Coal Use for Power into the Future and the need for Rapid Introduction of … S4FE Rom… · ·...

Coal Use for Power into the

Future and the need for Rapid

Introduction of CCS

“Sustainable Fossil Fuels for Future Energy”“Sustainable Fossil Fuels for Future Energy”

S4FE, Rome, 7 July 2009

Dr John Topper

Managing Director of IEA Clean Coal Centre

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

MEMBERS

Italy Japan

Rep. of Korea

UK

Spain

USAAustria

Canada

GermanyCEC

Australia

Poland


BHEL

Anglo Coal

ESKOM

Netherlands Group

BG Group

BRICC

Australia

CANZ

Eletrobras

DPG

SuekSIG

Schlumberger

Banpu

Arup

CONTENTS

• IEA’s Projections for Coal

• Coal Use Today

• Carbon Capture and Coal


10 000

12 000

14 000

16 000

18 000

Mto

e

Other renewables

Hydro

Nuclear

Biomass

World primary energy demand in the Reference

Scenario: this is unsustainable!this is unsustainable!IEA WEO 2008

0

2 000

4 000

6 000

8 000

10 000

1980 1990 2000 2010 2020 2030

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

Incremental primary energy demand in the

Reference Scenario, 2006-2030

IEA WEO 2008

Other Asia

E. Europe/Eurasia

Latin America

AfricaCoal

Oil

Gas

Nuclear

Hydro

Other

- 500 0 500 1 000 1 500 2 000

China

India

OECD

Middle East

Mtoe

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

The continuing importance of coal in world

primary energy demand

60%

80%

100%

All other fuels

Coal

Shares of incremental energy demand

Reference Scenario, 2006 - 2030Increase in primary demand, 2000 - 2007

Mto

e

600

700

800

900

1 000

4.8%% = average annual rate of growth

IEA WEO 2008

0%

20%

40%

Non-OECD OECD

Demand for coal has been growing faster than any other energy source & is projected to

account for more than a third of incremental global energy demand to 2030

0

100

200

300

400

500

600

Coal Oil Gas Renewables Nuclear

1.6%2.6%

2.2%

0.8%

The Reference Scenario:

World coal production

5 000

6 000

7 000

8 000

Mil

lio

n t

on

ne

s o

f co

al

eq

uiv

ale

nt

Brown coal and peat

Coking coal

Steam coal

IEA WEO 2008

Steam coal, used mainly in power generation, dominates the 60% growth in global coal

production in 2006-2030, its share of output rising from 77% to 81%

0

1 000

2 000

3 000

4 000

1990 2006 2015 2030

Mil

lio

n t

on

ne

s o

f co

al

eq

uiv

ale

nt


Net hard-coal exports

Latin America

OECD North America

Africa

Other Asia

Russia

OECD Oceania 2006

2030

IEA WEO 2008

-300 -200 -100 0 100 200 300 400

OECD Asia

India

OECD Europe

China

Middle East

Other E. Europe/Eurasia

Latin America

Million tonnes of coal equivalent

Trade in hard coal grows by 2% per year to 2030, reaching almost 980 Mtce,

with most of the growth in exports going to China & India

Source: Powerline, Feb 2008



World electricity generation

8 000

10 000

12 000

14 000

16 000

TW

h

Coal

Oil

Gas

Nuclear

Hydro

Biomass

IEA WEO 2008

0

2 000

4 000

6 000

8 000

2006 2030

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

Total power generation capacity today

and in 2030 by scenario

Hydro

Nuclear

Gas

Coal 1.2 x today

1.5 x today

2.1 x today

1.8 x today

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

Coal and gas with CCS

GW

13.5 x today

2.1 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) 545/581580

590

600

610

Max S

H S

team

Tem

pera

ture

, °C

⊗⊗⊗⊗Ultrasupercritical


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

1980 1985 1990 1995 2000 2005 2010

Year

Max S

H S

team

Tem

pera

ture

,

Supercritical

Locations for G8 case studies on Coal Plant

Genesee 3, Canada

Niederaussem K

Germany

Nordjylland 3

Denmark Wangqu, China

Younghung

S. Korea

Isogo New #1

Japan


Isogo New #1

Japan

Suratgarh, India

Majuba

South Africa

Natural gas fired

plant, Enfield, UK

Nordjylland 3, Denmark – highlights

• Most efficient coal-fired plant

• Operating net efficiency 47% LHV, power only mode/44.9%

HHV (not annual)

USC, tower boiler, tangential corner firing,

int. bituminous coals, cold sea water


HHV (not annual)

• High steam conditions 29 MPa/582°C/580°C/580°C 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

Niederaussem K, Germany – highlights

• Most efficient lignite-fired plant

• Operating net efficiency 43.2% LHV/37% HHV

• High steam conditions 27.5 MPa/580°C/600°C at turbine; initial

difficulties solved using 27% Cr materials in critical areas

USC, tower boiler, tangential wall firing,

lignite of 50-60% moisture, inland


difficulties solved using 27% Cr materials in critical areas

• Unique heat recovery arrangements with heat extraction to low

temperatures – complex feedwater circuit

• Low backpressure: 200 m cooling tower, 14.7°C condenser inlet

• Lignite drying demonstration plant being installed to process

25% of fuel feed to enable even higher efficiency

• NOx abatement Combustion measures


• Desulphurisation Wet FGD

Isogo New Unit 1, Japan – highlights

• Near zero conventional emissions (NOx 20 mg/m3, sulphur oxides 6

mg/m3, particulates 1 mg/m3, at 6% O2, dry); full waste utilisation

• Highest steam conditions: 25.0 MPa/600°C/610°C at turbine: ASME

USC, tower boiler, opposed wall firing, int

bitum and Japanese coals, warm sea water


• Highest steam conditions: 25.0 MPa/600°C/610°C 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 21°C CW, fewer FW heating stages

• Dry regenerable activated coke FGD (ReACT)

• NOx abatement Combustion measures and SCR


• Isogo New Unit 2 will use ReACT specifically for multi-pollutant

control, including mercury

Torrevaldaliga Nord – highlights

• 3 units at 660MWe = 1980MWe station

• Very low conventional emissions (NOx <100 mg/m3, sulphur oxides

<100 mg/m3, particulates 15 mg/m3, at 6% O , dry); full waste

USC, boilers supplied by Babcock Hitachi ,

using bituminous coal


<100 mg/m3, particulates 15 mg/m3, at 6% O2, dry); full waste

utilisation

• Highest steam conditions: 604°C/612°C at turbine: 25 MPa

• Operating net efficiency >44.7% LHV

• Wet scrubber based limestone/gypsum FGD

• NOx abatement SCR

• Particulates removal Bag filters

• New sea port for coal delivery

• Solids handling all enclosed

E On 50% efficient plant

… 50 plus by using new materials

Location

Efficiency

Capacity

Wilhelmshaven

50 %

500 MWe


Investment

Start of operation

1 billion €

2014

Size of plant Search for location

2007

Material developmentRequest for proposal

2010

ConstructionStart of operation

2014

Coal use in China, India and South Africa

Subcrit PCC

SC/USC PCC

FBC IGCC

China X X X X

India X (X) X X

South X (X)

Power generation: •Shanghai, 900 MW SC units

•Fuyang Huaren, 660 MW SC units


South

Africa

X (X)

Sipat power plant, India

Lagisza Supercritical CFBC – new design

• The world’s first CFBC

unit with supercritical

steam conditions

• Largest CFBC; 460 MWe

• Start-up in 2009


• Start-up in 2009

• Emissions of SOx, NOx

and particulates lower

than required by latest

EU LCPD limits.

• Located to NE of

Katowice, Poland

Carbon Capture


Carbon capture and storage

CaptureTransport

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


CaptureTransport

Storage

Vattenfall’s 30 MWth oxy fuel carbon capture

unit

Italian CCS activities – Oxy-fuel combustion –

CCS2, Brindisi

Pilot plant• Pressurised oxy-fuel technology

• Test programme (3 and 5 MWth

test facilities)

Demonstration plant

ENEL-Livorno

Demonstration plant

• Full scale combustor(48 MWth) combustion tests at

Brindisi

• Commercial operations 2011

• Data used for 35-70 MWe PCC-based

zero emissions oxy-coal power plant

(2012)

Courtesy ENEL

ITEA –Gioia del Colle

Brindisidemo

China’s 1st Post Combustion CO2 Capture Pilot Plant

The design parameters

are:

� Flue gas flow to unit

2000-3000 Nm3/h

� Steam consumption


� Steam consumption

3GJ/tonne CO2

� Solvent consumption <

1.35 kg/tonne CO2

� Owners: Huaneng

� CSIRO assisted

Italian CCS activities

Post-combustion CO2 capture – CCS1, Brindisi

Pilot plant• MEA scrubber

• 2.5 t/h CO2 (5 kt/y) capture• Completed December 2008

• Startup 2009• 4 year programme

• ENI will inject CO2 (24 kt total)

into depleted Stogit gas field

Demo plant

• Retrofit of SC PCC unit at Porto

Tolle• CO2 storage (up to 1 Mt/y) from

2015

• Deep saline aquifer beneath

North Adriatic Sea• Detailed feasibility underway

Courtesy ENEL

Development of IGCC by RWE Power

RWE Power will develop a zero-CO2 lignite-fired IGCC in

Germany


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 2009, generating 250MWe, expanding to 650

megawatts in later phases.

THE END

Thank you for Listening

[email protected]

+44 20 8780 2111


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