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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

2

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

3

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

41 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

AbsorptionReboiler

Heat Duty

SolventCp

[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

5

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

6

RTI non-aqueous solvents showing substantially reduced reboiler heat duties

Reb

oil

er H

eat

Du

ty (

GJ/T

-CO

2)

L/G (mass/mass)

Experimental Reboiler Duty Data

7

Conditions for Experimental Data • Absorber: 37-40°C

• Regenerator: 87-98°C

• Pressure: 2.5 bar

• Interstage Heater Regeneration

Reb

oil

er H

eat

Du

ty (

GJ/T

-CO

2)

L/G (mass/mass)

Specific Reboiler Duty Comparison

8

0

0,5

1

1,5

2

2,5

3

3,5

4

MEA KS-1 Shell Cansolv DC-103

RTI NAS-5

SR

D (

GJ/T

-CO

2)

(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

9

• 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 velocityR

eboil

er H

eat

Du

ty (

GJ/T

-CO

2)

10

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

11

NAS Baseline Testing in SINTEF’s Tiller Plant

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

12

NAS Baseline Testing Results at Tiller

13

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

optimum conditions

It is expected that the Tiller plant

modifications will bring the SRD further down

(next slide).

NAS-Specific Components for SINTEF Plant

14

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

15

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

16CO2 Technology Centre Mongstad (TCM), Mongstad, Norway National Carbon Capture Center (NCCC), Alabama, USA

17

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

of 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

19