pulp & paper)

Reference Examples•••

2020 - Industrial CCS Engineering Study for 2,000 tpd
in EU (FCC)
2021 - Industrial CCS Process Design Package +License for 2400 tpd in EU (Zeeland Refinery - SMR)
2021 - Selection by US DOE for a FEED on Holcim St
Genevieve plant in US (e.g. 10,000 tpd CO₂)

Cryocap™ Oxy
Cryocap™ Oxy uses oxy-fuel combustion exhaust as afeedstock. Its unique technological bricks include flue gas
drying, dust filtration, and cryogenic purification. Throughthis technology, a high rate of CO₂ recovery is achieved, andcan reduce atmospheric emissions from power plants toalmost zero (emissions of NOx, SOx, fine particles and Hg).
Cryocap™ Oxy is in the process of several patent filings.
The flue gas issued from the cement or lime or power plantis first treated in a pre-treatment unit, which aims to cool thegas and remove SOx, HF, HCl, most of the NOx, and dust.
Then, the gas is compressed and dried before entering
the cryogenic purification unit. In the cold process, CO₂ isrecovered by a combination of partial condensation anddistillation, which allows the removal of heavy compounds
such as NOx and various light elements such as O₂, Ar, N₂,
NO and CO. The CO₂ product is compressed, condensed
and pumped up to supercritical pressure or directly
produced in liquid state.
Key Figures
•
•
•
•
•
•
•

Capacity: 1,000 and 15,000 tpd
30 - 50 €/tCO₂ captured
Energy savings through residual gas
Gaseous or liquid CO₂
Enriched flue gas above 60% CO₂
Smart impurities management (high NOx)
CO₂ capture rate: 90-98%

Main Applications•••

Cement/Lime
Power plant
Any applications with CO₂ concentration of >40%

to the blast furnace or used to produce fuels.
Key Figures
•
•
•
•
•

Capacity: 300 - 5000+ tpd
Compact and flexible footprint: compressors, PSA andcold-box can be located in three different plots
25-60 €/t CO₂ captured
Gaseous or liquid CO₂
CO₂ capture rate: 80 to 95%

Main Applications•

Iron and Steel Production

Reference Examples••••

2005 - Pilot CCS EPC for 40 tpd in Sweden (MEFOS)
2012 - Industrial CCS FEED for 3,600 tpd in France(ULCOS)2019 - CCU for 800 tpd in Belgium (Steelanol)2020 - CCU LCO₂ Pre-FEED for 350 tpd in Korea

Reference Examples
•
•
•
•
•
•

2008 - Demo CCS EP for 200 tpd in France (Total oxyfuels)
2010 - Pilot CCS EP for 80 tpd in Australia (Callide coal burners)
2012 - Pilot CCS EPC for 200 tpd in Spain (CIUDEN coal oxyboilers)
2014 - Industrial CCS FEED for 3,500 tpd in US(Futuregen - coal power plant)2015 - Industrial CCS FEED for 1,500 tpd in France(Lafarge - cement)
2021 - Pre-FEED in EU (cement)

Cryocap™ SteelThis solution was designed to specifically capture CO₂ fromsteel-making plants, with CO₂ stream concentrations of 2050%. The gas is first compressed, dried and sent to a PSA(Pressure Swing Adsorption). The PSA pre-concentrates theCO₂ in the offgas while producing a CO rich stream. The preconcentrated CO₂ stream is compressed and sent to a cold
process. There, the CO₂ is recovered through a combinationof partial condensation and distillation, which allows theremoval of light elements such as Ar, N₂, H2 and CO₂.
The CO₂ product can be produced as a gaseous or liquid
product. The pressurized CO-rich stream is either recycled

Cryocap™ NG
The CO₂-rich natural gas is first dried and sent to acold process, where CO₂ is separated from the othercomponents through a combination of partial condensationand distillation. High CO₂ partial pressure favours the partial
condensation of CO₂, and therefore, makes its separationfrom natural gas even easier. The non-condensable gas
is enriched in methane and sent to a membrane for final
purification. The CO₂ purity of the product corresponds
to pipeline specifications, generally 1 - 10 mol%. The CO₂enriched permeate stream of the membrane is sent backto the cold process. The CO₂ and heavy hydrocarbons
condense in the cold process and are collected at highpressure. NGL recovery is possible with almost no additionalcost. Cryocap™ NG is tolerant to some content of H₂S.
Cryocap™ NG also allows for bulk removal of H₂S from NG.
Key Figures•••

Up to 1,000,000 Nm3/h
Separation cost: less than 1 USD/MMBTUCapEx savings: > 50% vs. amine absorption (at highCO₂ content)

Main Applications•

Natural gas with high CO₂ content (>35%)

CONTACTHYDROGEN TECHNOLOGY PORTFOLIO FOR
LOW-CARBON SOLUTIONSAIR PRODUCTS

Technology
Leadership

Air Products’ Blue H2, Syngas & CCUS Portfolio
Feedstock

SyngasGeneration

Processing, Separation & Purification

Natural Gas
Refinery Off-gas
BiogasNaphthaHigh(~3 to 4)
Water-Gas Shift

POx

Heavy Oil / Petroleum Residue

PetcokeCoal
Biomass
Waste

Separations• H2 PSA• CO cold box• Membranes

Oil
Gasification

CO2 Capture• Absorption• Adsorption• Partial Condensation (Low T)

Entrained Flow
Gasification
Low(~0.3 to 0.7)

Fluidized Bed
Gasification

ASU

Hydrogen

Methanation

ATR

Markets

Off-gases

H2 to CO ratio
SMR

Products

CO2 Conditioning• Drying• Purification• Compression• CCS-scale liquefaction

O2

SyngasCO

CO2

Fertilizer / Ammonia
Refining
Methanol
Plastics
Chemicals
Iron / Steel
Mobility
Renewable Fuels
Synthetic Fuels
Power
Sequestration
Utilization

Steam / Heat
/ PowerAtmospheric
Gases

Merchant Industrial Gases

SUMMARY
Air Products operates in approximately 50 countries,
serving clients globally with a unique portfolio of products
and technologies in dozens of industries including refining,
LNG, chemicals, metals, electronics, and manufacturing.
The company’s integrated approach to research,development, production, and distribution of industrial
gases is a key competitive advantage, helping it becomea leading player in this space. Leveraging its integrated
platform, Air Products is executing an ambitious growthplan driven by its mission to support clients throughthe energy transition with environmentally sustainable
solutions.
Air Products has successfully demonstrated large-scalecarbon capture at its Port Arthur hydrogen facility in Texas,
USA. Operating since 2013, key learnings from this project

have helped the company develop the next generation of
low-carbon hydrogen projects in its franchise. In Canada,
the Net-Zero Hydrogen Energy Complex, targeted for2024, incorporates +95% carbon capture and hydrogenfired power generation. In the U.S. Gulf Coast, the Louisiana
Blue Hydrogen Clean Energy Complex, targeted for 2026,
includes the development of one of the world’s largest
carbon sequestration operations.
Air Products’ diverse portfolio of technologies enables
the production of hydrogen and syngas from a varietyof feedstocks with diverse options for carbon capture,
sequestration and/or utilization. The company maximises
value for all stakeholders by operating an integrated
industrial gases platform that is continuously focused onsafety, reliability, and cost.

A diverse portfolio of technologies enables optimised hydrogen and syngas solutions considering technical, economic,
and legislative factors.

•

Multifacility integration and monetization of co-products are key enablers of value creation for all stakeholders.

•

An integrated approach to technology development and operational excellence has led to superior safety, reliability, andcost performance.

16

STATE OF THE ART: CCS TECHNOLOGIES 2022

Email:

keivans@airproducts.com

Web:

www.airproducts.com

DESCRIPTION
Air Products is an industry leader with expansive
operations, continuously refining and optimizing its
technology portfolio at research and engineering centres
located in the United States, Europe, Saudi Arabia,
India, and China. A global team of engineering andconstruction professionals are responsible for bringing
these technologies to life, building world-scale industrial
gas projects including carbon capture, utilization, andsequestration (CCUS) facilities. Completing the technology
lifecycle, as one of the sector’s largest operators, Air
Products gathers real-world data and experience fortechnology refinement, which is achieved throughcross-collaboration among research, engineering, andoperations teams. The integrated approach to technology
and operational excellence is a major source of strengthand differentiation, leading to advantages in safety,
reliability, and cost performance.

When developing low-carbon hydrogen projects, Air
Products tailors facility configurations from an extensive
portfolio of technologies (as seen in the figure on the left
hand side). With multiple technologies available for eachstep of the process, Air Products develops an optimised
and integrated solution considering technical, economic,
and legislative factors. Hydrogen and syngas generation
can be designed for a wide variety of feedstocks, allowing
carbon capture from any input stream including solid,
liquid, or gaseous hydrocarbons, waste, and/or biomass.
Air Products operates the world’s longest hydrogenpipeline in the US Gulf Coast, linking about 25 hydrogenproduction plants across approximately 1,100 km (around
700 miles) from New Orleans to Texas City, USA. Within the
Gulf Coast System, the Port Arthur Blue Hydrogen plant in
Texas approached 8 million tonnes of captured CO2 as of
2021.

Net-Zero Hydrogen Energy Complex(Alberta, Canada)
CO2

Air Products Alberta Heartland
H2 Pipeline for H2 Customer Supply
95% Captured
for Sequestration

H2 Plant
AlbertaNatural Gas

ATR

Net-Zero
Hydrogen

H2 Plant
55-kilometer pipeline
Envision >1,500 MTPD of production

H2 Plants(future)H2 Plant

OxygenLiquid Hydrogenfor MerchantMarket and H2fM

LHY

ASU

BENEFITS•

Sina Keivani

H2 Power Plant

LIN

LOX

Power for Export

for Merchant Market

LHY – liquid hydrogen
LIN – liquid nitrogen
LOX – liquid oxygen
ATR – autothermal reformer

ASU – air separation unit
CO2 – carbon dioxide
H2 – hydrogen

H2fM – hydrogen for mobility

CONTACTHYDROGEN TECHNOLOGY PORTFOLIO FOR
LOW-CARBON SOLUTIONSAIR PRODUCTS

The project, completed in 2013, entailed the retrofit of two
existing steam methane reformers (SMR’s) with carbon
capture units to reduce +90% of high-pressure CO2 inprocess streams, equating to approximately half of thedirect emissions associated with hydrogen production.
CO2 is captured using vacuum swing adsorption (VSA)
separation units, purified by a tri-ethylene glycol (TEG)
dryer, compressed to supercritical pressures, andtransported by Air Products through an approximately 21
km (around 13 mile) pipeline to an offtaker. A cogeneration
unit was integrated into the scope to further enhancethe efficiency and reduce emissions. The successful
completion and operation of this retrofit project in the
middle of an operating refinery was a testament to thecompany’s engineering, project execution, and operations
capabilities. Lessons learned from this project in capturing
CO2 from high-pressure streams were critical in developing
the company’s next generation of low-carbon hydrogenprojects.
In advancing its decarbonization mission forward, Air
Products is building the Net-Zero Hydrogen Energy
Complex in Edmonton, Canada to integrate anddecarbonize its Alberta Heartland Hydrogen Pipeline
System. Engineering work is currently underway, and thefacility is targeted to start up in 2024. Hydrogen will be
produced using autothermal reformer (ATR) technology
integrated with carbon capture systems achieving +95%
capture. The facility will be self-powered using hydrogenfired turbines and will also export power, helping further
reduce emissions by offsetting higher carbon intensity
electricity on the grid. Low-carbon hydrogen will be
distributed along the 55 km (34 mile) Heartland Pipeline
System to multiple offtakers, as well as liquified on-sitefor distribution to merchant and mobility markets by Air
Products’ road fleet. This is a common theme across Air
Products’ portfolio where integration allows for enhanced
value creation.

18

STATE OF THE ART: CCS TECHNOLOGIES 2022

Similarly in the U.S. Gulf Coast, the Louisiana Blue
Hydrogen Clean Energy Complex moves the franchisefurther down the decarbonization path, utilizing natural gas
gasification technology, also known as partial oxidation,
to produce hydrogen whilst capturing +95% of theassociated direct emissions. Air Products has identified theideal geologic structure for CO2 storage and will lead its
development into one of the world’s largest sequestration
operations. Once fully commissioned, over 5 Mtpa CO2
will be captured, transported, and sequestered in thisdedicated underground storage facility.
The company’s holistic development approach creates
opportunities for energy and product integration between
different company-owned and/or client facilities. The
Louisiana Blue Hydrogen Complex for example not only
integrates into the Gulf Coast Hydrogen Pipeline System,
described previously, but also serves a new ammonia plant
to enable the global distribution of low-carbon hydrogenmolecules.
Air Products has extensive experience with designingand operating standalone CO2 facilities in various scales
including merchant CO2 plants. The company also
operates world-scale facilities such as the Doe Canyon
Helium Plant in Colorado where approximately 9,000 tpd
of CO2 is separated from Helium using a patented partial
condensation separation process.
Air Products is executing an ambitious growth plan driven
by its mission to support clients through the energy
transition with environmentally sustainable products andsolutions. The company can help maximize value forall stakeholders through early engagement in project
conception and execution.

Sina Keivani
Email:

keivans@airproducts.com

Web:

www.airproducts.com

Blue Hydrogen Clean Energy Complex(Louisiana, USA)

CO2 Capture
NaturalGas

Permanent Sequestration in
Air Products DedicatedUnderground Facility

Natural Gas
Gasification>750 Million SCFDBlue Hydrogen

OxygenASU

NitrogenAmmonia Plant

Injection into the
Air Products~700-Mile Long
Hydrogen Pipelineon the Gulf CoastBlue Ammonia
Exported to Global
Hydrogen Markets

CONTACTADVANCED CARBON CAPTURE (ACC™)

AKER CARBON CAPTURE

Email:

ccus@akercarboncapture.com

Web:

www.akercarboncapture.com

BENEFITSSUMMARY
Aker Carbon Capture is a dedicated carbon capture
technology company with solutions, services andtechnologies covering the entire carbon capture utilizationand storage (CCUS) value chain. We serve a range ofindustries with carbon emissions, including cement, wasteto-energy, gas-to-power, hydrogen and our carbon capture
plants offer several advantages such as low energy
requirements, very robust solvents, and excellent HSE
performance.
Aker Carbon Capture’s Advanced Carbon Capture(ACC™) technology has been developed since 2005 andoffered commercially since 2009. It is an energy and costefficient post-combustion capture process with minimal
environmental impact, based on ACC™ proprietary solventsand proprietary process solutions.
The ACC™ proprietary solvents were developed in aneight years’ comprehensive R&D program (SOLVit)
together with industry players and Norwegian research
partners. Numerous solvent mixtures have been tested
and compared with regards to energy consumption,robustness, toxicity, material compatibility and – mostimportantly – HSE performance. The SOLVit program
resulted in energy efficient solvents, with no negativeenvironmental impact or occupational hazards.

20

STATE OF THE ART: CCS TECHNOLOGIES 2022

Due to the testing of different capture technologies at theTechnology Centre Mongstad, potential harmful effectsof amines used for carbon capture have been brought
to attention. Aker Carbon Capture has been involved inthis evaluation from the very start, which has resulted in athorough understanding of potential issues with nitros- andnitra-amines and their formation mechanisms. Proprietaryprocess solutions as well as the robust solvents eliminate
the emission of harmful amines or the degradation
products from any ACC™ capture plant.
The ACC™ capture technology including the ACC™
solvents and ACC™ Emission System has been tested
and verified on flue gases from gas-fired and coal-fired
power plants, cement kilns, waste-to-energy plants andhydrogen production plants, with more than 50,000 hoursof operating experience from the US, Germany, Scotland,
Sweden, Poland and Norway. Based on the extensive
testing, the ACC™ capture technology is qualified by DNV
GL according to DNV-RP-A203 Qualification Procedures
for New Technology and DNV-RP-J201 Qualification
Procedures for CO2 Capture Technology.

•

Highly energy-efficient capture process with innovative heat integration solutions•

Includes proprietary ACC™ advanced emission control system to prevent the formation of amine mist, which nearly
eliminates the emissions of amine and amine’s degradation products•

Verified for operating on flue gas from cement kilns, waste-to-energy plants, coal-fired power stations, gas boilers, gas
power plants, hydrogen production, and refinery applications, through campaigns with our Mobile Test Unit, and at
TCM.

•

Aker Carbon Capture’s ACC™ CO2 capture process, including CO2 liquefaction, intermediate storage and CO2 export
has been qualified by DNV-GL according to DNV-RP-A203 Qualification Procedures for New Technology and DNVRP-J201 Qualification Procedures for CO2 Capture Technology•

Includes extremely robust solvents for environmentally friendly operation. The proprietary ACC™ solvents arecharacterized by low solvent degradation, which is associated with low corrosion rate in the plant, low amine makeup requirement, low emissions of amine’s degradation products, low demand for amine’s reclamation, and thereby,
resulting in low production of reclaimer waste•

No generation of wastewater contaminated with amine traces during normal operation

CONTACTADVANCED CARBON CAPTURE (ACC™)

AKER CARBON CAPTURE
DESCRIPTION
The main unit operations of the ACC™ process include
the ACC Direct Contact Cooler (DCC), the ACC Absorber,
the ACC Desorber columns, the ACC Reboiler, the ACC
Reclaimer, the ACC Energy Saver, the Flue Gas Fan, and aliquefaction unit (ACC CO2 Compression).
Flue gas from the client’s plant is extracted downstreamof any existing flue gas emission control units through theflue gas fan. The flue gas is pre-treated in the DCC. The
purpose of the DCC is to cool the flue gas and to remove
any acid gases, such as SO2, HCl and HF. Condensed
water from the flue gas will exit the DCC as a bleed stream.
Flue gas from the DCC is routed to the CO2 absorber
downstream of the booster fan. The CO2 absorber consistsof a CO2 absorption section in the lower part of thecolumn and a water wash section with an emission control
system in the upper part of the column. In the absorption
section, flue gas contacts the lean amine solvent in acountercurrent flow regime, absorbing CO2 from theflue gas. Continuing to the upper part of the column, theemission control system including the ACC™ Anti-Mist
design cools and cleans the CO2-lean flue gas of traces ofamines and potential amine’s degradation products, thus
effectively preventing emissions of amine and potential
amine-degradation products in the form of aerosols. CO2lean flue gas is either emitted from the absorber stack or
returned to the existing flue gas stack downstream the fluegas extraction point.
CO2-rich amine is drained from the absorber sump. The
rich amine solvent is regenerated using steam. The steam
is condensed in a reboiler and returned to the battery limits
as hot condensate. The increase in temperature during theindirect heating of rich solvent with steam strips the CO2
out of the solvent. The resulting lean amine is returned tothe absorber for reuse in the CO2 capture process, while
the CO2 exits the top of the desorber.

22

STATE OF THE ART: CCS TECHNOLOGIES 2022

Email:

ccus@akercarboncapture.com

Web:

www.akercarboncapture.com

REFERENCES
Further treatment of the CO2 depends on the CO2 productspecifications. Carbon dioxide (CO2) may be liquefied forexample, for ship transport, in which case it is dried andstripped of non-condensable inert components to thespecified CO2 quality prior to being sub-cooled and sent
to onsite liquid storage vessels. The ACC proprietary CO2Compression Solution includes internal heat recovery that
reduces the overall steam requirement for the carbon
capture plant. Alternatively, the CO2 is compressed and fed
into regional CO2 pipeline to be transported to permanentstorage.
To maintain high solvent performance, a reclaimer
is included to intermittently remove impurities anddegradation products from the amine solvent. A small
amount of concentrated liquid waste is generated in thereclaimer. This reclaimer waste needs to be disposed off
batch-wise as chemical waste. Due to the low degradation
rate of the ACC™ solvents, along with a properly designed
DCC, the amount of reclaimer waste from the ACC™
process is very low compared to standard plants operatingwith generic solvents such as MEA.

Technology Center Mongstad (TCM)

Norcem Cement Plant

Aker Carbon Capture designed and was awarded the
EPC delivery of the carbon capture test facility plant at
TCM. This full-scale CO2 capture plant captures CO2 fromthe gas-fired combined heat and power plant and thecatalytic cracker at the Mongstad refinery. Different fromcompetitors, Aker Carbon Capture has not only tested our
ACC™ technology at the TCM facility, but designed anddelivered the actual plant, which has been in continuous
operations since 2012. Customer: Statoil (now Equinor).

Aker Carbon Capture has worked together with
Heidelberg Norcem and partners in developing a full-scale
CO2 capture, conditioning, compression, heat integration,intermediate storage and loading facility for the Brevik
cement plant. Carbon dioxide (CO2) is being captured
from the flue gases of the cement kiln using waste heatrecovered from the cement plant and the CO2 compression
plant through a proprietary heat integration technology.
The ACC™ capture plant at Norcem will be the world’s
first CO2 capture plant from a cement plant when thecapture commences in 2024, and is part of the NorwegianLongship Project.

Twence Waste-to-Energy
The project will enable the removal of CO2 from fluegases at the Twence’s waste-to-energy installation facility
located at Hengelo, the Netherlands. The captured andliquefied CO2 will be used primarily by greenhouses in thehorticultural sector, where it will enhance crop growth.
CO2 capture capacity: 0.1 Mtpa

CO2 capture capacity: 0.4 Mtpa

CONTACTDMX™ PROCESS

AXENSNadège Guernalec
Email:

nadege.guernalec@axens.net

Web:www.axens.net

BENEFITS
Main Benefits of Axens’ DMX™ process are the following.

SUMMARY
CO2 removal using amine scrubbing is a well-known
process used since 1920 in natural gas treatment. Axens
and IFPEN have acquired over 60 years of experiencein CO2 removal from natural gas through the licencing ofAdvamine™ processes.
Although CO2 can be easily recovered from pressurizedgases with currently available technologies, its recovery
from low-pressure or flue gases leads to a significant
energy penalty. Furthermore, most solvents currently usedin the oil and gas or chemical industries, will be severely
degraded by the oxygen present in the flue gases. More
suited technologies are therefore required for most CCS
applications.
To address these challenges, Axens and IFPEN have been
involved in several R&D programs over the past years todevelop enhanced CO2 capture technologies. The DMX™
process is an outcome of these developments.
The DMX™ process is a CO2 capture process based on
absorption using a demixing solvent. The DMX™ solvent
consists of a mixture of two organic compounds in aqueous
solution, which is demixing under certain conditions oftemperature and CO2 partial pressure.

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STATE OF THE ART: CCS TECHNOLOGIES 2022

The DMX™ solvent has a high cyclic capacity (4 times
more than the MEA benchmark), whereas only the CO2rich phase needs to be regenerated. As it is very stable,
it may be regenerated at higher temperature than amine
solvents such as MEA, which allows producing CO2 athigher pressure (up to 5 barg). Thanks to the properties of
DMX™ solvent, the DMX™ process has a great potential for
reducing the energy penalty and the cost of CO2 capture.
Compared to the first-generation absorption process using
30 wt.% MEA, the DMX™ process allows a 30% reduction
in energy penalty and the subsequent cost of the CO2
capture (main results from Octavius (ENEL) and Valorco(coordinated by Arcelor Mittal and founded by ADEME)
projects). The DMX™ solvent is also less corrosive than
MEA, and therefore, carbon steel may be used as theprincipal material, which reduces the CapEx, as comparedto the first-generation solvents.

•

Versatile process applicable to multiple types of flue gases (for example: coal power stations, steel mill gas, FCC unit,
Steam Methane Reformer, waste incinerator, cement plant, district heating and also electricity from biomass). The
DMX™ process is well-adapted to CO2 capture on industrial smoke or industrial gas when the CO2 partial pressures are
low to medium, typically below 1 bara.

•

Low steam energy consumption from 2.3 to 2.9 GJ/tCO2 depending on application and capture rate•

Thermally stable solvent with low degradation rate•

CO2 produced readily under pressure up to 5 bars for significant compression cost-savings•

High capture rate achievable (> 95%) and high purity of produced CO2 (> 99%)•

- 30% of CO2 capture cost compared to 1st generation amines

CONTACTDMX™ PROCESSAXENSDESCRIPTION
The DMX™ process can be broken down into four main
sections.
A CO2 absorption section (absorber): the conditioned gas
is washed in a counter-current absorber with the DMX™
solvent. The absorber is equipped with an intercoolingstage to enhance the absorption capacities of the solvent
and reduce the solvent circulation to its minimum. A water
wash section is installed at the top of absorber to limit thesolvent losses with the treated flue gas. A DMX™ solvent
demixing and settling section (decanter): the CO2-richsolvent recovered at the bottom of the absorber is pumped
and heated in the rich/lean solvent exchanger, leading todemixing of the latter. After decantation, three phases are
obtained:•

A liquid phase low in CO2 can be returned directly tothe absorption section.

•

A liquid phase rich in CO2 is directed to theregeneration section.

•

A gas phase rich in CO2

A regeneration section (regenerator): the CO2-rich phase
coming from the settling section is thermally regenerated
by steam stripping effect (generated in situ with a reboiler
operating with medium-pressure steam) producing agaseous effluent rich in CO2 at the top of the column. The
regenerated heavy phase is sent to a regenerated solvent
hold up drum, before being recombined with the low CO2
light phase (from the settling section). It is then cooled
down through rich/lean solvent exchanger and lean solvent
cooler before being returned to the absorption section.

26

STATE OF THE ART: CCS TECHNOLOGIES 2022

The gaseous CO2 streams recovered at the decanterand regenerator overhead are cooled down to recovercondensed water before being mixed and routed at battery
limit under pressure. The DMX™ process has alreadyundergone 10 years of development from laboratory scale
to global optimisation in the power and steel industries andhas now reached Technology Readiness Level 4 (TRL4).
The technology now requires to be demonstrated atindustrial scale in order to be commercialized by Axens. It
will be done through the 3D Project that intends to build
a demonstration unit at the steel mill of Arcelor Mittal in
Dunkirk located in the north of France. This project will also
study the full-scale CO₂ capture, conditioning, transportand storage of 1 Mtpa CO₂ from blast furnace gas. This
project will contribute to the development of a CO₂ hub
located in Dunkirk and connected with the storage facilities
like those foreseen with the Northern Lights (or Longship)
Project supported by the Norwegian government.
The demonstration plant with a capacity of 0.5t CO₂
captured/h has been delivered by Axens at the end of 2021
at Arcelor Mittal’s steel mill in Dunkirk. The operation of thedemonstration plant will start in Q2 2022 and is expectedto last until mid-2023.
Additional information is available at the following web
address: https://3d-ccus.com

Nadège Guernalec
Email:

nadege.guernalec@axens.net

Web:www.axens.net

CONTACTNEXT GENERATION SOLVENT-BASED CARBON CAPTURE TECHNOLOGYC CAPTURE

Phil Southerden
Email:

p.southerden@c-capture.co.uk

Web:www.c-capture.co.uk

BENEFITS•

Significantly reduced process energy requirements (1.5-1.8 GJ/t CO2) due to low steam requirements and reduced
costs of compression due to higher CO2 release pressure•

Environmentally benign solvent manufactured from nitrogen/amine-free biodegradable components•

High tolerance to impurities, including O2, SOx and NOx, reducing the need for feed-gas pre-cleaning•

Reduced solvent management costs due to high thermal, chemical, and oxidative stability, and low volatility, minimisingsolvents losses per tonne CO2 captured•

Low levels of environmentally benign emissions due to low volatility of solvent components and low rate ofdegradation product formation•

Reduced operations and maintenance costs due to less corrosive solvent

SUMMARY
C-Capture has developed the world’s most energy-efficientsolvent technology for carbon capture that delivers stepchange performance-improvements over the current stateof-the-art whilst being robust enough for use in even themost challenging of industrial applications.
C-Capture’s novel solvents are based on salts of simple
organic acids, representing a new paradigm in carbon
capture technology. When compared to traditional, aminebased technologies, this alternative approach to thechemistry of carbon capture, in combination with tried andtested engineering concepts, delivers significant benefits
to customers including lower overall cost of capture, lower
O&M costs, lower environmental impact, easier permitting,and lower solvent management costs.
The low cost of capture for C-Capture’s technology isderived from the reduced energy demand of the process.
In addition, C-Capture’s solvent components are all
highly thermally stable, meaning that higher desorbertemperatures can be achieved, creating far greater CO2
pressures on its release, and reducing the compression
energy to prepare CO2 product for transport and storage.
C-Capture’s biodegradable solvents are environmentallybenign, both inside and outside the capture plant.
Manufactured from simple, readily available commodity
chemicals, the solvents exhibit lower corrosivity thancompeting amine-based solvents, thus reducing the need

28

STATE OF THE ART: CCS TECHNOLOGIES 2022

for expensive, high-grade materials of construction andminimising the need for expensive plant maintenanceshutdowns.
C-Capture’s technology is suitable for a wide range ofindustrial applications including, but not limited to, biomass-,coal-, waste-, and gas-fired combustion processes, cement
and lime manufacture, hydrogen production, biogas andnatural gas refining, and even industrial applications thatmight normally be considered too hard to abate withamine-based solvents such as glass furnaces, and iron andsteel production. These latter applications are possible as aresult of high chemical stability of C-Capture’s solvents, aswell as their high selectivity towards CO2, which minimises
the scope for solvent degrading side reactions.
C-Capture’s
technology
has
been
successfully
demonstrated at a range of locations on various
applications, including biogas and landfill gas upgrading,and biomass fired post-combustion capture at Drax Power
Station, N. Yorkshire, UK and on SINTEF’s world-renowned
pilot facility at their CO2 Laboratory in Tiller, Norway.
Building on these successes, C-Capture is now working
to design and build an intermediate scale demonstration
plant on a waste wood gasification process, as well as aseries of engineering feasibility studies across a variety ofindustrial sectors, one of which will be selected to go on to
be the first full-scale, commercially operated demonstrationof the technology.

C-Capture’s BECCS pilot plant operating at Drax Power Station, N. Yorkshire, UK

DESCRIPTION
CCS is widely recognised as an essential component of
any credible path to net-zero carbon emissions by 2050. To
roll out CCS broadly enough to meet this target, affordable
technologies, which are applicable across industry andenergy generation are required. The perennial nascencyof the carbon capture industry is, in part, a consequenceof today’s state-of-the-art not meeting these affordability
and applicability criteria, and therefore, more innovation isrequired. It is this innovation gap that C-Capture’s technology
has been developed to address.
The core of C-Capture’s technology is their family of uniquesolvents, based on a fundamentally new approach tocarbon capture chemistry, deployed into well known, tried
and tested engineering concepts and unit operations. This

combination of highly innovative solvent technology andindustry standard process engineering, reliably delivers
C-Capture’s distinctive commercial, environmental, andoperational benefits.
To date, the step-change performance improvements of
C-Capture’s technology have been demonstrated in theirlaboratories in Leeds, UK, and validated through small-scalebiogas and landfill gas upgrading trials, and via pilot plant
trials on biomass derived flue gas at Drax Power Station,
N. Yorkshire, UK and SINTEF’s 1 tpd pilot plant in their CO2
Laboratory at Tiller, Norway (vide infra).
One of the key disadvantages associated with the state-ofthe-art amine-based technologies is the significant energy
penalty of the process; a parasitic load of 2.5 GJ/tonne CO2

CONTACTNEXT GENERATION SOLVENT-BASED CARBON CAPTURE TECHNOLOGYC CAPTURE

Phil Southerden
Email:

p.southerden@c-capture.co.uk

Web:www.c-capture.co.uk

DESCRIPTION CONT.
captured or greater is typical. In a like-for-like comparison
with other commercially available solvent technologies,
C-Capture can deliver energy penalty reductions of up to
40%, with significant gains made from the reduced enthalpyof the capture reaction lowering the energy input to release
the CO2, lower solvent volatility reducing losses to vapours,
lower heat capacity of the solvent improving the efficiencyof heat integration, and increased CO2 release pressure
reducing the compression energy demand.
There are additional benefits to eliminating amines from
C-Capture’s solvents, over and above reducing the energy
penalty of the process. One is that the corrosivity of thesolvents is much reduced, cutting the costs of essential plantmaintenance and opening up the possibility of using lessexpensive materials of construction.
Recognising the enormous scales at which CCS will need
to be deployed, C-Capture’s solvent has been designed
for minimal environmental impact. To that end, only
biodegradable components are used in the manufacture of
C-Capture’s solvent, potentially problematic elements, suchas nitrogen or sulphur, have been engineered out (which has
the added benefit of making end-of-life disposal significantly
cheaper and easier), and technologies have been identified
which will allow the petrochemicals in the solvent supply
chain to be reduced, or phased out altogether, in favour ofbio-derived feedstocks. A future for C-Capture where CO2
captured at one site is used to make the solvent to capture
more CO2 at another site is planned.
A crucial benefit of C-Capture’s technology is that it is a
new concept in carbon capture chemistry, not just a minor
variation on what has come before. This has allowed theirchemists to design to a range of criteria, not just maximising
CO2 capture rate or capacity. One such criterion has been
to maximise the robustness of the solvents, particularly
towards more challenging flue gases with high levels ofreactive impurities from industries, which are normallyconsidered hard to abate such as glass, or iron and steel.
In all tests, C-Capture’s designed-to-be-robust solvent has
shown significantly reduced degradation which will translate
to lower solvent management costs at full scale.

This built-in robustness is attracting the attention of arange of partners across challenging applications where
C-Capture’s technology will not only reduce costs, butsometimes open the door to deploying carbon capture
at all. Since extraordinary claims require extraordinary
evidence, C-Capture is deploying a series of Carbon
Capture Solvent Compatibility Units (CCSCUs) across these
sectors through 2022/23 to gather the data to back up theirclaims of solvent resilience and performance stability insuch challenging applications. For C-Capture, their partners,
and their customers, this is recognised as critical to de-risk
future projects and investments in CCS at commercial scale,and deliver the cost reductions required to decarbonise allindustry sectors.

Additional work at SINTEF’s CO2 Laboratory pilot plantat Tiller, Norway has further confirmed compatibility of
C-Capture’s solvent with biomass flue gas. For those trials,
the burner which provided the flue gas for the trials was
fuelled with Drax’s biomass pellets. A parallel campaign
was run using 30%w/w aq. MEA as a baseline to allow
like-for-like comparisons to be made. The trials confirmed
the lower emissions profile even with particulates present,
the reduced rate of solvent degradation, and the reduced
energy penalty of C-Capture’s solvent.
C-Capture has recently completed the design of anintermediate scale demonstration plant for Ince Bio Power,
owned by Bioenergy Infrastructure Group, in Cheshire,
UK. The project is a critical steppingstone in scaling up
the technology. It has developed significant learnings

BECCS Piloting
A critical element of the net-zero concept is that of negativeemissions to offset those from activities which are too hardto decarbonise in the short or even medium term. One
such path to negative emissions is BioEnergy with Carbon
Capture and Storage (BECCS) whereby the CO2 absorbed
by biomass during its growth is released when the biomass
is combusted, then captured and stored.
Drax Power Station, N. Yorkshire, is the UK’s largest power
station, and has converted four of its boilers to run on 100%
biomass. In 2019 Drax was the first company in the world toannounce its ambition to become carbon negative by 2030,
by deploying BECCS. C-Capture’s technology is one ofthose being evaluated to deliver this ambition.
C-Capture’s BECCS pilot plant at Drax has been operational
since February 2019, and has confirmed the compatibilityof the solvent with its biomass flue gas, and validated thelow rate of solvent degradation and low environmental
impact of the process. C-Capture’s latest, fully integrated,
protype capture plant will begin operating at Drax in 2022,
to demonstrate optimised process engineering designed tomaximise the unique benefits of the solvent technology.

One of C-Capture’s Carbon Capture Solvent Compatibility Units

30

STATE OF THE ART: CCS TECHNOLOGIES 2022

in constructability of the plant, and has supported theinnovative development of a semi-modular approach toconstruction strategy. This will support further explorations
towards pre-assembled modular approach for future plantdesigns.
In summary, C-Capture’s technology offers step-change
performance benefits which address many of the limitationsof current state-of-the-art solvent technologies. Thesetranslate into specific value propositions for customers
including lower energy demand, operating costs, andenvironmental impact, and the potential to deploy acrossa far wider range of industrial applications. C-Capture hasdeveloped the carbon capture technology needed for theworld’s net zero targets to be achieved.

CONTACTDIRECT AIR CAPTURECARBON ENGINEERING

Email:

info@carbonengineering.com

Web:

www.carbonengineering.com

DESCRIPTION
DAC technology captures CO2 by pulling in atmosphericair. Then, through a series of chemical reactions, CO2 isextracted from the air while returning the rest of the air tothe environment. DAC is a different, and complementary,technology to “carbon capture and storage”, whichremoves CO2 from industrial flue gas instead of theatmosphere.
CE’s DAC technology approach is focused on achieving
large, industrial scale at an affordable price. To achievethis, CE’s DAC process uses chemical reactions and aclosed loop system to absorb CO2 from the air, using thesame chemicals over and over to minimize waste andconsumables. CE’s solution borrows existing and widelyused equipment and processes from other industries, andinnovates and integrates them to deliver a DAC systemwith low scale-up risk, known supply chains, and reliableequipment costs.

SUMMARY
Direct Air Capture (DAC) is a technology that captures
carbon dioxide (CO2) directly from the atmosphere with amechanical system. This is similar to how trees absorb CO2
for photosynthesis, except that DAC does it much faster,with a much smaller land footprint, and delivers the CO2
in a pure, compressed form. The captured atmospheric
CO2 can then be permanently and safely stored ingeologic reservoirs to deliver negative emissions, or used
to produce low carbon intensity products, such as fuels
including diesel and aviation fuel that work in existingvehicles and infrastructure.

For more than a decade, Carbon Engineering (CE) has
pioneered a liquid sorbent-based DAC system optimized
for scale. Today, alongside industry-leading development
partners, CE is working to deploy large-scale commercial
facilities globally. Industrial facilities that use CE’s DAC
technology can be built in one or more modules, eachcapable of capturing 0.5 Mtpa CO2.

There are a number of uses for atmospheric CO2 captured
through DAC, but CE is focused on delivering solutions for
two types of industrial facilities:
1.

DAC and sequestration plants combine DAC
with secure geologic storage of CO2 to deliver thepermanent and verifiable removal of CO2 from theatmosphere. This provides a mechanism to help

difficult-to-decarbonize sectors, such as aviation,
address their emissions faster and at a lower costthan many existing mitigation solutions. In the future,
in a post net-zero world, these same facilities could
be used to address legacy emissions, creating an
opportunity for climate restoration.
2. AIR TO FUELS™ plants capture atmospheric CO2
and combine it with green hydrogen to produce low
carbon intensity fuel that is drop-in compatible withexisting vehicles and infrastructure. In addition to fuel,atmospheric CO2 can also be used to produce otherlow carbon intensity products, such as concrete andchemicals.
To enable rapid and widespread deployment of DAC
solutions, CE licenses its technology to development
partners around the globe so multiple plants can be built
in parallel. The first commercial facility to use CE’s DAC
technology is being developed in the United States by
1PointFive. With construction expected to begin in 2022,
the facility is expected to be capable of extracting one Mtpa
atmospheric CO2 once complete. This facility provides
a blueprint for global projects, supporting the design ofadditional facilities already progressing in multiple markets
around the world.

BENEFITS
Key features of CE’s DAC technology include:•

Scalable – CE’s technology can be built in 0.5 Mtpa CO2 modules to capture millions of tonnes of atmospheric CO2
annually using known equipment with industrial precedent.

•

Affordable - Peer-reviewed research published in Joule Journal (2018) showed how CE’s technology could achieve
capture costs of below US$100 per tonne at megatonne-scale.

•

Freedom of location - Facilities can be built on non-arable land, avoiding competition with agriculture and other land
use priorities.

•

Transition ready – Existing equipment, supply chains and workforce skillsets will be in demand as the world builds thisnew, clean infrastructure. Each project is expected to create thousands of construction jobs and hundreds of steadystate operations jobs.

Carbon Engineering’s Innovation Centre and Advanced Development Headquarters located in Squamish, Canada.

32

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACTCYCLONECC™

CARBON CLEAN

Laura Gillions
Email:

communication@carbonclean.com

Web:

www.carbonclean.com

I - State of the Art: CCS Technologies 2022
BENEFITS
CycloneCC™ is a breakthrough modular technology that brings carbon capture within reach of more companies than everbefore. Its benefits include:eCC

n Cleanary (up to 400 words)

Clean a global leader in cost-effective industrial carbon capture technologies and.

artered in the UK, we are focused on helping industries achieve their net zero
SUMMARY
by reducing
the cost of carbon capture.
Carbon Clean is a global leader in cost-effective industrial
Built on a pre-fabricated skid mount, every CycloneCC™
carbon capture technologies and services.

unit will be delivered ready to install and with the potential

er a decade of experience designing, building, financing
andinoperating
industrial
to be operationalless than eightweeks, avoiding a
Headquartered in the UK, we are focused on helping
lengthyandcomplexdesign,build
and engineering
apturehard-to-abate
systems,industries
we areachieve
workingwithleading
their net
zero targets
by industrial companies globally toprocess. There is minimal disruption to operations and thecost of carbon
capture. With over a decade ofnt our reducing
carbonthecapture
solutions.
safety risks onsite are significantly reduced.

experience in designing, building, financing and operating
industrial carbon capture systems, we are working with
As a compact, modular scalable solution, it also allows
on is atleading
the heart
of
all
we
do
and
we
are
dedicated
to todevisingsolutionsthattime
willin line
industrial companies globally to implement ourcompanies
increase CCUS
capacity overcarbonsolutions.adoption
Innovation is ofat theheart of capture.
allwith their decarbonisation strategies. In terms of resources,e barriers
tocapture
the masscarbonwe do, and we are dedicated to devising solutions that willenergy, time, and space, CycloneCC™ is changing theovercome barriers to the mass adoption of carbon capture.
landscape of carbon capture.
we launchedabreakthroughtechnology
that
will
revolutionise the sector –In 2021, we launched a breakthrough technology that will
For many industrial companies, carbon capture will no
revolutionise the sector – CycloneCC™.
CC.
longer require a massive infrastructure project – instead
It is a fully modular carbon capture solution that addresses
your carbon capture unit will arrive and be up and running
two major concerns from industries who are consideringin a matter of weeks. CycloneCC™ is a ground-breaking
odular carbon
carboncapture solution that addresses two
major concerns from industries
capture – cost and space. CycloneCC™ uses
solution that makes carbon capture simple, accessible, andconsidering
carboncombination
captureof– twocostprovenand process
space. affordable.
a breakthroughintensification technologies: Carbon Clean’s advanced,“Carbon Clean’s innovative new technology will help makeproprietary amine-promoted buffer salt solvent (APBSthe widespreadindustrial adoptionof carbon capture a
C uses aCDRMax®)
breakthroughcombination of two proven processintensification
technologies:
and rotating packed beds. As a result, thereality,” said Greg Hands, UK Minister of State for Business,lean’s advanced,
proprietaryamine-promoted
buffersalt solvent (APBS-CDRMax®) andphysical footprintof CycloneCC™
is up to 50% smaller than
Energy and Clean Growth.”
conventional carbon capture units and CapEx and OpEx
packed beds.
costs are also reduced by 50%.

lt, CycloneCC has a more than 50% reduction in footprint than conventional carbon capture.
d OpEx costs are also reduced by up to 50%, bringing the cost of carbon capture down toonne on average.

STATE OF THE ART: CCS TECHNOLOGIES 2022
34
a pre-fabricatedskid mount, every CycloneCC unit will be delivered ready to install and withntial to be operational in less than eight weeks, avoiding a lengthy and

GCCSI - State of the Art: CCS Technologies 2022
CycloneCC•

Cost-effective carbon capture - CapEx and OpEx are reduced by up to 50%•

Compact size – mass transfer equipment is 10 times smaller, and its overall physical footprint is up to 50% smaller thanconventional carbon capture units•

Modular and scalable – units are stackable and can be added over time to increase carbon capture capacity in linewith a company’s decarbonisation strategy•

Simpler and safer installation - the pre-fabricated, skid-mounted unit is delivered ready to install and can be operationalin less than eight weeks, with minimal site disruption and faster permitting

CONTACTCYCLONECC™

CARBON CLEAN

Laura Gillions
Email:

communication@carbonclean.com

Web:

www.carbonclean.com

DESCRIPTION
Carbon Clean has been providing innovative carbon
capture technology and services across a range ofindustries for over a decade. We offer technology licenses
and solvent supply, a full process design package andproprietary equipment, and end-to-end systems —including designing, building, financing and operation.
We installed the world’s first commercial CCUS plant at
Tuticorin Alkali Chemical and Fertilizers Ltd. in India andour technology is now operational at 44 sites across North
America, Europe and Asia.
Our next generation technology is designed to integratewith existing industrial operations for minimal disruption
and maximum cost-effectiveness. We enable hard-to-abate
industries to not only reach net zero, but also leverage
decarbonisation incentives and join the growing global
circular carbon economy.
Scaling up CCUS is essential to achieving global net zerotargets, but several barriers have prevented widespread
adoption, in particular cost and onsite space restrictions.
For example, a survey of hard-to-abate industries
conducted by Decarb Connect – Scaling up CCUS –market insights – found that space remains a major
concern and that industries need to be able to integrate
carbon capture solutions within their existing facility.
Most industrial sites are already optimised in terms oflayout, and traditional carbon capture solutions can almost
be as big as some of the plants already on site. Therefore,
a reduced physical footprint is critical to making carbon
capture viable for more sites.

Process intensification technologies
The two process intensification technologies are Carbon
Clean’s advanced, proprietary amine-promoted buffer salt
solvent (APBS-CDRMax®) and rotating packed beds (RPBs).
The solvent and RPBs are well-established technologies
which, when combined, enable CycloneCC™ to be morecost and space-efficient than conventional carbon capture
technology while matching the performance.
Our APBS-CDRMax® solvent has been formulated to
optimise carbon capture performance using fast-reacting
amines and high-capacity salts. The solvent chemistry
allows for rapid removal of carbon dioxide from fluegases with CO2 concentrations ranging between 2.5-25
vol.%. The solvent has greater stability, lower corrosivity
and lower regeneration energy requirements than thebenchmark amine.
The absorption process is further improved using the RPB
absorber, which contains a disk of packing material thatrotates about its axis. This generates a centrifugal force
within the packing, which enhances the CO2 absorption
process. Essentially, the solvent and flue gas move pasteach other more rapidly allowing for a higher rate of masstransfer.
This enhancement of the absorption process results in
10 times less volume, and therefore, a corresponding
reduction in equipment size to achieve the same
performance as the conventional options.

Our latest innovation – CycloneCC™ – addresses thesebarriers. As a modular, pre-fabricated and skid-mounted
carbon capture solution, CycloneCC™ reduces the overall
cost of carbon capture by up to 50% – bringing it withinreach of many more companies.

The solvent is introduced into the RPB at its centre, where
it is sprayed on to the packing via a liquid distributor. Whenthe solvent contacts the packing, the centrifugal force
applied to the solvent from the rotational motion forces
the solvent to travel radially towards the outer edge ofthe packing where it drains down to a sump before being
pumped to the next stage of the process.

Using a breakthrough combination of two processintensification technologies, CycloneCC™ has a physicalfootprint that is up to 50% smaller than conventional
carbon capture units and can be installed in less than eightweeks.

The flue gas is introduced to the RPB from the outer edgeof the packing and exits at the inner edge, where thesolvent enters. The gas and the liquid contact each other ina counter-current fashion, ensuring maximum contact andgreater absorption.

The CO2 that is present in the flue gas selectively reacts
with the active components in the solvent, temporarily‘locking’ the CO2 in the solvent.

capture carbon from several point sources – as a compact
and modular solution it can be installed at multiple
locations across a site.

RPBs are ideally suited to carbon capture as they canhandle very high gas and liquid volumes. We have beenworking with academic and industry partners in the UK and
US to test and develop the potential of RPBs.

Next steps for CycloneCC™

Wide ranging benefits
CycloneCC™ is set to revolutionise carbon capture anddeliver huge benefits to industries that have limited options
to decarbonise.
Apart from its radical reduction in size and up to 50%
reduction in both the CapEx and OpEx, it offers incredible
flexibility to companies that are on a decarbonisation
pathway. As a modular, scalable solution, it uses
standardised designs that allow companies to add units
in line with their decarbonisation trajectory, phasing theinvestment required to achieve their goals.
Built on a skid mount, each CycloneCC™ unit will bedelivered ready to install and can be fully operational inless than eight weeks. This minimises site disruption andsafety concerns, as well as facilitating faster permitting.
The technology is particularly suitable for use with small
to mid-size emission point sources. It can also be used to

Cyclone CC Plant Block Flow Diagram

36

STATE OF THE ART: CCS TECHNOLOGIES 2022

GCCSI - State of the Art: CCS Technologies 2022
CycloneCC

CycloneCC™ has been successfully pilot-tested at 1 tonne
CO2 per day (TPD) and is currently being commercialised
at 10 TPD and 100 TPD with select partners, including
CEMEX, Chevron and Veolia. For example, CEMEX has
announced a project at its Rüdersdorf plant in Germany to
use CycloneCC™ technology to capture 100 TPD of CO2,
before increasing the carbon capture by an additional 300
TPD. The plant is expected to be operational by 2026 anda study will also be completed to investigate how to scale
up to 2,000 TPD of CO2.
With Chevron, we are seeking to develop a carbon capture
pilot using CycloneCC™ on a gas turbine in San Joaquin
Valley, California. While, with Veolia, we are integrating
CycloneCC™ technology into its energy recovery facilities
in the UK. CycloneCC™ has also received some Royalattention in the UK – HRH The Prince of Wales saw it onsite at Doosan Babcock’s Emissions Reduction Test Facility
in Renfrew, Scotland, while at COP26. Our intention is tomass produce CycloneCC™ units to meet global demandand deliver the huge increase in the scale and pace of
CCUS adoption across industry that is required to reachnet zero.

CONTACTCAPSOL EoP™

CO2 CAPSOL

Capsol EoP
CO2
CAPSOLTM

CO2 CAPSOLAS
Capsol EoP

Tone Bekkestad

CONTACT

Email:

Tone Bekkestad

Web:

Chief Marketing Officer

tone.bekkestad@CO2capsol.com
www.CO2capsol.com

CONTACT
Tone Bekkestad

TM

Chief Marketing Officer

CO2 CAPSOL AS

BENEFITSBENEFITS OF Capsol EoPTM

CO2 Capsol has a large portfolio of patents, developed over a 15-year period.

Ca ps ol has a l arge portfolio of patents, developed over a 15-year period.

•

Cost
Competitive: Theenergyenables lowest carbon capture costs and flexibility to monetiseTM
BENEFITS
OFpatented
CapsolEoPre-circulationheat
and/orelectricity
fromthecaptureunit.
• COST COMPETITIVE: The patented energy re -circulation enables low ca rbon capture costs a nd flexibility to monetise heat and/or
Ca ps ol has a l arge portfolio of patents, developed over a 15-year period.
el ectricity from the capture unit.

•

Safe, Non-Carcinogenic Solvent, Free of Harmful Emissions: The use of Hot Potassium Carbonate (HPC) is non-toxic,

non-flammable,
environmentallyfriendly.
• SAFE, NON-CARCINOGENICSOLVENT: Thenon-carcinogenic
solvent Hot Potassium andCa rbonate(HPC) is non -toxic,
non-flammable, non-carcinogenic
a nd envi ronmentally fri endly.• COST COMPETITIVE: The patented energy re -circulation enables low ca rbon capture costs a nd flexibility to monetise heat and/or
el ectricity
the capture
unit. Capsol EoP™ unit can process flue gas from plants with emissions of up to 2.5 Mtpa
• Flexible
Andfrom
Scalable:
A single• FLEXIBLE AND SCALABLE:
ingle Capsol
EoPTM
unit can process flofue gasfromTwoplantsorwithemissionof up to2.5 miunits
llion will operate in parallel for facilities withflue gas
concentrations
20%).
more
CapsolEoP™
COA2• s(with
SAFE, NON-CARCINOGENIC
TheEoPTM
solventunits
Hot Potassium
Cainrbonate
is non -toxic,
tonnes/year, wi th flue gas CO2
concentrationsof 20%. Two orSOLVENT:
more Ca psol
will operateparallel(HPC)
for facilities
with non-flammable, non-carcinogenic
emissionsofmore than
2.5 Mtpa.
nd environmentally
fri endly.
emi ssions of more than 2.5 miallion
tonnes/year.

Capsol EoPTM – THE FUTURE TECHNOLOGY FOR ALL EMITTERS – NEW
CAPSOLEoP™ -STREAMSTHE FUTURETECHNOLOGYENABLINGCOSTSNEW REVENUE STREAMS AND
REVENUE
WITH
LOWEST CAPTURE
LOWEST CAPTURE COSTS FOR ALL EMITTERS• Minimals ystemisnoexternal
PlantcanImpact:The systemcanberun sonelectricity
only.
AND
A s ingleonly.
CapsolEoPTM
canprocess flNo
uemodification
gasTherefrom plants
withemissionsteam
of up torequired.
2.5 mi llion No modification• MINIMAL PLANT IMPACT: •TheFLEXIBLE
beSCALABLE:
run on electricity
There
is nounit
team
required.
needed.
tonnes/year, wi th flue gas CO2 concentrations of 20%. Two or more Ca psol EoPTM units will operate in parallel for facilities withneeded.
emi ssionsof more than
2.5 mifrom
llionthetonnes/year.
• EXPERIENCED TEAM: Technicala nd commercial
experts
Energy, Chemical a nd Oi l&Gas industry, with 25+ years’
experience.

CO2 Capsol has developed
and offers
theTM
environmentally
release itsTECHNOLOGY
high CO2 content to the FOR
steam flow.
TheEMITTERS
pure CO2
CapsolEoP– THE FUTURE
ALL
– NEW
friendly, non-carcinogenic, energy-efficient, and affordable leaves the top of the desorber, from where it can be liquified
REVENUE
WITH
LOWEST
carbon capture technology
Capsol EoPTMSTREAMS(End of Pipe), forand further
processed.CAPTURE
The lean solventCOSTS
is led back to the top
large
scale
emitters
like
Waste-to-Energy,
biomass,
cement,sectionof
theabsorber.
SUMMARY
CO2 Capsol has developed and offers the environmentally release its high CO2 content to the steam flow. The pure CO2
power plants and industrial facilities. Capsol EoPTM utilises
friendly, non-carcinogenic, energy-efficient, and affordable leaves the top of the desorber, from where it can be liquified
desorber,
where
theHPC
partial
CO2 theCapsolhasdeveloped
and offers
an environmentally
is low, forcing
thesafe and proven Hot Potassium
Carbonate(HPC) solvent. Carbon
captureusing
hasCO
severaladvantages.
In
2 pressure
carbon capture technology Capsol EoPTM (End of Pipe), for and further processed. The lean solvent is led back to the top
additiontobeing
environmentallyfriendly
and
safe,
it
is
friendly, non-carcinogenic,large
energy-efficient,affordable
solvent
tocement,
release its
highofCO
2 content
scale emitters andlike Waste-to-Energy,
biomass,
sectiontheabsorber.to the steam flow.
HPCcapture
as a solventof CO2 Capsol
is well documented
andPipe),used forin energy-efficient,flexible,and cost competitive. Fur ther more,carbontechnology
EoP™
of
The EoPTM
pure CO
2 leaves the top of the desorber, from where it
power plants
and(Endindustrial
facilities. Capsol
utilises
thousands of plants globally in multiple industries. However, it prevents potentially carcinogenic degradation products
the safe and proven(EfW),
Hot Potassium(HPC)
solvent.andCarbon
usingThe
HPC
severalis advantages. In
large scale emitters like energy-from-waste
biomass,Carbonate
can beliquifiedfurther capture
processed.
leanhassolvent
until recently, using HPC in post combustion carbon capture and harmful emissions, both in the lean flue gas and the
additionoftothe
being
environmentally friendly and safe, it iscement,power
plantsandindustrial
facilities.
Capsol
EoP™
led
back
to
the
top
sectionabsorber.
processes from flue gas was discarded as a viable option, due captured CO2. In addition, it is low-cost (approximately EUR
HPC asa solventof CO2is well documented and used in energy-efficient, flexible, and cost competitive. Fur ther more,utilises
the energy
safe demand.
and proven
Hot
Potassium
Carbonate
to high0.3/ton of CO2 captured) and non-proprietary.
Carbon However,
capture itusing
CapsolEoP™carcinogenic
has several
thousands of plants globally in multiple industries.
prevents
potentiallydegradation products(HPC) solvent.
until recently, using HPC in post combustion
carbon captureand harmfultoemissions,bothin the lean flue gas and theadvantages,
inaddition
being
environmentally
To overcome this challenge, CO2 Capsol has developed the Capsol EoPTM can be run on electricity-only or utilise excess
processesCO
fromisflue
gas was discarded as afriendly
viable option,
due itcaptured
CO2. In addition, it is low-cost(approximately EUR
well-documented
HPC Capsol
as an absorption
safe,
EoPTM (End solventof Pipe)oftechnology– a standalone, steam
from andthe host
plant,isif energy-efficient,available. Hence, noflexible,
need forand cost
2
to
high
energydemand.
0.3/tonof
CO2
captured)and
non-proprietary.
retrofit unit, with a patented energy r e-circulation process potentially costly investment in external steam production or•Experienced Team: Technical and commercial experts from the Energy, Chemical and Oil&Gas industry, with 25+ years’• MINIMAL PLANT IMPACT: The s ystem can be run on electricity only. There is no s team required. No modification needed.
experience.
• EXPERIENCED TEAM: Technical a nd commercial experts from the Energy, Chemical a nd Oi l&Gas industry, with 25+ years’
experience.

and used in thousands of plants globally in multiplecompetitive. Furthermore, it ensures the absence of
which offers
low capture
and theusing
flexibility
to monetisereconstructionof the existingdegradation
plant. Additionally,
Capsolindustries.
However,
untilTocost
recently,
HPC
for
post
potentiallycarcinogenic
products
and harmful or utilise excess
overcome this challenge, CO2 Capsol
has offers
developed
CapsolEoPTM
can beelectricity-only
heat and electricity.
EoPTM
great theflexibility
for theoperation
ofrun
theon
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from
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in
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Capsol EoPTM (End of Pipe) technology
steam fromhost plant,
if available.CO
Hence,
no need for2.
plant – –a standalone,
optimizing either
for theminimum
electricity
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unit,
with
a
patentedenergyre-circulation
process
potentiallycostlyinvestment
inexternal
steam
as a viableoptionoverview
due to high(and inhence
In addition,is low-cost(absorbent
consumption cost production or
A simplifiedof theenergy
processdemandis presented
the consumption,or HPCto generate
additional
valuable heat.
offerscost andtothe flexibility
to monetiseEUR
reconstructionof captured).
the existing plant. Additionally, Capsolcost).figure to the right. The whichof approximately
0.3/ton of CO
CO2 richfluelow
gascapture
is compressed2heat andaround 5-8 bara (depending
onelectricity.
the CO2 concentration)

EoPTM offers
flexibility
for the operation of the capture
For CO2 Capsol, carbon capture
is not great
only about
capturing

plant
optimizing
either intoforminimum electricity
To solve
problem,
CO2 Capsol
developed
the carbon,
CapsolEoP™thecan
be integration
run– onelectricity-onlyor utilise
beforethis
it enters
the bottomof the has
absorber,where thebut also
optimalof our solutionA
simplified
overview
oftheprocessispresented
intheconsumption,ortogenerate
additional
valuable heat.
CapsolEoP™ (Endof reacts
Pipe) withtechnology– a flow
standalone,
steam
fromtothe
hostcomplexity
plant, if andavailable.
pressurised
flue gas
the downward
of HPC. theexcess
host plant’s
processes
decreasecreate Thus,
figuretotheright.
The
CO2
rich
flue
gas
is
compressed
to
Theunit,leanwithflue gasleaves theenergy
absorberre-circulation
column at the process,top. The new
for the industrial
emitter.
retrofita patented
a revenue
costly streams
investment
in external
steam production oraround5-8 baraat(depending
onisthe CO2 concentration) For CO2 Capsol, carbon capture is not only about capturingrichlowsolvent
leavestheabsorberthetobottom,
whichCO2
offerscapture
cost
and
the
flexibility
monetisethereconstructionoftheexistingplant
is notrequired.
beforebottomwhereof the absorber, where the carbon, but also the
optimalintegrationof our solution into
depressurised, and led into
the ittopentersof thethe
desorber,heat and
electricity.
Additionally,
CapsolEoP™
offersgreat
flexibility
forthepressurised
flue
gas
reactswiththedownward
flow
of
HPC.
the
host
plant’s
processes
todecreasecomplexity
and create
the partial CO2 pressure is low, forcing the sorbent tooperationof Thethe capture
plant– optimisingeitheremitter.
for
The lean flue gas leaves the absorber column
at the top.
new revenue
streams
for the industrial
A simplified overview of the process is presented in theCO2 rich solvent leaves the absorber minimumat the bottom,
is consumption, or for maximised internal
electricity
is compressed
to of the desorber, where
figure to the right. The COdepressurised,
2 rich flue gas
and
led into the top
heat generation, for example for district heating.
around 5-8 bar(a) (dependingon theCO2
COpressure
the partial
is low, forcing the sorbent to
2 concentration)
before it enters the bottom of the absorber, where the
For CO2 Capsol, carbon capture is not only about capturing
pressurised flue gas reacts with the downwards flowing
carbon, but also the optimal integration of our solution into
STATE OF THE ART: CCS TECHNOLOGIRS IN 2022
solvent. The lean flue gas leaves the absorber column
the host plant’s processes to decrease complexity andat the top. The CO2 rich solvent leaves the absorber atcreate new revenue streams for the industrial emitter.
the bottom, is depressurised, and led to the top of the
STATE OF THE ART: CCS TECHNOLOGIRS IN 2022

38

STATE OF THE ART: CCS TECHNOLOGIES 2022

CO2 CAPSOLCONTACTCAPSOL EoP™

CO2 CAPSOLDESCRIPTION
Optimisation of Capasol EoP™
The Capsol EoP™ process uses electricity for runningthe main flue gas and steam compressors in the system.
In addition to this, it utilizes the energy contained in theincoming flue gas.
The heat recuperation system manages to efficiently
produce 1.3 bar steam out of 75 to 90 °C water by heatpumping. Process waste heat from the parent plant at
temperatures above 75 °C may be used in the Capsol EoP
plant (optimised for minimum electricity consumption) to
decrease the energy demand of the overall system. Whenthe capture plant is optimised to supply a district heating
network, a minimal increase of electricity consumption can
result in a significant output of valuable energy in the formof heat. In addition, the Capsol EoP™ solution can profitably
make use of energy from the CO2 compressor intercoolers(in the liquefaction plant) at temperatures above 75 °C in
the energy recuperation.
Depending on the temperature, the energy in the fluegas entering the Capsol EoP™ unit can also be used in
the Capsol EoP™ heat recuperation. This is also an area of
optimisation for each specific case.
Whether to optimise for lowest electricity consumption or
maximum heat into the district heating system is analysedfor each specific plant based on close dialogue with theplant owner.

40

STATE OF THE ART: CCS TECHNOLOGIES 2022

Investment cost of equipment for a capture plant –CapEx and OpEx
Investment cost is project specific, however the following isprovided as an example.
Main factors affecting the CO2 capture costs is the costof energy used in the capture process and the CO2
concentration in the flue gas.
The capital cost for capturing 0.4 Mtpa CO2 from anindustrial facility or incineration plant with flue gas
concentration of 15% CO2 will be within the range of EUR
40 million, excluding any civil works and liquefaction of
CO2 for export.
In a recent study, the total OpEx was estimated to bewithin the range of EUR 15-18 per tonnes of captured CO2(excluding compression and liquefaction of CO2 for export).
CapsolGo™ – Affordable demonstration of safe carbon
captureCapsolGo™ is the answer to the many challenges ofindustrial emitters, who consider investing into a full-scalecarbon capture plant. CapsolGo™ is a small-scale carbon
capture demonstration unit for industrial facilities such asenergy-from-waste, biomass, cement, and power plants.
CapsolGo™ consists of two, easily deployable, shipping
containers, stacked on top of each other, to minimize
footprint. The unit is easy to install. The only infrastructure
required is electricity, compressed air, demineralised water,and of course, the flue gas. The captured CO2 can be fed
back to the flue gas stack, or it can be compressed todemonstrate utilization options.

CapsolGo™ comes with an all-inclusive package: transport,
installation, deinstallation, operation, and testing by anindependent party. CapsolGo™ offers many advantages forindustrial emitters, including:1.

Experience the CO2 Capsol’s energy-efficienttechnology to verify the effectiveness of the Capsol
EoP™ technology before investing into a full-scale
application.

2.

The Capsol EoP™ technology utilises the proven,environmentally friendly solvent potassium carbonate.
An increasing number of industrial facilities have heard
about potassium carbonate and understand the many
advantages of it, like lower capture and material costs.
Potassium carbonate is widely available and there areno harmful emissions.

3.

During a CapsolGo™ campaign, the plant’s specificflue gas and operation is tested to define an optimalsolvent blend for the full-scale carbon capture plant.

4.

CapsolGo™ is a powerful tool to demonstrate safe
carbon capture to stakeholders. Operation andmaintenance teams can get familiar with CO2 Capsol’s
technology and prepare for the full-scale operation.
The public, such as residents, can experience theenvironmentally friendly carbon capture solution live,in person.

With an independent test report, plant owners will be able
to accelerate their decision processes towards the fullscale plant and enhance the quality of their soft funding
applications.
With a capture capacity of several hundred tonnes of CO2
per year, CapsolGo™ enables maximum insights about thetechnology, while at the same time making it affordable forindustrial emitters to test carbon capture at their plant.

CO2 CAPSOL

Tone Bekkestad
Email:

tone.bekkestad@CO2capsol.com

Web:

www.CO2capsol.com

CONTACTDECARBONTEK LLC

DECARBONTEK LLC

Yong Ding
Email:

yong.ding@decarbon.techWeb:www.decarbon.tech

DESCRIPTION
CCUS is essential to achieving the net-zero objective,
and the key to large scale deployment of CCUS is a lowcost separation process to purify CO2 from a gas stream
containing very low CO2 concentration. Currently, CO2
separation accounts for about 80% of the total CCUS cost.
The primary technology utilized today is the solvent-based
absorption process. In addition to the high cost of solvent
regeneration, the solvent-based process also suffers fromsolvent and water losses, high corrosion to the equipment
and results in bulky unit operations.

SUMMARY
Decarbontek LLC (Decarbon) has developed a novel class ofregeneration heat and temperature. The sorbent fiber
next generation solid polymeric sorbent fibers and devices fordevices are constructed with controlled packing density todirect air capture (DAC), and point of source carbon capture
minimize pressure drop. Decarbon’s sorbent fiber devices areapplications.
The novel class of sorbent fibers are
suitable for passive direct air capture and can significantly
manufactured by a novel industrially feasible phase inversion
decrease the carbon capture costs. Decarbon’s novel sorbent
process utilizing widely available inexpensive raw materials.
fibers and devices are protected by a series of pending
SUMMARY
patents.
These sorbent fibers are mechanical strong, exhibit higharea, and highCO2 sorptiona capacity,
low
Decarbonteksurface
LLC (Decarbon)
has developed
novel
These sorbent fibres are mechanically strong, exhibit highclass of next-generation solid polymeric sorbent fibres
surface area, high CO2 sorption capacity, low regenerationand devices for direct air capture (DAC), and point ofheat and temperature. The sorbent fiber devices are
BENEFITS
source carbon
capture applications. The novel class ofconstructed with controlled packing density to minimize
sorbent fibres
aremanufactured
by
a
novel
industriallythe pressure
drop. Decarbon’s
fiber
devicesareCompared with conventional solvent based absorption process
and adsorption
process, CCUSsorbent
processes
utilizing
Decarbon’s
feasible phase
inversion
process,
widely advantages:
available
suitable for passive direct air capture and can significantly
novel
solid sorbent
fibersutilizing
exhibit following
inexpensive raw materials.
decrease the carbon capture costs. Decarbon’s novel•
Lower CAPEX and OPEX due to low sorbent cost sorbent
and regenerationenergyfibres anddevices are protected by a series of•
No solvent emissions
pending patents.

BENEFITS••••No need to make up water due to evaporation
No corrosion
Modular construction, ready to scale
Insensitive to water content in the feed, no need for humidity control

Compared with the conventional solvent-based absorption and adsorption processes, the CCUS processes utilizing
Decarbon’s novel solid sorbent fibres exhibit following advantages.
•

Lower CapEx and OpEx due to low sorbent cost and regeneration energy•

No solvent emissions•

No need for make-up water due to evaporation•

No corrosion•

Modular construction, ready to scale•

Insensitive to water content in the feed, no need for humidity control

42

STATE OF THE ART: CCS TECHNOLOGIES 2022

DECARBONTEK LLC

Solid sorbent technology has been sought-after due to its
low regeneration energy requirement. Significant amountof development work has been carried out to prepare
sorbents by loading amines onto the porous supports,such as silica, carbon and molecular sieves. Due to thelimitation of pore structure of the supports, often a low
molecular weight amine is used, which is prone to be lostin the regeneration step, either due to the evaporation oroxidation, or the formation of urea. High molecular weightpolyamines can overcome all of these issues. In addition,
inorganic sorbents often suffer from attrition and highpressure drop.

To overcome all the issues mentioned above and toprovide a low-cost solution for CCUS, Decarbon has
developed a novel class of next-generation solid polymericsorbent fibres. These sorbent fibres are manufactured by anovel one-step phase inversion process, a process similar
to a membrane manufacturing process. All raw materials
are widely available on commercial scale and are low costs.
These sorbent fibres are mechanically strong, exhibit
high surface area, have high CO2 sorption capacity, andlow regeneration heat and temperature. Decarbon also
designed and filed patent applications for the sorbent fiber
devices that can be conveniently utilized for small or largegas streams and up to Gt CO2 scale. The fibre packing
density can be controlled by a computer-controlled
winding. Decarbon’s sorbent fiber devices are suitable forpassive direct air capture (DAC) under all air humidity levels
and all weather conditions and can significantly decrease
the DAC cost.
Decarbon’s novel sorbent fibres and devices are protectedby a series of pending patents, ranging from fiber
preparation to device design and utilization.

CONTACTMCCS™ AND ENTROPY23™

ENTROPY

Jason Chadwick
Email:

jchadwick@entropyinc.com

Web:

www.entropyinc.com

DESCRIPTION
Entropy has created a post-combustion CCS system, whichmakes use of proven technology that has been improved
and adapted specifically for carbon. Entropy’s proprietary,build-for-purpose technology is unrivalled with respect toefficiency and cost and with modular building technology,
and is available to small and mid-sized emitters.
Entropy’s CCS system is highly efficient and derives net
negative carbon on an operational basis (Scope 1&2).
Carbon emissions are reduced by more than 80% relative
to pre-CCS carbon emissions, net of the carbon generated
in Entropy’s process.

SUMMARY
Entropy Inc. is a global leader in post-combustion carbon
capture and sequestration project development, witha full suite of proprietary state-of-the-art technology, inhouse engineering and subsurface technical teams,
and approximately 1.8 Mtpa CO2 of projects underdevelopment. Entropy’s first commercial project, which isdesigned to capture and store approximately 0.2 Mtpa CO2
in 2 phases from gas-fired compressor engines, began
construction in 2021 and the first phase (0.05 Mtpa) will
be commissioned in Q2 2022. Entropy technology wasdeveloped in partnership with a team from the Universityof Regina’s Clean Energy & Technology Research Institute,using a world-renowned carbon capture testing facility.
The product of this multiyear collaboration is a low-cost
CCS system using innovative modular carbon capture(MCCSTM) technology and a novel, high-performancesolvent (Entropy23™), capable of abating CO2 for less than
CAD 50/t CO2 for both retrofit and new equipment projects.

BENEFITS•

Low Cost: Break-even carbon price (achieving 10% rate of return on capital investment) less than CAD 50 as being
demonstrated by the Glacier CCS project in Alberta, Canada•

Innovative: Combining modular technology with heat capture and high-performance carbon capture solvents unlocks
never-before-seen CCS methodology•

Scalable: Entropy’s technology enables emitters to quickly implement post-combustion CCS in a phased approachwith minimal initial costs, and increase scale gradually•

Retrofit: Entropy’s modular carbon capture technology can be retrofitted to facilities of existing emitters, without theneed of plant expansion•

Proven: Entropy’s team has decades of post-combustion CCS experience, and the first gas-fired project underway.

44

STATE OF THE ART: CCS TECHNOLOGIES 2022

Entropy has partnered with CETRI (Clean Energy andTechnical Research Institute) from the University ofRegina to commercialize technology that has been underdevelopment for decades by an internationally renowned
team of experts. Entropy has developed a CCS system,
which includes process improvements and an advanced
high-performance solvent that has demonstrated material
performance improvements relative to traditional solvents.
Entropy23™ outperforms traditional CCS solvents andrequires fewer heat inputs resulting in an energy and costefficient process.
The initial commercial application of Entropy’s technology
is currently under construction at the Glacier Gas Plant
near Grande Prairie Alberta, with start-up planned forQ2/22. This post-combustion CCS facility will capture
approximately 0.05 Mtpa CO2 in Phase 1 and will provide
real-world data to backstop extensive testing. Phase 2 ofthe project is scheduled to come on-stream in 2023 andwill capture an incremental 0.15 Mtpa CO2.
The efficiency gains Entropy has achieved results in overall
carbon capture costs of approximately CAD 50/t CO2.
This technology is applicable for multiple types of postcombustion projects across a range of sizes and industries.
Entropy has a planned capital program of approximately$250 million per year to build CCS facilities in exchange
for environmental attributes related to the carbon capture
projects. The Company is also pursuing a technology
licensing strategy.
Entropy is currently working to adapt its CCS system to avariety of emission sources with a total project inventory of
1.8 Mtpa CO2. Modular construction techniques employed
by Entropy result in reduced construction time, project risks
and costs.
The Entropy team is highly skilled in engineering, projectand regulatory management and has extensive subsurface
experience injecting CO2, acid gas and industrial waste
fluids underground while meeting the highest regulatory
standards.

CONTACTHONEYWELL

T. Lozanoski
Email:

nathan.lozanoski@honeywell.com

Web:

www.pmt.honeywell.com

BENEFITSCHALLENGES FOR INDUSTRY LEADERS

Reduce CO₂ emissions in hard-to-abate industries•

National and corporate net- zero policy ambitions

At Honeywell, our CO₂ solutions can help make an impact
within a wide range of industrial market segments wheredecarbonatization has been a proven challenge, such as:•

Legal, regulatory, and financial frameworks areprogressing•

Large scale projects remain a significant hurdle due toenergy requirements•

Full ecosystem that embodies all elements of carbon
capture to support fast-moving projects

•

Power

•

Steel

•

Cement•Refining•

Petrochemical•

Hydrogen Plant•

Natural Gas Processing

POWER PLANTSTEEL PLANT

CEMENT PLANT

SUMMARY
A path to Carbon Neutrality starts today
With a global focus on combatting climate change, industry
leaders are aggressively seeking technology solutions that
limit greenhouse gas emissions.
This is especially critical for carbon-intensive industrial
markets such as power, steel, cement, refining,
petrochemicals, hydrogen and natural gas processing
where reducing environmental impact has been difficult.
There are many avenues a company can take to meetsustainability goals – and a drive towards carbon
neutrality is gaining prominence as a key driver of meeting
commitments. While many companies are taking the firststeps towards carbon neutrality with more energy-efficientmachinery and processes, technology supporting these
initiatives is continuously evolving and improving, andcompanies need to keep up.

46

STATE OF THE ART: CCS TECHNOLOGIES 2022

Carbon Capture Technologies and their role in sustainable
operations
Deciding what sustainability initiatives to implement to start
your company’s journey towards more environment-friendly
processes can be daunting. From making commitments toplant a certain number of trees to implementing energyefficient processes, there are multiple pathways leading
towards more carbon-neutral operations, some of which canbe integrated immediately, but others require longer-termplanning.

CARBON CAPTURE PLANT
WITH HONEYWELL TECHNOLOGIESCarbon capture, utilisation and storage (CCUS) is a key
technology for reducing greenhouse gas emissions.
According to the International Energy Agency, carbon
capture capacity must increase more than 20 times toenable the capture of 840 Mtpa CO2 by 2030 to meet global
emission goals.
Incorporating carbon capture technologies into production
is an effective path industrial companies can take to reduce
their environmental impact and prevent harmful emissions
from entering the atmosphere. However, carbon capture isa broad and complex field, requiring in-depth knowledge ofboth the technology and industry to effectively execute.

STORAGE AND
SEQUESTRATIONOTHER INDUSTRYCONTACTHONEYWELL

T. Lozanoski
Email:

nathan.lozanoski@honeywell.com

Web:

www.pmt.honeywell.com

DESCRIPTIONYour experienced provider of carbon capture solutions

Chemical Solvents

Adsorbents

At Honeywell, we’re uniquely qualified to support industrial
sectors with implementing carbon capture technology into
their operations. With more than 70 years of experiencein carbon capture, we have the knowledge to help you
progress your journey to carbon neutrality.

AmineGuard™ & Amine Guard FS Process

Polybed™ Pressure Swing Adsorption (PSA) System

Largest licensor of high concentration MEA-based systems;
formulated solvents have low OpEx compared to MEA(>600 units)

Optimized adsorbents and cycles for CO₂ rejection (>1100
units, 3 operating in CO2 application)

We offer a proven suite of solvent, membrane, adsorbent
and cryogenics technologies with industry-leading captureof CO₂ emissions. Honeywell CO₂ solutions are alreadycapturing 15 Mtpa CO₂ worldwide with additional installedcapacity ready to do more.1
Significant track record in Carbon Capture with vast
technology portfolio
Honeywell has a vast portfolio of carbon capture
technologies that help support industry leaders to movetowards a lower carbon footprint. Our team of experts canwork with you to determine the best solution to meet yourCO₂ emission goals.

Benfield™
Inorganic solvent for pressurized flue gas & industrial
processes (>650 units)
Advanced Solvent for Carbon Capture
Direct CO2 capture from flue gas for power, steel, cement,
natural gas, refining & petrochemical industries.
Physical solvents
SeparALL™ Process

Cryogenics & Membranes
Separex™ Membrane Systems
High, partial-pressure CO₂ capture, significant experiencein offshore capturing and sequestering (>300 units)
Ortloff CO₂ Fractionation
Captures CO₂ and also provides it as a high-purity liquid
product

Post-combustion advanced solvent technology unlocks
potential
In collaboration with the University of Texas, Honeywell isproud to offer a new advanced solvent technology to lower
CO₂ emissions generated from combustion flue gases
in hard-to-abate industries, such as power, steel, cement,
refining, petrochemical and other industrial plants.
Utilising an advanced solvent, this point source CO₂
removal technology enables CO₂ to be captured at a lower
cost through greater efficiency using smaller equipment.
This creates viable project economics today as countries
across the globe progress to meet their sustainability
targets.2 It can be retrofitted within existing plants or
included as part of a new installation.
A carbon neutral future starts today
Meeting future sustainability goals requires action
now. Honeywell has the expertise and carbon capture
technology portfolio available at scale today to help you on
your journey to carbon neutrality.

H2S/CO2 selectivity using Selexol solvent for sources
containing sulphur in oxidative conditions (>50 units)

CO₂ ProductCompressor& Coolers

Wash
Water

High
Pressure
Stripper

Novel
Heat Exch
DesignSteam

StripperAdvanced
Absorber

Air / Water
Cooling

Cond

Flue Gas /Industrial Gas

Honeywell can provide technology as initial studies to define best path forward, transfers the technology through license, engineering and modular supply.
Lower cost of CO₂ capture based on comparing estimated capital and operating costs of this solution against other conventional amine solvents in same
applications. CO₂ pricing considers current policies of $50/ton tax credit (USA per IRS Section 45Q for permanent storage) and $60/ton (UK and Europe –approximate averages from August 2021 through country/regional Emission Trading Systems and as reported by IHS Markit).

2

Includes capacity of deployed Honeywell technology (membranes, chemical and physical solvents) in installed projects enabling CO₂ capture from gas
streams, of which 15 million tons of the captured CO₂ is being utilized for enhanced oil recovery annually.
1

48

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACTPOST COMBUSTION CAPTURE (CHEMICAL ABSORPTION)

IHI CORPORATION

Takatsugu Kanatani
Email:

kanatani4992@ihi-g.com

Web:

www.ihi.co.jp

BENEFITS•

Specially designed to recover CO2 from low-pressure, oxygen-containing streams, such as the flue gas of power plant.

•

Applicable to both the existing and new power plants and providing CO2 purity in excess of 99%.

•

Adapting to customer’s demand for both full and partial CO2 capture with module design.

•

Providing sequential build up of CO2 capture capacity.

•

Minimizing energy requirement for CO2 capture using developed technologies.

DESCRIPTION
Pilot Plant
20 t-CO2/d Pilot Plant

Outline of Chemical Absorption•

The flue gas from a power plant contacts a solvent in
the CO2 absorber. The solvent selectively absorbs theCO2 and is sent to the CO2 stripper. In the stripper, theCO2-rich solvent is heated to release almost pure CO2.

•

The CO2-lean solvent is then recycled to the absorber.

50

STATE OF THE ART: CCS TECHNOLOGIES 2022

Developed original solvent, packing and system•

Achieved approximately 40% higher energy efficiency

Specifications

SUMMARY
Post combustion capture technology (chemical absorption)
can be applied to various flue gas. Captured CO2 usingchemical absorption can be applied to CO2 utilization andstorage.

•

CO2 source and utilization/ storage
IHI has not only CO2 capture technology, but also works
with utilization technologies, such as methanation and olefin
production.

PICA (Post-combustion carbon capture, IHI, CSIRO, AGL)
Pilot Plant•

Demonstrated by using actual flue gas from coal-fired
power plant•

5,000 hours operation successfully completed

Specifications

Location

IHI’s AIOI Works in Japan

Source Gas

Flue Gas of Coal-Fired Boiler or
Propane Gas Boiler

Captured CO2

20 t-CO2/d

CO2 Capture Ratio>90%

Location

Loy Yang A Power Plant In Australia

Source Gas

Flue Gas of Coal-Fired Boiler

Captured CO2

0.5 t-CO2/d

CO2 Capture Ratio>90%

CONTACTOXYFUEL COMBUSTIONIHI CORPORATION

Takatsugu Kanatani
Email:

kanatani4992@ihi-g.com

Web:

www.ihi.co.jp

DESCRIPTION
Callide Oxyfuel Project

Callide A Power Station

Features•Owned by CS Energy

The world’s first and only oxyfuel power plant;•

4 x 30 MWe•

Steam: 136 t/h at 4.1 MPa, 465 °C•

Commissioned: 1965 – 69•

Refurbished: 1997/98•

Placed in storage in 2002•

having all processes required for commercial use•

selling electricity by capturing CO2•

using existing old, not CCS-Ready, coal-fired power
plant

Injection of captured CO2 into the underground;•

the world’s first injection from oxyfuel power plant

Scope:•

No. 4 Boiler refurbishment•

2 x 330 TPD ASU

Applicable to both existing and new plants.

•

Oxyfuel combustion Retrofit•

Achievable CO2 capture rate of up to 98% and nearlyzero emissions.

•

75 TPD liquid CO2 recovery•

Trucking to CO2 reservoir••

Injection and monitoring

IHI is the only boiler company in the world to have applied
the oxyfuel combustion technology to a thermal power plantand operated it for more than 10,000 hours.

Pure CO2 through CPU can be obtained suitable for
utilization and storage.

•

Economical benefit by utilization and sale of byproducts
such as N2 separated in the ASU.

Example of the application to coal fired power station -•Utilization of excess or surplus oxygen is possible.

•

Energy storage using oxygen production is possible.

SUMMARY

BENEFITS

Oxyfuel Combustion will convert fossil-fuel or biomass-fired
plants into carbon-neutral or -negative with CO2 utilization/
storage by way of coping with the climate change issue, andwill contribute to the environment and the economy of thecommunity.

•

52

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACT

THE LEILAC GROUP

Daniel Rennie
Email:

contact@leilac.com

Web:

www.leilac.com

DESCRIPTION
The cement and lime industries play a vital role in oursociety. Cement is used in our roads, buildings, homes,
offices and almost all infrastructure. Lime is used in a variety
of applications, including the iron and steel, chemical, paper,
pharmaceutical, drinking water, food, and farming industries.
However, the cement industry alone is responsible foraround 8% of global CO2 emissions, as most of theiremissions are inherent to the production process and are
therefore difficult to avoid. The latest IPPC report concluded
that the world has just eight years to get emissions undersufficient control. “It’s now or never…without immediate
and deep emissions reductions across all sectors, it will be
impossible.” IPCC Working Group III Co-Chair.

SUMMARY
The LEILAC Group, a subsidiary of Calix Ltd., aims to apply
a breakthrough in carbon capture technology that will
enable the cement and lime industries to reduce theiremissions dramatically - while retaining their international
competitiveness – by capturing those process emissions at
low costs. This is a completely new type of carbon capture
technology: a process modification approach, rather
than requiring additional chemicals or processes. The
technology can also be retrofitted in a modular form at any

scale, and makes use of any fuel or energy source (such as
biomass, hydrogen, or electricity) – providing a future proof
solution.
The LEILAC2 project has passed its Final Investment
Decision (FID) to build a plant capable of capturing 20% of acement plant’s CO2, and will be integrated into Heidelberg
Cement’s plant in Hannover, Germany. LEILAC2’s modular
design will form the basis for decarbonising a full plant.

BENEFITS•

Low Cost: LEILAC2, as a first-of-a-kind modular retrofit, is aiming to ultimately separate CO2 for a cost €20 - 25 per
tonne of CO2 avoided.

•

Addresses Unavoidable Emissions efficiently: While there are challenges still to be overcome, the technology aims
to have a minimal energy penalty – meaning there is a potentially low production abatement cost, and not just thecapture cost.

•

Low-Impact Retrofit Integration: The LEILAC2 plant is being designed to have minimal impact on the host plant, as a
retrofit to a fully operational plant.

•

Energy Agnostic: The technology is being designed to use any fuel or energy source, such as biomass, hydrogen, or
electricity – with the intention of enabling plants to continue to transition to more sustainable, low-carbon fuels, andachieve net zero CO2 emissions.

•

Scalable: The technology is being designed in a modular fashion, to enable scaling to any plant size.

•

Efficient, global roll out: The intent of the technology is to enable its rapid rollout through the use of local engineeringfirms.

54

STATE OF THE ART: CCS TECHNOLOGIES 2022

The LEILAC technology is a new type of carbon capture
technology, designed to address the unavoidable CO2
process emissions from the cement and lime industries.
The design involves a process modification approach,rather than requiring additional chemicals or processes,
and therefore, can separate CO2. It uses externally heatedtubes that keep the CO2 released during the manufacturing
process pure and not contaminated by flue gases or air, andso – as a capture technology - does not need the significant
additional energy to separate gases from gases required formost other approaches.

Supported by the European Union’s Horizon 2020 scheme,
the LEILAC1 and 2 projects have been proving, developing
and scaling up this concept. LEILAC2 was established todemonstrate that the Calix technology can be retrofitted tobe capable of capturing 20% of a cement plant’s emissions;be integrated without causing major issues or interruptions
to the host plant; investigate the use of alternative fuels;and be a replicable module enabling scale up. Since theproject commenced in 2020, as a global society, we have
faced significant challenges: resulting in delays and priceincreases across the supply chain. Nevertheless, the project
team – involving talented individuals from all of the project
partners - have managed to develop a cost-efficient andtechnically viable design. The project successfully passed
its Financial Investment Decision (FID), and will now proceed
into detailed design phase through 2022, followed by
procurement and construction of the plant itself (with flag
gates to deal with risks, particularly the current market
volatility).
LEILAC2 – despite being a 1st of a kind demonstration
retrofit – has the potential to make a step-change inindustrial decarbonisation. Including expected compression,
fees and, CapEx costs – this equates to an avoidance (notjust capture) cost of around €20-25 per tonne. This is an
R&D plant, with associated risks, but will deliver a replicable
module that will be a step change in addressing a plant’s
emissions cheaply.

CONTACTCO2 SOLUTIONSSAIPEM

The enzyme is a Carbonic Anhydrase (CA) tailored toperform under industrial process conditions and produced
affordably in large quantities. CA catalyses the hydrationand dehydration of CO2, attaching and removing a watermolecule to CO2 by accelerating the reaction rate up to
1 million times per second – one of the fastest catalytic
reactions in nature!
Many different forms of CA exist in nature as they arepresent in all animals and all plants. If you breathe, you are

Email:

info@CO2solutions.com

Web:

www.saipem.com/en/solutions/

exploiting the benefits of carbonic anhydrase, as it is usedby your body to expel CO2 from your lungs and perform
other biological functions. CA is as old as life on this planet.
The innovation is to use CA in an industrial process.
The carbonate system acts as a CO2 carrier by forming
bicarbonates, gets transformed back into carbonate byexhaling the CO2, similar to in our lungs. The technology
has the nickname “Industrial lung™” for this reason.

BENEFITS
There are many advantages of using a carbonate system compared to other carbon capture technologies.

SUMMARY
In the next five minutes of reading this article, humanactivities will add approximately 300,000 tonnes of CO2 tothe biosphere that supports all life forms. Carbon dioxide(CO2) is a powerful greenhouse gas (GHG). Climate change
events such as droughts, floods or uncontrolled fires
are more frequent, putting vulnerable populations andecosystems at risk. Scientists and civil authorities recognizethat the pace of GHG production is unsustainable.
Legislators impose new rules to curb emissions.
Progressive industrial leaders want to act without delay,as they acknowledge that their future business is ina symbiotic relationship with the environment. GHG
abatement is the goal of a generation, so it is not the last.
Tensions
betweenbusiness-as-usualcommercial
imperatives, more stringent regulations and the pressure toact within the next capitalization cycle in an undiscovered
competitive landscape put an immense burden on theindustry, specifically in sectors with unavoidable CO2
emissions.
The past is an enlightening source of insight to secure thebest path forward. SAIPEM’s rich history offers a glimpse ofhope. Since 1957, the Milan-based global solution provider
has been delivering complex projects worldwide in 72
countries with 35,000 dedicated project and technology
experts.
SAIPEM has vast and lengthy experience managing carbon
dioxide throughout the Carbon Capture, Utilization andStorage (CCUS) value chain.
56

STATE OF THE ART: CCS TECHNOLOGIES 2022

SAIPEM designed and built many of the world’s mostremarkable gas treating projects in numerous applications
such as natural gas processing, syngas treating, hydrogen,methanol, ammonia and urea synthesis, to name just a few.
SAIPEM erected significant infrastructures to transport
gasses and liquids in 130,000 km of pipeline projects
throughout all geographies.
Many of the 7,000 wells that SAIPEM drilled over land andwater have been used to re-inject or sequester acid gas
and CO2.
Finally, through its intimate knowledge as engineering,procurement and construction (EPC) contractor and as theurea technology provider of 140 fertilizer projects, SAIPEM
developed expertise and know-how with many carbon
capture technologies, such as processes based on amines
and carbonates, as well as distinctive competencies in
the compression of CO2 from atmospheric to supercriticalpressures and re-use of CO2 in urea and methanol
products.
SAIPEM has been looking to find the best secondgeneration process to reduce costs and environmental
liabilities associated with predominant amine-based
technologies. In 2019, SAIPEM acquired a disruptive andinnovative technology from CO2 Solutions Inc. (CSI), now
marketed as “CO2 Solutions by SAIPEM”, which uses anaqueous carbonate solution catalysed by an enzyme. It
improves a proven scheme with carbonates to catch CO2
with a salt and protein water solution.

•

In post-combustion application, salt systems are less sensitive to oxygen, sulphur and nitrogen oxides, which cansignificantly degrade amine systems. This avoids, in most instances, the need to remove SOx and NOx from the fluegas before carbon capture.

•

The water-based salt system’s low volatility does not create aerosols that must be mitigated and controlled.

•

The enzymatic process does not use or generate any toxic compounds, which reduces environmental liabilities
compared to other technologies and avoids secondary containment.

•

The process does not create sludges or solid wastes that require a reclamation system to be recycled back into thesolvent.

•

Finally, the enzymatic carbonate technology is regenerated with low-temperature residual heat at 85 °C.

All these benefits reduce the capital and operating costs.

CONTACTCO2 SOLUTIONSSAIPEM
DESCRIPTION

The enzymatic carbon capture technology developedby CSI over the last 20 years is very classical in its form
from a gas treating point of view. The process starts witha conditioning step where the raw gas is cooled down to
between 20 °C and 40 °C. Fine particulates are removed,
and water vapour is condensed. The flue gas then flows
into an absorption column at near atmospheric pressure,
where the rising flue gas is comingled with a cascading
liquid solution that gets loaded with CO2. The last step is a
stripping column where the CO2 is expelled from the liquidand captured, and the solution is regenerated and sent
back to the absorption column.
Secondary systems to the primary process include theCO2 compression cycle, the additions of enzyme andcarbonate, the waste heat collection, and the condensate
handling system.
The Technology Readiness Level (TRL) of the enzymatic
process has progressed to TRL-8 with the first commercial
start-up in 2019. This unit is getting its flue gas from a lime
kiln in a Kraft pulp mill and delivers up to 30 tonnes per dayof CO2 to an adjacent greenhouse. The operation of thissmall commercial unit revealed vital points to consider for
the industry:1.

The lime kiln’s dusty gas stream has compositional
similarities to cement kiln emissions.

2.

The process is regenerated 100% with low-grade
residual heat from the host plant at 85 °C, which has
no impact on the host plant’s heat balance, and thiscomes at no cost to the carbon capture process.

3.

The capture unit produces CO2 purity that surpasses
greenhouse grades and any sequestration grade
without additional efforts.

4.

The power consumption of the system is low.

5. The enzyme’s sustained performance is economically
viable, and the OpEx competes favourably well withother amine technologies.
6. As all the process equipment used is standard in gas
treating, the process blueprint and architecture areeasily scalable to much larger sizes.

58

STATE OF THE ART: CCS TECHNOLOGIES 2022

SAIPEM intends to quickly scale up the disruptive process
to a size adapted to the industry’s needs. As SAIPEM
designs and delivers the largest gas treating units globally
across its portfolio, it sees the scale-up does not present
any technological concerns or insurmountable engineering
challenges.
In the broader context of CCUS, SAIPEM has the trackrecord, expertise, and know-how to integrate technologies
and deliver systems beyond the scope of capture, i.e., in
the capture – transport – storage – utilization value chain.
Moreover, SAIPEM typically offers projects in lumpsum
turnkey mode, which can help accelerate the attainment ofcarbon neutrality.
If the past is an enlightening source of insight to secure
the path forward, rely on SAIPEM to abate your GHG
emissions, deliver CCUS projects and accompany yourenergy transition.

Email:

info@CO2solutions.com

Web:

www.saipem.com/en/solutions/

CONTACTCANSOLV™ CO2 CAPTURE TECHNOLOGY

SHELL

Rajiv SrinivasanWeb:www.shell.com/ct

BENEFITSThe CANSOLV™ CO2 Capture System can capture up to 99% of the CO2 from post-combustion streams and is proven for
CCS at a 1 Mtpa CO2-capture scale. It offers:

SUMMARY
adaptable to retrofit scenarios and greenfield projects,
and a wide variety of industrial applications, gas
flow rates and CO2 concentrations. Units have been
designed for CO2 concentrations from 3.5 to 27%
and treating gas flow rates from 11,000 to 4,500,000
Nm3/h.

Shell Catalysts & Technologies offers two leading, aminebased, high-capacity carbon-capture technologies,
CANSOLV™ CO2 Capture System and ADIP™ ULTRA, thatare robust and proven, and have established records ofperforming cost-effectively in a wide range of industries.
Shell’s CANSOLV™ CO2 Capture System captures up to
99% of the CO2 from post-combustion streams while
Shell’s ADIP™ ULTRA technology captures CO2 from highpressure, pre-combustion process streams, for example,
from hydrogen manufacturing units, chemical plants andnatural gas treating plants.
As a standalone, low-pressure, CO2-capture technology,
the CANSOLV™ CO2 Capture System is well-suited for
retrofitting to existing plants and can also be included ingreenfield developments. It uses a regenerable proprietaryamine to capture CO2 that is released as a pure stream,
which makes the technology highly suitable for CCS
projects.
Following technical and economic evaluations, capturing
CO2 from flue gas using the CANSOLV™ CO2 Capture
System may emerge as the preferred option because of
the key features such as:•

CO2 purity: The pure CO2 product enables CCS or
utilisation downstream of the plant.

•

Adaptability:

60

The

standalone

STATE OF THE ART: CCS TECHNOLOGIES 2022

systemishighly•Asset integrity: The system has been designed forreliability through its high turndown capacity andthe solvent’s resistance to oxidative and thermal
degradation.

•

Low waste: The process uses a regenerable solvent,so very little waste by-product is generated, which can
reduce project costs as the effluents are minimal.

•

Low operating costs: The system offers cutting-edge
performance. For example, its low parasitic energy
consumption, fast kinetics and low volatility help toreduce the cost of operation and amine consumption.

•

Track record: The technology is proven in large-scale
CCS applications, having captured more than 4.5 Mtpa
CO2 from a power station flue gas in Canada since its
start-up in 2014.

•a high-purity CO2 stream suitable for sequestration or utilisation projects;•

a highly adaptable, standalone system suitable for retrofitting and greenfield developments across a wide variety ofindustrial applications, gas flow rates and CO2 concentrations;•

low operating costs; and•continuous technological developments to reduce capture costs and energy requirements through extensive researchand development, targeted piloting and demonstration campaigns.

CONTACTCANSOLV™ CO2 CAPTURE TECHNOLOGY

SHELL

Rajiv SrinivasanWeb:www.shell.com/ct

DESCRIPTION
through a lean–rich amine heat exchanger and thenon to the regeneration column.

Process description
Figure 1 shows the CANSOLV CO2 Capture System. The
key steps are:1.

Feed gas is quenched and saturated in a circulated
water pre-scrubber.

2.

Gas contacts the lean amine solution in a countercurrent mass transfer, packed absorption column.

3.

CO2 is absorbed and the treated gas exits toatmosphere.

4.

Midway along the column, partially loaded amine isremoved from the tower, cooled and reintroduced
over a layer of mass-transfer packing.

5. CO2-rich amine from the absorption column is pumped

6. Rising, low-pressure saturated steam in the column
regenerates the lean amine solution. CO2 is recovered
as a pure, water-saturated product.
7.

Lean amine is pumped from the stripper reboiler to theabsorption column for reuse in capturing CO2.

8.

The CO2 is directed to by-product management
systems.

9.

Energy is recovered through a system such as amechanical vapour recompression compressor and/or a condensate flash, which helps to reduce the net
reboiler duty requirements for amine regeneration.

Proof point: SaskPower 1 Mtpa CCS project

Proof point: Polaris CCS projectBecause of tighter regulations, SaskPower needed toreduce CO2 and SO2 emissions at its Boundary Dam power
station in Saskatchewan, Canada, which is a significant
source of power for the region.

Shell’s CANSOLV™ CO2 Capture System has been selected
for the proposed Polaris CCS project, one of a series of
low-carbon opportunities being explored to decarbonise
the Scotford complex, Alberta, Canada, to create oneof Shell’s proposed five global energy and chemicals
parks. The initial phase is expected to start operations inabout the middle of the current decade, subject to a final
investment decision by Shell, which is expected in 2023.
Polaris would have storage capacity of about 300 million
tonnes of CO2 over the life of the project. When fully built,
Polaris would contribute to the region becoming a bluehydrogen hub.

After carefully evaluating a range of technical options,
SaskPower chose to add a CANSOLV™ SO2–CO2
Integrated Capture System for combined carbon capture
and flue-gas desulphurisation. It opted to do this for a 150MW unit that was due for refurbishment. This involved
adding a 55-m-tall CO2 absorber, a 40-m-tall CO2 stripper, a31-m tall SO2 absorber and a 17-m-tall SO2 stripper.
In 2014, the power station became the first in the world
to successfully use CCS at scale. The plant has been in
operation now for over 7 years with the capacity to capture
up to 1 Mtpa CO2, thereby helping SaskPower to meet strict
Canadian regulations on CO2 emissions from coal-fired
power stations and thus retain its licence to operate. The
CO2 is compressed, transported through pipelines andpermanently stored in deep geological formations as partof an enhanced-oil-recovery operation. The captured SO2
is converted to 60 t/d of a marketable sulphuric acid thatcan be used as a feedstock for the local fertiliser industry.
The learnings from this still-operating, first-of-a-kind
deployment continue to help develop Shell’s CANSOLV™
CO2 capture technology and promote and develop CCS
projects globally.

Figure 1. Shell CANSOLV™ CO2 Capture System.

62

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACTADIP™ ULTRA CARBON-CAPTURE TECHNOLOGY

SHELL

Chris Egby
Web:

www.shell.com/ct

BENEFITSThe Shell ADIP ULTRA™ pre-combustion gas-treating process cost-effectively treats gases containing high CO2 levels. It is
proven for CCS at a 1 Mtpa CO2-capture scale and, compared with conventional process line-ups, it can help to:

SUMMARY
Shell Catalysts & Technologies offers two leading, aminebased and high-capacity carbon-capture technologies,
ADIP ULTRA™ and CANSOLV™ CO2 Capture System, thatare robust and proven, and have established records ofperforming cost-effectively in a wide range of industries.
Shell’s ADIP ULTRA™ technology captures CO2 from highpressure, pre-combustion process streams, for example,
from hydrogen manufacturing units, chemical plants andnatural gas treating plants, while Shell’s CANSOLV™ CO2
Capture System captures up to 99% of the CO2 from postcombustion (oxygen-containing) streams.
ADIP™ technology is deployed at more than 500 Shell andnon‑Shell sites worldwide and has established an enviable
record for deep CO2 removal in the natural gas sector.
ADIP ULTRA™, the latest development, uses an optimised
solvent formulation and an improved design based on
years of operational learnings. With the latest-generation
column internals (Shell Turbo Trays), this technology can
maximise CO2 capture and meet deep specifications forthe treated gas while optimising solvent circulation andregeneration duty.
The ADIP Ultra™ technology offers the following distinct
features, which makes it attractive for high pressure precombustion CO2 capture:•64

reduced capital cost through the latest-generation
column internals (Shell Turbo Trays) in the absorber

STATE OF THE ART: CCS TECHNOLOGIES 2022•

low regeneration energy requirements determinedusing a highly enhanced modelling capability basedon many years of operating experience and data•

availability in advanced energy efficient line-ups that
reduce capital and operating costs, depending on thetreated gas specifications and application•a solvent that is robust to foaming upsets and does not
suffer from any degradation, which leads to zero wastefrom the process•

a noncorrosive, nontoxic solvent

Shell ADIP ULTRA™ technology combines with Shell gas
partial oxidation technologies to provide the carbon
capture step in the production of blue hydrogen fromnatural gas in a line-up known as The Shell Blue Hydrogen
Process(catalysts.shell.com/en/blue-hydrogen-ondemand-webinar).

•reduce equipment costs by up to 30%•

cut regeneration energy requirements by up to 30%•

achieve deeper CO2 removal

CONTACTADIP™ ULTRA CARBON-CAPTURE TECHNOLOGYSHELL

DESCRIPTION
Process description

Proof point: Quest 1 Mtpa CCS project

ADIP™ technology dates to the 1950s. In 2000, ADIP-X
technology was introduced. This featured a significantly
upgraded solvent that unlocked a step change in CO2
removal capability. The latest generation of this arrived
in 2017 with ADIP ULTRA™, which has several enhanced
design features, compared with previous-generation
technology, that further reduced the cost of CO2 removal.
These includes a shorter absorber column, reduced
solvent circulation, a slimmer regenerator and a smaller
reboiler (Figure 1).

The Scotford upgrader in Alberta, Canada, generates CO2
during hydrogen manufacture. As part of the Quest CCS
project, Shell’s ADIP ULTRA™ technology captures CO2from the three hydrogen manufacturing units’ process
gas streams. The captured CO2 is then dehydrated andcompressed before being transported about 75 km
by pipeline and injected and permanently stored 2 km
underground. The facility has a proven CO2-capture
capacity of over 1 Mtpa CO2 and has captured more than
6 million tonnes of CO2 since coming online in 2015. The
facility has better than projected reliability, cost and storage
performance, and greater than 99% uptime. Its operating
cost is approximately $25/t of CO2 and it would cost about
30% less if built today.

Combining ADIP ULTRA™ technology with Shell’s newabsorption column internals, Shell Turbo Trays, can further
enhance process performance. At the column scale, liquidand gas flow counter-currently, that is, gas moves up
while the liquid solvent moves down. However, on eachtray within each element, gas and liquid flow co-currently
within multiple contacting boxes before being separated
effectively (Figure 2). Contact between the gas and theliquid is increased significantly, which enables higher masstransfer rates. The net effect is to increase the hydrauliclimits of the system, which means operators can process
higher CO2 concentrations and increase capacity by up to
80% or reduce the column diameter by up to 35% and theweight by up to 50%.
ADIP ULTRA™ technology uses two amines, methyl
diethanolamine (MDEA) as the main reactant andpiperazine as the accelerator, and water. It can help toreduce the capital and operating costs of grassroots plants
and revamps owing to the solvent’s high capacity for
CO2 and its low circulation rate compared with aqueous
MDEA. ADIP ULTRA™ solvent can facilitate efficient andstable operations owing to its characteristics of low levelsof hydrocarbon solubility, foaming, fouling, corrosion anddegradation.

Proof point: The Porthos CCS project
In September 2021, a final investment decision wasmade to build an 0.82 Mtpa biofuels facility as part of thetransformation of Pernis refinery, the Netherlands, into
the Shell Energy and Chemicals Park Rotterdam, one offive global energy and chemical parks. Once built, thefacility will be among the biggest in Europe to produce
sustainable aviation fuel and renewable diesel madefrom waste. Carbon dioxide (CO2) emissions from the
manufacturing process will be captured using Shell’s ADIPULTRA™ technology and stored in a depleted North Sea gas
field as part of the Porthos CCS project. A final investment
decision for Porthos CCS project is expected in 2022.

Figure 1. The Shell ADIP ULTRA™ process.

The line-up can be varied, for example, using a hot flash
instead of the regenerator, depending on the CO2 removal
requirements. This line-up is fully derisked and part of the
Shell Blue Hydrogen Process.

Figure 2. Increased capacity from Shell Turbo Trays.
*ADIP and CANSOLV are Shell trademarks
66

STATE OF THE ART: CCS TECHNOLOGIES 2022

Chris Egby
Web:

www.shell.com/ct

CONTACTSOLID SORBENT TECHNOLOGY

SHELL

Chris Egby
Web:

www.shell.com/ct

DESCRIPTION
The solid sorbent technology is an innovative process.
which separates carbon dioxide (CO2) from flue gas
streams. This continuous temperature swing adsorption(TSA), fluidized bed process uses a solid adsorbent
and is being developed for the delivery of high capture
performance, lower capture costs and low emissions.
At low temperatures (ca. 50 °C), CO2 is first adsorbed ina first multi-staged fluidized bed (adsorber) where heatis released due to the exothermicity of the adsorption
reaction. Subsequently, the adsorbent is transported ina riser to a second multi staged fluidized bed (desorber)
via heat exchangers, where the previously bound CO2
is released using steam at a temperature of 120 °C. In
this way, the adsorbent is regenerated (in a continuous
process) and can be returned to the adsorber where it isagain available for CO2 capture.

SUMMARY
The Solid Sorbent Technology (SST) is a novel technologythat separates CO2 from flue gas in a continuous
Temperature Swing Adsorption (TSA) fluidized bed processusing solid adsorbent. The technology is being developed
for medium to small capture capacity across a range ofsectors, with industrial partners. The technology potentiallydelivers simultaneously > 90% CO2 capture efficiency and> 95% CO2 purity with low to no process-related emissions
and with lower capture costs. The technology is currently
piloted at BMC Moerdijk in a 1 tonne CO2/day pilot plant
operating 24/7 to optimize the process and qualify new
adsorbents. A technology readiness level (TRL) of 6 has
been reached. The next steps are to de-risk the technology
further to enable first deployment.

A fluidizable adsorbent material is used where CO2 can bevery selectively bound to, for example, active amine groups
that are tethered on the adsorbent surface. The adsorbent
displays high temperature and mechanical stability and as
a result, produces very low emissions without the need for

expensive post-treatment. The process contains no liquidwater, and therefore, lower-cost construction materials canbe used.
The base case material is a chemisorbent, fluidizable,
attrition resistant and suitable to be produced at a tonne
scale for commercial applications. Novel adsorbents arebeing developed with improved properties using lesssteam for the regeneration of the adsorbent and to extend
the adsorbent lifetime.
In the ViennaGreenCO2 project, the technical University of
Vienna and Natural Resources and Applied Life Sciences(BOKU) designed and operated a pilot plant for 900h in aflue gas slip stream from a wood fired power plant at Wien
Energie. After project closure, the pilot plant was moved
to the Netherlands and since early 2021, operated 24/7
in a flue gas slip stream from the poultry litter fired power
plant at BMC Moerdijk in the Netherlands. The pilot plantis used to qualify novel adsorbents, optimize the process
consumables, and test equipment improvements. Next
step undertaken is to scale-up and prepare the technology
for commercial deployment.

BENEFITS•

Pilot plant results show that the new process can separate over 90% of the CO2 from industrial gas and that this CO2
has a purity of over 95% (dry basis), even at inflow CO2 concentrations of less than 4 percent by volume.

•

Solid sorbent technology development focusses on medium to small scale application (0.1-0.5 Mtpa CO2), including
waste to energy, hydrogen manufacturing and specific applications in the steel and cement industries. End user
experience is brought into the development via collaboration with external partners.

•

Pilot Plant operation shows that without any flue gas post-treatment, the atmospheric emissions from this process
are very low, significantly less than 1 milligram/normal cubic meter (mg/Nm3) of ammonia and below the detection
limit (< 0.2 mg/Nm3) for other potential degradation products. The water condensate from the process contains mainlyammonia that can be removed in a relatively simple treatment plant to produce boiler feed water make-up.

•

Work to date has shown that CapEx is competitive for this technology, with room to reduce further. OpEx reduction istargeted by developing a novel sorbent to reduce cost further whilst maintaining emissions benefits.

Figure 1: Simplified Process flow scheme of the Solid Sorbent Technology pilot plant.

68

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACTSVANTE

Julia McKenna
Email:

jmckenna@svanteinc.com

Web:

www.svanteinc.com

BENEFITSSUMMARY
Capture of CO2 from industrial operations using chemicalsolvents is technically proven, but the costs in terms ofcapital and energy use are high and the potential for
toxic emissions has prompted developers to seek othertechnological approaches. One avenue showing promiseis the use of solid adsorbents. Svante has developed asolution to capture large-scale CO2 emissions, produced
from hard-to-abate industries such as cement, hydrogen,chemicals, and pulp & paper, either for safe storage or to
be used for further industrial use in a closed loop.
Svante’s technology is currently being deployed in the fieldat pilot plant-scale by industry leaders in the energy andcement manufacturing sectors, such as:•

CO2MENT Pilot Plant Project: Partnership between
Holcim and TotalEnergies operating a 1 tonne per day(TPD) plant in Richmond, British Columbia, Canada,that will re-inject captured CO2 into concrete.

•

Cenovus: Construction and commissioning of a 30
TPD demonstration plant completed in 2019 at anindustrial facility in Lloydminster, Saskatchewan,
Canada.

•Chevron USA: A 25 TPD demonstration plant iscurrently under construction for deployment near
Bakersfield, California, USA.

•In addition, several engineering projects forcommercial-scale carbon capture projects ranging
from 500 to 4,500 TPD are underway in North America
and Europe.

70

STATE OF THE ART: CCS TECHNOLOGIES 2022

Svante has now attracted more than US$195 million in
funding since it was founded in 2007 and is currently
expanding its commercial filter manufacturing facility in
Canada. By the end of 2023, the new facility will havean annual capacity to deliver filter modules capable ofremoving 5 Mtpa CO2.
Svante’s energy efficient and low-cost technology, theVeloxoTherm™ carbon capture process, is an intensified
rapid-cycle Temperature Swing Adsorption (TSA) systemusing advanced Structured Adsorbent Beds (SAB). This
novel process is designed to capture CO2 directly fromindustrial sources and release pure CO2 in less than
60 seconds, compared to hours for other technologies
and requiring significantly less capital cost. The capture
process is implemented via a device similar to that ofregenerative air heaters widely used in power plants, inwhich a proprietary structured adsorbent is arranged ona circular rotating structure, known as a Rotary Adsorption
Machine (RAM). The device simultaneously exposes
different segments of the structure to each step of the
TSA cycle. A key advancement is the development ofinnovative adsorbent materials, which enable the use of a
rapid temperature swing cycle.

•

Svante’s technology utilizes a single piece of compact equipment enabling a competitive reduction in capital costs
compared to first generation approaches.

•

Capacity is scalable in multiples of individual Rotating Adsorption Machines (RAMs) between 500 and 5000 TPD of
CO2 captured, depending on the application and product purity requirements.

•

Svante’s technology is flexible by using different adsorbents and can target low and high concentration industrial fluegases.

•

Inherent ability to load follow and start and stop extremely quickly by easily controlling the rotation speed of the RAM.
This feature enables CO2 capture from intermittent process such as lime production PFR kilns and electric arc furnaces.

•

Svante’s proprietary VeloxoTherm™ process is environment-friendly based on novel Structured Adsorbent Beds (SAB),
which are not subject to nitrosamine and nitramine emissions.

•

No process safety associated with new hazardous chemicals being brought onsite.

CONTACTSVANTE
CO2 Capture Plant Process Description
The Svante carbon capture process consists of a series ofsteps which include passing flue gas, regenerating steam,and conditioning air through structured adsorbent beds ina specific order.
i.

ii.

72

Adsorption: The first step in the process is theintroduction of the feed gas into the structured
adsorbent beds, where CO2 is adsorbed onto thesurface of the adsorbent, while the remainder of theflue gas mainly N2, O2 and H2O is sent to the stack asspent/exhaust gas.
Regeneration: The CO2-rich adsorbent bed thenrotates to a sector of the process where low pressure
steam flows through it, requiring only a small amountof superheat to overcome heat losses from thesystem. This is the first regeneration step, wheresteam regenerates the adsorbent, releasing a stream
composed primarily of CO2 and steam.

STATE OF THE ART: CCS TECHNOLOGIES 2022

iii. Conditioning: After regeneration with steam, thebed rotates through a sector of the process where
heated ambient air is used to condition and cool thestructured adsorbent. The ambient air stream, termed
Conditioning Gas, removes most of the water vapor
from the adsorbent.
The adsorption, regeneration, and conditioning functions
described above are integrated and implemented in theRAM, as shown in the figure below.

Julia McKenna
Email:

jmckenna@svanteinc.com

Web:

www.svanteinc.com

TRANSPORTCONTACT“K” LINE

Satoshi Kanamori
Email:

Kanamori.satoshi@jp.kline.com

Web:

www.kline.com

DESCRIPTION“K” LINE considers the realization of a carbon-neutral
society to be an important issue for society and is
promoting various environmental initiatives.
In particular, “K” LINE has been promoting its CCUS andLCO2 transportation businesses as key technologies tocontribute to the zero emission of both our company andsociety.

SUMMARY
Kawasaki Kisen Kaisha, Ltd. (“K” LINE), founded in 1919,
is one of the largest shipping companies in the world.
Its core business is marine transportation particularly
deploying LNG tankers, LPG tankers, crude oil tankers,
offshore support vessels, dry bulk carriers, car carrier, andcontainership. “K” LINE is operating about 440 vessels
worldwide as of today.
We will put full effort into the decarbonization of thecompany and society with the aim of achieving asustainable society and enhancing the corporate value.
The initiatives include vessels for projects related tooffshore wind power, transportation of new energy sources
such as hydrogen and ammonia, and transportation of CO2
captured from CCUS projects. We continue to leverage
the knowledge and network that we have accumulated
over the years to promote the initiatives. We believe that
supporting and promoting decarbonization of society
is a major opportunity to open up new domains for the
shipping business.

BENEFITS•“K” LINE currently operates 47 LNG carriers and 4 LPG carriers and has extensive experience and know-how in theliquefied gas transportation. Based on our experience, we can provide safe and reliable transportation service ofliquefied CO2 (LCO2).

•

Carbon dioxide (CO2) must be constantly under pressure to remain in liquid phase and LCO2 needs to be carried inpressurized tanks for shipping. “K” LINE has accumulated operational experience of pressurized tanks and can meetcustomers’ transportation requirements under various pressure conditions.

•“ K” LINE is participating in the demonstration project on LCO2 ship transportation and developing LCO2 transportation
technology under low-temperature and low-pressure conditions, which is considered to be suitable for large-scale
LCO2 transportation. We contribute to the development of the CCUS value chain in terms of ship transportation.

•“K” LINE is steadily promoting an action plan of achieving net-zero greenhouse gas (GHG) emissions by 2050 andworking on various approaches such as improvement in efficiency, zero-emission marine fuel and on-board CCS
system. We are also proceeding with another demonstration project of, “CC-Ocean”, which is on-board CO2 capture
plant. We can contribute to the zero emission of the entire CCUS value chain with such solutions.

76

STATE OF THE ART: CCS TECHNOLOGIES 2022

“K” LINE has gained a lot of experience in the businessof low-temperature liquefied cargo transportation such as
LNG, LPG, hydrogen and ammonia transportation for a longtime. In recent years, we have also been operating LNG
bunkering vessels equipped with pressurized tanks, andhave accumulated know-how on pressurized tanks, which
are expected to be used for LCO2 transportation. With thisknowledge and a proven track record of safe operations,“K” LINE is now accelerating its CCUS-related businessand is preparing for the future large-scale international
LCO2 transportation.
“K” LINE is currently developing CCUS technology from
two angles.
Firstly, since 2021, “K” LINE is participating in thetransportation
demonstration
project
on
LCO2
supported by New Energy and Industrial Technology
Development Organization (NEDO), Japanese national
research and development agency. In this project,

the demonstration test ship will be constructed anddedicated to LCO2 transportation. The project aims todevelop the necessary technologies for an integrated
LCO2 ship transportation system and safe operational
method. In this demonstration project, in addition to theexisting technology of transporting LCO2 under mediumtemperature and medium-pressure conditions, a seriesof transportation experiments under various conditions,
including low-temperature and low-pressure conditions
will be conducted to develop a large-scale CCUS chain.
“K” Line is in charge of safety evaluation and establishingtechnical guideline for LCO2 transportation and cargohandling of the demonstration vessel. Then, “K” Line is also
working on another demonstration project, called the “CCOcean”, which aims at onboard CO2 capture to ensure
zero emissions from vessels. We have been conducting a
joint project with Mitsubishi Shipbuilding and Nippon Kaiji
Kyokai (Class NK) to develop CO2 capture plant onboard
vessel as part of the “Research and Development for
Advancing Marine Resources Technologies”. The plant
was installed on the coal carrier “CORONA UTILITY” inearly August 2021 to separate and capture CO2 from theexhaust gas of the vessel’s engine. An operational test has
been conducted in this regard. We, at “K” LINE, will further
strengthen our efforts in the CCUS business and contributeto the realization of a net-zero society.

CONTACT(1) Name of Company:
Knutsen NYK Carbon Carriers AS (50/50 JV between NYK and Knutsen Group)

PCO2® TECHNOLOGYKNUTSEN NYK CARBON CARRIERS

Anders Lepsøe
Email:

ale@kn-cc.com

Web:

www.kn-cc.com(2) Contact:
NYK:
Svein Steimler+47 900 11 166
svein.steimler@nykgroup.com

Below is an enthalpy diagram showing the transportcondition of the CO2:
The PCO2® vessel design, construction, fabricationand operation shall be based on Maritime Rules andRegulations and recognized Codes & Standards such as,
but not limited to:Knutsen Group:
Trygve Seglem+47 52 70 40 00
firmapost@knutsenoas.com
KNCC:
Anders Lepsøe+47 48 12 19 83
ale@kn-cc.com
Website : https://www.kn-cc.com/contact-us•

IMO regimes•

IACS Classification Rules and Standards for design andConstruction of Ships•

Flag state

Subject to direct injection offshore, the PCO2® vessel will beequipped with an adequate DP system and a Submerged

SUMMARY
Knutsen NYK Carbon Carriers AS (“KNCC”) is a joint
venture owned by the Knutsen Group (Knutsen) of Norway
and the NYK Group of Japan. Our owners already havea successful cooperation in place through Knutsen NYK
Offshore Tankers, which is engaged in the shuttle tankers
business.
KNCC’s PCO2® technology is based on the preparatorycompressed gas (PNG®) technology developed byKnutsen. The conceptual design started about 20 years
ago with an idea to apply basic design principles from thepipeline offshore industry into a design of a CNG carrier,such as for the transportation of LNG in gaseous phaseat 250 bar pressure. The technology has been further
developed to transport liquids with high evaporationpressure such as crude oil, products and CO2 at ambient
temperatures.
Adoption of the above technology was made to enhance
the process to design a containment system that would
fulfil all safety requirements and proven viable at an
efficient cost.
To meet our objectives, it was recognized at an early stage
that strong partners had to be present to enable addressing
all elements involved in the new concept. DNV acceptedto perform all work necessary to qualify and demonstratethat the system was safe, reliable and technically viable.
The other strategic partner, who accepted our approach,

was Europipe GmbH, Germany, who has participatedthroughout the entire Cargo Tank Cylinder (“CTC”) designand development program.
The strategic cooperation made it possible to achieve
a DNV GASA (General Approval for Ship application) in
CNG technology, ensuring that all requirements for a safe,
reliable and robust solution for CNG marine transportation
at 250 bar are met.
The PCO2® technology is logic continuation of a feasibility
study executed on behalf of a well-known Oil Major back in
2018. That study evaluated the feasibility to transport crude
oil at high TVP (true vapor pressure). The latter including
LPG in the crude flow. The study was based on the samecargo tank containment system. It became evident that thesame system could be used for several products including
CO2.
Following the above, the PCO2® technology comprises
the transport of CO2 at ambient temperature in verticalstacked cylinders in the vessel’s cargo hold. The ambient
temperature lies within the range of 0 - 10 °C and thepressure in the cylinders ranges from 34 bar to 44 bar. We
are convinced that PCO2® is the optimal transport condition
and for direct injection offshore, where pipeline and shore
storage for low and medium pressure is not feasible.

(1) Name of Company:
Knutsen NYK Carbon Carriers AS (50/50 JV between NYK and Knutsen Group)

78

STATE OF THE ART: CCS TECHNOLOGIES 2022
(2) Contact:
NYK:

Turret Loading (“STL”) compartment to accommodate aturret and swivel system for hook-up to a pre-installed
STL loading buoy. In addition, KNCC will apply inherent
competence and experience from KNOT for CO2 offshore
loading, offloading and injections by the PCO2® vessels.
The PCO2 vessel will have a certain number of cargocylinders installed in the vessel’s cargo hold.
Number and size (height) will vary according to needs
and requirements. Each cargo hold will have individual
pumps and utility equipment for safe discharge and cargomonitoring.
Approval in Principle (AiP) has been awarded for PCO2®
tank system from DNV.

CONTACTPCO2® TECHNOLOGYKNUTSEN NYK CARBON CARRIERS

Anders Lepsøe
Email:

ale@kn-cc.com

Web:

www.kn-cc.com

BENEFITS

Image of a PCO2® vessel with bow-loading system.

•

Easily scalable for both the vessel size and the CO2 volume to be transported•

Free surface tank effect eliminated regarding stability impacts•

Stable cargo condition during loading/offloading/transportation (far from triple point)•

Relatively lighter Cargo Containment System than other transportation modes, which require less ballast and draft(7-9m) making the vessel more compatible to many ports worldwide•

Lower cost for manufacturing Cargo Tank Cylinders by using well-known carbon steel•Less facility (equipment)/energy/cost required for liquefaction and temporary storage at emission source•Less facility (equipment)/energy/cost for heating and pumping required at injection/storage site•

Approval in Principle(AiP) awarded for PCO2®︎ tank system from DNV.

Below – side view of the PCO2®

(1) Name of Company:
Knutsen NYK Carbon Carriers AS (50/50 JV between NYK and Knutsen Group)

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STATE OF THE ART: CCS TECHNOLOGIES 2022
(2) Contact:
NYK:

CONTACTNAME OF TECHNOLOGYMAN ENERGY SOLUTIONSPeter Klotzsche
Email:

peter.klotzsche@man-es.com

Web:

www.man-es.com

DESCRIPTION
Our integrally geared compressor design is tailored forcarbon dioxide compression up to 250 bara. Adapting thepinion speed compensates for the decreasing volume flow(high compressibility of CO2), thus maintaining the best
efficiency throughout the entire compression.
Intercooling of the wet CO2 after each compression stage
and removal of the condensate reduces the water vapor
content in the stream and the head requirements, thereby
lowering the power consumption. Furthermore, hot water,oil, or even steam can be recovered from the intercoolers
to supply heat for the CO2 capture and purification process.
For example, the heat recovered from the intercoolers cancover 30 - 50% of the energy required by the chemical
absorption process for the desorption of captured carbon
dioxide.

SUMMARY
Currently approximately 80% of the captured industrial
CO2 emissions are purified by chemical absorption in
post combustion applications at low pressure. Economic
pipeline transportation and a safe sequestration requirea high-density CO2 (supercritical/dense condition) bycompressing the stream beyond the critical point topressures between 10 – 15 MPa.
Capturing, compressing, and transporting the CO2 to asuitable sequestration site account for approximately 90%of the costs for each ton of CO2. Therefore, compressor
efficiency improvement, waste heat use and power
recovery are key for reducing costs.

Supercritical compression of wet CO2, integrationof efficient cooling, drying and performance control
concepts make CO2 compression a challenge. MAN
Energy Solutions SE has researched and developed thesesubjects for over three decades while monitoring morethan 30 operating references including approximately 20
in the high-pressure, supercritical conditions. Our extensive
experience, paired with a dedicated CO2 test rig, in-house
gearbox manufacturing and digital capabilities enable MAN
Energy Solutions to optimize the compression solutionsin terms of efficiency, heat and power recovery while
securing a high-quality standard.

BENEFITSMAN Energy Solutions’ compression and energy recovery solution are reliable, safe and efficient:•Over 30 years of experience in CO2 compression with integrally geared compressors.

•

Own gearbox design and manufacturing•

Extensive knowledge in supercritical compression (up to 250 bara) based on research and modelling competencies•

Solutions provider for cost reductions in the CCS value chain integrating heat and power recovery within thecompression system.

•

Deep know-how in auxiliaries’ integration, such as cooling and drying systems.

•

Strong digital capabilities, e.g. digital twin, dynamic simulations, training simulator, remote services, efficiency
optimization and preventive maintenance.

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STATE OF THE ART: CCS TECHNOLOGIES 2022

Admissions and extractions between stages make our
integrally geared design extremely flexible for gathering
or delivering multiple streams at different pressure levels,
or even combining from different processes with thesame compressor. MAN Energy Solutions can match ourcompressor to your process, thereby improving the overall
efficiency. We co-operate with our customers and partners
to find the best solution.

Our test benches can run ASME PTC10 Type 1 and 2 tests
to prove performance and mechanical soundness.
MAN Energy Solutions has a unique CO2 test bench thatallows R&D tests in the supercritical phase, monitor seal
behaviour and cooler heat transfer at high pressures,verify Joule-Thompson-Effects in valves, measure shaft
vibrations, and bearing temperatures under severe
conditions.
Predictability of the compressor plant behaviour, especiallyin emergency and transient situations are importantto reduce risks and costs. Our digital competencies
complement our portfolio with dynamic performanceand training simulations of a digital twin. Remote services
and commissioning, efficiency optimization and online
monitoring reduce your costs and enhance the availabilityof your equipment.
Appropriate integration experience of different coolingsystems, e.g. water cooled or air cooled heat exchangers,
closed loop water systems and drying units such as tryethylene glycol gas dehydration, molecular sieves andothers contribute to the optimization of the plant.

CONTACTLIQUID CARBON DIOXIDE (LCO2) PUMPSVANEHØJ

Thomas Uhrenholt Nielsen
Email:

tun@svanehoj.com

Web:

www.svanehoj.com

DESCRIPTIONSUMMARY
Svanehøj is a market leading pump manufacturer,
specialised in multi-gas fuel and cargo pumping systems.
Based upon nearly 100 years of experience of pumping
liquids, we have developed an unparalleled design andtechnology, ensuring our customers the best, safest andmost reliable pump solutions on the market.
Our pumping solutions are a key part of the fuel andenergy cargo supply in the shipping industry, and we arecommitted to reducing the impact on the environment
through sustainable solutions.

At Svanehøj, we believe in working closely withour customers, and we strive to build longstanding
relationships. Our employees are highly educated,
experienced, and possess the technical know-how
required to suit the needs and demands of our customers.
With our in-depth experience and a proven track-record,
we make it simple to adapt to the fast-growing world ofcarbon-neutral solutions.

BENEFITS•

Multi-gas: A Svanehøj pump can handle all types of gas cargo at all temperatures and gravities without any component
changes; including CO2, LNG, LPG, ammonia, methanol, hydrogen, ethane, and ethylene.

•

Service not required until 5 years of operation. Full overhaul after 10 years of operation,•

Low pressurized CO2 with pressure down to 5.2 bar, which together with the unique design of the Svanehøj DW Pump
ensures a low net positive suction head required (NPSHr) and reduces the risk of cavitation and dry ice formation.

•

Fully pressurised tankers, cargo at ambient temperature, tank pressure more than 20 bar.

•Semi-refrigerated tankers, cargo liquified by cooling/pressure process down to -55 °C.

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STATE OF THE ART: CCS TECHNOLOGIES 2022

Complex CCS solutions – we already have theexperience

without any component changes, including CO2, LNG, LPG,
ammonia, methanol, hydrogen, ethane, and ethylene.

Carbon Capture and Storage is described by many as oneof the most promising technologies to help reduce CO2
emissions from heavy transport and industry. In this context
LCO2 carriers will play an essential role in transportingliquefied CO2 to depleted oil and gas reservoirs or otherdeep places, where it is stored.

The Svanehøj deep-well pump is designed with the mostsensitive components placed outside the tank, allowing
easy access to bearings and mechanical seal with noneed to depressurize the tank. The unique design of the
deep-well pump eliminates excess heat and pressure andensures a low NPSHr, which reduces the risk of cavitationand dry ice formation. In order to always ensure safe
operation, the pump is equipped with a pressure boosterthat monitors the pressurized shaft seal and ensures anoverpressure in the mechanical seal of 2 bar compared tothe actual tank pressure.

What few people know is that, Svanehøj is one of thevery few pump manufacturers with actual experiencein CO2 pumping systems. Already more than 20 years
ago, we delivered our first deep-well cargo pumpsolution for an LCO2 carrier, and our deep-well pumptechnology is suitable to support a growing CCS industry.
So, even though long-term storage of CO2 is currently
in a rudimentary stage, we at Svanehøj already have theexperience and competencies to supply the pumping
systems.
The first Svanehøj deep-well cargo pump was developedin the 1960’s. Since then, we have developed andmanufactured tailored cargo pump solutions for more than
1,300 gas carriers, delivering more than 14,500 deep-wellpumps around the world.
Our product range in deep-well gas pumps ensures
suitability for almost all needs with tailored gas pumpsolutions for all vessel types. Our pumps can handle
all types of gas cargo at all temperatures and gravities

With a Svanehøj deep-well pump, maintenance is easy.
As all sensitive components are placed outside thetank, the pump only requires servicing every five years
during regular docking. In fact, the maintenance until 10
years/50,000 hours does not require access to the tank.
At Svanehøj, we take pride in being flexible and adapting
solutions to specifically suit any challenges that ashipowner or a shipyard may encounter. Our dedicatedproject team tailors gas pump solutions for all vessel
types, from the smallest fully pressurized push barges anddedicated CO2 carriers to the largest fully refrigerated verylarge gas carriers (VLGCs).

CONTACTCENTRIFUGAL PUMPS FOR DECARBONIZINGTORISHIMACENTRIFUGAL PUMPS & CRYOGENIC PUMP SERVICEOne Stop Shop/Cradle to Grave•

Key benefits that Torishima brings to the CCUS, andcarbon-intensive market include:

Bjarne Olsen
Email:

bjarneolsen@torishima.co.uk

Web:www.torishima.co.jp/en

In conjunction with our partners, we can supply ordevelop pumps for all of the applications in the CCUS
process• With our worldwide service network and specialised
has
As a Decarbonizing
market leader in desalination, Torishima
Innovative Products for •theIndustry
expertise in cryogenic pump repair, we can offer aextensive pumping experience in the field of water
management, which will be crucial to the carbon
footprint of the carbon capture plants

cradle to grave service on the pumping equipment

The demand for energy continues to increase around the globe with particularly high growth rates and rapid
economic expansion worldwide. As a result, the Globe is now facing the challenge of reducing the CO2 footprint
and achieving Net Zero Emission by 2050.

Torishima is well placed to provide a fullrange of pumps designed for theapplications needed within the

SUMMARY
Innovative Products for Decarbonizing the Industry

Service Solutions

The demand for energy continues to increase aroundthe globe with particularly high growth rates and rapid
economic expansion worldwide. As a result, the world isnow facing the challenge of reducing CO2 footprint andachieving Net-Zero Emissions by 2050.

Torishima has a large installation base with pumps locatedthroughout the world. We are conscious that we must
provide a reliable service support network to our clients.
To this end, we have a network of service facilities locatedin key areas providing access to both spare parts andinnovative service solutions.

Torishima is well-placed to provide a full range of pumps
designed for the applications needed within the carbonintensive industry from carbon capture plants to CO2transport and storage. The products are applicable to fuelvariants of blue or green hydrogen for small combinedcycle to large super-critical thermal stations. We are able
to supply pumps for flue gas treatment, carbon capture,boiler feed pumps, boiler circulation pumps, circulatingwater pumps and condensate extraction pumps as well
as a range of auxiliary duties. Torishima pumps have been
installed globally in this market.

decarbonizing industry from carbon capture
plants to CO2 transport and storage. To
fuel switch utilising blue or green hydrogenfor small combined cycle to large superFigure 1 Water Transmission Pump

critical thermal stations. We are able tosupply pumps for flue gas treatment,

Through subsidiary, C.P.R Ltd, Torishima has over 30 years’
carbon capture, boiler feed pumps, boiler
experience in the inspection, maintenance, installationand commissioning of submersed motors and cryogenic
circulation pumps, circulating water
pumps for the liquefied gas industry. This experience ispumps
andcapture,condensate
extraction
pumps as well as a range of auxiliary duties. Torishima pumps have been
fully transferable
to carbon
utilisationand storage(CCUS) and greenhousegas (GHG)
reduction
pumping
installed globallyin thismarket.
equipment.

Research & Development

Research & Development

Energy demand continues to increase globally, however taking into

Energy demand continues to increase globally, howeverconsidering the need to also conserve power, Torishima’ s
objective is to produce high efficiency pumping equipment.
Torishima continues to invest in research and development(R&D) to meet such objectives, developing highly
technical equipment with high reliability whilst keeping ourenvironmental commitments.

account the need to also conserve power, Torishima’s objective is

86

STATE OF THE ART: CCS TECHNOLOGIES 2022

to produce high efficiency pumping equipment. Torishimacontinues to invest in R & D to meet such objectives., developing
high technology equipment with high reliability whilst keeping
Figure 3 SPVour
Water Intake Pump (Left) & MHB Barrel Case Pump (Right)
environmental commitments.

Service Solutions
CENTRIFUGAL PUMPS & CRYOGENIC PUMP SERVICE

Figure 2 Cooling Water Pump

CONTACTCENTRIFUGAL PUMPS FOR DECARBONIZINGTORISHIMA

Carbon Capture and Storage

Torishima and Partners’ Products for Various CCUS needs:

Torishima Pump has a wide product range of centrifugal
pumps capable of providing optimum pump performancefor a carbon capture and storage plant. Reference can bemade to a waste-to-energy plant fitted with an end of pipe
carbon capture plant.

The product range of Torishima Pump combines ourcapabilities within the power generation and desalinationindustry to provide optimum pump solutions for various
capture technology processes, such as post combustion,
pre-combustion and oxy fuel combustion capture. Bothlow-pressure and high-pressure pumps for application as
water intake and cooling systems, solvent handling, steam
power regeneration and CO2 treatment and storage canbe provided. In addition, Torishima is also targeting the fuelswitch market by providing liquid hydrogen pumps.

Figure 4 Schematic of waste-to-energy plant fitted with carbon capture - amine Based Solvent

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STATE OF THE ART: CCS TECHNOLOGIES 2022
CENTRIFUGAL PUMPS & CRYOGENIC PUMP SERVICE

Bjarne Olsen
Email:

bjarneolsen@torishima.co.uk

Web:www.torishima.co.jp/en

STORAGE

CONTACTDRIL-QUIP®

John Mossop
Email:

john_mossop@dril-quip.com

Web:

www.dril-quip.com

DESCRIPTIONSUMMARY
Dril-Quip® is actively supporting global goals forenvironmental sustainability. We have applied our
extensive expertise and capabilities as a leading
manufacturer of cost-effective drilling and production
products for the world’s most challenging oil and gas wells
to develop offerings that enable the economical, reliabletransportation and storage of CO2 offshore.
Our ‘shore-to-seabed’ solutions save time and money,
minimize operational and environmental risks, and reducecarbon footprint. Our technically and commercially proven
CCS portfolio includes best-in-class Dril-Quip® wellheads

BENEFITS•

Economical shore-to-seabed solutions•

Lightweight, compact and Green By Design™

•

Simple installation, operation, and monitoring•

Low maintenance, and reliable, enduring service•

Measurably reduces carbon footprint•

Seamlessly integrates with subsea templates

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STATE OF THE ART: CCS TECHNOLOGIES 2022

and the lightweight, compact Dril-Quip® SBTe™ SingleBore™
vertical tree system with patented VXTe™ self-aligningtechnology. A fully electric version of the SBTe™ is available
to allow long-distance power distribution and management
and faster data transfer for optimal digital monitoring.
Through partnerships with onshore and marine
logistics and storage development companies thatprovide innovative transportation, logistics and storage
technologies, Dril-Quip® can enable operators and storage
licensees to store CO2 efficiently and reliably for decades.

Dril-Quip offers an extensive portfolio of field-provendifferentiated products, including wellheads, connectors,
trees, templates, manifolds, and flexible risers that enable
customers to work safer, smarter, faster, and cleaner, whilesaving time and money. However, our game-changing
SS15 RLDe™ wellhead and SBTe™ SingleBore™ vertical tree
are essential to the successful injection and safe, long-term
storage of CO2 in depleted subsea oil and gas reservoirs
and saline aquifers.

By eliminating hardware, tooling, and operational steps,
the SBTe™ tree enables operators to save significant timeand money, reduce risks, and lower carbon emissions.
Additionally, the Dril-Quip® SBTe™ is designed to handle
the specific pressure and temperature considerations of
CCS and can deal with CO2 impurity levels as low as 92%
by using either a combination of CRAs, or high toughness,
low alloy steel with CRA cladding, depending on theapplication

Dril-Quip® SS15 RLDe™ Rigid Lockdown Subsea Wellhead
SystemAble to integrate seamlessly as part of a wider system, the
SBTe™ can be incorporated into a template arrangement,
attached to a marine buoy for injection purposes, or
hooked up to flexible risers and attached to monitoring
equipment as needed. It is well-suited to be an integral
part of the storage and injection infrastructure and isavailable in both hydraulic and electrical models.

Field-proven in pressure and temperature extremes, DrilQuip®’s SS15 RLDe™ System’s reliability is superior. It has
been rigorously tested and surpasses industry standards
for bending, tension, and load-carrying capacities. By
eliminating the need for extra lockdown devices andenabling casing hanger and seal assemblies to be run in
one trip, it saves significant time and money and lowers
carbon emissions.
Dril-Quip® SBTe™ SingleBore™ Vertical Tree System
Our SBTe™ SingleBore™ Vertical Tree is the most economical
tree system in the industry. Extremely lightweight andcompact, the innovative SBTe™ can be deployed from any
vessel (no rig required). Installation is simple and there arenone of the complex interfaces and downtime associatedwith competitive trees.

Dril-Quip® has designed, engineered, and manufactured
an extensive portfolio of lightweight, compact, configurable
products that when combined with the innovative offeringsof our world-class partners, bring exceptional value toevery project. Dril-Quip® is the optimal choice technicallyand commercially for all your shore-to-seabed CO2 needs.

CONTACTDUOLINE 20® FIBERGLASS (GRE) LINED TUBINGIN CO2 INJECTION AND SEQUESTRATIONMAXTUBE LIMITED

A. Fernandes & G. Radhakrishnan
Email:

ccs@maxtube.com

Web:

www.maxtube.com

Duoline GRE has been proven to withstand:•

Temperatures from -51 °C (-60 °F) to 144 °C (291 °F)•

More than 300,000 ppm chlorides•

100% wet and dry CO2•

Over 18,000 psi pressure

Duoline 20 has been a workhorse in CO2 injection wells since 1984. This track record provides significant experience forknowledge transfer into material selection for carbon injection and utilization downhole in global CCUS projects.

BENEFITS
There are two distinct contributions that Duoline 20 GRE lined tubing can make to reducing the carbon footprint of a CCUS
project.
•

Firstly, Duoline 20 GRE lining provides a corrosion barrier which protects carbon steel tubing for decades. The
combined system costs a fraction of chrome and higher alloy steel tubing. Additionally, unlike sensitive alloy steels,
Duoline GRE liners will offer consistent corrosion protection irrespective of contaminants in the flue gases fromdifferent industrial sources over the life of the project.

•

Secondly, eliminating the use of chemicals for corrosion inhibition means eliminating carbon emissions from chemical
manufacture, transportation, and injection into the wells over the life of the well.

SUMMARYAs CCUS projects are driven by the common goal of
reducing global carbon emissions, the technologies
employed in these projects have a critical role to playin achieving this goal. In several cases, existing ageing
infrastructure from oil or gas field projects is repurposed
for injecting CO2 for up to five more decades. Maxtube
provides a technology that contributes to increasing thelongevity of the asset while reducing the cost and overall
carbon footprint of the project.
Maxtube Limited are the proud owners of Duoline
Technologies in the United States. Duoline are thepioneers of Fiberglass (GRE) Internal Lining systems, used
to prevent corrosion in downhole tubulars. Over 110 million
feet of Duoline GRE lined tubing has been installed in over
55,000 wells worldwide.
What is Duoline 20 GRE Lined Tubing?
Duoline 20 is a Glass Reinforced Epoxy (GRE) composite
liner, which is installed inside steel tubing to protect it fromcorrosion due to CO2, free O2, H2S, chlorides, water, andother constituents which may exist in the process fluids.
This tubing is used downhole in injection and production
wells. Duoline GRE also mitigates solid deposition inside
the tubing.

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STATE OF THE ART: CCS TECHNOLOGIES 2022

Tubing made Carbon steel, lined with Duoline 20 GRE, canbe utilized instead of expensive chrome and higher alloysteel grades, which are often the appropriate material forresistance to CO2.
Duoline 20 GRE Lined tubulars have been successfully
employed in a variety of applications where they havebeen exposed to extreme process conditions – hightemperatures, high pressures, high concentrations of
dissolved gases, high chlorides, and high flow rates aswell as mechanical “abuse” during multiple downhole
interventions. The success of the technology is basedon extensive testing and trials conducted by operators
worldwide over five decades.
Duoline GRE liners are a proven flow assurance enabler.
Benefits derived from the properties of the system include
elimination of solid deposition, higher flow rates, reduced
frictional losses and higher fluid temperature retention.
These are attributed to the smoother surface of the Duoline
GRE compared to steel, as well as the added insulation
provided by the layers of grout and GRE. Enhanced
flow assurance allows a more consistent, uninterrupted
injectivity rate.

The above benefits of applying Duoline 20 GRE Lined tubing in CCUS applications enable significant reductions in Capex
and Opex over the lifecycle of the wells. This in turn enhances the overall viability of the project.

CONTACTDUOLINE 20 FIBERGLASS (GRE) LINED TUBINGIN CO2 INJECTION AND SEQUESTRATIONMAXTUBE LIMITED

A. Fernandes & G. Radhakrishnan
Email:

ccs@maxtube.com

Web:

www.maxtube.com

DESCRIPTION
The Duoline 20 Lining system consists of a fiberglass
reinforced epoxy resin composite liner inserted inside low
alloy carbon steel tubing with a cement grout. The grouttransfers fluid pressure directly to the steel. The ends ofthe liner are protected from mechanical damage by end
caps known as flares. A polymeric Corrosion Barrier Ring
(CBR) extends the corrosion barrier across the coupling
between two adjacent flares.
Duoline 20 GRE Lined Tubing in CO2 Injection and
Sequestration
The first miscible CO2 Injection EOR project in Canada
began in 1984 in the Joffre Viking Tertiary Oil Unit byVikor Resources and the Alberta Oil Sands Technology
and Research Authority. This is the first known successful
application of fibreglass lined tubing to combat CO2
corrosion.
Since then, Duoline 20 has been used extensively by
Equinor, ExxonMobil and Oxy in CO2 injection wells. In the
United States, nearly 20 million feet of Duoline GRE Linedtubing has been used in CO2 sequestration and injection.
In 1996, Statoil were among the first to use Duoline GRE
Lined Tubing in offshore Water Alternating CO2 (WAG) wells
in Europe.
Duoline 20 has since become the gold standard for tubing
material in CO2 injection wells, CO2 WAG wells, carbonatedwater injection wells and hydrocarbon producers with highCO2 concentrations. Duoline GRE has been tested andfield-proven to withstand 100% CO2 (wet and dry) and low
pH solutions from dissolved CO2 for decades.
Duoline 20 GRE lined tubing offers attractive savings
compared to capital intensive high-chrome materials,
such as 25CrSDSS and 28Cr, that are often the metallic
selection for CO2 applications.
While CCUS projects depend on dehydration of the CO2
gas to prevent corrosion, it is undoubtedly challenging
to maintain the 100% absence of moisture downhole.
There are concerns around the impact of residual waterfrom the reservoir during possible shut-in of CO2 injection
wells. In such cases, the dehydration of the gas will proveineffective in combatting corrosion downhole. This risk
necessitates a pre-emptive corrosion prevention strategy.

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STATE OF THE ART: CCS TECHNOLOGIES 2022

Over the life of CCUS projects, it is expected that the
injected gas may be contaminated with NO2, SO2 andother contaminants from flue gases generated at various
industrial sources. The performance of metallic alternatives
is sensitive to variations in the composition of process
fluids. Duoline GRE liners, on the other hand, will offer
consistent corrosion resistance irrespective of variations inconstituents over the life of the project.
The selection of Duoline GRE lined tubing provides added
insurance against potential process interruptions on thesurface. For instance, any disruption to surface facilities
for dehydration or treatment of the injected gas will notinterrupt CO2 injection if the material used downhole is able
to withstand all corrosive elements. It is also noteworthy
that repairs due to avoidable downhole failures are far
costlier and time-consuming than repairs on the surface.
Such cases justify the added insurance of Duoline GRE
lining of tubing.
The above points demonstrate how Duoline GRE
enhances the integrity and flow assurance of CO2 injection
systems thereby reducing the overall carbon footprint of
the project. Duoline GRE Lined tubing offers substantial
value to the overall economic and environmental viabilityof CCUS projects. Whether the well is completed onshore
or offshore, platform or subsea, Duoline GRE lining is asingle solution for tubing corrosion prevention and flow
assurance.
Industry and Regulatory Authority Endorsements
Duoline GRE liners have been tested extensively forresistance to exposure to a variety of industry chemicals,
full-scale combined loading inside tubing, pressure
cycling, high erosional velocities, fatigue, and durability
when exposed to downhole, coiled tubing and wireline,
interventions.
Saudi Aramco, Shell, BP, Eni, and Statoil have conducted
tests to confirm the viability of Duoline 20 GRE lined tubing
as an alternative to chrome alloy steels.
Eni have performed several tests to qualify Duoline 20
GRE Lined tubing specifically for gas-well applications.
These include tests to confirm the erosion resistanceand mechanical properties of Duoline GRE which provedthat its fatigue resistance is about nine times higher thansuper-duplex stainless steel. Direct impact and straightpipe test results showed a very good resistance of Duoline
GRE comparable to that of a Nickel Alloy 625 sample
under similar conditions. These tests verified the erosional
resistance of Duoline GRE essential for use in high velocity
gas wells.
Duoline GRE has been used in wells with bottom holetemperatures up to 145 °C (293 °F) and has also beentested for resistance to temperatures as low as -51 °C (-60
°F). The resistance of Duoline GRE to temperature swings
is particularly relevant considering the phase changesensitivity of CO2 relative to temperature and pressure.
Operators have tested the compatibility of the Duoline
20 GRE Lining System with several families of premium
connections. These confirm that the Duoline’s GRE
lining process and system components do not affect theconnection dimensions, torque values and gas sealability.
Duoline 20 GRE Lining systems have been applied on
pipes with premium connections from Tenaris, Vallourec,
JFE, Voest Alpine and TMK, among others.
In the US, experience and good practices recorded in
the field of CO2 injection are documented as regulatory
alternatives and operating practices for the geologicalsequestration of CO2 by the United States’ Environmental
Protection Agency (USEPA). Federal Requirements under
the Underground Injection Control (UIC) Program for CO2
geologic sequestration wells, are codified in the US Code ofFederal Regulations, known as the Geologic Sequestration
Rule, which establishes a new class of injection well (ClassVI) and sets minimum technical criteria for these wells forthe purpose of protecting underground sources of drinking
water (USDWs). Proper well construction is necessary toensure that CO2 is safely injected into and contained within
the targeted injection zone for the protection of USDWs.
This guidance describes the construction and operating
requirements for an approved Class VI injection well. GRE
lined tubing is well accounted for in this document.

Value addition from flow assurance benefits
Duoline GRE retains its surface smoothness over its
life. This has proven to retard, and even eliminate, thenucleation and subsequent deposition of solids suchas scales, paraffins and hydrates on its surface hence
enhancing flow assurance in wells.
Flow assurance benefits derived from Duoline 20 GRE
Lining have also been attributed to the thermal insulation
provided to the steel by the fiberglass and grout. Eni andPertamina have published findings of higher temperatureretention in wells with Duoline GRE lined tubing compared
to bare steel tubing.
For completions requiring higher levels of thermal
insulation, Duoline can engineer a lining solution
compatible with premium connection Vacuum Insulated
Tubing (VIT) to combine superior corrosion resistance withsuperlative thermal insulation.
The benefits of Duoline GRE lining system have also
been applied to flowlines. Since 2008, Eni, Shell, andApache subsidiaries have been using Duoline GRE
lined, API and Premium connection, tubing to constructflowlines used for the transportation of hydrocarbons
and water. While standalone GRE systems are available
for flowline construction, the presence of steel reinforces
the pressure bearing capabilities of the flowlines. In aworldwide first, Shell constructed a high-pressure flowline
network using premium connection tubing. In such asystem, the combination of the metal-to-metal seal in thepremium connection tubing, and the Duoline GRE backed
by the steel body of the pipe, ensure that there is nopermeation of dissolved gases through the flowline into
the atmosphere.

FULL VALUE CHAIN

CONTACTCHILLED AMMONIA PROCESSBAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

BENEFITS•

Demonstrated low specific thermal energy consumption of 2.6 GJ/ton CO2•

Uses ammonia, a commodity chemical that is easily procured and not bound to a specific supplier•

Stable reagent. Unlike amine-based solvent systems, it does not suffer from thermal and oxidative degradations•

Flexible for process integration. Allows efficient-direct high temperature waste heat utilization or direct electricalheating without the degradation of solvent performance•

Tolerant towards oxygen in flue gas and towards contaminants such as SOx and NOx•

Produces less harmful emissions and potentially useful by-products•

Regenerates CO2 at high purity (> 99.5%) at elevated pressure, thus requiring less compression energy for thedownstream CO2 product

SUMMARY
The Chilled Ammonia Process (CAP) was developed toaddress the challenges of removing carbon dioxide fromlow-pressure flue gases, which were generated by fossilfuel-based power plants and industrial emissions points,
such as coal-fired power plants, waste-to-energy power
plants, biomass power plants, cement plants, refineries,
and petrochemical complexes.
CAP is a post-combustion carbon-capture process thatuses a non-proprietary solvent formulation based onammonia. Ammonia is a low-cost, inorganic commodity
chemical, readily available on the global market frommultiple sources and not bound to any specific supplier.
It is also stable, tolerant to flue gas contaminants andtypically exhibits very low and controllable loss in the CAP
process. Moreover, green ammonia (produced from greenhydrogen) could be used instead of conventional ammonia
in the CAP process.
Amine-based solvents have a tendency to degrade
as a result of exposure to hot environments (thermal
degradation), in the presence of oxygen (oxidative
degradation) and in acid gas reactions (such as NOx).

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STATE OF THE ART: CCS TECHNOLOGIES 2022

Chiller System

REF
TreatedFlue Gas

The degradation results in a reduction of performance,
solvent loss, equipment corrosion and the generation ofvolatile degradation compounds that are emitted into thetreated flue gas, including nitrosamines, which are known
carcinogens. Such degradation phenomena are absent
for CAP, as the process uses an ammonia-based solvent,which is inorganic. CAP has the added advantage of being
able to regenerate CO2 at elevated pressure, resulting in
reduced energy costs to liquefy or further compress theCO2 downstream.
CAP has been validated at several test facilities with adesign capacity of up to 100 ktpa CO2, treating flue gases
generated by oil boilers, coal boilers and industrial offgases. A CAP plant designed to capture up to 80 ktpa
CO2 has been operated at Test Centre Mongstad (TCM)
in Norway for 2 years, where it demonstrated low specificthermal energy consumption of 2.6 GJ/ton CO2 on refinerycracker offgas (12.5 -16.0% CO2). The testing at TCM also
demonstrated CAP’s ability for quick start-up, low ammonia
emissions, high CO2 product purity and meeting targeted
CO2 capture rates.

Cooling
Steam
REF

NH3 Stripper

Flue Gas
Water
Rich Solution
Lean Solution
CO2
NH3/CO2
Refrigerant

REF

DCH

CW

Water
Wash

Product CO2
to Compression

REF

CO2 Wash

CO2
Absorber

REF

CO2Regenerator

DCC

Flue Gas In
Flue Gas
Condensate

Flue Gas
BlowerSteam In
Reboiler
ReturnCondensate

CONTACTCHILLED AMMONIA PROCESSBAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTION
The Chilled Ammonia Process (CAP) uses an ammoniatedaqueous carbonate solution to absorb CO2 from the fluegases at ambient pressure and low temperature. Unlike
other technologies, the functionality of the ammonium
solution is not affected by oxygen and easily purged ofheat stable salts formed by trace acidic components,
which may pass dedicated flue gas preconditioning steps.
Moreover, since its gaseous emissions and liquid waste
streams are non-toxic, no additional treatment facilities are
required.
A simplified process flow diagram of the CAP technology isshown in the accompanying figure and the process can be
described as follows.
Inlet flue gas first undergoes cooling via a direct contact
cooler (DCC) that enables the contact of gas with coolingand chilled water to lower the flue gas temperature to asuitable level (typically below 15 °C), which is needed for
the CO2 absorption process and water balance. Most of thewater vapour contained in the flue gas is removed in thisstep, which reduces the volumetric gas flow and increases
the CO2 concentration. For conventional amine-based
solvents, a flue gas pre-treatment step is required, which
is typically integrated with the DCC to reduce NOx, SOx
and other contaminants in the flue gas to very low levels
to decrease degradation and formation of heat-stable salts
when the flue gas interacts with the solvent. However, for
CAP, this pre-treatment step is typically not required as
the ammonia-based solvent is able to tolerate these fluegas contaminants. Strong acids such as SOx react withammonia and form heat-stable salts, which are withdrawn
from the system as an aqueous by-product.

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STATE OF THE ART: CCS TECHNOLOGIES 2022

Cooled flue gas from the DCC enters the bottom of theabsorber column, where it is washed counter-currently
with lean ammonia-based solvent (orange line). CO2
is selectively removed from the flue gas in a chemical
absorption process using the alkaline lean solvent. The
lean solvent is a solution comprising ammonia, waterand CO2 where different species (ammonium carbamate,ammonium bicarbonate, ammonium carbonate and alimited amount of free ammonia in an aqueous solution)
are in equilibrium. The dissolved ammonia species reactwith CO2 from the flue gas in the absorber by shifting thespecies’ equilibria towards bicarbonate. The CO2-richsolvent (green line) leaves at the bottom of the absorberand is sent to the regenerator section, where it is heatedto a temperature high enough for CO2 to be released
from the solvent. A reboiler located at the bottom of theregenerator column provides the heat to the solvent. The
heating source is typically steam, although hot oil or heatfrom a direct-fired or electric heater can also be used dueto the absence of thermal degradation.

Heat is imparted to the solvent to shift the equilibria toammonia-rich species releasing the absorbed CO2, whichleaves at the top of the regenerator column. Comparedto the amine-based post-combustion technologies thatregenerate CO2 at near atmospheric pressure, CAP
regenerates CO2 at an elevated pressure (14 bar - 25
bar[a)), which reduces the downstream compression power
requirements.
Regenerated lean solvent (orange line) is returned to theabsorber after undergoing cooling through heat exchangewith the cold rich solvent in the lean-rich heat exchanger,
which simultaneously heats the rich solvent. This is an
important heat integration step that significantly reduces
the reboiler heat requirement.

Treated flue gas exiting the top of the absorber column
contains residual CO2 and ammonia, which is recovered
with a water wash step to prevent unacceptable emissionsof ammonia into the atmosphere. After the water wash
step, the flue gas is routed to a flue gas heater. A guardsystem is integrated with the flue gas heater, which relieson the injection of sulfuric acid to neutralize any residual
ammonia, converting it into ammonium sulphate. The fluegas is reheated with warm water condensed from the DCC,
which serves to raise the temperature of the final treatedflue gas to a temperature high enough to be released into
the stack and to optimize the water balance of the system.

CONTACTMIXED-SALT PROCESSBAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTIONMSP is a post-combustion technology that is applicable toa wide range of flue gases. It uses a blend of ammonium
and potassium-based salts to absorb CO2 from flue gases
at ambient pressure and temperature. The stability of the
inorganic solvent used by MSP’s ammonium solution
is not affected by oxygen and shows high tolerance toacidic trace components present in the incoming flue gas.
The process is characterized by very low emissions andproduces little-to-no toxic waste.
A simplified process flow diagram of the MSP technology is
depicted in the accompanying figure and the process canbe described as follows.

SUMMARY
Baker Hughes uses the Mixed-Salt Process (MSP) forCO2 capture under license from SRI International. SRIInternational received support from the US Departmentof Energy’s Office of Fossil Energy and National Energy
Technology Laboratory (NETL) for the development of thistechnology.
MSP is a post-combustion carbon-capture process thatuses a novel solvent formulation, which is based on
potassium carbonate and ammonium salts. Both chemicals
are low-cost, inorganic commodity chemicals, and readily

available on the global market from multiple sources.
The inorganic solvent used by MSP is tolerant to fluegas contaminants (such as SOx, NOx, and O2), unaffectedby thermal and oxidative degradation, results in lower
emissions, lower toxicity, and higher CO2 regenerationpressure compared to conventional amine-based
solutions. MSP has been demonstrated at the capacity of
0.25 tpd at the SRI campus in Menlo Park, USA. A 10 tpd
pilot-scale plant to demonstrate the MSP technology at the
University of Illinois is currently in the design phase.

Inlet flue gas first undergoes cooling to 20 - 30 °C in a directcontact cooler (DCC) and subsequently enters Absorber
1, where it contacts the mixed salt solvent countercurrently. The mixed salt solvent in Absorber 1, which hasa higher concentration of ammonium-based species thanpotassium-based species (high ammonia/potassium ratio),
performs the bulk removal of CO2, absorbing 60-80% of
the CO2 in the flue gas. The remaining CO2 is absorbed in
Absorber 2, which operates with the mixed-salt solvent witha lower ratio of ammonium-based species to potassiumbased species than that of the solvent feed of Absorber 1.
Absorber 2 performs the trim removal of CO2 to achieve
an overall CO2 capture rate of more than 90% and reduces
the ammonia slip from Absorber 1. A water wash located at

Reduced reboiler energy consumption of 2.0 – 2.3 GJ/ton CO2•

Uses inexpensive, industrially available chemicals (potassium and ammonium salts)•

Stable reagent. Unlike amine-based solvent systems, it does not suffer from thermal and oxidative degradation•

Tolerant towards oxygen in flue gas and to contaminants such as SOx and NOx•

Regenerates CO2 at elevated pressure, thus requiring less compression energy for the downstream CO2 product•

Reduced auxiliary electricity loads

Both absorbers operate with liquid recycle using heatexchangers to remove the heat of reaction and keep
the solution at the optimum temperature for efficientabsorption and minimum ammonia slip. The CO2-richsolvent collected from the absorbers is sent to theregenerator for regeneration via an integrated rich-leanheat exchanger network that is designed to recoversensible heat.
Heat is supplied to the regenerator via a reboiler locatedat the bottom of the column. The increase in temperature
releases CO2 as a gas and regenerates the mixed-salt
solvent to be returned to Absorber 1 and Absorber 2.
CO2 is released at an elevated pressure of 10 - 20 bar(a)from the regenerator column, which serves to reduce thedownstream CO2 compression power requirements.
The CO2-lean mixed salt solvent is drawn from the lowermiddle stage of the column and sent back to Absorber 1
to perform bulk CO2 removal. Near the bottom of theregenerator where the temperature is higher, ammonia isvaporized, resulting in a lean solvent with low ammonia/
potassium ratio, which is returned to Absorber 2 where it
performs the trim removal of CO2 and reduces ammonia
losses.

TreatedFlue Gas

BENEFITS•

the top of Absorber 2 further reduces the ammonia content
in the treated flue gas to ensure that it meets the ammonia
emission limits.

Product CO2
to Compression
CW

Water WashCW

CO2 Ovhd
RefluxCW
CW

DCC

Flue Gas In
Flue Gas
Condensate

Flue Gas
Blower
Absorber
1

Absorber
2

CO2
Regenerator

Steam In

Reboiler
ReturnCondensate

104

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACTCOMPACT CARBON CAPTURE (CCC)

BAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTION
Compact Carbon Capture has transformed the processequipment used in post-combustion carbon capture byintroducing rotation and high G-forces to capture CO2. The
G-forces are created in several cross-flow rotating packed
beds. CO2-lean solvent is distributed from the inner axis
and horizontally flung outwards in the direction of the wallof the column, while the flue gas moves vertically from thebottom to the top. Mass transfer takes place between theflue gas and the solvent in a cross-flow type arrangement.

SUMMARY
Baker Hughes acquired Compact Carbon Capture (CCC),
a pioneering technology development company basedin Bergen, Norway, that specializes in compact carbon
capture solutions. CCC employs the rotating packed bed
technology, a novel process intensification that utilizes
centrifugal acceleration to intensify mass transfer, thereby
reducing the equipment size and cost. CCC’s technology
is solvent-agnostic and in principle, can be applied to any
solvent developed for post-combustion carbon capture.
Using its rotating packed bed technology, CCC drasticallyincreases the vapor-liquid contact area, overcoming the
traditional hydraulics limitations. Compared to traditional
solvent-based systems using static equipment, CCC’s
enhanced mass transfer results in reduced residence timein both the absorber and the regenerator, thereby requiringmuch smaller equipment.
CCC is currently validated at the lab-scale (CO2) at
Equinor’s test facilities (PLAB) in Porsgrunn, Norway. Stepsfor further advancement are ongoing, with a demonstration
plant at the 30 tpd scale currently in the planning stage.

BENEFITS•

Up to 75% reduction in the overall size of the capture plant compared to conventional technologies•

Up to 50% reduction in capital expenditure compared to conventional technologies•

The possibility to reduce operating expenses significantly by using new, viscous, and efficient solvents•

Reduced lead time through standardized and containerized production, design thinking for simplified logistics, anddecreased demand for civil works•

Modular scalability to increase the deployment speed of CO2 capture equipment. For example, it is possible to invest
in partial capture right away and increase the capture capacity at a later stage.

106

STATE OF THE ART: CCS TECHNOLOGIES 2022

Due to the rotation of the packed bed within the columnthat induces high centrifugal forces (60-100 G-force), thesolvent is accelerated when it hits the packing structure,
forming small droplets. This generates a large vapor-liquidcontact area compared to traditional static mass transfer
technology that rely on gravity. The larger contact area
between gas and liquid results in a faster mass transfer of
CO2 from the flue gas into the solvent droplets, resulting
in a much shorter absorber column height compared toconventional, static absorber columns.
The high G-forces allow for the application of highly viscous
solvents that improve the process efficiency. Higher
solvent concentration results in higher absorption rates.
When this is combined with the compactness introducedby the process intensification, a considerably lower solvent
volume is needed, and the pump capacity needed forsolvent transfer is reduced.

The compact stripper is a combined reboiler and desorber
unit that can operate at higher pressures and handle highly
viscous solvents. High-speed rotation of the stripper unit
introduces turbulence and high G-force to the solvent
regeneration, which are advantageous for mass and heattransfer, resulting in very compact equipment. The rotating
bed desorber/stripper can be described as a lightweightpressurized shell-and-tube heat exchanger where the“hot-side” tube bundle rotates to generate the centrifugal
force required to produce small solvent droplets. Insteadof a static regenerator column with attached reboiler ina conventional solvent-based system, CCC will have asingle compact rotating bed/flash drum that both heats therich solvent and flashes off CO2 to generate a high purity(>99%) CO2 product stream.

CONTACTTRANSPORTATIONBAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTION
The operating envelope for CO2 delivery to sequestrationsites is very broad in terms of volumetric flow and deliverypressure. It ranges from several thousand m3/h at relatively
low pressures, up to a few hundred m3/h at extremely highpressures (700-800 bar). Baker Hughes offers a range ofcustomizable CO2 compression systems, depending on site
conditions such as delivery pressure, temperature, coolingsources and gas composition. General configuration
options for CO2 compression are shown in the table below.
PRESSURE

CONFIGURATION OPTIONS< 200 barIn-line compressor
Integrally geared compressor+ pump> 200 barIntegrally geared compressor
with MP pump + HP pump

SUMMARY
Leveraging its extensive domain expertise in compression
and pumping technologies from decades of experience inrelated areas such as urea and liquefied natural gas, Baker
Hughes has the comprehensive capabilities to make thecompression of CO2 safer, easier and more cost-effective
for CCUS applications. Baker Hughes has focused its
attention on customizing complete compression trains
suited for the unique characteristics of CO2 so that thesecan operate more efficiently and minimize the overall
parasitic power consumption of CCUS processes.

Baker Hughes offers a range of products, including
reciprocating, centrifugal and integrally geared CO2compressors, as well as centrifugal CO2 pumps. These
technologies have undergone years of proven in-field
performance. Baker Hughes has also continued to develop
and optimize these technologies at our global research
centres, performing extensive testing in both laboratory
and in-field environments before launching these products
for our customers’ use.

BENEFITS•Reduced compression train parasitic power consumption•

Optimized high compression ratio across a wide range of flow rates•

Optimum rotor balance for low vibration level•

Easily accessible components for maintenance•

Automatic capacity control and safety system to reliably match any operating condition•

Reduced lead time through standardized and containerized production, design thinking for simplified logistics, anddecreased demand for civil works

108

STATE OF THE ART: CCS TECHNOLOGIES 2022

In-line compressor + HP pump

MP = medium pressure; HP = high pressure

Baker Hughes has optimized the configuration of theoverall CO2 compressor-pump train for CCUS applications.
This includes the selection of the intermediate pressure
between the last compression stage and the pump suction
with the goal of decreasing the total power consumption
and cost.

Integrally geared compressors
The main advantage of integrally geared centrifugal
compressors are that coolers can be installed after eachstand-alone stage. Baker Hughes’ design features abull gear and from one to four high-speed pinions, with
one or two impellers mounted on each pinion shaft.
Stand-alone stages optimize impeller speed and allow
impellers to operate at higher peripheral speed and levelof compression. Each stage can be fitted with inlet guidevanes to eliminate the need for recirculation for partial
loads. The net result is a high efficiency operation that
requires less work than an in-line compressor.
In-line centrifugal compressors
Baker Hughes has supplied more than 200 in-line
compressor units with discharge pressure within therange of 200 bar. The typical train arrangement includes
a steam turbine or electric motor that drives a low-speed,
horizontally split compressor, and a high-speed barrel
compressor through an increasing gearbox, typicallyfollowed by a pump for CO2 injection. For applications
where the CO2 stream contains H2S and water, Baker
Hughes uses primarily stainless steel for improved
corrosion resistance.
Pumps
Baker Hughes’ development of its high-pressure CO2
injection pumps rely on the experience of over 1,000 multistage centrifugal pumps for liquefied gas applications. Our
multistage barrel pump is a good fit for CO2 applications,providing better overall efficiency compared with the inline rotor configurations, thanks to its opposing back-toback impeller configuration.

CONTACT

SUREVIEW™ WITH COREBRIGHT™ OPTICAL FIBRE

BAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTION
SureVIEW™ downhole cable by Baker Hughes uses
CoreBright™ optical fibre, which leads the industry inhydrogen darkening resistance, a leading cause of failure
for fibre optic systems over time. CoreBright™ fibre isconstructed from pure silica that minimizes hydrogendarkening. The cable also includes a layer of hydrogenabsorbing gel. This combination provides the industry’s
best protection against hydrogen darkening.
Fabricating a downhole optical cable with the performanceand reliability demanded by our industry requires asophisticated understanding of fibre design, fibre coatings,
cable manufacturing processes, and cable construction.

SUMMARY
Reliable downhole measurement of well and reservoir
parameters is imperative to the success of geologicalsequestration projects. Baker Hughes is uniquely
positioned to holistically address the monitoring
challenges. Baker Hughes leverages a broad portfolio oftechnology and experience across permanent downhole
gauges, microseismic monitoring, wireline monitoring, andfibre optic solutions. Specifically, fibre optic monitoringis an effective solution to gather a range of real-timedata downhole. These systems can provide distributed

temperature, acoustic & strain measurements, transmit
point gauge data, and capture seismic measurements foruse in vertical seismic profiling. The majority of traditional
downhole fibre optic installations are intended for 1020 years of hydrocarbon production life. However, thegeological sequestration projects can require much longer
service life. SureVIEW™ with CoreBright™ technology is a
proprietary fibre optic cable design with industry-leading
40+ years of reliability and unique resistance to commonhydrogen darkening failure.

BENEFITS•

Collect multiple measurements with a single cable including distributed fibre optic sensing, pressure/temperaturegauges for well integrity, compaction monitoring, and seismic data.

•

Utilizes CoreBright™ hydrogen resistant fibres to limit the effects of hydrogen darkening•

Cable is cladded with robust Inc 825 corrosion-resistant nickel alloy for maximum protection against chemicals,
abrasion, crimping and crush.

•Continuous cable with no orbital welds•

Fibre In Metal Tube (FIMT) utilizes continuous (splice-free) fibres throughout•

Equipped with excess fibre to ensure that no strain is transferred to the optical fibre core during deployment oroperation. Excess fibre compensates for thermal expansion, as well as tubing stretch.

Fibres are typically coated, often with carbon, to prevent
this hydrogen darkening. However, over time, this coating
can break down or suffer from uneven application during
manufacturing. A well applied coating will likely break
down in about 20 years, particularly at higher temperatures(above 150 °C). CoreBright™ fibre offers its extended
lifetime through a simple principle: instead of attempting
to avoid hydrogen damage by trying to block hydrogen,
CoreBright™ optical fibre avoids the hydrogen damage by
preventing the reaction between the SiO2 structure of the
optical fibre and the hydrogen. In addition, Baker Hughes’
fibre optic cables are fitted with hydrogen scavenging gelsto further reduce darkening risk.
In this way, Baker Hughes’ solution is unique: the fibre will
not darken, and reliable readings over the full life of theinstallation are assured. Independent testing has concluded
that CoreBright™ optical fibre is the only fibre in the industry
that is suitable for harsh downhole environments over along duration. It is the only known fibre that was designed
for, and has demonstrated, long-term immunity to first andsecond-order hydrogen darkening effects.1
SureVIEW™ fibre optic cables, powered by CoreBright™
fibre, have been installed in over 300 wells worldwide. Asof today, there are no instances of hydrogen darkening
ever experienced. In addition, during high-temperaturemonitoring work performed by Baker Hughes for electricalsubmersible pumps where it is common practice to test thefibre as the pumps are pulled, the CoreBright™ fibre has

maintained its mechanical and optical reliability in every
instance. Proof-testing of the fibre showed levels that are
typical of ‘as-built’ condition and demonstrated negligible
changes in optical loss profiles.
High reliability and longevity enable the use of fibre optic
measurement in more applications particularly behind thecasing where workover is likely impossible. Baker Hughes’
SureVIEW™ downhole cable is expected to improve data
quality and facilitate better decision-making in geologicalsequestration today.

tedTemperatures Under Hydrogen Conditions”, SEAFOM Industry Meeting (Dec. 2012)

1 

110

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACTSURESENS™ QPT ELITE PDHG

BAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTIONSUMMARY
Well-known pressure and temperature are key to proper
functioning throughout a CO2 storage system. For mostapplications, the best way to monitor these parameters iswith permanent downhole gauges (PDHGs). These gauges
can be used as a standalone means of measurement or
as calibration for a fibre optic-based or other extensive

measurement system. Baker Hughes leverages thequality and performance of the SureSENS™ line to executeintegrated monitoring solutions that combine point gauges,
fibre optics, along with periodic means of measurement
such as wireline logging data.

The SureSENS™ QPT ELITE gauge for permanent
downhole installations measures static and dynamic
pressures and temperatures while introducing a stepchange in reliability and accuracy. The gauge is qualified
for operation at pressures less than 35,000 psi (2,414
bar) and temperatures up to 225 °C (437 °F). The staticand dynamic pressure information obtained can be used
to determine the effects of injection and plume growth
on monitoring wells, monitor injection characteristics,
and provide input or validation to reservoir models. The
SureSENS™ QPT ELITE gauge includes the new ELITE
electronics package, built upon Baker Hughes’ industryleading STAR hybrid electronic package design. The ELITE
electronics package incorporates an application-specificintegrated circuit (ASIC), providing a new level of reliability
to the industry. Baker Hughes provides three configuration
options—single, dual, and triple gauge. The single-gauge
configuration is an economical option that will also permit
the smallest possible running diameter for a streamlined,
slim-hole gauge carrier. A dual-gauge configuration
provides isolated operational redundancy of electronics
and transducer at any given installation point. Eachgauge in a dual package operates individually, providing
independent measurements for data redundancy and

BENEFITS•

Provides superior reliability in long-life and/or demanding (high-pressure and high-temperature) applications•

Derives finest pressure/temperature measurement resolution attainable•

Deploys multiple gauge combinations on a single standardized carrier•

Eliminates the need for additional splices, increases reliability, and reduces installation time through uniqueconstruction configurations with fewer connections•

Deploys multiple gauges, flowmeters, and valve positions to provide redundant readings•

Serves as platform for future developments

Gauge Carrier configured with QPT ELITE permanent downhole gauge

112

STATE OF THE ART: CCS TECHNOLOGIES 2022

integrity verification. The triple gauge option can offer
redundancy or be ported to record three independentpressure measurements. The shorter carrier for a side-byside triple-gauge assembly also retains a slim hole runningoutside diameter.
For applications requiring long active life and highdata accuracy, even in demanding high-pressure/hightemperature type environments, the SureSENS™ QPT ELITE
gauge system provides a flexible and reliable solution.
Being highly robust, the SureSENS™ QPT ELITE gauge
maintains mechanical integrity by deep-penetration andhigh vacuum, electron-beam fusion welds, without theneed for filler material. Only two fittings, the pressure port
and the tubing encapsulated conductor (TEC), are required
to interface the gauge with the carrier. The gauge pressureinterface connection to the carrier can be externallytested in the direction in which it will experience pressure,eliminating the need for an internal pressure test tool.
The TEC’s primary seal is a dual metal-to-metal pressuretestable interface. The mechanical package is completely
integrated into the gauge assembly, which eliminates therequirement for external Y-block components.

CONTACTMICROSEISMIC MONITORING SERVICESBAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTION
The range of the monitoring solution can be described in
3 distinct stages that can be performed as a whole or as
independent services.
Network design
In this phase, consideration is given to the project’s
constrains (regulatory, geological, operational and logistical)
and advanced modelling is used to determine the mostcost-effective network that will meet the project’s objectives.
This network can consist of a specific technology (surface or
downhole solutions with analogic geophone or fibre optics)
to be deployed, but can also have a combination of them tobenefit from their different capabilities.
Installation and maintenance

SUMMARY
Monitoring seismicity is essential to guarantee the integrityof geological sequestration reservoirs and caverns. In
terms of physical integrity, seismicity in the cap rock is anindicator of the risk of catastrophic failure. At the reservoir
scale, seismicity at faults can identify the reactivation
by fluid injection or that they provide a pathway to thesurface for the stored fluids. With more public attention
towards induced seismicity and environmental impact

BENEFITS•

Maximize storage capacity within safety limits•

Compliance with regulations•

Monitor structure integrity (cap-rock & faults)•

Distinguish induced versus natural seismicity•

Avoid water breakthrough

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STATE OF THE ART: CCS TECHNOLOGIES 2022

of human activity, reputational integrity is becoming asimportant as physical integrity. It is therefore becoming
essential to detect growing activity trends before criticalsituation happens to support operators’ injection program.
Baker Hughes provides the whole range of customized
microseismic services and instrumentation to provide
lifetime monitoring of CCS assets.

Baker Hughes ensures supply of all the required
instrumentation: surface sensors, shallow buried sensors(100 m), borehole sensors, surface electronics, fibre optics,
digitizers, and fully equipped seismic cabinets. Where notinternally developed, Baker Hughes works with trusted
suppliers with long-term relationships to develop reliablehardware (Mean Time Between Failures of more than five
years) with advanced capabilities.
Baker Hughes installs and maintains all the instrumentation,
including borehole sensors. The requirement for preventive
maintenance is extremely low (one visit a year at most). This
allows us to operate sites all over the world. Most of the sites
are totally autonomous, relying on solar panels for power
and 4G networks for communications.

Monitoring - Processing
A dedicated team of experts processes the data andreports on the seismicity through a dedicated web portal.
The portal allows the operator to visualize the seismicity in
two-dimensions (2D) or 3D along with the well trajectories
and formation interfaces and offers statistical analysis
capabilities. It also plays the monitoring network’s state ofhealth and expected sensitivity in real time. Pressure and/or
flow rate curves can be displayed along with seismic rates toeasily relate any seismic activity to its probable cause.
Automation of the process can be utilised to enhance
the processing solution by adding 24/7 services such as
traffic light systems that will alert the operator when criticalseismicity is reached, and the prediction of the level ofseismic risk for the upcoming hours using machine learning.

CONTACTCORTIVA™ CORING SYSTEM

BAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTIONCore jamming during coring operations and/or loss of friablecore material during trip-outs leads to additional coring runs,
resulting in increased rig time and cost. Jams that occur
inside the inner tube of a core barrel can often be mitigatedby certain jam-mitigation techniques, allowing coring tocontinue. However, jams that occur in the core catcher,provoked by the mechanical interaction of the core with thecatcher mechanism, would not be mitigated by such antijamming technologies. These typically occur in formations
that are a mixture of fractured (jamming-prone) and friablerock. This type of complex, coring application demands
technologies beyond what is currently available in themarket. Competitors have either standalone jam mitigation
systems for jam-prone formations, or full-closure catcher
systems for unconsolidated/friable rock.

SUMMARY
Seal integrity is key to the success of any geologicalsequestration project. Along with the logging andmeasurement technology, taking physical cores is oneof the best ways to characterize these structures. Core
samples retrieved with traditional coring systems can often
break and become jammed or lost in a hole. Jams andpoor core quality can lead to re-runs that incur significant

additional cost. The CORTIVA™ coring system improves
efficiency and de-risks core recovery through the use of afully-closed and jam-mitigating core barrel. By combining
these key features, CORTIVA™ shortens the time and costs
required to cut and retrieve a core sample by ensuring thewhole core section is retrieved safely in a single trip.

BENEFITS•Core longer even in fractured or other jam-prone formations by neutralizing up to two jamming events•

Full-closure catcher completely seas inner tube to prevent loss even when the core is unconsolidated•

The HT30™ Max core barrel system delivers larger, longer samples than other systems•

Unobstructed ‘slick’ entry eliminates risk of jam at core’s centre

116

STATE OF THE ART: CCS TECHNOLOGIES 2022

Baker Hughes combines the benefits of various
technologies to improve the efficiency of coring operations
in complex formations. With its CORTIVA™ full-closure systemwith jam mitigation technology, Baker Hughes combines
the JamBuster™ jam mitigation coring system and theHydroLift™ full-closure catcher system−industry standards
for jam mitigation and recovery of friable rock to improvethe efficiency and recovery of high-quality core in complex
fractured and friable formations.
The Baker Hughes patented JamBuster™ system neutralizes
jams inside the inner tube through concentric inner core
barrel sleeves that automatically telescope if a core
becomes jammed in the core barrel, allowing coring tocontinue without interruption. The HydroLift™ systemefficiently recovers high-quality, intact core samples
collected in soft, or unconsolidated formations. The system’s
slick, unobstructed entry eliminates the risk of jamming at
the core catcher for the incoming core, while the full closure
mechanism secures the core, thus preventing loss of friable/loose formation during trip-out.
The CORTIVA™ full-closure system with jam mitigation
technology is also integrated with HT30™ Max core barrel
system to deliver an unmatched core size. It also reducescore acquisition costs by acquiring longer, high-quality coresamples per run, even in harsh environments.

CONTACTAPTUM™ DOWNHOLE SEALSBAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTION

In geological sequestration, completion integrity for any
well penetrating the target storage interval is key tomaintaining storage integrity over the life of the project.
Chemical corrosion inhibitors and reservoir’s environmental
factors can be damaging to elastomer seals over time.
The most common sealing elastomers in the industry
today often force a choice between effectiveness at low
temperatures or chemical compatibility with corrosion
inhibitors. Aptum™ seal systems, along with industry-leading packers such as the Premier™ NXT removableproduction packer, perform at lower, more appropriate
temperatures for CCUS and yet maintain excellent
chemical compatibility and mechanical properties. With
Aptum™ seals in the completion, operators can better
protect their metal tubulars and equipment without fear ofelastomer degradation.

BENEFITS•

Delivers high performance across a wide temperature range•

Compatible in a range of environments including corrosion-inhibited fluids and reservoir fluids•

Resistant to sour conditions•

Single compound simplifies material recommendations and testing for well planning across all seals including packing
elements, O-rings, and bonded seals•

Extends life of seal, further improving reliability•

Meets ISO 23936-2 and API 11D1 standard

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STATE OF THE ART: CCS TECHNOLOGIES 2022

PRODUCED
RESERVOIRFLUIDSBALANCEDMECHANICALPROPERTIESH2SRESISTANCE>10%

OIL-BASEDMUDRESISTANCE

BROMIDERESISTANCEINHIBITED
BRINE >200 °F(93.3 °C)

For instance, NBR has balanced mechanical properties
and performs well even at lower temperatures. However,its chemical resistance, particularly to corrosion inhibitors,
is quite low. Aflas, on the other hand, is excellent for use inmany inhibited brines, but has significant limitations in lower
temperatures. Baker Hughes set out to develop a balanced
element system that could be used confidently in a broader
range of applications – carbon storage being a primeexample.

TEMPERATURE
350 °F (177 °C)

MATERIALS

SUMMARYTEMPERATURE
40 °F (4 °C)

In typical well completions, the injection or monitoringtubing string is isolated from the well casing by a production
packer. This packer creates a mechanical anchor anda seal between the tubing and casing. The four main
elastomers currently used in these packer element systems
to seal between the tubing and the casing are Nitrile (NBR),
hydrogenated Nitrile (HNBR), Aflas (FEPM), and Viton (FKM).
These elastomers provide an excellent range of capabilities
for most applications. However, in each case, there are tradeoffs, which can introduce risks and costs to an operation.

Aptum Seal
Nitrile (NBR)
Hydrogenated Nitrile (HNBR)
Viton (FKM)
Aflas (FEPM)
Due to excessive swelling, limit exposure to oil-based mud (OBM) during run-in
Due to excessive swelling, O-rings and packing elements require back-up mechanisms to reduce extrusion

Aptum™ seals are compatible with a range of industry
standard corrosion inhibitors while still maintaining sealing
capabilities in low downhole temperatures.
Carbon storage applications can create corrosive
environments when CO2 becomes mixed with water andother fluids in the wellbore. Completion equipment canoften be exposed to hydrocarbons, formation water, CO2
and a host of other corrosive fluids. A common and effective
way of combating this corrosion is to treat the completion
fluids with corrosion inhibitors. These corrosion inhibitors
protect the metallic components of the completion including
the casing, tubing, and packer body. However, they can alsodegrade the elastomer. As mentioned earlier, elastomers
with excellent compatibility with inhibited fluids often havetemperature limitations.

Many target formations for sequestration are shallow andhave lower temperatures, making them difficult applications
for elastomers such as Aflas. Add the potential for significant
cooling during various phases of CO2-injection operations,and a new solution is needed. Aptum™ provides excellent
performance at 4 °C (40 °F) yet maintains long-term
compatibility with bromide- and chloride-inhibited brines.
When used as a part of the Premier™ removable production
packer, Aptum™ seals enable a secure seal between thetubing and the casing, create a reliable mechanical anchor
for the tubing string throughout extreme temperature andpressure changes, and is easily removed from the well forworkover or plug and abandonment activities.

CONTACTHEAVY METAL™ SWARF-FREE SECTION MILLINGBAKER HUGHES

Gianluca Di Federico
Email:

gianluca.difederico@bakerhughes.com

Web:

www.bakerhughes.com

DESCRIPTION
Section milling is a conventional method for casing
removal during plug and abandonment (P&A) operations
where annular well integrity is compromised or questioned.
The removal of casing by milling a window provides fullaccess to the virgin formation, enabling placement of arock-to-rock barrier. Swarf is an unavoidable by-product ofsection milling, generating thousands of pounds of thesesharp metal cuttings that have to be removed from thewell. Retrieving and handling the swarf is a time-consuming
and costly process that poses additional health, safety, andenvironmental (HSE) risks, and oftentimes operators will
opt for less reliable options, such as perf-and-wash, just to
avoid swarf.

SUMMARY
Many of the world’s most promising geological targets forlarge scale CO2 storage exist in and above late-life anddepleted hydrocarbon plays. Late-life fields often have
many existing wells that penetrate the target storage
geology and can pose seal integrity risks. Baker Hughes
offers advanced plug and abandonment solutions toensure that the integrity of aging infrastructure is notcompromised for the life of the sequestration project.
During plug and abandonment operations, it is sometimes
required to remove a section of the casing and adjacentcement sheath to expose the formation. This process iscalled section milling. Section milling operations provide
an effective downhole seal during plug and abandonment

by setting a cement plug directly across the geologic seal
- removing metal tubulars and potentially failed cement.
However, section milling operations can be challenging,which makes its large scale use less appealing.
Additionally, conventional section milling requires
specialized equipment to handle the cuttings or ‘swarf’ thatare brought to surface during milling operations. HEAVYMETAL™ swarf-free section milling system increases theefficiency while decreasing the cost and carbon footprint ofsection milling operations. By improving the performanceand economics of section milling operations, wells can beplugged more effectively and with less long-term risk ofseal integrity issues.

BENEFITS•

Provides a robust rock-to-rock barrier•

Reduces cost and time associated with section milling•

Decreased health, safety & environment (HSE) risk for personnel on site•

Reduces requirements for rig capability, swarf handling, and other specialized equipment•

Eliminates the need for swarf cleaning, transport, and disposal

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STATE OF THE ART: CCS TECHNOLOGIES 2022

Baker Hughes offers the HEAVY METAL™ swarf-free section
milling service to provide a reliable solution without thenegative side effects of swarf. It eliminates swarf to surface
through a unique upwards milling process, depositing
swarf deep in the rathole, while still enabling a securerock-to-rock barrier. This unique service reduces timeand costs in half, eliminating the need for swarf removal
and the risks that swarf presents to people, equipment,
and the environment. The bottomhole assembly (BHA)
consists of multiple tools providing different functions toenable upwards section milling using normal right hand
drill pipe connections without any rotation at surface. A
torque isolator allows uninterrupted axial movement andcontinuously isolates reactive torque of the left-hand mud

motor, while milling upwards. The mud motor requires
circulation from surface and provides downhole left-handrotation and torque to the section mill and auger.
The system’s section mill features upward-facing
knives that utilize METAL MUNCHER™ advanced milling
technology (AMT) carbide cutting structures and allow
upward milling and reaming in one run—even in longlaterals. The section mill cuts through the casing at thebottom of the window, mills upwards to the desired
distance, and then reliably retracts its knives at the top of
the window.
The auger continuously transports any swarf created fromthe window to the bottom of the rathole, leaving it all in thewell, while providing a window free of swarf. Because theswarf does not have to be circulated to surface, there is noneed to change over to a high viscosity milling fluid, saving
additional cost and logistics.
A Baker Hughes dedicated project management teamcan oversee the entire P&A project—from planning phasethrough final abandonment— all with a strong focus
on safety and efficiency. With a single point of contact,customers achieve a simplified, streamlined process thathelps reduce time and minimize risk.

CONTACTCO2 CAPTURE AND MINERALIZATIONCAPTICO2

Email:

mail@CAPTICO2.com

Web:

www.CAPTICO2.com

DESCRIPTIONSUMMARY
Our mineralization technology has billions of hours of
testing in nature, as we replicate the process where sea
urchins build their shell and spikes through mineralizationof CO2 and calcium that are naturally found in seawater.
Dr. Lidija Siller at the Newcastle University upon Tyne is a
nano-scientist and the inventor of CAPTICO2’s unique andpatented mineralization technology. CAPTICO2 uses acatalyst to dramatically increase the speed and efficiency
of CO2 mineralization. CAPTICO2 has an exclusive
worldwide license to commercialize this patent, covering
all areas of use on any fossil burning source.

Carbon dioxide (CO2) mineralization is a process, which
does not require CO2 capture. This is because, there
is already a significant amount of CO2 present in brineor seawater. This CO2 will be converted regardless of
its concentration. CAPTICO2 has developed a highly
cost-effective cryogenic capturing technology, which
can capture CO2 at a cost of EUR 15-20/t CO2. With the
CAPTICO2 turnkey CCUS solution, the total cost of CO2
capture and mineralization, including source supply andlogistics for the end-product is between EUR 30 – 40/t
CO2, and the best of all - we offer a solution for each stepof the CCUS loop: Carbon Capture, Utilization and Storage.

BENEFITS
The following highlights describe the benefits of the CAPTICO2 CCUS technologies:•

Proven, patented and certified CO2 mineralisation technology applicable for all fossil-based emission sources•

High-speed and high conversion rate due to utilization of readily available catalyst in the mineralisation process•

Proven and patented cost-effective, health and environment-friendly CO2 capture technology, by cooling thecomponents in flue gas and separating CO2 without the use of expensive and harmful amines•

Highly competitive investment and operational cost between EUR 30 - 40/t CO2 captured and mineralized, which ishalf the cost of competing solutions•

Closed loop solution covering CO2 capture to mineralisation, storage, and utilisation, whereas most competitors offer
only CO2 capture, leaving out solutions for transportation and storage•

Rapid technology development enables us to bring our technology to a commercial state by the end of 2022, offering
full-scale compact and scalable 1.3 Mtpa CO2 capture and conversion modules to customers worldwide

122

STATE OF THE ART: CCS TECHNOLOGIES 2022

While studying marine biology at a nano-particle level,
Dr. Siller discovered the natural process through which
sea urchins quickly mineralize CO2 to build their shelland spikes, using naturally available catalyst present in
sea water. Building upon this discovery, Dr. Siller and herteam at Newcastle University upon Tyne, successfully
tested a laboratory-scale tubular reactor for hundreds ofhours that mineralized CO2 in only 60 seconds. CAPTICO2
holds a worldwide, exclusive license to commercialise
the patented technology developed by the Newcastle
University upon Tyne. In August 2020, CAPTICO2
successfully tested the CO2 mineralization technology at
a government owned waste-to-energy plant in Norway, incollaboration with “Det Norske Veritas”, DNV, a renowned
third-party certification company, upon which we received
a Certificate of Feasibility. The cryogenic capture
technology was developed by CAPTICO2 in collaboration
with Sintef, a renowned Norwegian independent research
institution. Cryogenic gas distillation has traditionally been
known to require high energy consumption. By utilizing
energy conserving principles from the oil and gas industry,and running extensive advanced process simulations,
CAPTICO2 has been able to develop a cryogenic
distillation process, which can separate 99% CO2 from theflue gas at a cost of EUR 15-20/t CO2.

The traditional approach to CO2 capture involves theutilization of amine-based absorption. There are several
challenges with most amine-based technologies, suchas the high cost of the amines, the harmful health impact
from the toxic amines, and limitations on the lifetime of theamines. CAPTICO2’s cryogenic capture is non-toxic, uses
nitrogen and oxygen present in the flue gas as coolingmedium to distil CO2 from the flue gas. In combination with
the CO2 mineralization technology, CAPTICO2 can provide
yet another step in the CCUS process, which is typicallynot offered by CO2 capturing companies: conversion of
captured and volatile CO2 to a non-toxic, long-term storable
and usable mineral, calcium carbonate, and thereby
closing the loop for our customers.
In collaboration with Enea, the fourth largest Polish providerof electrical power, CAPTICO2 will certify our technologies
to the European Union’s definition of Technical Readiness
Level (TRL) 7 in 2022, which is described as a systemprototype demonstrated in operational environment.
A fully mobile project test rig with a capacity of 1,300 tonne
CO2 capture and mineralization per year will be installed
at one of Enea’s coal power plants in Poland for a periodof 3 months, followed by a Front-End Engineering and
Design (FEED) study for full-scale CCUS modules. At theend of 2022, we expect to be ready to offer the sale of ourmodules.

CONTACTCARBFIXCARBFIX

Kristinn Ingi Lárusson
Email:

kristinn.ingi.larusson@carbfix.com

Web:

www.carbfix.com

BENEFITSThe Carbfix technology is:

SUMMARY
The Carbfix process captures CO2 and turns it into stoneunderground in under two years through technology that
imitates and accelerates natural processes, providing apermanent carbon storage solution. Carbfix is the world’s
first organisation dedicated to facilitating and implementing
carbon capture and mineral storage (CCMS) worldwide.
Robust research and innovation based on subsurface
geochemical processes laid the foundation for injectionof dissolved CO2 into mafic and ultramafic formations for
efficient mineralisation. To date, such approach is thesafest and fastest carbon capture and storage (CCS)
method applicable at industrial scale.
Carbfix can adapt its well-established technology toa range of point source emissions as well as direct air
capture technologies with a portfolio of solutions. Where
local conditions allow, mineral storage operations co-

124

STATE OF THE ART: CCS TECHNOLOGIES 2022

located with the emission sources offer one of the mosteconomic full-chain CCS in the world. Carbfix is also
pioneering mineral storage in connection with direct air
capture technologies (for example, Climework’s Orca plant)
as well as large scale hubs that can receive transported
CO2 (Coda Terminal). On top of the numerous ongoingprojects, Carbfix offers consultancy services and carries
out feasibility studies tailored to each project and facility.
Factors such as flue gas composition, local geology andwater availability determine whether on-site storage ortransport to offsite storage facilities is the most feasible
for customers wanting to permanently convert their CO2
emissions to stone. Carbfix has carried out generic costestimates and process simulations for selected industry
sectors, providing assessments for footprint, water andenergy requirements and associated CapEx and OpEx.

•

Built on firm scientific foundation and robust monitoring campaigns•

Safe. The risk of leakage is fully eliminated by dissolving CO2 in water•

Cheaper than alternative solutions, has lower up-front capital costs and financial risks•

Environment-friendly. The process imitates and accelerates nature’s way of storing CO2 in rocks with no chemicals
used other than water•

Permanent. Minerals are stable for thousands of years limiting the need for long-term monitoring•

Highly flexible with respect to capture technology used, injection strategy and up-scaling•

Dissolved CO2 has less stringent requirements for pipe and casing material than pure CO2•Able to provide added value through co-capture of other soluble industrial gases such as sulphur oxides, nitrogenoxides, hydrogen sulphide and fluorine•

Seeing higher levels of public acceptance than conventional CCSCONTACTCARBFIXCARBFIX

Kristinn Ingi Lárusson
Email:

kristinn.ingi.larusson@carbfix.com

Web:

www.carbfix.com

DESCRIPTION
Trees and vegetation are not the only form of carbon
drawdown from the atmosphere. Vast quantities ofcarbon are naturally stored in rocks. Carbfix imitates andaccelerates these natural processes, offering a permanentand safe carbon sink. The technology provides a complete
carbon capture and injection solution, where CO2
dissolved in water is injected into the subsurface where it
reacts with favourable rock formations, such as basalts, toform solid carbonate minerals via natural processes. For
the Carbfix technology to work, one needs to meet threerequirements: suitable rocks, water, and a source of carbon
dioxide.
Carbonated water is acidic. The more carbon you can packinto water, the more acidic the fluid will become. Carbfix’s
carbonated water reacts with rocks underground andreleases available cations such as calcium, magnesium
and iron into the water stream. Over time, these elements
combine with the dissolved CO2 and form carbonates, thus
filling up the empty space within the rocks. The carbonates
are stable for thousands of years and can therefore beconsidered permanently stored. The timescale of thisprocess initially surprised scientists. In the CarbFix pilot
project, it was determined by a suite of chemical andisotopic tracers that at least 95% of the injected CO2
mineralised within two years, much faster than previously
thought. Once the mineralisation process is confirmed,
further monitoring is not required.

The injected carbonated water is denser than thesurrounding water in the geological formation, andtherefore, has the tendency to sink after it has been
injected. This differs from more conventional methods ofcarbon capture and storage, which depend on cap rockto prevent possible leakage of gaseous CO2 injected into
deep formations that are overall not very reactive. Youngbasaltic rocks are highly fractured and porous such thatwater seeps easily through the interconnected cracks
and empty spaces underground. It has been estimatedthat after injecting 100,000 tons of gas into the Hellisheidi
basaltic reservoir only 0.05% of the storage space wasfilled with solid minerals. The global storage potential ofsuch favourable formations (Carbfix atlas)1 is greater thanthe emissions of the burning of all fossil fuels on Earth. It
is estimated that Europe could theoretically store at least
4,000 billion tons of CO2 in rocks, while the United States
could store at least 7,500 billion tons.
The Carbfix technology requires significant amounts ofwater, which is co-injected into the subsurface with theCO2. To address this, Carbfix has already developed
the scientific basis for using seawater, a near-unlimited
resource, to dissolve CO2 prior to injection, thus expanding
the applicability of the technology to water scarce regions,coastal and offshore areas. A field site demonstrationof mineral storage using seawater will take place in SWIceland in 2022 (CO2-Seastone project).2

Carbfix operations only use minimal above-surface
infrastructure, whose footprint is further reduced byinnovative approaches such as using multi-well well-pads
where several injection wells are drilled from the well-pad.
Carbfix is being deployed and further validated innumerous ongoing projects. The now routine CCS
operations taking place at the Hellisheiði power plant(Iceland) capture the plant emissions (CO2 and H2S)
through a simple on-site single-stage water scrubbing
process, and then injecting the mixture into the basaltic
bedrock where it forms solid carbonate and sulphideminerals. With the help of EU Innovation Fund, emissions
from the power plant will be reduced to near-zero by 2025
(Silverstone project).3 Cost of on-site CCS operations at
Hellisheiði is US $24.8/ton – much lower than the recent
average price of EU Emission Trading System allowances.
By applying the Carbfix process also to capture andmineralise H2S along with CO2, instead of conventionalsulphur removal methods, significant economic benefits
have been achieved.

OPTIONAL
IMAGE 2 (if around 700 words in DESCRIPTION):
1
https://www.carbfix.com/atlas
A007_C038_1023E5.0000507 (credits Benjamin Hardman and Carbfix)

The Carbfix
technology requires significant amounts of water which is co-injected into the subsurface
STATE OF THE ART: CCS TECHNOLOGIES 2022
126with the CO2. To address this, Carbfix has already developed the scientific basis for using seawater, a2

https://www.carbfix.com/CO2-seastone3

https://www.carbfix.com/Silverstone4

https://www.carbfix.com/currentoperations

5

https://www.carbfix.com/codaterminal

Further developments of the Carbfix technology at the
Hellisheiði power plant include the Orca project,4 whichbuilds upon the collaboration with a Swiss tech company
specialized in direct air capture (DAC). Project Orca has
the capacity of capturing 0.004 Mtpa CO2, which is being
injected by Carbfix into nearby basaltic formations andpermanently turned into stone.
An even bigger Carbfix upscaling towards tackling
the global CO2 emissions is represented by the Coda
Terminal,5 a scalable cross-border carbon transport andmineral storage hub in Iceland. Carbon dioxide (CO2) is
captured at industrial sites in North Europe and shippedto the Terminal where it is unloaded into onshore tanks
and subsequentially pumped into a network of nearby
injection for permanent storage. The target capacity of the
Coda Terminal is to reach 3 Mtpa CO2 stored in the basaltic
bedrock by 2030-2034.

CONTACTCARBON CAPTURE, UTILIZATION AND STORAGECHEVRON

Brian Chase
Email:

newenergies@chevron.com

Web:

www.chevron.com

DESCRIPTION
Why we need CCUS at scale
Carbon capture, utilization and storage (CCUS) is a criticalenabler of global net-zero, and our CCUS targets reflect its
importance. We see CCUS as an enabler in reducing thecarbon intensity of our existing assets and as a business
opportunity to provide emissions reduction solutions
for partners and customers. We are targeting 25 millionof tonnes per annum in equity storage by the end of thisdecade.

SUMMARY
At Chevron, we believe the future of energy is lower
carbon. Reducing the carbon intensity of the energy thatpeople rely on is a tremendous opportunity to advance theglobal net-zero ambitions of the Paris Agreement. We’relooking to the future with confidence by applying morethan 140 years of experience to help meet the expanding
energy needs of a growing world, while accelerating
progress towards a lower carbon future.

New Energies (CNE) in August 2021 to advance lower
carbon solutions, and scale businesses in hydrogen,carbon capture, utilization, and storage, offsets andemerging lower carbon opportunities. These businesses
will target sectors of the economy where emissions are
harder-to-abate or that cannot be easily electrified, suchas heavy-duty transportation, refining and petrochemicals,
steel, and power generation.

Our energy transition approach is straightforward: weare lowering the carbon intensity of our operations andgrowing lower carbon businesses. We formed Chevron

Chevron New Energies aims to provide integrated, lower
carbon solutions across the value chain by leveraging ourcapabilities, assets, and customer relationships.

BENEFITS•

Chevron is well-placed to be a CCUS leader building upon our capabilities, assets, and customer relationships.

•

We bring decades of operational experience and a proven track record of carbon capture projects.

•

We are one of a few companies with the ability to execute across the CCUS value chain and scale CCUS.

•

Since 2018, we’ve committed about $500 million to lower-carbon investments to help bring innovation to scale.

•

Chevron New Energies aims to provide integrated, lower carbon solutions across the value chain for partners andcustomers, and is working to help lower the carbon intensity of our operations.

128

STATE OF THE ART: CCS TECHNOLOGIES 2022

Chevron is actively evaluating multiple locations to
implement CCUS solutions that would support our internal
efforts to lower the carbon intensity of our operations,and also grow a lower carbon business. By aggregating
emissions, we see a future in the development of CO₂
sequestration hubs in underground storage sites where
CO₂ can be stored permanently. We have oil & gas
operations across the world and our refinery network

spans the United States and Asia Pacific, providing avariety of high-value products to the global marketplace.
Neighbouring industrial plants and third-party emitters canbe enrolled as potential partners and customers as hub
concepts and projects are developed.
We are also focused on investing in innovative projects
across the CCUS value chain to reduce costs, develop new
ways to capture, use, and sequester carbon, with the goalof scaling these solutions.
Chevron has committed $100 million to the Oil & Gas
Climate Initiative, bringing our lower carbon investments
through our venture organization since 2018 to about$500 million. These investments target cutting edge
technologies, bringing early insights through pilot
programs – often utilizing Chevron’s existing assets. Learn
more by visiting https://www.chevron.com/technology/
technology-ventures

CONTACTCARBON CAPTURE, UTILIZATION AND STORAGECHEVRON

Chevron CCUS project spotlights
Chevron brings decades of operational experiencethrough our large-scale deployment of CO2 injection into
oil formations for enhanced oil recovery in the UnitedStates over approximately the last 40 years. We havesafely operated a CO₂ pipeline in Colorado for 35 years.
This experience is coupled with our capabilities in drilling,geology, injection, pipeline operations, monitoring andmanaging pressure in wells, and our ability to successfully
bring together diverse stakeholders across the value chain.
We have a proven track record of carbon capture projects
that have been focused on lowering the carbon intensityof our existing assets. For example, our Gorgon Project inAustralia is one of the largest sequestration projects in theworld with the capacity to store up to 4 million of tonnes
per annum CO₂. The Gorgon carbon capture and storage
project involves the design, construction, and operation offacilities to inject and store CO2 into a deep reservoir unit,
known as the Dupuy Formation, more than two kilometres
beneath the Barrow Island — providing us with key
operational experience.
Chevron is committed to leveraging its capabilities, assets,
and customer relationships to lead the way in carbon
capture, transportation, storage, monitoring, and utilization.
We are investing in several technologies related to CCUS
and implementing pilots to demonstrate more efficient andcost-effective capture solutions for emissions streams withvarious CO2 concentrations.
We are advancing a project awarded from the U.S.
Department of Energy (project #DE-FE0031944) to pilot
technology that captures CO2 from post-combustion gas at
our Kern River Carbon Capture site in San Joaquin Valley,
California. In collaboration with Svante and the National
Energy Technology Laboratory, we are planning to test
Svante’s innovative new technology to reduce CO2 capture
costs.
We recently completed front-end engineering design(FEED) on concentrating equipment for a commercialscale pilot in the San Joaquin Valley, California to capture
CO₂ from a cogeneration plant’s gas turbine. The project
combines two technologies, CarbonPoint Solutions* SemiClosed Cycle CO₂ Concentration Technology and Carbon
Clean Solutions Limited’s Advanced Rotating Packed
Bed Solvent Capture Technology. This opportunity could
capture over 200 tonnes per day of CO₂.
* Acquired by Caterpillar in 2021
130

STATE OF THE ART: CCS TECHNOLOGIES 2022

Chevron and Carbon Clean aim to develop a carbon
capture pilot for Carbon Clean’s CycloneCC™ technology
by separating CO2 from a co-generation plant’s exhaust at
our facility in San Joaquin Valley, California. Carbon Clean’spatented technology is expected to reduce the costs andphysical footprint required for carbon capture comparedwith many existing techniques.
CCUS offers opportunities to unlock markets for lower
carbon products as compared to conventional products,
such as blue hydrogen and biomass power to meetgrowing energy demands while creating a lower carbon
economy. At our Richmond Refinery, we’re exploring thedevelopment of a regional CCUS hub that could enable
blue hydrogen.
Delivering Lower Carbon Solutions
Our capabilities, assets, and customer relationships willserve as a platform for rapid growth in the years to come.
Our existing assets span the value chain and are in areas
where we can facilitate demand based on cost-competitive
supply combined with appropriate policy support. We havestrong relationships with key customers and partners,
which will be critical in developing economic projects thatcan scale quickly across a complex value chain.
Innovation, technology, and policy will be key driversof change. We begin with a portfolio of existing assets
and decades of experience as a strong foundation for
future growth. We’ve successfully managed complex,
joint ventures all over the world. We have deep technicalexpertise inside the Company and a long history ofadvancing and adopting external innovation. We
have strong commercial capabilities and experiencemanaging rapidly changing businesses. Managing diverse
stakeholder and government interests is something we doevery day. Chevron’s credibility and reputation make us thepartner of choice, bringing access to new opportunities.

Gorgon is one of the largest sequestration projects in the world.

Brian Chase
Email:

newenergies@chevron.com

Web:

www.chevron.com

CONTACTSTORAGEJAPAN CCS CO., LTD.

Yoshihiro Sawada
Email:

info@japanccs.com

Web:

www.japanccs.com

BENEFITSJCCS can share the following knowledge and experience acquired from the Tomakomai Project.

SUMMARY
Japan CCS Co., Ltd. (JCCS) was founded in May 2008 whena group of major companies with expertise in CCS-related
fields, including electric power, petroleum, oil development,
and plant engineering, joined forces to answer the Japanese
government’s call for development of CCS technology.
JCCS has been conducting the Tomakomai CCS
Demonstration Project, Japan’s first full-chain CCS
demonstration project in Tomakomai City, Hokkaido
Prefecture, Japan since JFY2012 (JFY: Japanese fiscal
year from April to March). The project was commissioned
to JCCS by the Ministry of Economy, Trade and Industry(METI) between JFY2012 and 2017, and from JFY2018
by New Energy and Industrial Technology Development
Organization (NEDO) with subsidies from METI.
Prior to the selection of Tomakomai as the demonstration
project site, site surveys and a site selection process wereconducted from JFY2008 to 2011. At first, there were 115
candidate locations. After an evaluation of existing dataand site surveys, Tomakomai was finally selected due
to technical reasons including the confirmation of goodreservoirs and overlying cap rocks, and that no active faults
were found at the Tomakomai site. In addition, a decisive
factor was that the local community, in particular the
Tomakomai city mayor, supported the project. Furthermore,
the Tomakomai site was located in an oil exploration area
where a leading shareholder of JCCS had acquired a lot ofgeological data. This made it possible to characterize thesite within a limited period. The original project schedule
132

STATE OF THE ART: CCS TECHNOLOGIES 2022

comprised a four-year construction, three-year CO2 injection
and two-year post injection monitoring period. Aiming toestablish CCS technology for practical use by around 2020,
the main objectives and tasks of the project are as follows:•

Demonstrate a full-chain CCS system from capture to
storage•

Demonstrate that the CCS system is safe and reliable•

Remove concerns about earthquakes by the datacollected by establishing:•

No influence by natural earthquakes on CO2 stored•

No perceptible earth tremors induced by CO2
injection•

Disclose project information and data and enhance
understanding of CCS by local residents•

Acquire operational technology as well as strive towards
practical implementation.

As Japan is an earthquake-prone country, removing
concerns regarding earthquakes is vital.
The actual CO2 injection period was three years and eightmonths. The target of 300,000 tonnes of CO2 injection wasachieved in November 2019. Monitoring operations arebeing continued.
JCCS is able to share the knowledge and experienceacquired from the Tomakomai Project.

•

Capture and compression technologies (excluding inherent know-how belonging to the process licensor)•

Injection and monitoring technologies•

Public outreach experiences

CONTACTSTORAGEJAPAN CCS CO., LTD.

Yoshihiro Sawada
Email:

info@japanccs.com

Web:

www.japanccs.com

DESCRIPTIONJCCS can share the knowledge and experience acquired
from the Tomakomai project as described below.
1. Overview of the Tomakomai Project
The Tomakomai CCS Demonstration Project is an offshore
CCS project in Japan. The CO2 source is offgas from an HPU(Hydrogen Production Unit) of an oil refinery located in the
coastal area of the Tomakomai Port. Carbon dioxide (CO2)
captured by an activated amine process is compressed andinjected by two highly deviated injection wells drilled froman onshore site targeting two offshore reservoirs.
2. Key Results of Tomakomai Project

Figure 2. Schematic geological section

2.1 CO2 capture

2.2 CO2 injection and monitoring

The CO2 capture process used in the Tomakomai project is
a commercially proven amine scrubbing process (OASE® by
BASF), and the capture facility comprises of a two-stage CO2
absorption tower, a CO2 stripping tower and a Low-Pressure
Flash Tower (LPFT), as shown in Fig. 1. The maximum CO2
capture rate is 25.3 tonnes per hour.

A schematic geological section is shown in Fig. 2 withprofiles of the deviated injection wells. The Tomakomaiproject targets two independent reservoirs of different
depths and different lithofacies; the Lower Quaternary
Moebetsu formation at about 1,000 to 1,200 m in depth and
3 km off the coastline, and the volcanic and volcaniclastic
layers of the Miocene Takinoue formation at about 2,400 to
3,000 m in depth and 4 km offshore.
Onshore monitoring facilities consisted of a seismic stationand three observation wells with pressure and temperature
sensors and seismic sensors.
Offshore facilities consisted of an OBC (ocean bottom cable)with 72 seismic sensors and four OBSs (ocean bottom
seismometers).

Figure 1. Two-stage absorption process

The two-stage absorption system results in a significant
reduction of amine reboiler heat consumption in the CO2
stripping tower as only a small amount of semi-lean amine
needs to be sent to the CO2 stripping tower. The reboiler
heat consumption was measured as approximately 0.9
GJ/t CO2 or less, which is a significantly lower energy
consumption than that of a conventional one-stage
absorption system. The purity of the captured CO2 wasgreater than 99% (dry basis) at the top of the LPFT.

134

STATE OF THE ART: CCS TECHNOLOGIES 2022

The facilities were deployed as shown in Fig. 3 and started
operation on February 1, 2015, thirteen months before
the start of CO2 injection. CO2 injection into the Moebetsu
formation began on April 6, 2016 and was terminated withthe cumulative amount at 300,012 tonnes on November
22, 2019. Carbon dioxide (CO2) injections into the Takinoue
Formation were conducted from February 6 to February 23,
2018, and from July 31 to September 1, 2018. The injectivityof the Takinoue formation was much lower than expected,
and therefore, the cumulative injection of CO2 was 98
tonnes. To date, no seismicity attributable to CO2 injection
has been detected in the vicinity of the reservoirs. Seismic
surveys at cumulative CO2 injection of approx. 65,000,
207,000 and 300,000 tonnes into the Moebetsu Formation
detected anomalies, indicating evolution of the CO2 plume.
Seasonal marine environmental surveys have detected no
indications of seepage of the injected CO2.

Figure 3. Layout of monitoring facilities

3. Public outreach activities
As the project is being conducted close to the centre ofTomakomai, a large industrial city including active fishingwith a population of approximately 170,000, securing
the trust of the local community through sustained
communication, in particular with the local government andfishery cooperative, has been an important step in achieving
the smooth delivery of the project. A key factor was thestrong support of the city mayor and the local government,
which formed the Tomakomai CCS Promotion Associationin April 2010 that was chaired by the mayor of Tomakomai

Figure 4. Public outreach activities

and comprised of all the major local industries including thefishery cooperatives.
JCCS also places emphasis on removing concerns
regarding earthquakes and securing trust in the safetyof Japan’s CCS technology through various public
outreach activities such as forums for local residents, panel
exhibitions, exhibits at environmental conferences, site
tours, lectures, and experiment classes for schoolchildren.
We have also maintained an information disclosure systemin the city hall of Tomakomai (Fig. 4).

CONTACTREDUCING CO2 FOOTPRINT WITH LINDE

LINDE

Email:

ccus@linde.com

Web:

www.engineering.linde.com/CO2

TECHNOLOGIES FOR A LARGE VARIETY OF CARBON INTENSITIES AND SOURCES
In essence, decarbonization is about reducing the carbon
footprint of processes and products. For this, Linde
provides a portfolio of technologies and services along
the whole CO₂ value chain. When deciding which solution
to select, the company’s engineers first verify which CO₂
concentrations need to be addressed – low, medium andCO2 content in sources<3%

LINDE’S TECHNOLOGY AND OPERATIONAL CAPABILITIES SUPPORT THE SWIFTACHIEVEMENT OF DECARBONIZATION TARGETS AS WELL AS CO2 UTILISATION CONCEPTS
Linde has been developing and optimizing gas processing,separation and liquefaction technologies for more than
100 years. Through trusted, lasting business relationships,
the company collaborates closely with its customers allover the world to develop tailored solutions that maximize
plant lifecycle productivity, efficiency and service life. Its
Engineering business delivers high-quality gas processing
solutions to support customer expansion, efficiency
improvements and emissions reductions. The Gases
business is experienced in plant operations and in CO₂transportation and handling.

Capture and Processing

Low

Conditioning

MediumHigh

SMR syngas

Oxyfuel processes

Olefins production

Gasification

Chemicals production

Iron and steel production

Partial Oxidation (POX)

Natural gas sweetening

Cement and lime production

Auto Thermal Reforming (ATR)

Steam Methane Reformer (SMR)
flue gas

Direct Reduced Iron (DRI) process

Compression
and dehydration

Logistics andapplication
Logistics anddistribution

Storage (CCS)

Liquefaction

CO2 Processing Unit (CPU)OASE® blue

Industrial

Synthesis

Amine wash
HISORP® CC
Tank farms &loading stations

HISELECT®
SourcesFlue gas
Natural gas
SyngasTailgasFood andbeverage

Rectisol®
Electronics

Pressure Swing Adsorption (PSA)

Linde provides services along the whole value chain
Figure 1: Overview of Linde´s technology portfolio along the CO2 value chain

Linde also offers logistics and distribution solutions as well
as plant and operator services among others for carbon
storage and the industrial, synthesis, food & beverage andelectronics sectors. Linde operates approximately 1,000
plants worldwide, providing a variety of services such as

STATE OF THE ART: CCS TECHNOLOGIES 2022

>98%

Power generation

The CO₂ technology portfolio is complemented withcompression and dehydration plants as well as liquefaction
plants and CO₂ tank farms with loading stations for trailers,trains and ships.

136

The technologies are further divided into their suitability for
the CO₂ source, whether it be flue gas, natural gas, syngas
or tailgas.

Linde technologies cover a broad range of CO2 containing gas streams

The company offers a rich technology portfolio to help
industry decarbonize processes and assets: The portfolio
includes advanced technologies for harnessing renewableenergies, for avoiding, reducing or capturing CO₂
emissions. Moreover, Linde´s offerings cover purification,
compression, liquefaction, storage, distribution and use of
CO₂.
In addition, Linde covers every step in the hydrogenvalue chain from production, processing, distribution andstorage to applications. Services and digital innovations
complement its decarbonization offering.

high (Figure 1). Linde provides solutions for many different
CO₂ emitting industries.

•

On-site gas production•

Investment, assembly & start up•

Operation & maintenance•Backup system & logistics•

Remote Operations Centres•

Plant turnarounds

Further information on Linde’s decarbonization and carbon
management portfolio: Linde CO2 Management Solutions(https://www.engineering.linde.com/CO2).
In the following key technologies are described.

CONTACTREDUCING YOUR CO2 FOOTPRINT WITH LINDE

LINDE

FOR GAS STREAMS WITH LOW CO₂ CONTENTOASE® blue technology for Post-Combustion
CO2 Capture (PCC)
Post Combustion CO2 Capture (PCC) is a mature option
to capture CO2 from flue gas streams and thus ensurescompliance with increasingly strict emissions thresholds.
With the OASE®1 blue technology, CO2 is removed fromthe ﬂue gas through chemical scrubbing with an aqueous
amine-based solvent (Figure 2). It can be implemented
downstream of existing assets without interferingwith upstream processes. For new assets, advanced
plant integration concepts and optimized total costs ofownership can be accomplished.
The optimal design of turnkey facilities using OASE® blue
technology has been jointly developed by BASF and Linde.
It leverages BASF´s capabilities in high-performance gas
treatment technologies and Linde´s strength and proventrack record in design and delivery of turn-key industrial
plants. This results in optimal interplay of solvent, process
design, equipment and plant integration.
The technology can be applied to flue gases from various
sources such as different types of power plants, gas
motors, steam generators, cement plants and furnaces,
just to name a few. It easily covers a spectrum from 3 to 25
vol% CO₂ content in the flue gas. The technology allows
for CO2 capture rates higher than 95% and generates

a CO2 product purity of 99.9 vol% (dry). This purity is incompliance with the CO2 product specification in mostcases. Therefore, a further purification step may not benecessary.
This high-performance CO2 capture technology incombination with our solid track record in large-scale gas
treatment plants ensures low risk in EPC projects.
Highlights•

Compact footprint•

High CO2 capture rate even at low CO2 concentrations•

20% lower energy consumption and 20% lower
circulation rate compared to MEA solution•

Low solvent degradation rate even at elevatedoxygen content in flue gas, and therefore, low solvent
consumption rate•

Different options for energy and heat integration•

Unique emissions control technology for minimum
environmental impact•> 500 OASE® gas treatment plants in operation fordifferent applications•> 65,000 hours of operational experience with OASE®
blue•

Reference plants in Germany and USA

product
Absorption

Reclaiming

Figure 2: OASE® blue Post-Combustion CO2 Capture (PCC) process
1
OASE® is a registered trademark of BASF SE
138

STATE OF THE ART: CCS TECHNOLOGIES 2022

Amine wash
Amine wash processes are the standard for CO2 removalfrom Steam Methane Reforming (SMR) based hydrogen,syngas and ammonia plants. CO2 capture from syngas(Figure 3) is a proven technology. It achieves a CO2
recovery rate of 99.9%. Further advantages include a low
investment and favourable operating costs. Amine wash
units can be installed in various areas of a plant, from lowto high-pressure applications. They are also suitable foradvanced CO2 removal as well as simultaneous removal of
CO2 and sulphur. Amine wash units can also be combined

Web:www.engineering.linde.com/CO2

Heat
recovery

Regeneration

with other Linde technologies, such as with the Linde
Ammonia Concept (LAC™) or with cryogenic processes forcarbon monoxide production.
Highlights•

State-of-the-art process•

Compact design•

Favourable design for low-pressure and high-pressure
applications•

Compatible for CO₂ removal and/or sulphur removal

Gaseous CO2
(wet)

Lean
syngas

CO2 capture
rate >99.9%
CO2 containing
syngasSMR / ATR / POX

Amine-based
CO2 removal system

Figure 3: Amine wash-based CO2 capture process from syngas

Flue gas

Pre-conditioning

ccus@linde.com

FOR GAS STREAMS WITH LOW TO MEDIUM CO₂ CONTENT

Emissions control

Power generation / SMR /Production of cement, lime,
iron, steel and olefins

Email:

Temperature Swing
Absorption (TSA)

Gaseous (dry)CO2 productto sequestration

CONTACTREDUCING YOUR CO2 FOOTPRINT WITH LINDE

LINDE
HISORP® CC

The adsorption-based HISORP® CC technology targets the
reduction of the carbon footprint of hydrogen production
plants (both for new-built and retrofit), such as SMR,
autothermal reforming (ATR), partial oxidation (POX), andgasification (Figure 4). To produce blue hydrogen, it can beapplied for CO2 capture in the syngas or the hydrogen PSA
tailgas route of existing SMRs and ATRs. A further use caseis for Post Combustion CO2 Capture (PCC) from the fluegases of SMRs and power plants. The technology achieves
CO2 capture rates of up to 99% from the particular gas
stream and greater than 95% of the overall plant. HISORP®
CC is flexible in regard to scale (covering all relevant
industrial sizes), CO2 feed concentration, the state inwhich the CO2 should be exported (in gaseous, liquid orsupercritical form) and all product purities (e.g. industrial
grade or high purity beverage grade).

(1)

(2)

SMR

(3)

Flue gas

HISORP® CC
flue gas

Highlights•

No steam required for regeneration (therefore, noadditional CO2 generation), and no solvent is applied•

No solvent management required•

No extra cost for solvent makeup and handling•

Environmentally benign
renewable electricity•

No hydrogen losses when applied for CO2 capture
from syngas or tailgas•(1) Flue gas

www.engineering.linde.com/CO2

Highlights

The HISELECT® membrane was originally developedwith a focus on natural gas and process gas industries.
For natural gas resources with sour and acid fractions,membranes are an excellent alternative to conventional
amine wash systems for acid gas removal. Driven by partialpressure difference, the HISELECT® membrane works likea semi-permeable barrier and separates the feed gas intoa low-pressure permeate, rich in the gas to be removed
or recovered (such as CO2) and a high-pressure retentate
with a low content of these components. A typical setup
of a gas processing unit with membranes is shown in
Figure 5. HISELECT® membranes efficiently remove CO2from natural gas over a wide flow rate and concentration
range. The membranes demonstrate high selectivity
for CO2, irrespective of high hydrogen content (HHC)and CO2 partial pressure. Additionally, strong resistanceto unsaturated hydrocarbons, mechanical robustness,and high resistance to hydrogen sulphide (H2S) resultin low maintenance requirements and a rapid return on
investment. Beside applications in natural gas sweetening,
HISELECT® membrane technology can also be applied in
hybrid solutions with pressure-swing or temperature-swing
adsorption units to efficiently remove CO2 or other gases
from process gases.

•

Low CapEx and OpEx with high operational flexibility•

High separation capacity and high selectivity for
maximum recovery rates and high purities•

Ability to tailor membrane capacity and selectivity tocustomer requirements•

High volume efficiency due to optimized packing of
hollow fibre membranes•

Production flexibility with wide feed stream condition
range and supporting temperatures up to 100 °C andpressures up to 200 bar•

Resistant to CO2 partial pressure of up to 50 bar•

Robust and stable performance over time under harsh
operating conditions, reducing need for overdesign•

Reduced pre-treatment effort due to excellent
resistance to heavy hydrocarbons and plasticization•

Mechanical resistance to process fluctuations during
operation

SMR

Blue H2Blue
H2
H2 PSA

Membrane pre-treatment

H2 PSASMR

SMR

HISORP® CC
tail gas

Raw NG
upstream
Membraneseparation II

H2 PSA

CO2 export

Figure 4: Typical adsorption-based HISORP® CC process for capturing CO2 from flue gas (top right), syngas (bottom left), and tailgas (bottom right).

STATE OF THE ART: CCS TECHNOLOGIES 2022

Membraneseparation I(3) PSA off-gas/tailgas
Flue gas

CO2 export

O2

140

Web:

HISELECT® powered by Evonik membranes

H2 PSAHISORP® CC
syngasATR

CO2 export

withccus@linde.com

Blue H2(2) Syngas
Flue gas

poweredFlue gas (CO2 free)
HISORP® CC
flue gas

CO2 export

No flue gas

when

Low CapEx and OpEx

Blue H2

HISORP® CC
syngasHISORP® CC
tailgasIn addition, HISORP® CC can be applied to other industries
where CO2 emissions are hard to abate, such as steel andcement, or for coal-burning power plants.

Email:

CO2 removal

Figure 5: Typical process design of a gas processing unit with HISELECT® for natural gas acid removalww

CONTACTREDUCING YOUR CO2 FOOTPRINT WITH LINDE

LINDE

Email:

ccus@linde.com

Web:

www.engineering.linde.com/CO2

Rectisol® wash unit

Highlights

FOR GAS STREAMS WITH MEDIUM TO HIGH CO₂ CONTENT

Linde’s Rectisol® wash unit is able to extract sour gas fromsyngas. The technology uses proven technology that is
adjusted to the actual needs and requirements of plant
operators. Its application in syngas is indicated in Figure 6. It is flexible with respect to upstream syngas generation
as well as gas specification for downstream applications.
Rectisol® can either be used for selective removal of CO2
and sulphur or it can be designed for designated CO2
capture. In case of selective removal of CO2 and sulphur,about 99% of the CO2 can be captured sulphur-free,which means that no additional desulfurization units are
required. Rectisol® can be integrated with other Linde gas
processing technologies (such as downstream PSA andcryogenic processes). Nominal capacities can vary widely,
from small-scale plants (30,000 Nm³/h feed gas) up to highone-train capacity plants (2,000,000 Nm³/h feed gas).

•State-of-the-art process

CO₂ PSA

processing.

•

Used for the treatment of feed gas containing sulphur
and CO2•

Water- and sulphur-free CO2 product for further
processing

Linde’s pressure swing adsorption (PSA) system is aninnovative, efficient and low - CapEx technology for therecovery of CO2 from process gas streams covering a wide
concentration range, such as from process gases including
syngas streams and iron and steel production off-gases, as
shown in Figure 7.

A CO2 PSA unit can achieve a product purity of up to
95 vol%, with unit capacities ranging from a few thousand
Nm³/h to around 300,000 Nm³/h.
•

Mature and robust purification technology

In the case of syngas, PSA technology is used to recoverCO2 from upstream, high-pressure raw syngas streams
or low-pressure off-gas streams generated by SMR or
gasification processes. In many cases, PSA technology isa more cost-effective alternative to conventional washingsystems due to its lower investment and operating costs.

•

No electricity consumption•

No steam required for regeneration (thereby no
additional CO₂ generation). No solvent is applied.

•No negative environmental impact due to theemissions of solvent traces in exhausts or CO₂ productIn the iron and steel industry, PSA technology can beused to efficiently remove CO2 in direct reduction or
blast furnace off-gases. The process removes maximum
amounts of CO2, yet leaves valuable gas components,
such as H2, CO, and CH4 in the gas stream for further•

No extra cost for solvent makeup and handling•

Low CapEx and OpEx technology•

Enriched H2S fraction can be realized within one
process•

Easy solvent handling (chemically stable, low cost andreadily available on the market)•

Enhanced trace component handling•

Low product losses (H2 and CO)

Highlights

Gaseous CO2 (dry)Lean syngas

CO2 capture rate >99%
H2S / COS fraction to SRU
CO2 + H2S / COS

GaseousCO2 product tosequestration

CO2 export

containing syngas
SMR / ATR / POX

Rectisol® wash unit
CO2 removal system

Figure 6: Typical Rectisol® process design for CO2 capture from syngas

142

STATE OF THE ART: CCS TECHNOLOGIES 2022

Low / medium / high CO2
concentration source

Figure 7: Typical CO2 PSA process design for efficient capture of CO2 from process gases

CO2 PSACONTACTREDUCING YOUR CO2 FOOTPRINT WITH LINDE

LINDE

CO₂ Processing Unit
Linde’s CO2 Processing Unit (CPU) is applied to purify CO2
containing gas streams to provide typical CO2 productspecifications for a variety of industrial applications. TypicalCPU feed gas streams are CO2-rich gases generated
from CO2 capture processes, flue gases from oxy-fuelcombustion processes or CO2-rich off-gases from chemicalplants, such as ammonia, ethylene oxide, methanol or
ethanol plants. As shown in Figure 8, an extended toolboxof processes and technologies allows for the removal ofdifferent trace components, such as sulphur- or nitrogencontaining compounds, hydrocarbons, heavy metals andair gases.
Linde initially developed and commercialized the CPU
technology to treat oxy-fuel flue gases at an oxy-fuel lignitefired power plant at Schwarze Pumpe, Germany.

More recently, Linde’s CPU has been considered for
oxy-fuel projects in the cement industry. Mature CO2
processing technologies in combination with Linde’s trackrecord in large-scale gas-treatment plants ensure low-risk
EPC projects for clients.
Highlights•

Mature and robust purification technology•

Reference plant in Schwarze Pumpe, Germany, fortreatment of oxy-fuel flue gases•

Multiple EPC and Linde operation references for
production of food-, chemical- and electronics-grade
CO2•Standardized and skid-mounted modules as well aslarge-scale customized, stick-built solutions available

CO₂ compression/ dehydration
CO2 compression and dehydration (see Figure 9) are themost common process units in all CO2 plants. If the CO2
purity already meets specification requirements after theCO2 capture process, the downstream CO2 treatment
usually involves compression and dehydration. It is also atypical process unit for CPU and CO2 liquefaction plants.
Depending on the plant capacity, different types ofcompressors can be used, such as piston, screw and turbo
compressors. And depending on local costs for utilities,
electrical or steam-driven compressors can be employed.

Boil-off fromstorage

Other
recyclesEmail:

ccus@linde.com

Web:

www.engineering.linde.com/CO2

The targeted CO2 product pressure is defined by thedownstream application or distribution concept. Pressuresof up to a maximum of 215 bar have been realized.
Compressor stations not only compress the main CO2
feed gas stream, but can also be used to integrate andcompress boil-off gases from storage tanks and other CO2rich vents from the plant.
Highlights•

Mature and robust technology•

Various options for compressor types•

Multiple references for different scales worldwide

Vent

Raw CO2
product
Chemical plant /CO2 capture plant

Raw CO2

CO2 compression

product
Oxyfuel plant /CO2 capture plant /Chemical plant

Compression

Figure 8: Typical CO2 Processing Unit (CPU) design

144

STATE OF THE ART: CCS TECHNOLOGIES 2022

Purification
toolbox I

Purification
toolbox II

Liquefaction andrectification withrefrigeration unit

Figure 9: Typical CO2 compression and drying process design

Drying

CONTACTREDUCING YOUR CO2 FOOTPRINT WITH LINDE

LINDE

CO2 liquefaction
CO2 liquefaction, as shown in Figure 10, can be an
additional process step attached to a CO2 capture andprocessing plant. For example, when CO2 is purified
by means of cryogenic separation (rectification), CO2liquefaction is involved. In addition, CO2 liquefaction
might be required because of the CO2 logistics concept
when transporting it via road trailers, trains or ships.
Linde’s largest liquefaction plant in operation since 2015is producing approximately 1,350 tons per day of CO2. The
CO2 is used in enhanced methanol and urea production.
Additional large-scale plant references can be foundin Norway and the United States for carbon captureand storage (CCS) and food applications, respectively.
Depending on local needs, the integration concept, safety
considerations and cost efficiency, different refrigerants
can be considered for use in the refrigeration unit.
Highlights•

Mature and robust technology•

Various options for refrigerants available•

Extended reference list at various product capacities•

Standardized and skid-mounted modules as well aslarge-scale customized, stick-built solutions available

CO₂ tank farm and loading stations
Linde offers state-of-the-art tank farms to store liquid CO2.
A range of configurations are available. For example,
the storage tanks can be spherical or cylindrical (verticalor horizontal). Tank farms can be equipped with boil-off
gas re-liquefaction as well as integration of gas returnlines. Moreover, an essential component of a tank farmis a loading station. While most tank farms feature trailer

Boil-off tocompressionWeb:www.engineering.linde.com/CO2

loading stations, Linde has also built train and ship loading
stations (see Figure 11). This covers the whole range ofpotential distribution concepts.
Highlights•

Extended reference list at various product capacities•

High degree of standardization and skidded packages
to reduce CapEx

Truck loading

Liquid CO2

Vent gas
treatment

Distribution
CO2 liquefier

Raw CO2

Storage

Train loading

Boil-offliquefaction

Ship loading

Liquid CO2
to storage
Liquefier

Rectification

Sub-cooler

Figure 11: CO2 tank farm and loading station
Refrigeration unit

Figure 10: Typical CO2 liquefaction process design

146

ccus@linde.com

Gas returnlines

Vent gas

Chemical plant /CO2 capture plant /CO2 processing units

Email:

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACT ) !$/.$)'0 ѷ

NOV CARBON CAPTURE, UTILISATION
AND STORAGE SOLUTIONSNOVJeremy Grzywa
Email:

jeremy.grzywa@nov.com

Web:

www.nov.com/ccus

BENEFITSNOV is a one-stop-shop, offering capabilities to support throughout the entire value chain. These benefits include:•

Established execution and global supply chain models, featuring local, low-cost fabrication and decreased delivery times•

Experience in standardized system and equipment packages to drive efficiency•

Precision with large-scale projects, resulting in lower engineering design and project management•

Research and development activity to keep customers involved with the latest CCUS technology advancements•

Vast well construction capabilities for geological storage to streamline vendor operations

SUMMARY
The transition to cleaner, carbon-neutral energy, coupledwith the growth in decarbonization methods, is one of themost significant technological shifts to happen in modern
history. Throughout our 150 years of experience at NOV,
we have pioneered innovations that have enabled ourcustomers to safely produce abundant energy while
minimizing the environmental impact of their operations.
The energy industry depends on our deep expertise andtechnology to assist in advancing the energy transition
toward a more sustainable future.
We have joined the movement and our goal is simple:
rejuvenate to improve upon what we already offer,repurpose technology and equipment traditionally usedin oil and gas operations, and reposition the skills andknowledge from oil and gas towards the energy transition.
Carbon Capture, Utilization, and Storage (CCUS) is one
initiative where our gas processing technologists andprocess system experts have been able to utilize theircore competencies to design a carbon capture systemfor post-combustion flue gas. Within upstream oil and gas,
our Wellstream Processing group is recognized as theglobal leader in delivering gas processing technologies
and process systems. This expertise is cultivated fromour 35-year history of executing more than 350 complex
gas treatment and conditioning projects in close to 50
countries worldwide.

Last year, we announced the release of our built-forpurpose carbon capture system. This solvent based, postcombustion capture design removes more than 90% ofcarbon dioxide. The flexibility in the selection of technology
and scalability of our solution supports a wide range
of applications and industries. We are also involved instrategic partnerships to develop additional carbon capture
technologies.
In addition to our carbon capture technology, we designand supply gas dehydration and conditioning systems. Our
diverse dehydration portfolio includes triethylene glycol(TEG) units, molecular sieves, and silica gel, and we haveexecuted more than 100 projects. High-energy recovery
and low-glycol loss are achieved by our dehydration
packages and modules, which are compact, lightweight,
and small in footprint. Our CO2 dehydration systems
reduce the water dewpoint, preventing hydrate formation,condensation, and corrosion in the downstream processes.
Carbon dioxide (CO2) conditioning packages include
removing contaminants such as oxygen, H2S and mercury,and compression for end use.

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Submerged Turret Loading - An optimal solution for deep water locations, our Submerged Turret Loading (STL) system is designed for shuttling and0((-4
permanent mooring or continuous operation. Our STL ensures safe and secure injection offshore.

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
)
!$/.
projects in close to 50 countries worldwide.
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148

STATE OF THE ART: CCS TECHNOLOGIES 2022

CONTACTNOV CARBON CAPTURE, UTILISATION
AND STORAGE SOLUTIONSNOVJeremy Grzywa
Email:

jeremy.grzywa@nov.com

Web:

www.nov.com/ccus

DESCRIPTION
Industry-leading solutions for CO2 projects of any size arealso available for transport, offshore offloading, injection,and storage. Our growing suite of automation, control,and monitoring solutions also support safe and reliable
operations. A sampling of our solutions across CCUS
includes:Offshore offloading, injection, and storage

Research and technology•

Transportation•

We are home to multiple research and technology
centres. Two of our facilities are specifically linked to
NOV’s low carbon initiatives, the Springett Technology
Centre located just outside of Houston in Navasota, Texas,
and the Flotta facility in Orkney, Scotland located in theheart of the Orkney Net Zero Ecosystem. We can rapidly
produce prototypes and test technology for customers
with expanding capabilities to support more low carbon•

For more than 80 years, Tuboscope has provided
products and services that improve asset performanceand maximize useful life. Our TK™-Corrosion control
products and pipeline connection systems havesuccessfully been used in CO2 and carbon capture
applications, efficiently transporting waste, preventing
severe deterioration of pipeline and downhole tubing
due to the corrosive nature of carbon-containing
wastewater.

•

The proprietary suite of Tube-Kote™ coatings addresses
all operating environments, providing superior
corrosion protection, deposit mitigation and improved
hydraulics. When used with our pipeline connection
systems, the result is a continuous coated surface
throughout the connection area and improved pipeline
integrity and efficiency.

•

•

•

150

Our TK-Liner, GRE lined carbon steel pipe, delivers
excellent corrosion protection in highly corrosive
environments, as well as thermal insulation for
downhole tubulars and flowlines.
For more than 50 years, composite pipe has been usedin CO2 injection lines, high- and low-pressure pipelines,
ductwork, WAG systems, and other challenging
carbon capture and transportation applications. Our
products are ideal for these critical applications dueto their ability to handle concentrations of up to 100%
CO2. Composite solutions bring excellent corrosion
resistance without the additional cost of cathodic
protections or coatings traditional metallic materials
require.
Our energy efficient horizontal pumping systems are
an ideal option to boost CO2 pressure for pipeline entry.
Tying into our variable frequency drive (VFD), users
control the speed of the pump to adjust dischargepressure and flow rate, as needed. Additionally,
automation, control, and monitoring solutions drive
productivity and improve safety and reliability.
STATE OF THE ART: CCS TECHNOLOGIES 2022

•

•

•

We assist customers with offshore CO2 transfer, fromterminal or storage vessel to shuttle vessel, shuttle
vessel to storage facilities/well, or from shuttle vesselto storage and injection vessel. Transfer and mooring
systems are important to secure vessels and ensure
safe and reliable CO2 injection offshore.
Our Single Anchor Loading (SAL) and Submerged
Swivel and Yoke (SSY) systems are used in shallow
waters, while our Submerged Turret Loading (STL)
system is used in deep water locations. The SAL
system is designed for shuttling operations wherecontinuous injections are not required, also known asbatch wise injection. Alternately, the STL is suited forboth shuttling and permanent mooring/continuous
operation in deeper waters (50 - 2500 m). The SSY
is the preferable solution for permanent moored/
continuous operation systems in shallow waters (15- 60 m). Technology choice and individual systemcomplexity levels are also subject to specific seabed,soil, and weather conditions for the given terminal orstorage aquifer/reservoir location.
Our portfolio of dynamic high-pressure unbonded
flexible pipes is compatible with CO2. Already used indeep waters for CO2 enhanced oil recovery injection(EOR), our offshore flexible pipes are equally applicablefor injection into permanent storage.
We also develop solutions for safe and efficient
vessel integration of our technologies for CO2 transfer
interfaces, which include the Bow Loading System(BLS) and the Stern Discharge System (SDS). Thesehigh performing, field proven technologies have beenused in the oil and gas industry for decades and areeasily converted to CO2 transfer in all three pressure
and temperature levels considered for CO2 handling.
Our full suite of drilling technologies offers manysolutions for drilling into saline aquifers or depleted
oil and gas reservoirs for permanent CO2 storage. We
offer a complete suite of tubulars and bottom holeassembly (BHA) tools, as well as drilling optimization
services.

initiatives. Additionally, our lab services for low carbon
supports environmental impact research, surveys,
atmospheric monitoring, and permits.
As solutions to support decarbonization continue to evolve,
NOV will remain at the forefront solving challenges andpartnering with customers across the entire CCUS value
chain. Please let us know if we can assist with your next
project by emailing marketing@nov.com.

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!**/+-$)/ѵ0-с #4-/$*).4./ (.- 0 /# 2/ - 2+*$)/Ѷ+- 1 )/$)"#4-/ !*-(/$*)Ѷ*) )./$*)Ѷ)*--*.$*)$)/# *2)./- (+-* .. .ѵс*)$/$*)$)"+&" .$)'0 
NOV technology supports the entire CCUS value chain. (1) Emission source (2) Carbon capture system (3) Onshore CO2 injection well (4) Terminal for- (*1$)"*)/($))/.'$& *34" )Ѷ с) -0-4)*(+- ..$*)!*- )0. ѵoffshore CO2 transportation (5) Transportation vessel (6) Vessel for offshore offloading and CO2 injection (7) Re-purposed offshore platform for CO2

injection (8) Offshore injection well for CO2
 ) !$/.

$.*) Ҋ./*+Ҋ.#*+Ѷ*!! -$)"+$'$/$ ./*.0++*-//#-*0"#*0//#  )/$- 1'0 #$)ѵ# .  ) !$/.$)'0 ѷCONTACTSCHLUMBERGER
50+ Carbon Capture and Storage Projects

Active Projects
Across Industries
Ethanol
MethanolBlue H₂
BECCS
Oil & Gas Processing
Enhanced Oil Recovery
CementPower
Steel
Oxygen Production

SUMMARY

Location

Storage Type

OnshoreSaline Aquifer

Offshore

Depleted Oil & Gas

Schlumberger-Private

Carbon capture and storage (CCS) is a critical componentof advancing decarbonization and achieving the Paris
Agreement’s climate change goals. As a technology leader
in CCS and in the development of decarbonization andalternative energy solutions, Schlumberger is actively
progressing CCS technologies and business models toenable widespread adoption of CCS.
What Schlumberger brings to achieve these goals is
more than 90 years of experience in characterizing andmodelling underground rock formations and in designingand constructing wells. Schlumberger’s acquisition of
Cameron in 2016 added a rich legacy in gas processing
and pressure control equipment. For decades, we havebeen deploying digital tools and sophisticated sensors
to improve operations, minimize risk, and monitor assets,
including the use of automation, artificial intelligence, andcomprehensive data management.
We applied this know-how to become an early technology
leader in carbon capture for enhanced oil recovery (EOR)
applications. Thirty-five years ago, we helped build theworld’s first commercial CO2 plant at the SACROC Field inWest Texas.
For over two decades, Schlumberger has participated in
more than 50 CCS projects around the globe, in different
geological contexts and for various industry sectors. This
hands-on experience, combined with our technology
leadership, gives us unique insights into the varied

152

STATE OF THE ART: CCS TECHNOLOGIES 2022

complexities posed by CO2 sequestration. In order toovercome these challenges, we have united the diverse
disciplines of geoscience and engineering to develop
innovative, integrated end-to-end processes that enable us
to deliver sequestration projects anywhere in the world.
Recently, Schlumberger has explored creating strategic
partnerships with emitters to assess, develop, and operate
projects spanning the entire CCS value chain, from capture
to storage. The scope of collaboration goes beyond
subsurface requirements and includes project economics,
technology selection, business models, and permitting
for a CCS project. By partnering with leaders in a rangeof strategic sectors, we are demonstrating viable andscalable CCS solutions across a wide range of industries.
For example, we are exploring with Lafarge Holcim thefeasibility of capturing carbon emissions from cement
plants. Schlumberger is also collaborating with Chevron
Corporation, Microsoft, and Clean Energy Systems on abioenergy with carbon capture sequestration (BECCS)
project in Mendota, California.
In addition to our deep expertise, technological leadership,and experience in creating viable CCS solutions,
Schlumberger is uniquely positioned to help scale up the
manufacturing of CCS technologies. We are leveraging
our more than 80 technology centres and extensive
manufacturing capabilities around the world to industrialize
and deploy CCS technologies globally.

Schlumberger is developing, adapting, and applying
innovative technologies in scalable business models toprovide our customers and partners with economically
viable solutions across the CCS value chain. In this “Stateof the Art: CCS Technologies 2022” report, we highlightsome of the advanced technologies in our portfolio thatsignificantly support the CCS industry today, organized into
three sections:•Capture, Gas Processing, and Transport•

Storage Selection, Design, and Construction•

Storage Monitoring, Verification, and Reporting.

Capture, Gas Processing, And Transport
Highlighted Technologies and Services in our Portfolio
Capture and gas processing technologies•

Symmetry process software platform, available in our
DELFI cognitive E&P environment•

CYNARA acid gas removal membrane system•

Amine gas treating systems•

SULFATREAT H2S removal adsorbent•

Process Live data-enriched performance service

Transport technologies•

OLGA dynamic multiphase flow simulator, available in
our DELFI environment•

Horizontal pumping systems for pressure boosting
during transport•

Low-emission valves

Our Symmetry process software platform enables thedesign and simulation of CO2 capture process workflows
in one environment that integrates pipelines, capture andcompression facilities, and safety models while ensuringconsistent thermodynamics and fluid characterization
across the full system. The use of the Symmetry platformin several CCS projects in Canada was key in rightsizing
the process design and accurately modelling the phaseenvelope and control system integration. For eachproject, the Symmetry platform identified operational
improvements and minimized health, safety, andenvironment (HSE) risks.

Email:

ccus@slb.com

Web:

www.ccus.slb.com

The choice of capture technology depends on the purity of
the CO2 stream and whether capture is pre-, post-, or oxycombustion. Comprehensive evaluation of these options in
the Symmetry platform can achieve the optimum system interms of both technical and economic feasibility.
Once CO2 is captured, a variety of treatment technologies
may be needed. Schlumberger offers both membrane
systems and amine gas treatment systems in a range ofdesigns and sizes to meet specific project requirements.
The CYNARA acid gas removal membrane system works
to separate CO2 and H2S from natural gas via preferential
permeation of the smaller acid gas molecules. The
separated CO2 can be transported and sequestered at aselected storage site.
Monitoring valves and gas membrane systems with
Process Live data-enriched performance service provides
real-time status reports of performance and automates
event detection. These insights mitigate the risk of
downtime and reduce inventory costs. Using Process Live
service, we currently are providing uptime assurance andtreatment optimization of 4.92 Mtpa CO2.
The OLGA dynamic multiphase flow simulator models
and simulates the transportation of CO2 from capture to
injection. This enables a comprehensive understanding of
optimal operating conditions to ensure that CO2 remains inphase.
When transporting CO2 between facilities, horizontal
pumping systems provide the necessary pressure boost
to maintain it in a fluid state. Schlumberger has morethan 15 years of experience with a wide variety of CO2transport operations. We understand how the selectionof appropriate seals, valves, production chemicals, andmaintenance schedules plays a critical role in equipment
longevity and operational safety.
To date, Schlumberger has installed thousands of industrial
valves in various CO2 and gas processing applications. In
addition to enabling remote operation, these low-emission
valves incorporate custom seals that reinforce theiroperational integrity. Some of the valves in this portfolio are
manufactured to minimize leaks across the life of the valve.
To reduce maintenance downtime, our production
chemistry technologies address specific problems ofcorrosion and hydrate formation.

CONTACTSCHLUMBERGER
Storage Selection, Design, And Construction
Schlumberger has developed a wide range of risk
assessment methods for screening geological formations
and for identifying the most suitable site by conducting sitecharacterization assessments. This in-depth assessmentand evaluation of key criteria (such as storage capacity,
injectivity, and containment) enables our customers tominimize cost while ensuring secure long-term CO2
storage.
Integral to our involvement in CCS projects is our morethan 35 years of petrotechnical software development
experience paired with deep domain knowledge. Endto-end digital technologies harness this experience andexpertise to drive workflows that screen, rank, design,model, simulate, and analyse every phase of the CCS
project’s life cycle.
By conducting the workflows within the DELFI cognitive
exploration and production (E&P) environment, we leverage
artificial intelligence and machine learning. For example,
the interpretation workflows used to build a model of astorage site benefits from a 10× to 20× acceleration in
workflow time by employing machine learning. Reservoir
simulations benefit from high performance computing
capabilities that reduce simulation time so that theengineers can focus on analysing results and exploring
the full uncertainty space. The DELFI environment wasrecently selected by the Northern Lights joint venture
between Equinor, Shell, and TotalEnergies to streamline
subsurface workflows and longer-term modelling andsurveillance of CO2 sequestration.
Once the storage site has been selected and the projectcommissioned, we leverage our decades of expertisein well construction to optimize construction operations,
including the selection and installation of monitoring
methods.
Well integrity has been identified as the biggest risk
contributing to leakage of CO2 from underground carbon
storage sites. EverCRETE CO2-resistant cement systemenables more efficient and secure underground storage
compared with ordinary portland cement. Whereas
ordinary Portland cement is not resistant to CO2 fluids andcan degrade in a few weeks or less, the reaction between
CO2 fluids and the EverCRETE system results in a stablestructure after two weeks, and mechanical and chemical
properties are no longer affected.

154

STATE OF THE ART: CCS TECHNOLOGIES 2022

Schlumberger designs and manufactures specialized
wellheads, seals, and gate valves for achieving
permanent underground sequestration of CO2. Our
corrosion-resistant equipment is constructed withcustomized coating to withstand aggressive environments
under any temperature conditions. The metal andelastomer seals used in these wellhead systems areproved to endure demanding pressures, temperatures,and corrosive environments.
Storage Monitoring, Verification, And Reporting
Securing CO2 storage and containment over long periodsof time requires properly monitoring the CO2 plume andintegrity of the wells. A cost-effective combination of
sensors and monitoring protocols can deliver optimum
performance control and risk management in compliancewith regulatory requirements.
Monitoring strategy design must address•

what is to be monitored•

what are the property variations•

how will those variations occur.

For a monitoring strategy to meet its objectives in termsof assurance, verification, and cost optimization, a holistic
solution design and modelling workflow is required.
Critical to the success of the monitoring strategy designis the incorporation of dynamic geomechanical modelling,such as using our ECLIPSE, INTERSECT, and VISAGE
simulators, for predicting subsurface behaviour andidentifying the key parameters and their uncertainties.
This informs the design and planning of appropriate
geophysical measurements. A successful monitoring
strategy is able to history match the dynamic modellingagainst field observation to identify anomalies and update
the subsurface model, monitoring strategy, and risk modelaccordingly in real time.
Updating models requires timely measurements, for whicha primary objective is to minimize data acquisition time andeffort without adversely affecting interpretation quality.
Our versatile and highly sensitive distributed fibre-optic
sensing technology plays a significant role in achieving
this balance by providing continuous data in both timeand space. Optiq Schlumberger fiber-optic solutions

bring multidomain distributed sensing capabilities to
CCS projects for significant efficiency improvements intime-lapse reservoir monitoring through permanent fibre
installation or temporarily deployed fibre wireline cables.
In a 2016 project with the US Department of Energy andArcher Daniels Midland Company (ADM), we installed
modular intelligent completion equipment and Optiq
solutions to enable real-time monitoring and control of thesubsurface storage. Together, we captured from ADM’s
ethanol facility more than 2.5 Mt CO2 over a period of three
years.
Highlighted Technologies and Services in our Portfolio

Email:

ccus@slb.com

Web:

www.ccus.slb.com

services for water analysis•

PressureXpress
servicereservoirpressure-while-logging•

CoreFlow digital rock and fluid analytics services•

High-resolution well testing services

Well construction technologies•

DrillPlan coherent well construction planning solution•

EverCRETE CO2-resistant cement system•

Wellhead equipment: compact wellheads, monoblock
Christmas trees, coated FLS extreme-service API 6A
slab-style gate valves, elastomer seals, metal-to-metal
seals, MRD recessed-bore metal-to-metal seals

Site selection and design digital tools, available in our
DELFI cognitive E&P environment•

OLGA dynamic multiphase flow simulator•

Petrel E&P software platform

Well integrity technologies•

ECLIPSE industry reference reservoir simulator•

Wellbarrier well integrity life cycle solution•

INTERSECT high-resolution reservoir simulator•

Isolation Scanner cement evaluation service•

VISAGE finite-element geomechanics simulator••

Symmetry process software platform, available in our
DELFI environment

PS Platform production services platform multifinger
imaging tool (PMIT)•

Slim cement mapping tool (SCMT)•UCI ultrasonic casing imager, USI ultrasonic imager,
and PowerEcho and PowerFlex annular barrier
evaluation services•

EM Pipe Scanner electromagnetic casing inspection
tool

Formation evaluation technologies•

Litho Scanner high-definition spectroscopy andlaboratory services for X-ray diffraction, X-ray
fluorescence, and Fourier transform infrared
spectroscopy•

MR Scanner expert magnetic resonance and CMRMagniPHI high-definition NMR service; triple-combo
measurements for porosity, permeability, and capillarypressure; and laboratory services for routine andspecial core analysis, tight rock analysis, and mercuryinjection capillary pressure measurement

•

•

•

FMI-HD high-definition formation microimager, QuantaGeo photorealistic reservoir geology service, andlaboratory services for whole core description, core
fracture description, and goniometry
Sonic Scanner acoustic scanning platform, MDT
modular formation dynamics tester minifrac, XLRock large-volume rotary sidewall coring service,and laboratory services for unconfined compressive
strength, triaxial stress testing, and pore volume
compressibility
MDT modular formation dynamics tester, Ora intelligent
wireline formation testing platform, and laboratory

Monitoring, verification and reporting technologies•

Optiq Schlumberger fiber-optic solutions•

Pulsar multifunction pulsed neutron service and CHFR
cased hole formation resistivity tool•

Optiq StreamLINE polymer-locked fiber-optic wireline
conveyance•

Permanent gauges and pressure falloff (PFO) testing•

Isolation Scanner cement evaluation service and UCI
ultrasonic casing imager

CHFR, CMR-MagniPHI, CoreFlow, CYNARA, DELFI, DrillPlan,
ECLIPSE, EM Pipe Scanner, EverCRETE, FLS, FMI-HD, INTERSECT,
Isolation Scanner, Litho Scanner, MDT, MRD, MR Scanner, OLGA,
Optiq, Optiq Seismic, Optiq StreamLINE, Ora, Petrel, PowerEcho,
PowerFlex, PressureXpress, Process Live, PS Platform, Pulsar,
Quanta Geo, Sonic Scanner, Symmetry, SULFATREAT, UCI, USI,VISAGE, Wellbarrier, WellWatcher PS3, and XL-Rock are marks of
Schlumberger or a Schlumberger company.

CONTACTGAS ANALYSIS AND FLOW METERING FOR CCUS

SICK

Aurélie Moll
Email:

Aurelie.moll@sick.deWeb:www.sick.com

BENEFITSSUMMARY
From factory automation to logistics automation andprocess automation – SICK drives industries with sensors.
As a technology and market leader, SICK provides sensors
and application solutions that create the perfect basis forcontrolling processes securely and efficiently, protecting
individuals from accidents, and preventing damage to theenvironment.
Founded in 1946 by Dr.-Ing. h. c. Erwin Sick, the company
with headquarters in Waldkirch, Germany ranks among
the technological market leaders. With more than 50
subsidiaries and equity investments as well as numerous
agencies, SICK maintains a presence all around theglobe. In the 2020 fiscal year, SICK had more than 10,000
employees worldwide and a group revenue of around EUR
1.7 billion.
Sensor Intelligence. For all requirements.
When movement becomes collaboration, when industrial
systems have to be flexible, and when clean solutions are
the key, then customer can certainly benefit from SICK’s
many years of experience. As an innovation leader andpioneer in the development of groundbreaking sensor
technology, we offer solutions that are already up to thechallenges of the future today. With intelligent sensor
technology that collects data and evaluates it in realtime, adapts to its environment and communicates in the
network.

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STATE OF THE ART: CCS TECHNOLOGIES 2022

Process Automation
SICK’s Process Automation division offers sensors
and tailored system solutions as well as services foranalysis and process measurement technology. Whenmeasuring emissions, they monitor the legally prescribedgas components, accurately record dust and particle
emissions and measure volume throughput. The ultrasonictechnology by SICK is one of the leaders in the precise
flow measurement of natural gas in the pipeline distribution
network as well as for process gases and steam. SICK’s
measurement technology solutions make a valuable
contribution to resource-saving plant control in the primaryindustries.
Sensor solutions for CCUS
SICK already has solutions to support the complete CCUS
value chain, when it comes to continuous gas analysis or
CO2 flow metering.

•

CO2 reporting and accounting. Flow metering will become necessary for fiscal purposes, custody transfer andcompliance with future regulatory measurements. SICK provides solid experience from thousands of custody transfer
applications with natural gas. This experience can be transferred for each step of the CCUS value chain to ensure
accurate flow measurement and precise reporting.

•

Process efficiency. Carbon capture processes require a high degree of efficiency to improve their economic andenvironmental attractiveness. The measurement of CO2 content and the remaining components after the capture
process is essential for control and optimization purposes. SICK has more than 10 years of experience with pilot
installations.

•

Quality control. Regardless of the destination of the captured CO2 (storage or utilization), it is important to control thequality of the gas and possible impurities that can have a negative influence on the later steps of the CCUS networkand ensure protection of the environment.

•

SICK LifeTime Services. SICK LifeTime Services is a comprehensive set of high-quality services provided to support
the entire life cycle of products and applications from plant walk-through to upgrades. LifeTime Services range fromproduct-independent consulting to traditional product services.

CONTACTGAS ANALYSIS AND FLOW METERING FOR CCUS

SICK

Aurélie Moll
Email:

Aurelie.moll@sick.deWeb:www.sick.com

DESCRIPTION
Continuous gas analysers for quality measurement andreporting
Carbon capture processes produce a highly concentrated
gas with more than 90% CO2 by volume. On the other hand,
there are the low carbon emissions to the environment,
which have to be reported for taxation purposes. The gas
mixtures contain other components that can be considered
impurities, and which can be corrosive, and either have an
influence on downstream process steps or are harmful tothe environment.
To control and optimize the efficiency of processes andemissions along the CCUS value chain, SICK continuous
gas analysers accurately measure the concentrations in
CO2 and other components in the gas mixture. Together
with SICK’s precise gas flow measurement, a true mass
flow output is also available. Such measurements are
essential prior to transportation, storage or utilization of
CO2.
Depending on the application, SICK can offer different
measuring technologies, including:•In-situ gas analysers accurately measuring CO2
directly in the gas flow without gas sampling. The
reliability, precision and short response time offer key
advantages for efficient process control.

•

Extractive analysers from SICK ensure continuous
monitoring of multiple components simultaneously
such as CO2, H2O, HCl, SO2, CO, NOx, NH3 andO2 with high accuracy to control and optimize the158

STATE OF THE ART: CCS TECHNOLOGIES 2022

CCUS processes. The most suitable analyser can beselected depending on the application, the measuringconditions, and the requested measuring parameters.
Gas flow measurement for transfer and processapplications
Carbon dioxide can be captured from different emission
sources and then collected and transported via pipelines
or ships for further handling steps such as storage orutilization. Gas flow measurements are necessary at eachtransfer point to control the quantity of captured CO2 or thevolume stored or transferred.
Accurate gas metering allows for precise accounting tocompanies or calculation of CO2 taxes and credits basedon regulations. With our experience in custody transfer
applications for natural gas which can be easily transferred
to CO2 and our highly reliable ultrasonic gas flow meters,
SICK provides the precise data required to operate the
CCUS value chain. The FLOWSIC600/-XT gas flow meters
deliver optimal measurement performance and provide
the highest rated gas metering accuracy. Thanks toPowerIn Technology™, the FLOWSIC600-XT also ensuresthat measurements continue to be taken and data isstored even in the event of a power failure. The rugged
design provides both the fault-free and maintenance freesystems. Due to the direct path layout, the signals are notreflected inside the device and are thus not affected bycontamination. This results in long-term system stability
and accuracy.

Reliable turnkey solution for CO2 metering
The FLOWSKID flow metering system is a full gas flow
metering system. It is provided by SICK as a turnkey
solution for transfer applications. The system is flexible
in design and provides highly accurate measurement
data. With FLOWSIC600 or FLOWSIC600-XT gas flow
meters as the heart of the metering skid, system reliability
can be assured. The metering skid can be customized
with instrumentation including gas analysers, gas
chromatographs, and supervisory computers – systemsolutions made by SICK! It is manufactured according to
ISO standards and is of the highest quality in line with thelatest DIN, ANSI, and ASME standards. This means thesystem will fulfil local regulations and requirements.

Space and protection for measurement and analysis
technology
Container solutions are primarily used to protect the
installed analyser systems from extreme ambientconditions such as heat, cold, dust, wind, earthquakes
and corrosive or explosive atmospheres. They also offer
advantages for transport as well as on-site installation andmaintenance. At the factory, everything is coordinatedand pre-installed in the container in a clear manner. Eachcontainer can be equipped to fit individual customer
requirements. The installation of transformers and UPS,
extinguishing, climate and gas warning systems is possible,
as is the implementation of sample point switching orcomplex redundancy and signal concepts.

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