The Case for Coal Future Demand; Best Practice; CCS

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

[email protected]

www.iea-coal.org.uk

© IEA Clean Coal Centre www.iea-coal.org.uk

mailto:[email protected]



http://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

http://www.theodora.com/wfb/south_africa/south_africa_maps.html

http://www.theodora.com/wfb/south_africa/south_africa_maps.html

http://www.theodora.com/wfb/russia/russia_maps.html

http://www.theodora.com/maps/china_map.html

http://www.theodora.com/maps/france_map.html

http://en.wikipedia.org/wiki/Image:Flag_of_Poland_(normative).svg

Coal Demand , Best Practice Today, and CCS

• IEA’s Projections for Coal

• Best Practice in Power Plant use

• Carbon Capture for Coal


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



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


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


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


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



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


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


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


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


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

[email protected]

www.iea-coal.org.uk








SOME EXTRA SLIDES



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

Documents

The Case for Coal Future Demand; Best Practice; CCS