natural gas ccs networking meeting, may 30-31, london gas … · 2014. 4. 25. · natural gas ccs...

Technology for a better society

Natural Gas CCS Networking Meeting, May 30-31, London

1

Kristin Jordal BIGCCS/SINTEF Energy Research

Gas CCS in Europe

Sleipner gas sweetening/CCS project, storing ~1 Mtpa CO2 since 1996


• Anticipated large share of renewables in a future European energy system (solar, wind, biomass) • 32 GW solar power and 30 GW wind power

installed in Germany end of 2012 • Wind and solar power must be balanced by

large-scale reliable power production with rapid load response – e.g. natural gas (or hydropower)

• Natural gas has moderate installation cost, and moderate cost at part load, compared to coal and nuclear

• US LNG will reduce fuel cost for gas power

2

Integrating renewables in the European energy system


• The EU is committed to reducing GHG emissions to 80-95% below 1990 levels by 2050 • A 40% emissions reduction required by 2030 to be on track • Increasing role of electricity for transport as well as heating/cooling

• Required decarbonisation of the power system: 57-65% in 2030; 96-99% in 2050 • Gas will be critical for the transformation of the energy system – substitution of coal

and oil in the medium term (~2030-2035)

3

EU 2050 Energy roadmap


• For all fossil fuels, CCS will have to be applied from 2030 onwards

• Without CCS, the long-term role of gas may be limited to back-up and balancing renewable energy

• If commercialized, power generation with CCS will have to contribute with 19-32% of European power generation

• In all scenarios, the share of gas exceeds that of coal for power generation in 2050

4

The role of gas in the transition of the European energy system (EU 2050 Energy roadmap)

Reference scenario – Business as usual

Gas-fired installed capacity (GW)

Gas CCS capacity (GW)

% of gas capacity equipped with CCS

Coal-fired installed capacity (GW)

Coal CCS capacity (GW)

% of coal capacity equipped with CCS

226

37

16%

131

64

49%

EC 1bis – Current policies initiatives

366

6

2%

104

33

32%

EC 2 – High energy efficiency

187

121

65%

70

28

40%

EC 3 – Diversified supply technologies

218

142

65%

94

50

53%

EC 4 – High renewables

182

34

19%

62

18

29%

EC 5 – Delayed CCS

210

118

56%

73

30

41%

EC 6 – Low nuclear

255

169

66%

125

79

63%

Table by Green Alliance (www.green-alliance.org.uk) with EU 2050 Energy Roadmap data

http://www.green-alliance.org.uk/


• A flexible load follower is required to supplement the increasing share of renewables

• Gas is available in most of Europe, availability will increase with US LNG

• Currently planned gas plants are expected to double EU gas power capacity • Risk for locked-in carbon • Ideally, plant design should be capture-

ready • Multiple challenges for CCS realization

• Establish clear business case • Transport and storage of captured CO2

must be feasible - selection of CCS plant location crucial

5

The practicalities of gas CCS in Europe


• Source-sink matching, taking existing and planned gas power production into account

• "Go slow" is not a viable option for Europe to be en route to 2050 – renewed political engagement and policy actions are required

6

Green Alliance scenarios for gas CCS in Europe by 2030

Source: Green Alliance: The Practical potential for gas carbon capture and storage in Europe in 2030. (www.green-alliance.org.uk)

High gas Low gas

Level of potential Go slow Pragmatic Push Go slow Pragmatic Push

Capture unready

166 GW 64%

127 GW 49%

127 GW 135 GW 49% 73%

112 GW 61%

112 GW 61%

Capture ready, low feasibility for transport and storage

90 GW 35%

41 GW 16%

11 GW 47 GW 4% 26%

17 GW 9%

Technology for a better society 7

Gas power plants (CCGT) without CCS will be "high-carbon" by 2025 (IEA 2DS)

Gas suppliers could become drivers for introducing gas CCS and secure continued market for their product


Research on gas CCS in Europe


• The new EU framework for Research and Innovation (R&I) • Running from 2014-2020, budget 80 million€ • EERA and ZEP are providing input to Horizon 2020 in the field of CCS, including gas

CCS • EERA – the European Energy Research Alliance – open to all research institutions in

the EU, Switzerland and Norway • One of the SET-plan implementation mechanisms, together with the six European

Industrial Initiatives (EII) and the Fuel Cell and Hydrogen Joint Undertaking (FCH JU)

9

Horizon 2020

http://www.google.no/url?sa=i&rct=j&q=horizon+2020&source=images&cd=&cad=rja&docid=-soVrDutWIGNSM&tbnid=EKbRYVbPpb4ztM:&ved=0CAUQjRw&url=http://www.fp7-space.eu/news-135.phtm&ei=yyhuUe3RKsqN0AWDw4HgAw&bvm=bv.45368065,d.d2k&psig=AFQjCNHCxcInWH00iFDlZc5lhw5ibZIJvQ&ust=1366260267017036


EERA input to Horizon 2020

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w.ee

ra-s

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ZEP Recommendations for research on CO2 capture to support the deployment of CCS beyond 2020 in Europe

ZEP – The European Technology Platform for Zero Emission Fossil Fuel Power Plants • Founded in 2005 • Coalition of utilities, petroleum companies, equipment suppliers, scientists,

academics and environmental NGOs, who support CCS as a key technology for combating climate change

• Advisor to the European Commission on the research, demonstration and deployment of CCS


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Definitions and weighting factors for investment decision parameters employed to assess the impact of R&D topics on commercialized CO2 capture

Technology parameter

Weighting factor

Definition

Efficiency 2

Impact of the technology on the electric efficiency of the power plant.

CAPEX 2

Capital expenditures, i.e. impact of the technology on investment costs for the power plant.

O&M (excl.fuel)

1.5

Impact of the technology on operational and maintenance costs of the power plant, excluding fuel costs which are covered by the efficiency parameter. This can include costs incurred by e.g. solvent replacement or membrane replacement

Availability 1.5

Impact of the technology on the availability of the power plant. The availability of a power plant is the percentage of time over one year that the plant is capable of producing electricity, and includes both planned and unplanned stops.

Operability 1.5

Impact of the technology on the operability of the plant, i.e. on flexibility (acceptable steady-state operation over a range of conditions), controllability (ability to move to new steady-state set-points and to handle process disturbances), start-up/shutdown characteristics and ability to handle equipment failures in a safe manner.

HSE 1

Impact of the technology on health, safety and environment related to the power plant operation.

Capture rate 1

The fraction of the CO2 generated by the power plant that is actually captured. 90% CO2 capture is considered as the base case.


• Overall energy systems studies are necessary of power plants with CO2 capture operating as an integrated part in energy systems with a high share of renewables. This relates both to high requirements on load-following capabilities as well as to capturing CO2 from biofuels. CO2 transport and storage aspects should be included in such studies. Power plant availability and operability are also important elements.

• Attention should be given to the differences in design, when including CO2 capture, between base-load power and load followers.

• Investigations on how to integrate novel CO2 capture related technologies into power processes and other industrial processes is an important R&D topic.

• Support should be given to path-breaking concepts, with a potential to radically improve the performance of CCS.

• Support should be given to high-efficient retrofittable CO2 capture solutions to be able to address the urgent issue of locked-in carbon

• Enabling pilot scale testing is necessary for bringing technologies such as novel solvents, sorbents, membranes and CLC further on the road to demonstration.

13

ZEP - General recommendations for CO2 capture


• Post combustion • Continue research on Exhaust Gas Recirculation (EGR) as a means to increase CO2

concentration and reduce energy penalty for post-combustion capture from natural gas

• Oxy-combustion • For oxy-combustion in natural-gas based gas turbine processes, more R&D is

required to be able to determine whether this is a competitive option for natural gas.

• Pre-combustion • It is suggested not to focus research on the Integrated Reforming Combined Cycle

(IRCC) • Possibly, natural-gas based pre-combustion technologies should rather focus on

hydrogen production with CO2 capture • R&D on pre-combustion for coal (IGCC) should continue

14

ZEP - Recommendations for different capture routes related to natural gas + power production


BIGCCS activities on gas CCS

BIGCCS Vision International research centre for CCS as a climate mitigation measure


Duration: 8 years (5+3) Partners: 21 Budget: NOK 486 mill Funding: RCN: 50%, Ind.: 25%, Host: 25% Host inst.: SINTEF Energy Research Web: www.bigccs.no

BIGCCS Centre in a nutshell

Contact: BIGCCS Director, Dr. Mona J. Mølnvik BIGCCS Chairman, Dr. Nils Røkke

http://www.bigccs.no/http://www.geus.dk/index.htmhttp://www.google.com/imgres?imgurl=http://www2.imec.be/content/user/Image/GDF_20SUEZ_20logo.jpg&imgrefurl=http://www2.imec.be/be_en/press/imec-news/archive-2009/total-gdf-suez-and-photovoltech-join-imec-08217-s-silicon-solar-cell-research.html&h=916&w=2922&sz=276&tbnid=Ph22kItMzsTMBM:&tbnh=47&tbnw=150&prev=/images?q=gdf+suez+logo&usg=__IyWh_4M-rKi-fkvvo2d_hqTDC9g=&sa=X&ei=7iVpTP6IAcKMOKLf2LgF&ved=0CBsQ9QEwAQ


MEA + EGR + integrated reboiler improves efficiency

Post combustion capture from gas – research examples

17

Ca-looping with synthetic sorbents could approach 6% capture penalty


LP steam turbine for capture-ready NGCC – different design than for non-capture NGCC

• LPT exhaust should be chosen smaller for "CCS ready" NGCC than for standard NGCC

• Choice has to reflect the trade-off in performance between no capture and capture

• Part-load performance should also be taken into account when selecting exhaust dimensions

LP E

xit l

oss

LP outlet volumetric flow

No capture, full load

90% capture, full load

Collaboration SINTEF - Lund University within BIGCCS, To be presented at TCCS7

Technology for a better society 19 BIGCO2

BIGCCS Phase I

(2009-2011) BIGCCS Phase II

(20012-2013)

BIGCCS Phase III (20014-2016)

HIPR

OX

rese

arch

fa

cilit

y BIGCCS Phase IV

2017-

OXYG

T pr

ojec

t es

tabl

ished

Phase 1: Oxyfuel feasibility study Duration: 2 years (2012 – 2013) Budget: 16.5 MNOK Public/priv. ratio: High

Phase 2: OXYGT pilot plant phase Duration: 2,5 years (2014 – 2017) Budget: costs at site ~ 10 MNOK (estimate) Public/priv. ratio: Medium

Phase 3: OXYGT demonstration plant phase Duration: 3,5 years Budget: NA now Public/priv. ratio: Low

OXYGT Research partners: SINTEF, Lund University


• Natural gas sweetening with CCS (Sleipner, Snøhvit) • Hydrogen production through steam-methane reforming or autothermal reforming +

CCS • Hydrocarbon upgrading • Fuel cells (automotive/residential) • Fuel for combustion (ICE, refinery heaters…) • Methanol and ammonia production

• Aluminum production + power generation

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Opportunities for gas CCS in industry

Aluminum plant

Wet Scrubber

Gas t

urbi

ne

inle

t filt

er

Compressor

Com

bust

or

Turbine (power generation)


Wrap-up, gas CCS in Europe

• Natural gas is beneficial for integrating renewable energy in Europe - can provide large-scale balancing power

• Gas CCS has a role to play in the decarbonisation of European energy system

• Practical hurdles must be resolved: avoid locked in carbon, get access to transport and storage

• Political willingness, legal frameworks and project financing must be in place

• Gas CO2 capture routes: post combustion without or with EGR, oxyfuel

• BIGCCS is one of several research initiatives that can enable the realization of gas CCS in Europe

21


www.sintef.no www.bigccs.no

Thank you for your attention!

http://www.sintef.no/http://www.bigccs.no/


• Overall recommendation is to continue R&D on post-combustion capture

technologies for both coal and natural gas • Continue research on Exhaust Gas Recirculation (EGR) as a means to increase CO2

concentration and reduce energy penalty for post-combustion capture from natural gas

• Continue research on novel liquid solvents with reduced energy penalty, as well as on capture processes that utilise these solvents

• Continue research on solid sorbents due to the potential for reduced energy penalty compared to current liquid solvents. Investigate differences in operability and availability compared to liquid solvents • Interesting possible synergy effect between Calcium looping and cement industry

• Improved solvents, sorbents and membranes for post-combustion CO2 separation could improve HSE of post-combustion capture compared to current liquid solvents

23

Post-combustion CO2 capture from power plants


• R&D on oxy-combustion should continue for coal-fired power plants. The technology is feasible and can become competitive. Efforts should be address to mature this technology to make it more marketable and economically attractive.

• Continue R&D on advanced and flexible cryogenic ASU, as well as on oxygen separating membranes. The latter could prove to be an efficient technology alternative on a long term.

• Continue R&D on the oxyfuel boiler development and the overall oxyfuel process, including O2 mixing, flue gas treatment and cooling, and CO2 purification and compression.

• For oxy-combustion in natural-gas based gas turbine processes, more R&D is required to be able to determine whether this is a competitive option for natural gas.

• Continue R&D on Chemical Looping Combustion (CLC) due to possibility for high energy efficiency and possibly also high CO2 capture rate. Investigate whether operability and availability are acceptable.

24

Oxy-combustion CO2 capture from power plants


• Continue R&D on IGCC. IGCC, if implemented with modern technology, such as improved gasifiers and high-efficiency dry low NOx gas turbines, has a potential for high efficiency and can enable use of fuels of varying quality, including biomass.

• Innovations are important that make IGCC more attractive in a power market with significant load changes (e.g. flexibility in H2/electricity production ratio).

• Continue R&D on advanced and flexible cryogenic ASU as well as on oxygen separating membranes. The latter could prove to be an efficient technology alternative on a long term. It should be noted that optimization and integration of air separation technologies are different for IGCC than for oxyfuel.

• Continue R&D on novel shift catalysts (sweet and sour shift) to reduce IGCC cost and WGS steam consumption, as well as improvements in WGS reactor design

• Energy penalty for current liquid solvents for CO2 separation is low and technology is mature. Nevertheless, alternative technologies (sorbents, H2-separating membranes and low-temperature CO2 separation) have a potential for further efficiency improvements and should be supported for implementation on longer term.

25

Pre-combustion CO2 capture from power plants

Slide Number 1Slide Number 2Slide Number 3Slide Number 4Slide Number 5Slide Number 6Gas power plants (CCGT) without CCS will be "high-carbon" by 2025 (IEA 2DS) Slide Number 8Slide Number 9Slide Number 10Slide Number 11Slide Number 12Slide Number 13Slide Number 14Slide Number 15Slide Number 16Post combustion capture from gas – research examplesLP steam turbine for capture-ready NGCC – different design than for non-capture NGCC Slide Number 19Slide Number 20Wrap-up, gas CCS in EuropeSlide Number 22Slide Number 23Slide Number 24Slide Number 25

natural gas ccs networking meeting, may 30-31, london gas … · 2014. 4. 25. · natural gas ccs...

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