Current Situation Of Post and CCS - IEAGHG€¦ · (Well drilling, Seismic method) CategoryA...
Transcript of Current Situation Of Post and CCS - IEAGHG€¦ · (Well drilling, Seismic method) CategoryA...
Japan Coal Energy CenterJCOAL
Current SituationOf
Japan’s Post Combustion Capture and CCS
Terufumi Kawasaki, Michiaki Harada
Japan Coal Energy Center
September 8 & 9, 2015
PCCC3 in Regina1
Japan Coal Energy CenterJCOAL
Contents
JCOAL’s role
1. Japan’s Energy Post Fukushima
2. Government Policies
3. Situation of CO2 Capture Technology Development
4. Some Topics on the latest development
5. Summary
PCCC3 in Regina2
Japan Coal Energy CenterJCOALJCOAL’s Role
International AgenciesIEA, WCA, GCCSI, etc.
Coal Producing CountriesCoal Using Countries
coal mining, oil & gas, utilities, steel industry, heavy industry, electric‐machinery, engineering, trading, etc
Industries : 117 Member Companies
The Ministry of Economy, Trade and Industry
Japan Coal Energy Center ( JCOAL), originally established as a coal research center in 1948, has supported Japan’s important policies and business activities related to Coal and Energy.
Government of Japan
● Information Collection & Sharing and Advisory Activities● Coal Resources Development● Clean Coal Technology Development● Technology Transfer to Overseas● Public Relations and Human Resources Development
JCOAL as “One‐stop organization for coal‐related business”
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Japan Coal Energy CenterJCOAL 4
1. Japan’s Energy Post Fukushima
Japan Coal Energy CenterJCOAL1.1 Japan’s Energy Post Fukushima
One nuclear power unit, out of 44, was restarted in August, 2015
Several new coal‐fired plants are planned (8.75GW)
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A number of solar projects can been seen around the country.
Modification from oil‐fired to coal‐fired (1.0 GW)
A new IGCC plant(1.0 GW)
A new coal‐fired plant(2.0 GW)
A new coal‐fired plant(0.65 GW)
A new coal‐fired plant(0.6 GW)
A new coal‐fired plant(1.3 GW)
A new coal‐fired plant(1.2 GW)
A new coal‐fired plant(1.0 GW)
quoted from materials of METI’s consultation meeting, held on July 27 in 2015, on framework mitigating global warming .
Japan Coal Energy CenterJCOAL1.2 Drastic Change in Power Supply
Total power supply decreased by 9 %. All Nuclear Power plants were not operated in 2014.
44 units, 39.9 GW in totalThermal power generation has been making up the lack of power generation.
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2005 2010 2011 2012 2013 2014
Total Power Generation [TWh]
0%
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20%
30%
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100%
2005 2010 2011 2012 2013 2014
Ratio of Power Source [%]
Post Fukushima
quoted from materials of the Federation of Electric Power Companies of Japan, issued in May 2015
Geothermalrenewable
Hydro
OilCoalLNGNuclear
0%
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20%
30%
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2010 2011 2012 2013 2014 2030
Ratio of Power Source [%]
Geo/Renew
Hydro
Nuclear
LNG
Coal
Oil
Japan Coal Energy CenterJCOAL1.3 Expected Target of Power Supply in 2030
The government has shown the target of power supply ratio in 2030. ●renewable : 22 to 24 % , double of that before Fukushima● Nuclear : 20 to 22 % , about two thirds● LNG : 27 % , almost the same level● Coal : 26 % , ditto● Oil : 3 % , ditto
Uncertainty(1) Public acceptance of
nuclear power plants(2) Appropriate operation of
FIT for renewable energy(3) Structural changes
‐ Separation of power productionfrom distribution
‐ Electricity liberalization
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quoted from materials of METI’s committee on energy, held in July in 2015.
Geothermalrenewable
Hydro
OilCoalLNGNuclear
Japan Coal Energy CenterJCOAL1.4 Target of CO2 Reduction in 2030
Power Sector expressed
Reduction of 35 %from 2013 level(Aug. 2015)
Level year 1990 2005 2013
JAPAN 26%
EU‐28 40% (24%)
USA 26 to 28% (18% to 21%)
Russia 25 to 30% (4% to 12%)
(1) Targets of GHG emission reduction by 2030 (proposed to UN in 2015)
(2) CO2 emission in the power industry in Japan
Total Emission Reduction of 26% from 2013 level, reported in June, 2015
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0.00
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2005 2010 2011 2012 2013 2030
CO2 Emission [Million ton / year]
Others
LNG
Coal
Oil
quoted from materials of the Federation of Electric Power Companies of Japan, issued in July 2015
quoted from materials of a MOE’s committee on environment, issued in April 2015
OilCoalLNGothers
Japan Coal Energy CenterJCOAL 9
2. Government Policies
Japan Coal Energy CenterJCOAL2.1 Government’s Policies
Basic policies on Coal‐related Energy :
● Develop coal‐fired thermal power plants with much‐higher‐efficiency● Accelerate cost reduction of CO2 capture technology and CCUS ● Develop new technology to utilize low rank coal● Contribute to global emission reduction of CO2
by supplying high efficiency coal‐fired power generation technology
Basic policies on CCS:
● Conduct a demonstration test of CCS in Tomakomai● Continue intensive geological surveys of storage areas on sea bed ● Initiate distinctive CCS plans which are suitable for countries like Japan
ex. Shuttle ship Initiative
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quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
Japan Coal Energy CenterJCOAL2.2 Road Map toward Higher Efficiency
Higher efficiency means less emission of CO2.Practical and steady improvement of efficiency is strongly supported by the government.
IGCC
Advanced USC
IGCCIn 1700℃ level
IGFCIncl. Fuel Cell Efficiency (HHV) : 55 %
CO2 Emission : 590 g/kWhDevelopment year : 2025
Efficiency (HHV) : 46 %CO2 Emission : 710 g/kWhDevelopment year : 2016
Advanced IGFC
Efficiency (HHV) : 46~50 %CO2 Emission : 650 g/kWhDevelopment year : 2020
Efficiency (HHV) : 40 %CO2 Emission : 820 g/kWh
USCOsaki Cool Gen Project
started in 2013
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quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
2015 2020 2030
Capture Cost : 30 US$/t‐CO2
Japan Coal Energy CenterJCOAL2.3 Road Map toward CCS Cost Down
The government strongly supports cost down of capture technology to accelerate its commercialization.Oxy‐fuel combustion
Physical absorption for IGCCSolid absorber for A‐USC
separation membrane for IGCC
203020202015
Capture Cost : 10 US$/t‐CO2Development year : 2025
Amine‐base solvent
Capture Cost : 40 US$/t‐CO2
Capture Cost : 20 US$/t‐CO2Development year : 2020
Chemical Loop Combustion
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CO2‐circulated type of IGCC
quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
Japan Coal Energy CenterJCOAL2.4 CCS Demonstration Site in Japan
Tomakomai cityTokyo
CO2 Source CO2 Capture Transportation Storage Site
Refinery plant Chemical absorption(PSA)
none Saline layers under Sea Bed(Structured/non‐structured)
Storage site
Injection well Capacity Monitoring Schedule
Two1,200 m deep3,000 m deep
100,000ton/year
Elastic wave methodThree observance wells
2016 : injection & monitoring2018 : end of injection2020 : end of monitoring
3 km
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quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
Observation well OB‐3
CO2 Capture Site
3D elastic wave inspection area
Seismometer
Injection Well
Observation well OB‐2
Observation well OB‐1
Gas supply site
Japan Coal Energy CenterJCOAL2.5 CCS Demonstration Site in Japan 14
quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
2.6 Storage Survey on offshore areas by RITE Japan Coal Energy CenterJCOAL
3. Storage Survey (possible storage areas) around Japan By RITE
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( quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015 )
No.Geology Data
(Well drilling, Seismic method)Category A
(anticline structure)Category B
(Layer position trap)
1Existingoil & gas field
Plenty of both data A1 3.5
B1 27.5(aqueous gas field)
2 Basic test drilling area
Some of both data A2 5.2
3Basic physical survey area
Data only by seismic wave A3 21.4 B2 88.5
(16 sea bed areas)
4 Possible storage capacity (A1+A2+A3+B1+B2) 146.1 Billion ton
(1) Survey in 2012 : shallower than 200meters
(2) Survey in 2016‐2020Further survey continues for offshore areas deeper than 200meters
In the depth from 800 m to 4,000 m,except basin, inland sea, Osaka Bay and Ise Bay
Japan Coal Energy CenterJCOAL 16
3. Situation of CO2 Capture Technology Development
Japan Coal Energy CenterJCOAL3.1 Situation of Chemical absorption
No.
Tech. Status Product Organization Project/Capacity
Perf. Cost targetPrivate gov.
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Amine solvent
Demo. KS‐1 MHIKEPCO
NRG Energy (US)1 M ton/annum
2.3 GJ/ton
US$40
H3‐1 MHPS TEPCO
SaskPower(Canada)0.1 M ton/annum
TS‐1 Toshiba Mikawa in Japan0.01 M ton/annum
RITE‐6 RITE
2Solid absorber
Dev. Porous media carrying amine
RITE Lab test 1.5 GJ/ton
US$30
KHI Lab test
MHI : Mitsubishi Heavy Industry, MHPS: Mitsubishi Hitachi Power Systems, KHI : Kawasaki Heavy Industries, TEPCO : Tokyo Electric Power Company, KEPCO : Kansai Electric Power Company, RITE : Research Institute of Innovative Technology for the Earth,
(a) Japan’s utilities and companies have developed the technologies since 1990.(b) The government supports and puts emphasis on reducing their costs.
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Japan Coal Energy CenterJCOAL3.2 Demonstration Projects of Chemical absorption
1 Place Houston, Texas, USA
2 Company NRG WA Palish power station
3 Exhaust gas Coal‐fired
4 Solvent KS‐1
4 CO2 capture 4776 ton/day
5 CO2 capture rate 90 %
6 Commissioning end of 2016
MHI’s Technology
MHPS’s Technology
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1 Place Saskatchewan, Canada
2 Company SaskPower Shand power station
3 Exhaust gas Coal‐fired
4 Solvent H3‐1
4 CO2 capture 300 ton/day
5 CO2 capture rate 90 %
6 Commissioning end of 2015
Cooling tower CO2 Compressor
Regenerator
absorber
Gas cooler
Exhaust duct
boiler
Test facility
Japan Coal Energy CenterJCOAL3.3 development of Solid Absorber
RITE’s idea : Porous media carrying amine solvent could minimize heat loss due to its smaller heat capacity, keeping absorption performance of CO2.
Basic Development (2010 to 2015)
Joint project of RITE and companiesBench‐scale test with a capacity of 5 ton‐CO2/daySlip Stream test with about 50 ton‐CO2/day
Commercialization Development (2015 to 2020)
A new type of amine has been developed.Lab. Tests showedHigh regeneration rate : 95 % Low regeneration temp. : 60 to 70 ℃
Simulation studies indicatedmuch less separation energy : 1.5 GJ/ ton‐CO2low capture cost : 20 to 30 US$ / ton‐CO2
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Lab. Test rig
Bench scale Test rig (5 ton/day)
quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
Japan Coal Energy CenterJCOAL3.4 Situation of Oxy‐fuel Combustion
No.Tech. Status Organization Project/
CapacityCost targetPrivate gov.
1Oxy‐fuelCombustion
Demo. IHI,JPOWER,Mitsui & Co
JCOAL Callide (Australia)0.15 M ton/annum
US$ 30
IHI : IHI Corporation, JPOWER : Japan Electric Power Company,
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(a) Japan’s utilities and companies have developed the technology since 1990s.(b) Japan and Australia have cooperated for a demonstration project since 2004.(c) The project has completed this year.
Joint Venture(AU$ 24.5 Million)
IHI
JPOWER
CS Energy
GLENCORE
SchlumbergerMITSUI&CO.
‐ JapaneseGovernment
‐ AustralianGovernment
‐ QueenslandGovernment
‐ JCOAL
Financial support
Technical support
quoted from materials of JCOAL’s Work Shop on CCT in 2015
3.5 Oxy‐Fuel Combustion Tests in Callide
Coal‐fired Power Plant in Callide
Storage Site in Australia
CO2 Capture
CO2 Storage
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Japan Coal Energy CenterJCOAL
1 Place Queensland, Australia
2 Company & Site CS Energy Callide A power station
3 Power 30 MWe
4 Exhaust gas Coal‐fired
4 Air Separation 330 ton/day x 2 for oxygen
5 CO2 capture 75 ton/day
6 CO2 purification 99.9 %
7 Operation 2012 to 2015
1 Place Victoria, Australia
2 Organization CO2CRCOtway Project Site
3 layer saline
4 depth 1,400 meters
5 Operation 2014 to 2015
6 Monitoring 2014 to 2016quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
Japan Coal Energy CenterJCOAL3.6 Situation of IGCC and CO2 Capture
No. Project Operation Cap. Remarks
1Joban PowerNakoso station 10
2000 demo. 2013 Commercialized
250 MWe ‐ Efficiency of 42.9 % (LHV)‐ The world longest continuous operation of 3917 hours
2 Joban PowerNakoso station xx
2020 540MWe ‐ Planned as Fukushima bailout projects
3Tokyo Electric Co.Hirono station xx
2020 540MWe ‐ Planned as Fukushima bailoutprojects
IGCC (Air‐blown)
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quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
Nakoso Power Station No. 10
AIR
N2O2
coal gasifierfilter
char
AIR
compressorair separator
syn gas
<Flows of an air‐blown gasifier>HironoPower station
Japan Coal Energy CenterJCOAL3.6 Situation of IGCC and CO2 Capture
No.Project Operation Capacity
PressureCO2
CaptureRemarks
1
EAGLE(gasification test
plant)
2008 to 2014 1,000 Nm3/h (150 t‐coal/day) 2.5MPa
24 t/day ‐ The world’s first CO2 capture fromsyn gas of IGCC in 2008
‐ Results show:Chem. Absorption: 1.4 GJ/ CO2‐tonPhysical Absorption: 0.4 GJ/ CO2‐ton
2 Osaki Cool Gen.(IGCC + CCS)
Under construction2016 : IGCC2020 : CCS2023 : Fuel Cell
170 M We2.5 MPa
400 t/day(planed)
‐ CO2 capture for 15% of exhaust gaswith Physical absorption (planned)
IGCC (Oxygen‐blown) + CCS
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quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
GasificationPurification
Power Generation
Air separation
Gasification
Physical absorption unit
Chemical absorption unit
EAGLE Plant Osaki Cool Gen
Japan Coal Energy CenterJCOAL3.7 development of Separation membrane
RITE’s idea : A gate type of membrane could maximize separation of CO2.
Basic Development (2010 to 2015)
Further Development (2016 to 2020)
‐ A new type of amine, a polyamide amine dendrimer,has been developed, which showedCO2 permeation rate : 10 ‐9 to 10 ‐10 [m3(STP) m‐2 S‐1 Pa‐1]Selective permeability : 30 to 700 [for CO2 / H2]
‐ Simulation studies indicatedmuch less separation energy : 0.5 [ GJ/ton‐CO2]lower cost : 15 [ US$/ton‐CO2]
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quoted from materials of METI’s consultation meeting, held on June 16 & 22 in 2015, on thermal power technology development.
Research Organization and Governmental Support
‐ Established a research cooperative, consisting of several companies and RITE‐ Financial support by the government
A CO2 separation module(4‐inch‐long proto‐type)
Demonstration tests will be planned, designed and performed.
Japan Coal Energy CenterJCOAL 25
4. Some Topics of the latest development
Japan Coal Energy CenterJCOAL4.1 Topics 1 : Shuttle Ship initiative
(a) This concept originated as a two‐year Global CCS Institute project in 2011.
(b) The Japanese government has been actively supporting the plan since FY2014.It could help accelerate the CCS implementationin Japan.
Background
Concept of Shuttle ships
(a) Relatively small shuttle ships (3000 tons) go back and forth between power stations along the coast and offshore storage sites.
(b) Installing injection facility on shuttle ships, offshore facilities would not be necessary.
length width Weight CO2 tank CO2 Pump equipment
119.5 m 19.0 m 3000 tons 750 m3 x 4 180 kW Dynamic Positioning System, Pickup coupling device, Loading arms
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quoted from a report on CCS issued by the Ministry of Environment in 2014
Spec. of Shuttle ships
Power stations
Storage sites
The Latest design of ship
Japan Coal Energy CenterJCOAL4.2 Topics 1 : Shuttle Ship initiative
≪CO2 Carrier≫
Satellite
Communication buoy
Pick up buoy
Pick up float
(Sheer mount)Coupler winch
Riser end fittingBend stiffener
Sinker
Flexible riser + Umbilical cable
Pipe protector AnchorBend restrictor
Christmas tree
Signal & Battery charging wire
Mooring wire
Tele communication
Battery
Messenger linePick uprope
Pick up wire
Transponder
(a) This system highly extendable, allowing flexible applications for multiple capture and storage sites at low cost.
(b) Setting up a number of offshore storage site expands the potential of CO2 storage, making CCS a viable option in other countries as well.
Conceptual design of CO2 injection by shuttle ships
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quoted from a report on CCS issued by the Ministry of Environment in 2014
<Objectives>
<Period> October, 2014 ~ June, 2015<Contractors> IHI Corporation / J-POWER / JCOAL / MITSUI & CO., LTD.
They are financially supported by a governmental R&D organization, NEDO.
A new feasibility study on CCUS has been made for an existing coal-fired power plant in Alberta,
where an oxy-fuel combustion system, which includes air separationfacilities, could have an economical advantage by supplying nitrogento oil & gas sites, as well as carbon dioxide to EOR sites.
A further study is expected to start to make a conceptual design this year.
Chemical Plants(inert gas)
Oil & Gas Sites(N2 fracturing)
CO2CO2Oxy-fuel Combustion
Power Plants
CO2-EOR Site
N2N2
(Air Separation Units)
quoted from materials of NEDO’s Reports in 2014
28Japan Coal Energy CenterJCOAL4.3 Topics 2 : Advanced Oxy‐fuel Combustion Project
Japan Coal Energy CenterJCOAL5. Summary
Japan’s situation post Fukushima : Serious and critical in power generation and CO2 emission reduction
The target of GHG emission reduction in 2030 : 26 % decrease from the 2013 level, showing a strong intention to contribute to mitigating global warming.
Japan’s large‐scale CCS demonstration Test : ‐‐‐ Tomakomai Projectwill start CO2 injection into saline layers under the seabed in 2016.
Clean Coal Technology and CCS‐related technology :(1) development of power plants with much higher efficiency
ex. A‐USC, IGCC and IGFC(2) emphasis on cost reduction of CO2 capture technology
ex. solid absorber for chemical absorption,separation membrane for IGCC
New approaches to CO2 emission reduction : implementation of feasible studies on possible ideas
ex. Shuttle Ship Initiative, advanced oxy‐fuel combustion system●renewable : 22 to 24 % , double of that of before Fukushima
N l 20 22 % b hi d
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