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Application of a Heat Integrated Post-Combustion Carbon Dioxide Capture System with

Hitachi Advanced Solvent into ExistingCoal-Fired Power Plant (FE0007395)

An Advanced Catalytic Solvent for Lower Cost Post-Combustion CO2 Capture in aCoal-Fired Power Plant (FE0012926)

Heather Nikolic, Jesse Thompson, James Landon and Kunlei Liu

University of Kentucky - Center for Applied Energy Research

http://www.caer.uky.edu/powergen/home.shtml

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Project Summary

Motivation•Heat integration to recover rejected energy• Thermal compression via enriched carbon loading to the stripper•Reduced capital cost

Team Members

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Combustion Air (partial)

Pri/Sec Air

Coal

PC Boiler

PM Control

Steam Turbine

FWHs

Condenser

E-65

Liquid Desiccant

Air

Cooling Tower

To Cond.

From Condenser

Wa

ter

Eva

po

rato

r

To Storage or

Utilization SiteExhaust gas to Stack

(N2, H2O etc)

Carbon Capture

& Compression

Heat Recovery

Comp Comp

Tank

Reclaimer

Na2CO3

Sludge

Solid (Ash, Sulfur and Nitric Compound)

So

lve

nt

Ma

ke

up

E-41

Chiller

E-32

Finned Tube Heat Exchanger

Packing

Mist Eliminator

E-54

Plate Type Heat Exchanger

Rotary Filter

Kettle Reboiler

Gas Stream

Combustion Air

Makeup Water

Rich Solution

Lean Solution

Condensate Water

Power

Liquid Desiccant

Cooling Tower

LGE Power Plant

FGD Blowndown

Heat from ECO

• Near-zero makeup water for amine loop

• Advanced Solvent

• Utilization of low grade heat via internal heat pump• Secondary stripper• Liquid desiccant for cooling tower

UKy-CAER Advanced Technology

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Small Pilot Project Overview

• 0.7 MWe (2 MWth)advanced post-combustionCO2 capture pilot

• Catch and release program

• Designed as a modularconfiguration

• Testing at Kentucky UtilitiesE.W. Brown GeneratingStation in Harrodsburg, KY,approximately 30 milesfrom UKy-CAER

• Includes several UKy-CAER developed technologies

• Two solvent testing campaigns (MEA baseline and advanced H3-1)

Lexington

Harrodsburg

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BP1: October 1, 2011 to January 31, 2013 (16 months)

BP2: February 1, 2013 to August 31, 2013 (7 months)

BP3: September 1, 2013 to March 31, 2015 (19 months)

BP4: April 1, 2015 to March 31, 2017 (24 months)

Scope Addition: April 1, 2017 to March 31, 2019 (24 months)

Small Pilot Project Performance Dates

2011 2012 2013 2014 2015 2016 2017 2018 2019

BP1 BP2 BP3 BP4 New Scope

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All Criteria Met and Project Key Findings

MEA Parametric Campaign

MEALong-term Campaign

H3-1 Parametric Campaign

H3-1Long-term Campaign

Process can easilycapture 90% of CO2

Solvent regeneration energy of1200–1750 BTU/lb CO2-captured,

~13% lower thanReference Case 10 (RC 10)

Process can easilycapture 90% of CO2

Solvent regeneration energy of1200–1750 BTU/lb CO2-captured,

~13% lower thanReference Case 10 (RC 10)

Ambient conditions have animpact on CO2 capture

Absorber liquid/gas distributionhas an impact on performance

Lean/rich exchangerperformance is critical

Elemental accumulationin the solvent

needs to be monitored

Ambient conditions have animpact on CO2 capture

Absorber liquid/gas distributionhas an impact on performance

Lean/rich exchangerperformance is critical

Elemental accumulationin the solvent

needs to be monitored Solvent regeneration energy of900–1600 BTU/lb CO2-captured,

~36% lower than RC10 Secondary air stripper performs as expected

Solvent regeneration energy of900–1600 BTU/lb CO2-captured,

~36% lower than RC10 Secondary air stripper performs as expected

90% CO2 capture and low solvent regeneration energies

are possible with a range of solvent concentrations

90% CO2 capture and low solvent regeneration energies

are possible with a range of solvent concentrations

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Partial CO2recycling

(10-20% of CO2captured) to

enhance gaseous CO2

pressure at the absorber inlet.

A heat-integrated post-combustion CO2 capture system with:

Project Success Criteria - Achieved

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Much cooler recirculating

cooling water,3-9 °F

comparedto a

conventional cooling tower at the same

ambient conditions.

A heat-integrated post-combustion CO2 capture system with:

Project Success Criteria - Achieved

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Liquid/gas distribution can significantly reduce the absorber efficiency.

Project Key Finding

Process data with constant absorber L/G, inlet CO2

concentration, inlet amine CO2-loading and temperature.

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Understanding the L/R exchanger performance is critical when comparing regeneration energies.

Project Key Finding

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Positive correlation between NH3 emissions and higher Fe in the solvent.

Ammonia Emissions and Iron

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Accumulation of

contaminants from service

water is minor compared to

the impact from coal flue gas

Service Water Usage

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Hitachi

Hitachi MEA

MEA

Corrosion Characterization

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UKy-CAER’s

Pathway to

Target:

• 3rd generation

solvent

• Hybrid process

with pre-

concentrating

membrane

• Absorber gas

inter-conditioner

Summary of TEA (@2007$)

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The Cost of 2nd Generation Solvents Prevents COE Reduction

MEA Solvent A Solvent B

Make-up Rate (kg/ton CO2) 1.5 0.5 0.5

Energy Consumption to MEA 30% less 40% less

Unit Cost ($/kg) 1.5 9 15

Solvent Cost 2.25 4.5 7.5

COE (using MEA Solvent Cost) 106.5 93.3 91.2

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3rd Generation Solvent is Needed• Kinetics are faster than 2nd generation, but

• 25-30% better than MEA while the cost is 2x

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Large Bench Project Overview• 3rd generation solvent• Enriched carbon loading prior to solvent regenerator

Pre-absorber CO2 enrichment Rich Solution dewatering

Absorber

Stripper

CO2 Out

Polishing

Heat Exchanger

Rich-LeanHeat Exchanger

CO2 LeanSolvent

CO2 Rich Stream

Membrane 1(Gas Separation)

CO2 Lean

Stream

Coal-Fired Flue Gas Generator

Water Wash

Recovered Solvent

Treated Flue Gas Out

CO2 Rich Solvent

~ 4 bar

135°C

Water

Cooling

Water

Heat Input

40°C

40°C

55°C

40°C

CAER-B3 Solvent

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The OPEX, energy consumption, is particularly determined by the relationship of CO2

pressure between the scrubber and the stripper which MUST FOLLOW the thermodynamic Gibbs free energy.

• Gibbs–Helmholtz equation• Clausius–Clapeyron relation

𝑃𝐶𝑂2= 𝑃𝐶𝑂2,𝑠𝑐𝑟𝑢𝑏

× 𝑒

∆ℎ𝑎𝑏𝑠,𝑐𝑜2𝑅

×1

𝑇𝑟𝑒𝑓−1

𝑇

Motivation

∆𝐻 = 60𝑘𝐽

𝑚𝑜𝑙Ts = 45oC

• Driving force for high carbon loading• Thermal compression at low temperature then less degradation

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Effectiveness of Pre-concentrating Membrane

• Solvent independent• Stable performance

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PRETREATMENT

COLUMN

FLUE GAS FEED

BLOWER

ABSORBER

PRETREATMENT

PUMP

RICH PUMP

PRETREATMENT

COOLERINTERCOOLER

WATER EVAPORATOR

BLOWER

DESICCANT

COOLER

DESICCANT

CHILLER

.

GAS

WATER

STEAM

DESSICANT

RICH

SEMI-RICH

LEAN

MAKEUP

WASH

COOLING

TOWER

PRIMARY

STRIPPER

SECONDARY

AIR STRIPPER1

2

1

2

2

1

2

1

2

1

1: COOLING WATER SUPPLY2: COOLING WATER RETURN3: STEAM SUPPLY4: CONDENSATE RETURN5: CHILLED WATER SUPPLY6: CHILLED WATER RETURN

3

4

ABSORBER

POLISHING

EXCHANGER

SECONDARY

HEAT RECOVERY

EXCHANGER RICH HEAT

RECOVERY

EXCHANGER

LEAN/RICH

EXCHANGER

REBOILER

PRIMARY STRIPPER

PUMP

SECONDARY STRIPPER

PUMP

LEAN/DESICCANT

EXCHANGER

WATER

EVAPORATOR

PUMP

1

2

COOLING TOWER

BLOWER

DESICCANT

PUMP

PRIMARY

HEAT RECOVERY

EXCHANGER

DESICCANT

PREHEATER

3

4

5

6

INTERCOOLER

PUMP

WATER

EVAPORATOR

3

4

RECLAIMER

1

2

WATER

WASHSORBENT

BED

MEMBRANE

WATER

WASH

COOLERWATER

WASH PUMP

Updated 0.7 MWe CCS Flowchart for

Scope Addition

Target: ~800 BTU/lb-CO2

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CO2 Pre-concentrating Membrane(currently using MTR Product)

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Technology Development Pathway

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Acknowledgements

Lynn Brickett, Elaine Everitt and José Figueroa, U. S. DOE NETL

CMRG Members

Gerald Arnold, David Link,Mahyar Ghorbanian, and Jeff Fraley, LG&E and KU

UKy-CAER Slipstream Team

The Slipstream Team: Kunlei Liu, Lisa Richburg, Fan Zhen, Andy Placido,Jon Pelgen, Reynolds Frimpong, Amanda Warriner, Len Goodpaster,

Marshall Marcum, Otto Hoffmann, Leland Widger, Jonny Bryant, Brad Irvin, James Landon, Wei Li, Jesse Thompson,

Saloni Bhatnagar, and Keemia Abad