the case for coal future demand; best practice;...
TRANSCRIPT
The Case for Coal – Future
Demand; Best Practice; CCS
Policy Options for Energy Security and Sustainable
Development
Leon, Mexico, 6 October 2009
Dr John Topper
Managing Director of IEA Clean Coal Centre
www.iea-coal.org.uk
© IEA Clean Coal Centre www.iea-coal.org.uk
© IEA Clean Coal Centre www.iea-coal.org.uk
IEA Clean Coal Centre
MEMBERS
Italy Japan
Rep. of
Korea
UK
Spain
BHEL
Anglo Coal
USA
ESKOM
Netherlands Group
BG Group
Austria
Canada
GermanyCEC
BRICC
Australia
CANZ
Eletrobras
DPG
SuekSIG
Schlumberger
Banpu
Poland
Arup
Coal Demand , Best Practice Today, and CCS
• IEA’s Projections for Coal
• Best Practice in Power Plant use
• Carbon Capture for Coal
© IEA Clean Coal Centre www.iea-coal.org.uk
0
2 000
4 000
6 000
8 000
10 000
12 000
14 000
16 000
18 000
1980 1990 2000 2010 2020 2030
Mto
e
Other renewables
Hydro
Nuclear
Biomass
Gas
Coal
Oil
World energy demand expands by 45% between now and 2030 – an average rate of increase of 1.6% per year – with coal accounting for more than a third of the overall rise
World primary energy demand in the Reference
Scenario: this is unsustainable!
IEA WEO 2008
Incremental primary energy demand in the
Reference Scenario, 2006-2030
IEA WEO 2008
- 500 0 500 1 000 1 500 2 000
China
India
OECD
Middle East
Other Asia
E. Europe/Eurasia
Latin America
Africa
Mtoe
Coal
Oil
Gas
Nuclear
Hydro
Other
The increase in China’s energy demand to 2030 – the result of its sheer market size & stronger economic growth prospects – dwarfs that of all other countries & regions
Size of coal-fired fleet
Source: IEA Clean Coal Center and China Electricity Council[Data 2008 unless specified otherwise]
The Reference Scenario:
World electricity generation
0
2 000
4 000
6 000
8 000
10 000
12 000
14 000
16 000
2006 2030
TWh
Coal
Oil
Gas
Nuclear
Hydro
Biomass
Wind
Rest of renewables
The shares of coal & renewables in the power-generation fuel mix increase to 2030 – mainly at the expense of natural gas & nuclear power
IEA WEO 2008
Total power generation capacity today
and in 2030 by scenario
In the 450 Policy Scenario, the power sector undergoes a dramatic change – with CCS, renewables and nuclear each playing a crucial role
0 1 000 2 000 3 000
Other renewables
Wind
Hydro
Nuclear
Coal and gas with CCS
Gas
Coal
GW
1.2 x today
1.5 x today
13.5 x today
2.1 x today
1.8 x today
12.5 x today
15% of today’s coal & gas capacity
Today Reference Scenario 2030 450 Policy Scenario 2030
Global View of Coal Use Today
© IEA Clean Coal Centre www.iea-coal.org.uk
© IEA Clean Coal Centre www.iea-coal.org.uk
Recent Plant State-of-the-Art Conditions
G8 Case study plantsStudstrup (DK) 540/540
Maatsura 1 (J) 538/566
Esbjerg (DK) 560/560
Schwarze Pumpe (D) 547/565
Maatsura 2 (J) 593/593
Haramachi 2 (J) 600/600
Nordjylland (DK) 580/580/580
Boxberg (D) 545/581
Tachibanawan 1 (J) 600/610
Avedore (DK) 580/600
Niederaussem (D) 580/600
Hekinan (J) 568/593
Isogo (J) 600/610
Torrevaldaliga (I) 600/610
Hitachinaka (J) 600/600
Huyan (China)
Genesee 3 580/570
Yunghung 566/576
530
540
550
560
570
580
590
600
610
1980 1985 1990 1995 2000 2005 2010
Year
Ma
x S
H S
tea
m T
em
pe
ratu
re, °C
Ultrasupercritical
Supercritical
© IEA Clean Coal Centre www.iea-coal.org.uk
Nordjylland 3, Denmark – highlights
• Most efficient coal-fired plant
• Operating net efficiency 47% LHV, power only mode/44.9%
HHV (not annual)
• High steam conditions 29 MPa/582C/580C/580C at boiler by
early use of new materials (P91)
• Large number of feedwater heating stages
• Double reheat has prevented LP blade erosion
• Very low emissions and full waste utilisation
• NOx abatement Combustion measures and SCR
• Particulates removal ESP
• Desulphurisation Wet FGD
USC, tower boiler, tangential corner firing,
int. bituminous coals, cold sea water
© IEA Clean Coal Centre www.iea-coal.org.uk
Isogo New Unit 1, Japan – highlights
• Near zero conventional emissions (NOx 20 mg/m3, sulphur oxides 6
mg/m3, particulates 1 mg/m
3, at 6% O
2, dry); full waste utilisation
• Highest steam conditions: 25.0 MPa/600C/610C at turbine: ASME
CC 2328 steels in S/H; P122 for main steam pipework
• Operating net efficiency >42% LHV/40.6% HHV
• Efficiency tempered slightly by 21C CW, fewer FW heating stages
• Dry regenerable activated coke FGD (ReACT)
• NOx abatement Combustion measures and SCR
• Particulates removal ESP
• Isogo New Unit 2 will use ReACT specifically for multi-pollutant
control, including mercury
USC, tower boiler, opposed wall firing, int
bitum and Japanese coals, warm sea water
© IEA Clean Coal Centre www.iea-coal.org.uk
E On 50% efficient plant
… 50 plus by using new materials
Location
Efficiency
Capacity
Investment
Start of operation
Wilhelmshaven
50 %
500 MWe
1 billion €
2014
Size of plant
Search for location
2007
Material development
Request for proposal
2010
Construction
Start of operation
2014
• 750MWe
(net) unit
• 3938 psig / 1081 0F / 1077
0F
• BMCR steam flow 5,484,600 lbs/hr
• Sub-bituminous and high sulfur bituminous
coal
• Specific attention to combustion flexibility
and avoidance of furnace wall corrosion
• Boiler island scope includes pulverizers, fans,
airheater, SCR, low NOx
burners
• NOx
0.04 lb/mmBtu
• Designed for ease of construction
• End user E.ON - US
• Doosan Babcock Energy customer Bechtel
• Contract Awarded May 2006
• In service 2010
LG&E, Trimble County 2, Kentucky, USA
adapted from VGB 2007; efficiency – HHV,net
Average worldwide
~28.4%
~1110 gCO2/kWh
~36%
~880 gCO2/kWh
EU average
~42%
~740 gCO2/kWh
State-of-the artPC/IGCC
CCS
<2020
~48%
~665 gCO2/kWh
Advanced R&D
but deep cuts only by
CO2 emission reduction by key technologies
gC
O2
/kW
h
Energy Efficiency makes big change but deep cuts of CO2 emission can be done only by Carbon Capture and Storage (CCS)
Carbon Capture
© IEA Clean Coal Centre www.iea-coal.org.uk
© IEA Clean Coal Centre www.iea-coal.org.uk
Carbon capture and storage
CaptureTransport
Storage
Three Options;
• Post-combustion
• Pre-combustion
• Oxyfuel Two Options;
• Pipelines
• Ships
Three Options;
• Coal seams, 40 Gt CO2
• Oil and gas fields, 1,000
Gt CO2
• Deep saline aquifers – up
to 10,000 Gt CO2
Vattenfall’s 30 MWth oxy fuel carbon capture
unit
© IEA Clean Coal Centre www.iea-coal.org.uk
China’s 1st
Post Combustion CO2 Capture Pilot Plant
The design parameters
are:
Flue gas flow to unit
2000-3000 Nm3/h
Steam consumption
3GJ/tonne CO2
Solvent consumption <
1.35 kg/tonne CO2
Owners: Huaneng
CSIRO assisted
© IEA Clean Coal Centre www.iea-coal.org.uk
OECD roadmapping – PCC
2015-2017: 500 MWe 700°C PCC demo in Europe should be supplemented with other demos. Sidestream CO2
capture needed
2017-2020: 700°C plants should be offered commercially, supported by continuing materials dev/testing
Full-flow CO2
scrubbing demo should be designed on a 700°C plant for this period and oxy-coal material tests should be
conducted at these steam temperatures
Demonstration of 700°C technology with oxy-firing would follow in 2020-2025, commercialisation later
Current position (2009)
2009-2015
2015-2017
2017-2020
2020-2025
2025-2030
Post-2030
COMMERCIAL USC TO
25-30 MPa/600°C/620°C
46% NET, LHV, BITUM
COALS, INLAND, EU,
EVAP TOWER COOLING,
(44%, HHV).
ON HIGH MOISTURE
LIGNITE 43% NET, LHV,
SIMILAR CONDITIONS
(37%, HHV)
COMMERCIAL USC TO
25-30 MPa/600°C/620°C
COMMERCIAL USC TO
25-30 MPa/600°C/620°C
R&D, PILOT TESTS
Materials, cycles
CO2 capture
700°C DEMOS
R&D materials
Side-stream CCS
FULL FLOW CCS
DEMOS ON USC
600°C PLANTS
COMMERCIAL USC TO
35 MPa/700°C/720°C
ADVANCED FULL
FLOW CCS DEMOS
(scrubbing only for
700°C technology)
R&D
Materials
Novel post-comb
Oxy-coal materials 700°C
COMMERCIAL CCS USC
TO 35 MPa/700°C/720°C
(scrubbing only for 700°C
technology)
COMMERCIAL OXY-
COAL USC TO
30 MPa/600°C/620°C
OXY-COAL CCS
DEMO 700°C
TECHNOLOGY
COMMERCIAL CCS USC
TO 35 MPa/700°C/720°C
RANGE OF CAPTURE
SYSTEMS
COMMERCIAL CCS USC
ROUTINELY BEYOND
35MPa/700°C/720°C
ALL CAPTURE SYSTEMS
ALL COALS, ALL FIRING
CONFIGURATIONS
45%+ NET, LHV, INC CO2
CAPTURE, ALL COALS >700°C/720°C
DEMOS, ALL WITH
CCS, VARIOUS
TYPES
R&D materials
R&D
Oxy-coal materials
700°C
Emissions on bitum coals:
Particulates 5-10 mg/m3
SO2 <20 mg/m3
NOx 50-100 mg/m3
dry systems can give lower
emissions
Emissions on all coals:
Particulates 1 mg/m3
SO2 10 mg/m3
NOx 10 mg/m3
90% mercury removal
Near-zero emissions all
coals:
Particulates <1 mg/m3
SO2 <10 mg/m3
NOx <10 mg/m3
99% mercury removal
90% CO2 capture
Full environmental controls
at at least 2009 state-of-the-
art emissions
© IEA Clean Coal Centre www.iea-coal.org.uk
Development of IGCC by RWE Power
RWE Power will develop a zero-CO2
lignite-fired IGCC in
Germany
Plant will be commissioned with CO2
transport and storage
if market and regulatory conditions are appropriate
– Capacity: 450 MWgross, 360 MWnet
– Net efficiency (target): 40%
– CO2 storage: 2.6 million tonnes per year in depleted
Gas reservoir or saline aquifer
– Commissioning: 2014
Green Gen – The first Chinese IGCC
© IEA Clean Coal Centre www.iea-coal.org.uk
Near Tiajin, southeast of Beijing. The first phase of GreenGen is
expected on line in 2011, generating 250MWe, expanding to 650
megawatts in later phases.
THE END
Thank you for Listening
www.iea-coal.org.uk
© IEA Clean Coal Centre www.iea-coal.org.uk
SOME EXTRA SLIDES
© IEA Clean Coal Centre www.iea-coal.org.uk
© IEA Clean Coal Centre www.iea-coal.org.uk
Lagisza Supercritical CFBC – new design
• The world’s first CFBC
unit with supercritical
steam conditions
• Largest CFBC; 460 MWe
• Start-up in 2009
• Emissions of SOx, NOx
and particulates lower
than required by latest
EU LCPD limits.
• Located to NE of
Katowice, Poland
Geological Storage Options
Note: CO2 Storage capacity at cost of 20 US $ per tonne of CO2
Deep Saline Aquifers
400-10 000 Gt CO2Able to store 20 - 530 Years of 2030
Emissions
Depleted Oil & Gas Fields
930 Gt CO2Able to Store 50 Years of 2030
Emissions
Unminable Coal Seams
30 Gt CO2Able to store <2 Years of 2030
Emissions
Largest CO2 Storage Projects
Sleipner
capturing and
injecting 1Mt/y
CO2 since 1996
Weyburn
capturing and
injecting 1.6 Mt/y
CO2 since 2000In-Salah capturing and injecting
0.8 Mt/y CO2 since 2004
Snohvit capturing
and injecting 0.7Mt/y
CO2 since 2008
Rangeley
injecting
0.8 Mt/y CO2
since 1980’s
Total Anthropogenic CO2 captured
and injected currently 5 Mt/y
Utsira Fm.
Sleipner CO2 injection 1994
2001
2008
2008-1994
CO2 plume in map view
Time-lapse seismic data
How Does the CO2 Stay Underground?
• Structural Trapping
– CO2 moves upwards and is physically trapped under the seals
• Residual storage
– CO2 becomes stuck between the pore spaces of the rock as it moves through the reservoir
• Dissolution
– CO2 dissolves in the formation water
• Mineralisation
– The CO2 can react with minerals in the rock forming new minerals
Mineral trapping of CO2
Residual trapping of CO2
Dissolution of CO2