CCS achievements at TCMRelated to CHP

Managing Director Frank Ellingsen

CO2 history in Norway 1990-2020

2010 202020151995 2000 2005

Storage: Statoil Sleipner

R&D 1997:Klimatek

GASSNOVA SF The Norwegian state enterprise for carbon capture and storage, (2005)

TCM in operation Government ambition

full-scale CCS facility by 2020

Storage: Statoil, Snøhvit

R&D 2005 CLIMIT

CO2 tax offshore

1990

SHELL

This is TCM

Vision

• Develop and verify technologies owned by vendors

• Reduce cost and risks

• Knowledge sharing

• Develop the emerging market for CO2 capture technology

Gas Power Plant

Amine plant

Chilled Ammonia plant

Admin complex

Electricalsubstation

Utilities

Area for future development

Seawater

Catalytic cracker

Refinery

CHP (Powerplant)

• Test campaigns the Amine Plant

• Campaign-1 on CHP flue (3.5 % CO2)• Campaign-2 on RFCC flue (13-15 % CO2)• MEA campaig-3 on CHP flue (3.5 % CO2)• Campaign- 4 on CHP flue (3.5 % CO2)

Campaign 1. Amine Plant, CHP flue gas and S21 solvent

Target: Stable operation

• About 93% operability• CO2 capture rate about 90% • Emission about 0.2 ppm Amine

• Nitrosamines and nitramines below detection limit• Stable solvent with low degradation. Main degradation

products amines, amino acids with low volatility.• Very low concentration of solvent specific nitramines • Reclaiming showed low waste production(0,26 Kg/ton

CO2)

Dynamic operations of the amine plant – A test

The graph shows an example of tripping and starting the amine plant.– ability to go from zero to full speed in 1 - 1.5 hours after trip

• Testing the capture during dynamic transitions, replicating a fluctuating grid power consumptions

• Supporting growth of renewables

Campaign 2 RFCC gas (13.5 % CO2)

MIST generation

Preliminary conclusions:• SO3 and SO2 generate mist

Alternative solutions considered:• Reduce SO3 and SO2 by filters

• Process development

Operation of the Amine Plant

Campaign 3 MEA on CHP (3.5 % CO2)Campaign 4 New solvent (S26) on CHP (3.5 % CO2)- on going

Objectives of theMEA campaign - 3• Develop a dataset to chare

• Capture CO2 from CCGT power plant flue gas

• Create plant base line with 30% wt aqueous MEA.• Investigate the potential of high conc. MEA (up to

40% wt ) achieving about 85% CO2 capture

• Verify design capacity of the plant and specific functionalities

• Verify and improve process simulation model• Understand scale-up, performance and emissions

Baseline preliminary results: typical emission performance

MEA 0.02 ppmv (TCM DA lab)

NH3 10 ppmv (TCM DA lab)

Acetaldehyde 0.2 ppmv (third party lab)

Formaldehyde 0.1 ppmv (third party lab)

Total nitrosamines < 0.00008 mg/m3 (third party lab)

Total nitramines < 0.0002 mg/m3 (third party lab)

30% wt aqueous MEA base line run

MEA Campaign – 3Conclusions and way forward• 30% wt aqueous MEA base line established and

being verified by EPRI• 40% wt aqueous MEA base line established (not in

EPRI scope)• Plant operating window explored• Start up, shut down and transient operating

conditions tested and investigated• Low emissions during normal operation• Way forward: additional MEA campaign(s) necessary

to• Measure long term effects as degradation and

corrosion• Better understanding of scale-up• Test reclaiming• Test lean solvent vapor (LVC) compressor• Others to be defined

Test campaigns at the Chilled Ammonia Plant (CAP)

Campaign 1: Nov 2012 – April 2013Tests on RFCC flue gas. Need for process modification/improvement identified

Campaign 2: May 2013 – Sept 2013 Operation at CHP flue gas (3.5% CO2)Target: Stable operationOperability around 90%

Campaign 3: Nov 2013 – Aug 2014RFCC flue gas (13.5% CO2)New tests on low concentration flue gas

Alstom’s Chilled Ammonia Process

• TCM has demonstrated the Alstom CAP technology, and a successful and stable operations of more than 4000h (RFCC and CHP flue gas)

• No environmental or health risk• Very low emissions

The Chilled Ammonia CHP Campaign - 2

Operation experience confirmed• Low ammonia emission in the residual flue

gas to atm.: 1 to 3 ppmv

• Low ammonia concentration in the CO2 product: <10ppmv

• CO2 Capture rate: 85 to 90% (Reference period: 88% at 47 000 Sm3/h flue gas)

• Solvent is stable without any trace of degradation

• More than 1300 operating hours confirm:• Acceptable process stability• Flexibility and ability in handling

transient conditions

Operation experience confirmed• After flushing with water, a safe

maintenance/disassembling of equipment with ammonia solvent is performed with usual/suitable personal protection

• At low ambient temperature (under 0ºC), in case of leakage, the vaporization of ammonia from the solvent is very limited and may be not detected

• At higher temperatures, even small leakages are detected early by gas detectors or operator inspection

The Chilled Ammonia CHPCampaign -2

Operation lessons learned • Salt formation in gas phase: Heat tracing with temperature alarms are installed

in order to avoid salt formation in:• safety valves• critical pressure and level instrumentation• regenerator feed pump• Rich/Lean heat exchangers• Rich feed Tank vent line.

• Online analyzer for CO2 and NH3 in the flue gas are a challenge. The main causes are:• Instrumentation hardware and software complexity• Condensation of salts in gas phase• Accumulation of salts in piping/instrumentation when the liquid droplet

with salts entrained with the flue gas are dried by heat tracing.• Gas and liquid sampling and laboratory analyze are challenging due to salt

precipitations unstable and not visible

The Chilled Ammonia CHP - Campaign - 2

Welcome to Bergen and Mongstad;

…to share knowledge on carbon capture TCM launched the first International Test Centre Network to accelerate CCS technology development

• Sharing knowledge of developments, construction and operational experience

• Establishing benchmarks and performance indicators

• Promoting technology certification and standardization

..and be a part of TCM going ahead

To develop

• Large test facilities

• Utility/infrastructure and the available test area

TCM has proven its key role in reducing• Costs and risks

Thank you