CCS: CATTURA E SEQUESTRO DELLA CO2: STATO ATTUALE E TECNOLOGIE · CCS: CATTURA E SEQUESTRO DELLA...

CCS: CATTURA E SEQUESTRO DELLA CO2:STATO ATTUALE E TECNOLOGIE

Cover image: Aerial view of Tomakomai CCS Demonstration carbon capture facilities located at Tomakomai City, Hokkaido, Japan. Image provided by JCCS.

Guido Magneschi

CARBON CAPTURE AND STORAGE

Reserves to production ratio:

~75 years

CONTENUTI:

1. Il ruolo della CCS

2. Stato dei progetti CCS

3. Tecnologie di cattura della CO2

Fossil fuel demand growing and reserves robust

Source: BP Statistical Review of World Energy 2017Source: IEA World Energy Outlook, 2016 (New policies scenario)

Fossil fuel proved reserves:

~7 trillion barrels of oil equivalent


~80 years[CELLRANGE]

[CELLRANGE][CELLRANGE]

13%

14%

19%

[CELLRANGE]

[CELLRANGE]

[CELLRANGE]

0

4000

8000

12000

16000

20000

1990 2014 2040

Primary Energy Demand by Fuel Source(million Tonnes of Oil Equivalent)

Nuclear Renewables Fossil Fuels

Solar and Wind

CCS is a vital element of a low-carbon energy future

Source: International Energy Agency (2017), Energy Technology Perspectives 2017, OECD/IEA, Paris

A transformation in how we generate and use energy is needed

0

10

20

30

40

50

2015

2020

2030

2040

2050

2060

Gt C

O2

em

issio

ns

Nuclear 6% CCS 14% Renewables 35% Efficiency 40% 2DS

2DS

Reference Scenario (current ambition)

31

Gt C

O2

Source: International Energy Agency (2017), Energy Technology Perspectives 2017, OECD/IEA, Paris

CCS contributes 14% of cumulative reductions through 2060 in a 2DS world compared to „current ambition‟ (Reference Scenario)

CCS is critical in a portfolio of low-carbon technologies

CCS is deployed more widely and more rapidly in

moving from 2DS to B2DS

International Energy Agency (2017), Energy Technology Perspectives 2017, OECD/IEA, Paris

2DS refers to a 2oC Scenario; B2DS refers to a Beyond 2oC Scenario, limiting average future temperature increases to 1.75°C

Light areas in the right graph represent cumulative emissions reductions in the 2DS, while dark areas represent additional

cumulative emissions reductions needed to achieve the B2DS

0

10

20

30

40

50

20

15

20

20

20

30

20

40

20

50

20

60

GtC

O2

2DS to B2DS

Renewables 15%

CCS 32%

Fuel switching 18%

Efficiency 34%

Nuclear 1%

2DS

B2DS

Reference Scenario ─ current ambition

0 100 200 300 400

GtCO2 cumulative reductions in 2060

Source:

Note:

Mitigation costs more than double in scenarios with

limited availability of CCS

*Percentage increase in total discounted mitigation costs (2015-2100) relative to default technology assumptions – median estimate

+ 7% + 6%

+ 64%

+ 138%

Baseline cost

with all mitigation

options utilized

Source: IPCC Fifth Assessment Synthesis Report, Summary for Policymakers, November 2014.

Cost increase under

limited technology

availability scenarios50

100

150

Perc

en

tag

e*

Nuclear phase out Limited solar/wind

Limited bioenergy

No CCS


~75 years

CONTENUTI:




A significant task within one generation

37 large-scale CCS facilities -

combined CO2 capture capacity

of approximately 65 Mtpa*:

• 21 facilities in operation or

construction (~37 Mtpa)

• 5 facilities in advanced

development (~11 Mtpa)

• 11 facilities in earlier stages of

development (~17 Mtpa)

OECDNon-OECD

~3,800 Mtpa of CO2 captured

and stored by 2040 (IEA 2DS)**

37 Mtpa

Global Status of CCS

November 2017

*Mtpa = million tonnes per annum

**Source: data sourced from International Energy Agency (2017), Energy Technology Perspectives 2017, OECD/IEA, Paris

Note: 2040 IEA 2DS data includes ~600 Mtpa “negative emissions” from BECCS

More facilities to be operational in 2018

7 8 8

12 1315 15

17 17

4

-

5

10

15

20

25

2010 2011 2012 2013 2014 2015 2016 2017 2018

Nu

mb

er

of

fac

ilit

ies

Facilities to enter operation Facilities in operation

Actual and expected operation dates up to 2022 for large-scale

CCS facilities by industry and storage type#

* Assessing CCS possibilities from ammonia production, from cement production and from waste-to-energy sources

# Facilities in the Operating, In construction and Advanced development stages


~75 years

Geographic distribution of operational facilities

CANCELLED CCS LARGE-SCALE FACILITIES IN EUROPE

Peterhead,

UKPower sector

(1.0 Mtpa)

Don

Valley, UKPower sector

(1.5 Mtpa)

ROAD, NLPower sector

(1.1 Mtpa)

Compostilla, ESPower sector

(1.3 Mtpa)

Porto Tolle, ITPower sector

(1 Mtpa)

Jänschwalde, D

EPower sector

(1.7 Mtpa)

Bełchatów, PLPower sector

(1.8 Mtpa)

White

Rose, UKPower sector

(2.0 Mtpa)

Ulcos

Florange, FRSteel production

(0.7 Mtpa)

Getica, ROPower sector

(1.5 Mtpa)

PLANNED CCS LARGE-SCALE FACILITIES IN EUROPE

Caledonia Clean

Energy, UKPower sector

(3.0 Mtpa)

Full chain CCS, NOVarious industrial

sources

(1.3 Mtpa)

Teesside

Collective, UKVarious industrial

sources

(0.8 Mtpa)

CO2

SAPLING, NL, NO

, UKCO2 pipelines &

shipping infrastructure

(PCI)

Teesside CO2

Hub, BE, GER, NL,

UKCO2 pipelines &

shipping infrastructure

(PCI)

Rotterdam

Nucleus, NL, UKCO2 pipelines

infrastructure

(PCI)

CO2 Cross Border

Transport

Connections

project, NL, NO, UKCO2 shipping

infrastructure to NCS

(PCI)

ERVIA,IrelandCCGTs + Refinery

(2.2 Mtpa)

Magnum project, NL Hydrogen (4.0 Mtpa)

PLANNED SMALL-SCALE CAPTURE PROJECTS IN EUROPE

Acorn, UKNatural gas

processing

(Full chain CCS)

CLEAG

Geothermal, HRPower sector

(1.5 Mtpa)

LEILAC, BECement production

(CO2 capture)

H21 Leeds City

Gate project , UKHydrogen

CEMCAP, EuropeCement production

(CO2 capture)

Cadent Liverpool-

Manchester

Hydrogen Cluster

project, UKHydrogen (0.73 Mtpa)

Green Hydrogen

project, NL Hydrogen

ECRA Cement

project, AU and ITCement industry

(Oxyfuel technology)


~75 years

CONTENUTI:




OVERVIEW OF CO2 CAPTURE SYSTEMS

Capture routes

for power

generation

Classified by application

POST-COMBUSTION SYSTEMS

Systems for the separation of CO2 from flue gases produced

by a combustion

State of art: chemical absorption with amine-based

solvents - Standard solvent is a solution of Mono Ethanol

Amine (MEA) 30-40%-wt in water

Several companies have produced proprietary amine based

solvent with improved performance and resistance but also

alternative solvents (e.g. amino-acid salts) for CO2 capture

purposes

Overall efficiency penalty* (in power plants):

PC plants 9-11%-points (20-25% less power output)

NGCC plants 8-10 %-points (15-20% less power output)

* Including CO2 compression to 110 bar

CHEMICAL ABSORPTION WITH AMINE-BASED

SOLVENTS

Flue GasLP Steam

Cooling Water

Electric Power

CO2

Condensate

N2/O

2

Source: Sintef

~130 °C

saturated

>95 % pure

90% captured

~40 °C

PC 12-14% CO2

NGCC 3-5% CO2

There are a few examples of large scale project using this technologies.

Main developers: Mitsubishi, Shell, Aker, Fluor

Petra Nova Carbon Capture

Operating since January 2017

Location: Texas, United States

Industry: Power generation

Capture Type: Post-combustion CO2 capture (1.4 Mtpa)

Storage: CO2-EOR in West Ranch oil field

Milestone: Over 1 million tonnes of CO2 captured.Source: NRG

CCS PROJECTS (POWER) USING AMINE ABSORPTION

Boundary Dam CCS

Operating since October 2014

Location: Saskatchewan, Canada

Industry: Power generation

Capture Type: Post-combustion CO2 capture (1.0 Mtpa)

Storage: CO2-EOR in Weyburn Oil Unit (and Aquistore)

Milestone: Over 1.5 million tonnes of CO2 captured.Source: SaskPower

PRE-COMBUSTION SYSTEMS

Systems for the separation of CO2 from H2 (before combustion)

Applied to Integrated Gasifier Combined Cycle (IGCC) or Hydrogen

production plants (15-60 %vol CO2)

State of art: chemical absorption with physical and chemical

solvents (commercially available processes)

chemical solvents: e.g. Methyl Diethanolamine (MDEA)

physical solvent: Rectisol and Selexol

mixtures of chemical and physical solvents are also possible

Overall efficiency penalty* in IGCC plants is 9-11 %-points (20-25%

less power output)

* Including CO2 compression to 110 bar

CO2 ABSORPTION BY PHYSICAL SOLVENTS

Example of application in IGCC

40 °C

48 bar 21 °C

1.7 bar

OXY-COMBUSTION SYSTEMS

Systems for the combustion of fuels in oxygen in order to produce a

near pure stream of CO2 ready for compression and transport

Applicable to any combustion processes but,

1. The boiler must be air leakages free,

2. Flue gas recirculation is required (to avoid high combustion T)N

2

Oxygen

Fuel

CO2 (+ H2O)OXY

COMBUSTION

Air

Air

Separation

Unit (ASU)


NEW

NEWNEW

EXISTING


Require only additional electric power (ASU), no heat (steam)

Do not use chemical solvents

Overall efficiency penalty* in coal fired power plants:

PC plants 7-10%-points (20-25% less power output)

NGCC plants 11-13 %-points (25-30% less power output)

Main Developers: Air Liquide, Air

Products, Praxair, Linde, Babcock&Wilcox, Doosan, Foster-

Wheeler, Alstom

No large scale project existing today with oxy-combustion

*including CO2 compression to 110 bar

SUPERCRITICAL CO2 GT (ALLAM CYCLE) OF

NET POWER

NET Power‟s Allam Cycle technology combines oxy-fuel combustion with a

supercritical CO2 turbine to generate power. Oxygen, produced using an Air

Separation Unit (ASU), is combined with fuel and high pressure CO2 in a

combustor and sent through a CO2 turbine where power is produced. CO2 and

water exit the turbine and go into a heat exchanger where the water is

condensed out and some of the CO2 is looped back to the combustor while the

rest exits the system through a high pressure CO2 pipeline

NET Power is completing construction of the first 50MWth demonstration plant in

Texas

Source: NET Power

CO2 CAPTURE IN INDUSTRIAL PROCESSES

Industrial

Sector

Process

(CO2 sources)

Estimated year of

maturity

Oil refining Fluid Catalytic Cracker (FCC)

Residues gasification

Hydrogen from Synthetic Gas Reforming (SGR) *

2020-30

2015-20

Currently mature

Hydrogen from fossil

fuels/biomass

Coal/Biomass Gasification

Steam Methane Reforming

Currently mature

Currently mature

Natural gas processing Gas sweetening * Currently mature

Liquid fuel Synthesis Fisher-Tropsch process * Currently mature

Bio-fuels synthesis Ethanol *

Bio-synthetic gas (digestion) *

Currently mature

Currently mature

Chemicals Ammonia * Currently mature

Iron & Steel Blast furnace

Direct Iron Reduction (DRI) *

2020-30

Currently mature

Cement Calcinator 2020-30

* Near pure CO2 streams are produced as part of the existing process

Different capture technologies can be used in each industry, some are the same

presented before, some are specifically developed for a certain industry (eg.

direct calciners for cement factories)

First-of-a-kind CCS costs in different industries

Source: Global CCS Institute (2017)

Relative US DOE cost reduction targets and timing for second

generation and transformational carbon capture technologies

Source: Fueling the Future: Safe, affordable, secure energy, Plasynski (2015)

Note: COE = Cost of Electricity

Promising innovative technologies under development

Technology/Developers Case Study Application Development TRL*

Oxy-combustion/Supercritical CO2 Power

Cycle

(Allam cycle)

NET PowerNew-build natural gas-fired power

generation

50 MWth demo (about 200 t/d CO2)

plant near completion

(Texas, US)

6-7

Chemical Looping Combustion

Babcock and Wilcox, Alstom, University of

Utah, Chalmers University

Babcock & WilcoxNew-build coal or gas fired power

generation

250 KWth (2 t/d CO2) pilot plant tested.

Now planning construction of a 10MWe

pilot (70 t/d CO2)

4-5

Fuel cell-facilitated capture Fuel Cell Energy

New-build or retrofit power

generation (post-combustion) and

industrial applications

Fuel Cells are commercial although no

specific CCS test done yet. Planning a 2.3

MWe pilot on both coal and gas-fired

flue gas in Alabama

3-4

Direct Separation Calciner (Flash

Calcination)CALIX

Cement production (calciner

emissions)

First pilot under construction as part of

the LEILAC project (BE).

150 t/d CO2 (240 t/d cement)

5-6

Metal Organic Frameworks (MOFs)

Multiple universities globally, MOF

Technologies

New-build or retrofit power

generation (post-combustion) and

industrial applications

Lab/bench scale testing 1-2

Sorption Enhanced Water Gas Shift

reaction (SEWGS)ECN

Pre-combsution at Integrated Coal

Gasification Combined Cycles (IGCC)

and blast furnaces gases at steel

production facilities

14 t/d pilot SWEGS unit is near operation

at Swerea MEFOS in Lulea (SE) as part of

the STEPWISE project

5-6

* The TRL is assigned basing on DOE definitions;

Conclusioni (1)

La CCS è una tecnologia necessaria per raggiungere gli accordi di Parigi.

Senza la CCS i costi aumentano del 140% e la probabilità di stare sotto i 2°C è

molto bassa (IPCC, IEA)

140 Gt/CO2 dovranno essere catturate da oggi al 2060 (IEA). Oggi sono

catturati circa 38 Mt per anno, con 17 progetti operativi.

Nel futuro la CCS su impianti industriali giocherà un ruolo critico, coprendo

circa il 50% del totale. Per alcune industrie la CCS è l‟unica vera soluzione

percorribile (vedi: cementifici)

La tecnologia CCS e‟ matura (anche per grossi volumi) ma non ancora

largamente applicata. Ci sono molte tecnologie a disposizione e la ricerca sta

continuando ad abbassare i costi (oggi tra 60 e 200 Euro/t)

Esistono sufficienti risorse per lo stoccaggio a livello mondiale, anche se certe

aree godono di migliore accesso rispetto ad altre.

Al livello politico mancano strumenti finanziari o incentivi che favoriscano lo

sviluppo di progetti. Il principali incentivi per progetti CCS sono l‟applicazioni di

EOR oppure la Carbon Tax.

Conclusioni (2)

In Europa ad oggi le nazioni che includono la CCS nei loro programmi di

decarbonizzazione, e quindi più attive nella promozione della CCS sono la

Norvegia, L‟Inghilterra e l‟Olanda.

Aree densamente industrializzate possono godere di infrastrutture condivise

per il trasporto e lo stoccaggio della CO2 (CCS clusters). La CCS è

particolarmente interessante per l‟industria del ferro, petrolifera e del cemento.

Si sta assistendo ad un ritorno d‟interesse verso l‟idrogeno come combustibile

pulito. In attesa che tecnologie per l‟idrogeno “rinnovabile” a basso costo siano

sviluppate, la produzione di idrogeno da gas naturale con CCS è oggi la

soluzione più economica.

C‟è grande interesso verso gli utilizzi della CO2 come materia riciclata (Carbon

Capture and Utilization, CCU), ma in molti casi gli utilizzi non garantiscono

l‟eliminazione della CO2 dall‟atmosfera in modo permanente.

The Global Status of CCS: 2017

http://www.globalccsinstitute.com/webform/gl

obal-status-ccs-2017

http://www.globalccsinstitute.com/webform/global-status-ccs-2017








www.globalccsinstitute.com

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