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8/14/2019 Technologies for Carbon Capture and Storage TEE 11.05.09
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Centre for Research and Technology Hellas/ Institu te for Solid Fuels Technology and Applications
CERTH/ISFTA
Technologies for Carbon Capture and
Storage
Pre-convention of the Technical Chamber of Greeceon the Optimization of lignite exploration in the
electricity production
Prof. Em. Kakaras and Dr. . Koukouzas
Kozani, 11 May 2009
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Table of Contents
1. Carbon dioxide capture options
2. CCS implementation and projects
3. CCS in the European energy market
4. Greek CO2 Capture PP
5. CCS in the Greek energy market
6. Carbon dioxide storage options
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Carbon dioxide capture options (1)
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Carbon dioxide capture options (2)
Post-
Combustion
Capture
Pre-
Combustion
Capture
Oxyfuel
Coal CO2 Capture
NGCC
Flue gasO2production CO2 Capture
IGCC
Cleaning StorageIRCC
CompressionTransport
O2production Oxyfuel
Technology availability / Industrial Maturity Storage location selection
Environmental Commitments Security of storage
Strategic Planning Monitoring / Verification
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CO2 scrubbing from flue gas using amine solution
European Technology Platform, Zero Emission Fossil Fuel Power Plants (ZEP), Working Group 1,Power Plant and Carbon Dioxide Capture
Carbon dioxide capture options (3)
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Oxyfuel combustion
Vattenfall
Carbon dioxide capture options (4)
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European Technology Platform, Zero Emission Fossil Fuel Power Plants (ZEP), Working Group 1,
Power Plant and Carbon Dioxide Capture
Production of a carbon free fuel
ASU
Gasifier Acid gasremoval
Powerisland
Sulphur
recovery
Gas cooling/dedusting
AirAir
AirAir
NN22
OO22
SteamSteam
RawRaw gasgas
CoalCoal
SourSour gasgas
ASU
Gasifier Acid gasremoval
Powerisland
Sulphur
recovery
Gas cooling/dedusting
AirAir
AirAir
NN22
OO22
SteamSteam
RawRaw gasgas
CoalCoal
SourSour gasgas
Carbon dioxide capture options (5)
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Timeline for CO2 capture technologies
European Technology Platform, Zero Emission Fossil Fuel Power Plants (ZEP), Working Group 1,Power Plant and Carbon Dioxide Capture
Timeline for CO2 capture technologies
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, CO2 Capture and Storage : A Key Carbon Abatement Option (2008)
Scenarios of CCS implementation
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CCS technologies in thermal PPs will contribute significantly in themitigation of the GHG effect since thermal PPs account for ca. 1/3 of
the total CO2 atmospheric emissions. This fact explains the intenseresearch activities aiming at the achievement of viable solutions in themedium term.
The following are a number of important EC CCS projects with Greekpartnership (CERTH NTUA - PPC):
ENCAP (Pre-combustion and oxyfuel technologies for solid fuels)
CASTOR (Post-combustion CO2 capture)
CACHET (Post-combustion CO2 capture for gaseous fuels) ISSC (Production of a carbon-free gaseous fuel from solid fuels
using CaO and pre-combustion CO2 capture)
C2H (Production of a H2-rich from solid fuels using CaO)
Research projects on the ZEPP
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European Technology Platform, Zero Emission Fossil Fuel Power Plants (ZEP), Working Group 1,Power Plant and Carbon Dioxide Capture
Natural
Gas
Hard coal
plant
Lignite
plant
Economic life time years 25 25 25
Depreatiation years 25 25 25
Fuel price EUR/GJ (LHV) 5,8 2,3 1,1Fuel price escalation % per year 1,5% 1,5% 1,5%
Operating hours per year hours per year 7500 7500 7500
Standard Emission factor t/MWh th 0,210 0,344 0,402
Common Inputs
O&M cost escalation
Debt /Equitiy ratio %
Loan interest rate %
Interest during construction %
Return on Equity %
Tax rate %
WACC 8%Discount rate % 9,0%
6%
12%
35%
Financial and other
Boundary Conditions
50%
6%
2%
CoalReference
Unit
Unit with pre-
combustion capture
Unit with post-
Combustion capturexyfuel
Power output MW 556 737 460 470Efficiency % 46 36 36 36
CO2 capture % - 92 85 91
EPC Capital cost Euro/kW 918 1577 1446 1447
Lignite
MW 920 717 731 760% 43 41 39 41
% - 85 85 90
Euro/kW 1065 1556 1683 1671
Natural Gas
MW 420 755 662 325% 58 41 47 48
% - 93 85 100
Euro/kW 410 763 742 1124
Power output
Efficiency
CO2 capture
EPC Capital cost
Power outputEfficiency
CO2 capture
EPC Capital cost
Reference
Unit
Unit with pre-
combustion capture
Unit with post-
Combustion capture xyfuel
Reference
Unit
Unit with pre-
combustion capture
Unit with post-
Combustion capturexyfuel
CCS in the European energy market (1)
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Estimated electricity generation cost from largecoal, lignite and natural gas PPs in 2020, withoutand with CO2 capture
European Technology Platform, Zero Emission Fossil Fuel Power Plants (ZEP), Working Group 1,Power Plant and Carbon Dioxide Capture
Estimated CO2 capture cost from large coal, ligniteand natural gas PPs in 2020, without and with CO2capture
CCS in the European energy market (2)
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At the left of the point of intersection of the cost curves without and with CO2 capture,investment in CCS technologies becomes economically viable
CO2 pentalty (Euros/tn) Coal Lignite Natural gas
100 23.5 14.2 56.9
40 58.8 35.6 >100
Break-even point where CCS
technologies become viable
(% emmissions)
30
40
50
60
70
80
90100
110
120
130
0 10 20 30 40 50 60 70 80 90 100
% of emissions with 100 Euros/tn CO2 penaltyElect
ricitygenerationcost(Eu
ros/MWh)
Coal Unit
Coal Unit
with CO2capture
Lignite Unit
Lignite Unit
Natural gas
Unit
30
35
40
45
50
55
6065
70
75
80
0 10 20 30 40 50 60 70 80 90 100
% of emissions with 40 Euros/tn CO2 penalty
Electricitygenerationcost(E
uros/MWh)
with CO2capture
Natural gas
Unitwith CO2capture
Coal Unit
Coal Unit
with CO2capture
Lignite Unit
Lignite Unit
Natural gas
Unit
with CO2capture
Natural gas
Unitwith CO2capture
Electricity generation costs of large PPs with and without CO2 capture/with CO2 penalty in 2020
CCS in the European energy market (3)
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In order to demonstrate the potential of CO2 capture technologies for ligniteapplications, the simulation of a typical new 330 MWel Greek PP was performed,including the retrofit options of amine scrubbing and Oxyfuel fuel firing. The PP hasa supercritical boiler, a three pressure stage steam turbine and 8 regenerative feedwater preheaters.
ConventionalPP
OxyFuelAmine
Fuel Thermal Input MWth 830.0
Thermal Consumptionfor Solvent Regeneration
MWth - - 256.5
ASU Consumption MWel - 58.1 -
CO2 CompressionConsumption
MWel - 22.4 20.5
Cooling PumpsConsumption MWel - 1.5 0.7
Power Consumptionfrom Amine ScrubbingUnit
MWel - - 8.7
Net Power Output MWel 293.7 211.0 200.5
Efficiency % 35.74 25.42 24.16
CO2 Capture Retrofit in Greek PPs
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New 360 MWel Lignite PP with Oxyfuel combustion (typical Greek lignite)
Feedwaterheatin
g
LPH1toLPH3
Feedwaterheating
LPH1toLPH3
I1I2
G7
G10
G11
G3
A7
G4
A8
A2
Air leakage
Ash
Air leakage
A5
A6
A9A10
I1 I3I2 I4
I5
G5
G6
G8G9
G1
G2
Lignite Dryer Waste waterDriedlignite
F3
DCAC
ASU
Wet ESP FGCSeparation of non-
condensables
TEG
N2
tomolecular
shieves
ESP
A1 A3 A4
A11A
12
F1 F2
F
3
Rawlignite
F3
D1
D2
D3
D4 D5 D6 D7 D8 D9 D10
D11
D12
D13
D14
D15
G12G13
G14
G15
G16
G17
G18
G19
S1
S2
S3
S4S5
S6
S7
S8S9
S10
S11
S13
S12
S14
S15
S20
S16S17
S21
S22
S18
S19
S23
S24
S25
I6I7I8
Oxygen Flow
I3I4
G20 G21
G22
G23
Green-field PPs with CO2 capture
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The electricity generation cost has been assessed for the following technologies:
Conventional lignite PP
Conventional lignite PP with CO2 capture with amine scrubbing
Conventional lignite PP with CO2 capture with oxyfuel combustion
State of the art super-critical lignite PP (CCT)
Natural gas Combined Cycle (NGCC)
Lignite Integrated Gasification Combined Cycle (IGCC)
The general and case-specific assumptions for the calculations are the following:
Discount factor: 8%, Inflation: 3%
Lignite cost: 1.8 / GJ, Natural gas cost: 5.5 /GJ
Depreciation for Solid fuel units: 25 years, for NG and IGCC units: 15 years
O&M costs: 3% of capital costs per annually, variable cost 0.01 /kWh for a lignite
unit and 0.005 /kWh for a natural gas unit. 7500 h of operation per year at full load
CO2 market cost: 18 /tnConv.
lignite PP
Conventional
lignite PP with
amine scrubbing
Conventional
lignite oxyfuel PP
State of the art
super-critical
lignite PP
NGCC. IGCC
Net power output MWel 294 201 211 300 380 766
Efficiency % 35.7 24.2 25.4 44.0 56.5 43.0
Capital cost /kW 1100 1900 1570 1150 600 1370
Specific CO2 emissions kg/kWh 1.075 0.17 0.34 0.865 0.37 0.76
CCS in the Greek energy market (1)
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Fixed cost includes depreciation and O&M costs, variable cost includes fuel.
The units have been grouped in two categories: current technologies andtechnologies that will be commercially available in the future. The differencein specific emissions from the reference unit for each category multiplied bythe CO2 cost is an estimation of the price risk due to the emitted CO2.
Electricity generation costs
0
12
3
45
6
7
8
9
Conventional PP State of the artSupercritical PP
Natural gasCombined Cycle
cent/kWh
CO2 risk (vsNGCC)
Rick due to NGprice volatility
Variable cost
Fixed cost
Electricity generation costs
0
12
3
4
5
6
7
8
9
10
AminescrubbingOxyfuelState of theart Super-
critical PP
NGCC IGCC
cent/kW
hCO2 risk (vs(amine/oxyfuel)
Risk due toNG price
Variable cost
Fixed cost
Electricity generation costs for current
technologies
Electricity generation costs for future
technologies
CCS in the Greek energy market (2)
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Capture Transport Geological
Storage
Carbon dioxide storage options (1)
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Potential CO2 storage sites :
Oceans
Depleted oil and gas reservoirs
Deep unmineable coal seams
Deep saline aquifers.
Mineralization of CO2.
Carbon dioxide storage options (2)
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Carbon dioxide storage options (3)
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CO2 disposal methods in the oceans
Oceans
Carbon dioxide storage options (4)
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Depleted oil and gas reservoirs
Enhanced oil recovery with thehelp of CO2
Carbon dioxide storage options (5)
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Deep saline aquifers (>800m).
Carbon dioxide storage options (6)
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Examples of storage projects:
Sleipner, North Sea saline reservoir
In-Salah, Algeria gas reservoir
K12B, North Sea gas reservoir
Weyburn, Canada oil reservoir
Enhanced Coal Bed Methane projects
Alisson (New Mexico)
Recopol (Poland)
Carbon dioxide storage options (7)
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Locations of CO2 storage activities
Carbon dioxide storage options (8)
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Storage potential
The estimated range of the economic potential for CCS varies between 220-2200 GtCO2, which would mean that 15-55% of the world-wide mitigation effort by 2100could be achieved through the implementation of CCS.
Gton CO2 20501 Gton CO2
2
Depleted oil fields 126-400 150-700
Depleted gas fields 800 500-1100
Enhanced oil recovery 61-65
Unminable coal seams >15 >73
Saline aquifers 400-10,000 320-10,000
1Source: (IEA GHG, 2001)2Source: (Edmonds, 2000)
Carbon dioxide storage options (9)
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CO2 point sources in relation
with the sedimentary basinswith storage potential(Koukouzas et al., 2009 Int. J. of GHG
Carbon dioxide storage options (11)
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Prinos basin geological cross - section
Prinos basin stratigraphic column (Koukouzas et al., 2009 Int. J. of GHG)
Carbon dioxide storage options (12)
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Geological cross section of Mesohellenic Trough
Cap rock
CO2 potential storage site
(Koukouzas et al., 2009 Int. J. of GHG)
Carbon dioxide storage options (13)
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CO2 storage capacity in saline aquifers -Greece
Aquifer Position Storage capacity (Mt CO 2)
Prinos offshore 1343
W. Thessaloniki onshore 459
W. Thessaloniki
sandstone
onshore 145
Alexandria onshore 34
Mesohellenic basin onshore 360
Total 2345
(GESTCO PROJECT)
Carbon dioxide storage options (14)
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2323 SiOMCOCOMSiO ++
Mineral carbonation: reaction of CO2 with metal oxide bearing
materials to form insoluble carbonates, with calcium and magnesium
being the most attractive metals.
The general reaction is:
M: divalent ion. Here, M corresponds
to Ca or Mg
Carbon dioxide storage options (15)
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Pyroxenite
Dunite
Dunite
Hartzburgite
Hartzburgite
Carbon dioxide storage options (16)
In collaboration with
Los Alamos National
Laboratory
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