Non-Aqueous Solvent CO 2 Capture Process S. James Zhou, Jak - - PowerPoint PPT Presentation

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Non-Aqueous Solvent CO2 Capture Process

• S. James Zhou, Jak Tanthana, Paul Mobley, Aravind Rabindran, Mustapha Soukri, Vijay

Gupta, Thomas Gohndrone, Markus Lesemann, and Marty Lail Andrew Tobiesen, Thor Mejdell, Ugochukwu E. Aronu, Andreas Grimstvedt, Kai Hjarbo, Lars Hovdahl

TRONDHEIM, NORWAY

June 12 - 14, 2017 9TH TRONDHEIM CONFERENCE ON CO2 CAPTURE, TRANSPORT AND STORAGE

Presentation Overview

▪ Overview and Objectives ▪ Summary ▪ Results and Discussion ▪ Next Steps / Technology Development Pathway

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Overview and Objectives

Objective: Continue the advancement of the

NAS CO2 Capture Process

• Increase solvent performance
• Design and build unique process modifications for

Non-aqueous solvent

• Perform pilot testing of NAS on coal-derived flue gas
• Techno-economic and EHS evaluation

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Path to Reducing ICOE and Cost of CO2 Avoided

▪ Primarily focus on reducing energy

consumption – reboiler duty

▪ Reduce capital expenditure ▪ Simplify process arrangement ▪ Materials of construction ▪ Limit operating cost increase

R&D Strategic Approach

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1 Rochelle, G. T. Amine Scrubbing for CO2 Capture. Science 2009, 325, 1652-

1654.

Breakdown of the Thermal Regeneration Energy Load

Sensible Heat Heat of Vaporization Heat of Absorption Reboiler Heat Duty Solvent Cp [J/g K] Dhabs [kJ/mol] Dhvap [kJ/mol] Xsolv [mol solv./ mol sol’n] Da [mol CO2/ mol solv.] Reboiler Duty [GJ/tonne CO2] MEA (30%) 3.8 85 40 0.11 0.34 3.22 Lower Energy Solvent System NAS 1.3 65 1 0.3 0.3 1.71

For NAS, heat of vaporization of water becomes a negligible term to the heat duty Process capable of achieving these criteria will have a lower energy penalty than SOTA processes

Oper. 11% Power 56% Capital 33%

NAS Process

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Wash Section

Wash Section Exhaust Gas Interstage Coolers

Flue Gas Feed Gas

Filter Absorber Solvent Make Up

Lean Amine Cooler

Condenser Interstage Heaters

Reboiler

CO2 Product Gas Knock-Out Drum

Rich/ Lean HX

Bench Scale Test Unit Results

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RTI non-aqueous solvents showing substantially reduced reboiler heat duties

Reboiler Heat Duty (GJ/T-CO2) L/G (mass/mass)

Experimental Reboiler Duty Data

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Conditions for Experimental Data

• Absorber: 37-40°C
• Regenerator: 87-98°C
• Pressure: 2.5 bar
• Interstage Heater Regeneration

Reboiler Heat Duty (GJ/T-CO2) L/G (mass/mass)

Specific Reboiler Duty Comparison

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0,5 1 1,5 2 2,5 3 3,5 4 MEA KS-1 Shell Cansolv DC- 103 RTI NAS-5

SRD (GJ/T-CO2)

(SaskPower) (Petra Nova Carbon Capture Project)

36 – 42% Reduction

• Ref. for KS-1
• Ref. Cansolv DC-103

Small-Pilot Testing with Coal-fired Flue Gas at SINTEF

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• Compare MEA and NAS in

conventional system

• Water balance
• Confirm reboiler heat duty
• Emission measurement
• MEA baseline testing completed at Tiller plant
• NAS baseline testing completed
• 400 hours of testing with propane+coal flue gas
• Confirmed the reduction in reboiler duty

Objective:

• Design and build unique process modifications for

SINTEF’s Tiller plant

• Demonstrate RTI NAS process on coal-derived flue gas
• Finalize NAS solvent formulations
• Techno-economic and EHS evaluation

MEA/H2O Baseline Testing at Tiller (Reboiler heat duty)

30 wt% MEA baseline testing at Tiller. 14 steady-state runs with varied parameters:

• Liquid circulation rate
• Heat rate (MJ/kg CO2)
• Inlet gas humidity
• Intercooling
• Absorber packing height
• CO2 capture efficiency
• Flue gas velocity

Reboiler Heat Duty (GJ/T-CO2)

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MEA/H2O Baseline Testing at Tiller (CO2 capture rate)

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NAS Baseline Testing in SINTEF’s Tiller Plant

Temperature profiles for NAS-3 baseline testing at SINTEF’s Tiller Plant

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NAS Baseline Testing Results at Tiller

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Tiller Run 18 Run 22 Date 12.01.2017 16.03.2017 Hour 06:50-07:50 16:00-17:00 Solvent NAS NAS Source Mimicked Coal Coal Gas inlet ABS 110.0 110.0 CO2 inlet ABS 14.87 14.42 CO2 outlet ABS 1.832 0.659 CO2 recovery 89.3 % 96.1 % Liquid inlet Absorber 18.00 18.00 L/G ratio 8.5 8.4 Lean amine (tit) 2.695 2.348 Lean Loading 0.121 0.074 Rich Loading 0.273 0.290 Water Lean 7.9 6.841 Temp Liq Reboiler 99.3 104.8 Desorber press top 100.68 97.08 Reboiler duty 17.82 17.80 Preheat rich flow 2.53 2.53 SRD (w/ heat loss) 3.06 2.90 Temp Gas outlet DCC 24.7 23.7 Temp Lean amine inlet 34.8 34.9 Temp Intercooling 38.1 38.7

Mimicked coal flue gas using propane burner flue gas (runs 18, and 22 respectively) SRD with account of heat loss amounts to about 2.8 GJ/t, assuming 1.5kW loss in the hot lines. In the coming months, several modifications will be made at Tiller to run NAS under

• ptimum conditions

It is expected that the Tiller plant modifications will bring the SRD further down (next slide).

NAS-Specific Components for SINTEF Plant

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Customized changes for the NAS solvents Installation of:

• Two additional absorber inter-coolers (total of three intercoolers)
• Improved water-wash (additional water wash section)
• Two custom made regenerative "inter-heaters"
• One additional cross-flow heat exchanger (that can work in series, or bypass, with the

current). Improved solvent:

• To run NAS-5, capable of operating with lower L/G ratios.

Plant modification to Tiller is expected to be completed by mid September 2017.

Developed rate-based process model Aspen ENRTL-SR Thermodynamic and physical properties acquired experimentally:

• Henry’s constant for CO2
• Liquid heat capacity
• Vapor pressures
• Reference state properties
• Heat of vaporization
• Dissociation constants
• VLE
• Density
• Dhabs
• Viscosity
• Surface tension
• Thermal conductivity
• Dielectric constant
• Diffusivity of CO2

Used process model to direct bench- scale testing after initial runs

Process Modeling

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Next Steps: Large Pilot Testing

• Large pilot testing for non-aqueous solvent technology targeted for 2018+
• ~ 1 - 10 MW equivalent
• Range of flue gas compositions (including coal, NGCC, etc)
• Extended operation with finalized NAS formulation and process design
• Technology Center Mongstad and U.S. National Carbon Capture Center

are potentially suitable sites

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CO2 Technology Centre Mongstad (TCM), Mongstad, Norway National Carbon Capture Center (NCCC), Alabama, USA

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Leveraging the U.S. – Norway Collaboration Framework

Pilot Testing at SINTEF Tiller Plant (Norway, 2015-2018)

Demonstration of all process components at in adiabatic system pilot scale (~60 kWe)

• Quantify solvent losses and

emissions

• Test campaign on coal derived

flue gas

• Collect critical process data to

support scale up, develop engineering package

RTI Novel CO2 Solvents

Large, Bench-Scale System (RTI Facility, 2014-2016)

Demonstration of key process features (≤ 2.0 GJ/T-CO2)

• Optimize NAS formulation
• Develop critical process

components

• Detailed solvent

degradation and preliminary emissions studies (SINTEF NASCHAR project)

• Detailed TEA and EH&S

assessments

Lab Development & Evaluation (2010-2013)

Solvent screening Lab-scale evaluation

• f process

Future Demonstration (2017+)

Pre-commercial Demonstration e.g. at Technology Centre Mongstad, Norway (~10 MWe) Planning ongoing

• Complete process unit with all

components at minimum size required for confident scale-up

• Collect critical process information to

support detailed T&E assessments, emissions monitoring, long-term testing to develop reliability, availability and maintainability (RAM) metrics 18

Acknowledgments

• Financial support provided by DOE NETL under DE-

FE0026466

• DOE Project Manager: Steve Mascaro
• RTI cost share and project partner SINTEF

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