Japan-Asia CCUS Forum 2020
Part 2 Toward deployment of CCS in Japan
Oct. 6, 2020
13：00～14：30
Roppongi Grand Conference Center

Cost of CCS- Current & Future Trends Takao Nakagaki

E-mail to: takao.nakagaki@waseda.jp

1

CCS: Process & cost structure
Retrofittable: Concentrated emission source•Thermal power generation•Iron and steel making
CO2 capture•Cement production>99% purity
OPEX
CAPEX
OPEX
CAPEX

5300\/t-CO230,000 t class shipping
e.g.: 0.7MPa, -50℃, 500km

Existing CO2 capture plants (Low Hanging Fruits)•Domestic natural gas production•Ammonia production

4000~2600*\/t-CO2

Pipeline(100㎞)
構造/層位トラッピング
Capture Hub

CaptureOPEX

400\/t-CO2（on the ground）• Cooling/Compression/ •Port improvement
Liquification facilities •Temporary retention tankTransport• Loading facility
OPEX CAPEX
Reference:
METI CCS official report (RITE, 2020)

Mooring & Receiving rig
Unloading facility
Storage/
Temporary retention tank
Monitoring
Conditioning facility
OPEX CAPEX-20ys～Feasex & FEED～ 0～Operation～30ys ～Decommission & Monitoring～80ys
2/5>Gt-scale Storage hub
2019 JCCS
Government supervision/
Feasible sites surveillanceCommission to company
6 sites >10Gt
1000*\/t-CO2 Monitoring equipment

Centurial plan

*1 Mt scale estimation based on Tomakomai（JCCS official report）

Cost down of capture technologies
Different emission source
Different suitable technology

Green innovation strategy committee
July 2020

Cyclical ABS-RGN reactors: OPEX reduction due to RGN energy
Membrane reactors: CAPEX reduction for scale-up (e.g., module manufacturing)

CO2 capture cost (\/t-CO2)

6000 Progress in amine scrubbing after pre-treatment gas from industrial process
Commercial (ready)
Other conventional technologies  Conventional chemical solvents 4,000\/t-CO2
Refinery, Natural gas/Ammonia production
KM-CDR TS ISOL etc.
hot potassium carbonate
 Chemical solvents
Chilled ammonia
Physical absorption: Selexol
Verification of CCS application with conventional technology
4000

Retrofit to post-combustion
Amine scrubbing: High TRL
1,000\/t-CO2: Feasible?

Progress in new R&D and demonstration

Adsorption: ASCOA Coal-fired power, Gavage combustion stations: Chemical solvents
 BFG: Physical adsorption, Chemical/Physical absorption
 Coal-fired power station: Solid sorbents <3,000\/t-CO2 BFG: Membrane <2,000\/t-CO2 Solid sorbent: KCC

JCCS Tomakomai: Result summary
2000 50%-CO (H /CH ) PSA off-gas 25,000Nm3/h2 2499% recovery by activated MDEA, purity=99.7%
9.3MPa(1000m)/22.8MPa(3000m) 25t/h injection rate
Pressure swing (flash) regeneration + 2-stage absorption
No observation of oxidative degradation
0 Regeneration energy = 1.2GJ/t-CO2 1 Mt-scale = 2600\/t-CO2
1980
1990
2000
2010
2020

year

Solvent-Membrane hybrid

Progress in implementation of new technologies
and deployment~1,000\/t-CO2IGCC / Reforming gas
Oxyfuel / Pre-combustion removal
2030

2040

2050~

DAC: granted by “Moonshot” program

3/5

Thermal PP: Additional modification for regeneration heat source
USC-PCPP, 300MW, 90%Capture
Replacing LP Turbine, High-pressure deaerator…

−92％

Shand CCS FEEDInternational CCS Knowledge Centre

LCOC=$45/t-CO2
50% Capital
31% Power loss

Relative reduction against
Boundary dam
−67％

−73％

GCCSI Global status of CCS 2019

\4,000

4/5

Shipping cost of liquefied CO2
Legal CO2 purity > 98%(H2 separation)
EU recommendation:
O2, CH4 < 4%*
N2+Ar+H2 < 4%
Others: ~ppm
*EOR requires lower
concentration

Shipping process (357 Mt-CO2/year, 500 km)

600MW-USC
357 Mt-CO2/year
0.2 MPa 40 oC

0CO2 conditioning
after unloading
7.38MPa 31 ℃

0.7 MPa, -50 oC
CO2(1150 kg/m3)

Temporary
retention tanks a)

Other
CAPEX

Chiller cost

Repairing/ TAX

Liquificationelectric power

1000

Injection

2 ships, Burden 30,000t(18knots=33.34 km/h)
One way ≈15h
0.7MPa, -50 oC

Liquification d)Capacity 20,000t ×3(2 Reserve tanks)
ShipCAPEXTransport b)

CO2 capture

2000

3000Unloading

Loading

Loading time=13h(Preparation=5h)

CO2 mass flow
58h=165 kg/s
(Preparation=8h)

Mooring:
SALMa) Not include countermeasures for CO2 leakageb) Not include periodical legal inspection (biannually for 2 Weeks)c) CO2 conditioning in ship and on sited) Electricity does not include avoided CO2 by CCS

Fuel cost
CO2 cond.
electricpower
4000

In-ship CO2 conditioning c)

50005236 [\/t-CO2]

Depreciation period:• Ship + CO2 conditioning → 15 years• Other → 30 years

Liquification power cost:
2241[\/t-CO2] >40% share5/5