Siemens AG – Division Power and Gas
CO2 Capture Utilization and Sequestration
(CCUS) with Siemens’ PostCapTM Technology
Copyright © Siemens AG 2015 All rights reserved.
Answers for energy.
Content
Market Development
CCUS within Siemens
Technology Leadership with Siemens PostCapTM
Engineering Capabilities and References
Business Models and Implementation Strategy
PG MOP CCS
Page 2
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Drivers of CCUS Development:
Greenhouse Gas Reduction and Enhanced Oil Recovery
Picture:
energy.gov “Office
of Fossil Energy”
Source: Siemens
Demand for (fossil) electricity still growing.
CO2 emissions will increase without CCUS
Emissions reduction GtCO2
Nuclear
Power Generation Efficiency
Renewables
End-use fuels switching
Demand of CO2 for Enhanced Oil Recovery is
increasing. Well-proven technology in USA.
S. & Cent.…
Middle East
Africa
CCS
North…
End-use fuel and electricity
efficiency
Welche
Ziele?
Source: IEA Technology
Roadmap CCS 2013
Page 3w/o
CCUS 2oC target cannot be achieved
Europe &…
Asia Pacific
Source: BP Statistical
Review 2014
50
100
Years
Total world proved reserves depleted within
next 50 years at current production levels
PG MOP CCS
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0
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Top-down market estimate of CO2-EOR potential
Total world proved oil
reserves 1688 billion
barrels (end 2013)
At daily production of 87 Mio
barrels oil (2013) reserves will
be exhausted in next 50 year
Sources: BP Statistical Review 2014
*at rates of 2013 **Enhanced Oil Recovery
Page 4
CO2-EOR potential estimated at
880 billion barrels which could add
further 30 years of production*.
Middle East
Russia
Africa
North America (non-US)
United States
Central/ Sout America
Asia Pacific
Europe
260 Gt of CO2 required to tap full CO2-EOR**
potential (note: annual CO2 reduction by CCS in
IEA’s 2oC scenario is 7 Gt in 2050)
Advanced Resources International (ARI), updated Review 12/2011 of ARI Report
PG MOP CCS
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Generation Costs of Electricity
IHS CERA European LCOE 2015
LCOE - 2015 - European Union
250
Gas price - LT
Gas price - Spot
Brent
Coal
CO2 Price
Capital
Fixed O&M
Var O&M
€/MWh (real 2014)
200
Fuel
1,9 €cent/kWh
1,9 €cent/kWh
65,1 $/barrel
0,8 €cent/kWh
6,4 €/t
219
194
CO2
Admin costs
150
TOTAL
125
95
100
77
CCS
119
89
79
110
Renewables
50
0
Nuclear III+
Notes: Add notes here or delete
Source: IHS
CCGT (oil- CCGT CC&S Steam Coal
linked gas)
(oil-linked
gas)
Steam Coal Gas Aero CT
CC&S
Peak
Onshore
Wind
Offshore
Wind
Solar PV
© 2015 IHS
CCUS is cost-competitive with other low-carbon generation options.
PG MOP CCS
Page 5
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Content
Market Development
CCUS within Siemens
Technology Leadership with Siemens PostCapTM
Engineering Capabilities and References
Business Models and Implementation Strategy
PG MOP CCS
Page 6
© Siemens AG 2015
2013 All rights reserved.
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Power and Gas
CEO Willi Meixner
 Gas turbines
from 100 to
400 MW
 Electrical
generators from
25 up to
2,235 MVA
 Fuel gasifiers
Distributed
Generation
(PG DG)
 Industrial gas
Turbines from
5 to 50 MW
 Aero derivative
gas turbines
from 4 to
64 MW
* Combined heat and power
Steam Turbines
(PG SU)
Compressors
(PG CP)
Energy Solutions
(PG ES)
 Steam turbines
from 45 kW to
1,900 MW
 Steam turbines
for industrial
applications &
power
generation
 Turbo
compressors for
- Oil & Gas
- Industrial
applications
 Compressor
packages incl.
drives
 50 HZ and
60 HZ Gas
turbine power
plant solutions
 CHP*
 IGCC**
 Repowering
 Integrated solar
combined cycle
 HRSG
Instrumentation
and Electrical
(PG IE)
 Control
solutions
 Electrical
solutions
 Energy
management
solutions
 Solutions for
distributed and
hybrid power
generation
Business Fields
Large Gas
Turbines,
Generators
(PG GT)
Business
Units
Division
Power and Gas Division
Organizational structure as of October 1st, 2014
** Integrated gasification combined cycle
PG MOP CCS
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Siemens competencies
CO2 capture and power plant integration
Instrumentation & Automation
CO2 Compressor
Engineering
competence
Chemical
Know-How
Compression
Transport
Injection
CO2
Capture
Reference Power Plants
Steam Turbines
Gas Turbines
Generators
Power
Generation
Software
skills
PG MOP CCS
Page 8
Post Combustion CO2
Capture Technology
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Siemens Combined Cycle:
Efficiency Evolution
SGT5-2000E
SGT5-4000F
SGT5-4000F
1992: 52 %*)
1996: 56 %
2001: 58 %
Killinghome
2 x 470 MW, 2x(2+1)
Basis
Didcot
702 + 710 MW, 2x(2+1)
- 113.000 t/a CO2
SGT5-8000H
2009: 60.75%
Mainz-Wiesbaden
Irsching 4
>400 MW, 1+1
- 164.000 t/a CO2
>570 MW, 1S
- 212.000 t/a CO2
Reduction of CO2 emissions
(scaled to 530 MW)
PG MOP CCS
Page 9
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Chemical Engineering of Siemens
in Industrial Park Hoechst (IPH) Frankfurt
Siemens PostCapTM Laboratory Plant
Key Figures IPH:
Area:
4,6 km²
Employees:
22 000
Companies:
> 90
Siemens at IPH:
Employees:
approx. 200
Disciplines:
PM, Process/ Mechanical
Design…
Proprietary Post Combustion CO2 Capture technology (Siemens PostCapTM), developed in
Industrial Park Hoechst, now ready for large scale demonstration projects.
Picture Source: http://www.horizont.net/news/media/6/Der-Industriep-Hch-zhl-zu-den-grt-Che--und-Pharmas57472.jpeg
Page 10
PG MOP CCS
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CO2 Capture Technologies and separation methods
CO2 Capture Technology
 Absorption
Post-Combustion
Pre-Combustion
Oxy-Combustion
Flue gas: CO2 content 4-15 vol% at atmospheric pressure
Syngas: CO2 content 40 vol-% in
pressurized fuel gas
Flue gas: CO2 content 70 vol-%
at atmospheric pressure
 Adsorption
 Condensation
 Membranes
 Cryogenic
distillation
 Chemical
looping
Post Combustion based on chemical absorption is preferred technology
in the upcoming demonstration projects
PG MOP CCS
Page 11
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CO2 Reduction Potential through
Siemens’ PostCap™ Technology
PostCap™ Technology
Validated in unit 5
of E.ON Staudinger
steam power plant
in Germany
700 MW CCPP in
O&G Business
340 g
CO2/kWh
800 MW Steam
Power Plant
730-1000 g
CO2/kWh
approx. 1,8 Mio tons of CO2
reduction per year
approx. 4,0 Mio tons of CO2
reduction per year
 40* g CO2/kWh
 80* g CO2/kWh
*90% CO2 capture rate
Page 12
Other Industrial
Processes
PG MOP CCS
CO2 concentrations higher,
CO2 quantities lower than in
power generation
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Content
Market Development
CCUS within Siemens
Technology Leadership with Siemens PostCapTM
Engineering Capabilities and References
Business Models and Implementation Strategy
PG MOP CCS
Page 13
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Siemens Post-Combustion Carbon Capture
for Fossil Fuel fired Power Plants
CO2 Absorption - Desorption
proven technology in chemical processing
and oil & gas industry…
…but special considerations for fossil
power plant environment, e.g.
 flue gas release to atmosphere
 high content of oxygen
 easy-to-handle for power plant personnel
Siemens PostCapTM Process
based on: AMINO ACID SALT Formulations
 “Scalable” market introduction
(from pilot to demonstration plant)
 Retrofitable to existing power plants as
well as applicable to new plants
Post Combustion is preferred solution for CCUS demonstration projects
PG MOP CCS
Page 14
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Amino acid salt is the basis of our solvent
Ammonia
H
H N
H
+
R’
HO
C
O
C
H
N
H
R
Amino Acid
C
H
2
N
2
H
O
C
R’
H
C N
H
R
Amino acid salt
H
HO C H
-
K O
MEA
Salts have no
vapor pressure
• No thermodynamic
solvent emissions
• Not inflammable
• Not explosive
• Odorless
• No inhalation risk
Negative ion is less
sensitive to O2
• Low degradation
No vapor pressure,
not volatile
Chemically stable
Naturally present
Amino acids are
naturally present
• Biodegradable
• Nontoxic
• Environmentally
friendly
Solvents based on amino acid salts are economic,
have low environmental impact and are easy to handle.
PG MOP CCS
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Siemens PostCapTM Process
Cleaned flue gas released to atmosphere,
Nearly zero solvent slip
CO2 Compression
Solvent
Reclaiming
Amine-based capture processes
have volatile solvent in exhaust gas;
additional washing units required
CO2 outlet
(concentration > 99%)
SIEMENS does not require it !
CO2 Absorption
 high absorption rate
 low degradation
Flue gas inlet
40-45°C
CO2 Desorption
 heating up solvent
 desorption of CO2
90-105°C  2.7 GJ per ton of
CO2 captured
Steam, @ approx. 120°C
(from power plant)
FGD polishing
not required
Siemens PostCapTM process based on amino acid salts is economic,
has low environmental impact
and easy to ©handle.
PG MOP CCS
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Siemens’ Reclaimer Technology
Proprietary Know-How
Solvent degradation
Solvent deactivation
due to degradation
(thermal, O2, NOx,
SOx, etc...)
 High amount of solvent can
be recycled
 Sellable Sulfur product
 FGD retrofit can be avoided
 Small amount of residue
Proprietary PostCapTM reclaimer
Sulfur
Recovery
solvent slip-stream
deactivated
solvent
Sulfur
Product
(sellable)
PG MOP CCS
Page 17
AAS
Recovery
reactivated
solvent
back to
capture
process
residue
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Solvent and process optimization for CCPP
with Post Combustion capture required
CCPP
SPP
CO2
14
vol-%
4
Lower CO2
content
vol-%
O2
3
12.5
Higher O2
content
Lower solvent
loadings and
driving force
Higher specific
energy demand
for regeneration
Slower reaction
kinetics
Higher
columns
Higher solvent
degradation
Higher solvent
consumption
Amino Acid salt has low sensitivity towards
Oxygen  low degradation
Specific
Fluegas
Flow
kg/MWel,gross
1.0
1.6
More
flue gas
Larger absorber
diameter
Currently Post-Combustion projects for gas fired power plants under evaluation in
UK, Middle East region and other countries...
SPP - Steam Power Plant
Page 18
CCPP - Combined Cycle Power Plant
PG MOP CCS
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Content
Market Development
CCUS within Siemens
Technology Leadership with Siemens PostCapTM
Engineering Capabilities and References
Business Models and Implementation Strategy
PG MOP CCS
Page 19
2013 All rights reserved.
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PostCapTM Pilot Plant at E.ON Staudinger
FGD
Project
Siemens PostCapTM Pilot Plant
Location
Frankfurt, Germany
Customer
E.ON (coal-fired power station Staudinger)
Commissioning
September 2009
Plant size
Approx. 1 t/d CO2 captured
Operating Hours
> 9,000 hours
 Siemens PostCap™-Technology verified for coal and natural gas
 Simulation tools and scale up-methods validated
 Optimizations and adaptations ongoing
CO2
Absorber/
Desorber
PG MOP CCS
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Masdar full-scale CO2 Capture Project
Project
Masdar full-scale CO2 capture project
Location
United Arab Emirates
Customer
Masdar Carbon
Process
Combined Cycle Power Plant
Plant size
1.8 Mio tons of CO2 per year captured
Commissioning
FEED finalized
 Growing CO2 demand for EOR in the next 25-30 years in UAE,
according to ADNOC estimates: 1000 MMSCFD (~ 20 Mtpa*)
 Masdar & ADNOC defined a CCUS strategy to enhance oil
recovery and potentially increase UAE’s gas availability
 Siemens finalized FEED for Masdar based on PostCapTM
CO2 capture technology
 Integration of a CO2 capture plant into an existing combined
cycle power plant
 Steam and power supply by revamp of existing power plant
(new heat recovery steam generator)
*million tons per annum
PG MOP CCS
Page 21
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Full-scale Carbon Capture Mongstad Project
Project
Full-Scale Carbon Capture Mongstad (CCM)
Location
Mongstad Refinery, Norway
Customer
Statoil Petroleum AS
Process
Combined Heat and Power Plant
Plant size
1.2 Mio tons of CO2 per year captured
Status
TQP finalized -project discontinued by Norw. Gov.
Type of Activity: Technology
Qualification Program (TQP):
1. Feasibility study
2. Demonstrate process operation
and specified emissions
level/criteria with test-rig and
pilot plant
3. Concept Phase incl. costing for
design of full-scale CO2 capture
PG MOP CCS
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Technology Qualification Program Mongstad
Pilot Plant Operation with Gas Burner
FGD
Flue
Gas
from
FGD
Technology Qualification
 3,000 operation hours
 Monitoring emissions
 Monitoring performance
CO2 Absorber/
Desorber
Gas burner package unit
Capture
Unit
Siemens PostCap™ successfully validated for application in gas fired power plant
PG MOP CCS
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Contract Study for Statkraft Norway
Combined-Cycle Power Plant (CCPP) with PostCap
Project
Contract Study for CCPP in Norway
Location
Norway
Customer
Statkraft
Process
Combined Cycle Power Plant
Plant size
1.2 Mio tons of CO2 per year captured
TASK 1
Adaptation and optimization of
Siemens PostCapTM process for
CCPP
TASK 2
Definition of capture ready CCPP
and PP performance evaluation
TASK 3
Evaluation of load change
bevavior of CCUS-CCPP
CCPP - Combined Cycle Power Plant
Page 24
PG MOP CCS
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Wilhelmshaven Feasibility Study
Project
Feasibility Study
Location
Europe, Germany Wilhelmshaven
Process
500MW Coal fired Power Plant (450 tons per
hour flue gas with 21%wt CO2)
Plant size
125 MW flue gas slipstream (700,000 tons per
year of CO2 @ 100 bar captured)
Status
Design finalized for 1 train PostCapTM Plant
PG MOP CCS
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Feasibility Study for ROAD Maasvlakte
Project
ROAD Maasvlakte Feasibility Study
Location
Netherlands
Process
1000 MW coal fired power plant (900 tons per
hour flue gas with 21%wt CO2)
Plant size
250 MW flue gas slipstream (1,100,000 tons
per year of CO2 @ 100 bar captured)
Status
Design finalized for 1 train PostCapTM Plant
PG MOP CCS
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Feasibility Study in USA
Project
Feasibility Study
Location
USA
Process
350 MW coal fired power plant (800 tons per
hour flue gas with 18%wt CO2)
Plant size
1,000,000 tons per year of CO2 (compression
out of scope captured)
Status
Design finalized for 1 train PostCapTM Plant
PG MOP CCS
Page 27
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Feasibility Study China
Project
Feasibility Study
Location
China
Process
New built coal fired power plant
Plant size
1,000,000 tons per year of CO2 captured
Status
Design finalized for 1 train PostCapTM Plant
PG MOP CCS
Page 28
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Capture Ready Design for SPP:
Basis: 800-900 MWel / Internat’l Coal
Capture
Plant
CO2compressor
PG MOP CCS
Page 29
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Capture Ready Requirements for SPP:
Plot Plan requirements including CO2 Compressor
Capture
plant: max:
25,000 m2
PG MOP CCS
Page 30
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Constructability and Maintainability
for full-size CO2 capture plant validated
Example photos for Tailing / Lifting using Crawler Cranes (Source:
Constructability of large-scale CO2 Capture equipment
extensively investigated and successfully validated.
PG MOP CCS
Page 31
)
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Capture Ready Requirements for Steam Power Plant:
technical aspects to be considered
Flue gas fan
Exhaust ducts
• consider Δp from CO2
absorption unit
• later flue gas connection to
capture unit (T-branch)
• upgradeable design
• or additional space for
installation of second fan
downstream of FGD
Steam turbine building
sufficient space/foundation for:
• modification of turbines
• steam and condensate pipes
Steam turbines
• extraction of approx. 40 % of LP
steam
• turbine table needs to be designed
for additional load
Electrical auxiliary load
sufficient space for:
• additional auxiliary transformer(s)
• switchyard
• cable routes
Cooling system
FGD
sufficient space for:
• additional circulation pumps
• service water system
• sufficient cooling capacity of
cooling tower
• consider capacity extension
in column design
Plant area for capture plant
sufficient space/foundation for
capture plant:
approx. 25,000 m²
Condensate system,
sufficient space for:
• heat exchangers for low grade
heat utilization
• additional piping routes with
supporting structure / racks
Raw water & cooling water
supply / Waste water
treatment
• sufficient space for enlargement
• secure water utilization rights
PG MOP CCS
Page 32
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Capture Ready Requirements for Combined Cycle
Power Plant: technical aspects to be considered
Stack:
Consider later flue gas
connection to capture unit
and flue gas flow switch
devices
Sufficient space for modification of
turbines, retrofit of steam extraction
and condensate return lines
9
Air
6
Steam turbines / Reheating:
Turbine building:
5
1
Auxiliary electric supply:
Life steam
Fuel
2
Adaptability for steam extraction; options for
modification of turbines depend on required
operating modes.
3
Sufficient space for additional
auxiliary transfomer(s), switchgear
and cable routes
10
7
11
4
Exhaust gas
Gas turbine plant:
Steam turbine plant:
1
2
3
4
7
8
9
10
11
12
Air intake
Compressor
Gas turbine
Heat recovery
steam generator
5 Generator
6 Transformer
Steam turbine
Condenser
Feeding pump
Generator
Transformer
Circulating pump
8
9
Cooling tower
Condensate
Cooling system:
Sufficient space for additional
circulation pumps and service
water system, sufficient space
for extension of cooling capacity
Elaboration of capture ready measures requires insight
into an appropriate capture process
PG MOP CCS
Page 33
12
Cooling
air
Water supply / Waste water
Fresh watertreatment:
Sufficient space for corresponding
retrofit measures; Provision of
additional water utilization rights
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Siemens compressors for CO2 applications
Gear-type compressor compared to single shaft
2 Inline casings (12 stgs),
3 coolers, gear, VSDS
Pi = 13.1 MW
100%
110,000 kg/hr
VSDS
+ 3 coolers, 12 impellers
Gear-type compressor,
1 casing, 8 stgs, IGVs
5 cooler, fixed speed motor
Pi = 11.7 MW
89%
110, 000 kg/hr
Intercooled integrally geared compressors fit perfectly to CO2 compression requirements
PG MOP CCS
Page 34
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Siemens compressors for CO2 applications
References – 30 Installations Worldwide
2014
Ganquanbao, China
79,000 m³/h
72 bar
15,500 kW GV (50-6) x 2
2013
Ningxia, China
136,000 m³/h
74 bar
28,200 kW GV (100-6) x 4
2010
APCI Port Arthur, USA
63,500 m³/h
157 bar
13,200 kW GV (50-8)
2010
Kemper County, USA
62,960 m³/h
150 bar
17,600 kW GV (50-8) x 2
2010
Enhance Energy, Canada
21,000 m³/h
39 bar
3,600 kW GV (16-6)
2010
Abengoa, Netherlands
26,106 m³/h
23 bar
3,350 kW GV (20-4)
2009
Chongqing, China
14,650 m³/h
29 bar
3,300 kW SH (8-8-B)
2008
Kharg
14,020 m³/h
46 bar
2,540 kW SH(8-8-B)+SV(6-6-A)
2007
Ningxia, China
83,200 m³/h
58 bar
2004
IFFCO, India
19,752 m³/h
1.8 bar
2004
Marun Petrochem
14,080 m³/h
32 bar
2004
IFFCO, India
17,165 m³/h
1.8 bar
2004
BASF, Germany
18,880 m³/h
27 bar
2,700 kW GV (10-4)
2004
QAFCO, Qatar
11,765 m³/h
26 bar
2,050 kW GV (10-4)
2002
Snohvit/Hammerfest, Norway
52,500 m³/h
62 bar
12,000 kW GV (40-6)
2001
BASF, Germany
12,170 m³/h
20 bar
1,750 kW GV (10-4)
1996
PPSL, Trinidad
18,620 m³/h
31 bar
2,750 kW SH (8-7-B)
PG MOP CCS
Page 35
16,900 KW GV (50-6)
470 kW GV (16-1-S)
2,800 kW SH (8-8-B)
420 kW GV (16-1-S)
© Siemens AG 2015 All rights reserved.
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References Southern Company
Kemper County IGCC Project
Siemens awarded “First” high pressure
CO2 compressors for Kemper County IGCC
Project
October 8, 2010, Mississippi Power (Southern
Co.) gave Siemens the award and notice to
proceed on the Kemper County IGCC project,
CO2 compressors. One compressor will also
receive a full load, full pressure test in Duisburg
with the job motor.
Model: STC-GV(50-8)
STC = Siemens Turbo Compressor
GV = integrally geared compressor
50 = frame/impeller size
8=
number of stages
CO2 Compressor Details
Volume Flow:
483,542 lb/h
Suction Pressure:
15 psia
Discharge Pressure: 2,165 psia
Suction Temperature: 43.0°C
Compressor Type:
STC-GV (50-8)
Driver:
EM (17.6 MW)
Order Year:
2010
Compressor Type:
Radial (8 stages)
PG MOP CCS
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References Air Products
Port Arthur ICCS Project
Siemens awarded high pressure CO2
compressor
December, 2010, Siemens have been
awarded one CO2 compressor by Air
Products. The compressor will be applied
in CO2 transport process for Enhanced
Oil Recovery.
Model: STC-GV(50-8)
STC = Siemens Turbo Compressor
GV = integrally geared compressor
50 = frame/impeller size
8=
number of stages
CO2 Compressor Details
Volume Flow:
63,455 m3/h
Suction Pressure:
1 bar
Discharge Pressure: 157 bar
Suction Temperature: 40.0°C
Compressor Type:
STC-GV (50-8)
Driver:
EM (16.3 MW)
Order Year:
2010
Compressor Type:
Radial (8 stages)
PG MOP CCS
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References Ningxia
CO2 - gear-type compressor STC-GV(50-6)
CO2 Compressor Details
Volume Flow:
83,200 m3/h
Suction Pressure:
1.2 bar
Discharge Pressure: 58,1 bar
Suction Temperature: 40.0°C
Compressor Type:
STC-GV (50-6)
Driver:
ST (17MW)
Order Year:
2007
Compressor Type:
Radial (6 stages)
PG MOP CCS
Page 38
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References Snohvit/ Hammerfest LNG
24XT - gear-type compressor STC-GV(40-6)
Package lift into the barge
LNG terminal status Oct. 2006 close to
Hammerfest / North Norway
http://www.statoil.com/STATOILCOM/snohvit/svg02699.nsf
Partial compressor view/shop testing
Barge installation in Cadiz
CO2 Compressor Details
Volume Flow:
52.500 m3/h
Suction Pressure:
1.05 bar
Discharge Pressure: 61.55 bar
Suction Temperature: 20.8°C
Compressor Type:
STC-GV (40-6)
Driver:
Electric Motor (12MW)
Order Year:
2002
Compressor Type:
Radial (6 stages)
PG MOP CCS
Page 39
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Content
Market Development
CCUS within Siemens
Technology Leadership with Siemens PostCapTM
Engineering Capabilities and References
Business Models and Implementation Strategy
PG MOP CCS
Page 40
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Post Combustion CO2 Capture Plant
Siemens Scope of Delivery
(optional)
Siemens Scope
Optional Siemens Scope
Compressor Solution
(optional)
Siemens PostCap™ License Package
for Core CO2 Capture Island
Power Plant
Integration Package
including:
Process Design
Package
(mandatory)
Siemens
PostCap™
Reclaimer
package unit
Engineering
Services
(optional)
EIA* Package for
Core Capture Island
Technical Field
Assistance
(optional)
Components/Devices
for Core Capture Island
*Electrical/Instrumentation/Automation
Siemens supplies License Package for core CO2 Capture Island and
reclaimer package unit  Implementation
by EPC
Partner
! All rights reserved.
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AG 2015
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PostCapTM Reclaimer delivery
Scope
 Reclaimer as transportable, skid mounted unit
 Consisting of standard equipment for chemical
plants
Partnering
 Siemens partners with profound experienced
partners which are experienced over decades in
the delivery of skid mounted units in chemical
and oil and gas industry
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Siemens Power Plant and CCUS Solutions – Partner
from process development to project implementation
Siemens Expertise
PostCapTM Benefits:
Good environmental performance
Chemical
Engineering
Power
Generation
O&G
Industry
Process is “easy-to-handle”
Intelligent two-step reclaimer, sellable sulfur
product
Low operating costs (OPEX)
Optimized power plant integration
Optimized electricity generation costs
Optimized cost of CO2 captured
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Summary
Fossil fuels will maintain a big share in global electricity production, CCS is urgently
needed.
Enhanced Oil Recovery is providing additional revenue streams (CCUS).
Siemens PostCapTM based on amino acid salt is very efficient and has good
environmental rating.
Siemens post-combustion CO2-capture technology successfully verified in pilot plant.
Large-scale applicability of PostCapTM demonstrated in several engineering projects
globally.
Siemens offers License Package for PostCapTM incl. delivery of reclaimer package unit for
large-scale scale projects.
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Find out more about
PostCap™
www.siemens.com/energy/
post-combustion-carboncapture
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Disclaimer
This document contains forward-looking statements and information – that is, statements related to future, not past,
events. These statements may be identified either orally or in writing by words as “expects”, “anticipates”, “intends”,
“plans”, “believes”, “seeks”, “estimates”, “will” or words of similar meaning. Such statements are based on our current
expectations and certain assumptions, and are, therefore, subject to certain risks and uncertainties. A variety of
factors, many of which are beyond Siemens’ control, affect its operations, performance, business strategy and results
and could cause the actual results, performance or achievements of Siemens worldwide to be materially different from
any future results, performance or achievements that may be expressed or implied by such forward-looking
statements. For us, particular uncertainties arise, among others, from changes in general economic and business
conditions, changes in currency exchange rates and interest rates, introduction of competing products or technologies
by other companies, lack of acceptance of new products or services by customers targeted by Siemens worldwide,
changes in business strategy and various other factors. More detailed information about certain of these factors is
contained in Siemens’ filings with the SEC, which are available on the Siemens website, www.siemens.com and on the
SEC’s website, www.sec.gov. Should one or more of these risks or uncertainties materialize, or should underlying
assumptions prove incorrect, actual results may vary materially from those described in the relevant forward-looking
statement as anticipated, believed, estimated, expected, intended, planned or projected. Siemens does not intend or
assume any obligation to update or revise these forward-looking statements in light of developments which differ from
those anticipated.
Trademarks mentioned in this document are the property of Siemens AG, it's affiliates or their respective owners.
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