CO2 Storage Experience in Japan including Impacts of Earthquakes. Ziqiu Xue Research Institute of Innovative Tech.

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1 CO2 Storage Experience in Japan including Impacts of Earthquakes Ziqiu Xue Research Institute of Innovative Tech. for the Earth

2 Purpose of Nagaoka Pilot Project World CCS Sleipner(Norway, Aquifer, Associated CO2) Weyburn(Canada, EOR, Coal Gasification) ー Nagaoka Project ー 1st on-shore aquifer CO2 injection test (Verification of CO2 Storage in Complex Geology)

3 Site Selection Active gas field at Minami Nagaoka (INPEX Co.) 1100m Reservoir 5000m Gas production Geological Factors Continuity of cap rock Gentle tilted reservoir Depth( m), Thickness (>10m) No faults within 1.5km 2 Details data for subsurface Operational Factors Social Acceptance, Well yard etc.

4 Overview of the Nagaoka Site Well Configuration at the Reservoir Depth OB-4 Injec. Well Injec. Period; Jul. 2003~Jan m Obs. Well Total amount; 10,400 ton CO 2 40m Rate; 20~40 ton/day OB-2 120m IW-1 CO 2 Tank OB-3 Compressor Pump Lorry Reservoir; Haizume Formation (Pleistocene Sand) Injec. Layer; Zone 2, 12m-thick Porosity; 23% Permeability; ave. 7mD (Pump-test) Conditions; 48 o C, 11MPa

5 Reservoir Modelling & Simulation - Summing up all Knowledge of Injection Site - Based on seismic, logging, and core Reservoir (Haizume Formation) Injection point is Edge of Anticline Pre-Injection:Evaluate injection plan (Injectivity) (Reservoir model is build based on the seismic and well data) During Injection:History matching with pressure & logging data (Reservoir model is updated by the monitoring data) Post-Injection:Long-term prediction of CO2 distributions (Based on the accurate reservoir model considering with trapping mechanisms, long-term prediction is acceptable)

6 Detection of CO2 breakthrough by time-lapse logging OB-4 OB-3 OB-2

7 Sonic OB Vp changes 37th 14 th 16 th 18 th 20 th 22 nd 24th th 26 th 28 th 30 th 32 nd 34 th 36 th End of CO 2 injection (24 th ) Post-injection BL Average up to 13th 37th Vp: -23%

8 Neutron OB n changes 14 th 16 th 18 th 20 th 22 nd 24 th 26 th 28 th 30 th 32 nd 34 th 36 th End of CO 2 injection (24 th ) Post-injection BL 37th

9 Induction OB Resistivity changes 15 th 17 th 19 th 21 st 23 rd 25 th 27 th 29 th 31 st 33 rd 35 th 37 th 14 th 16 th 18 th 20 th 2224th nd th 26 th 28 th 30 th 32 nd 34 th 37th 36 Post-injection 37th BL End of CO 2 injection (24 th )

10 Vp (km/sec) (ohm-m) Time Series of Logging Data OB-2) Breakthrough Imbibition SCO 2 max. 63% SCO /01/ /01/ /01/ /01/ /01/01 CO 2 injection period Date

11 P-wave Velocity and Resistivity vs CO 2 saturation OB-2) Vp (km/sec) Vp 5yr 3yr (ohm-m) 1.5 2yr ρ CO 2 Saturation Joint monitoring is key to understand CO 2 behavior SCO 2 max. 63%

12 Time-lapse Tomography OB2 OB3 Section (160m) Injection Rate(t-CO 2 /day) Section 3Section BLS:Base Line MS1:After 3,200t MS2:After 6,200t Injection Period MS3:After 8,900t MS4:After 10,400t(End Injection) MS5:After 9 months Post-Injection Injection Rate:20~40 ton/day Total Injection:10,400 ton 2002/01/ /01/ /01/ /01/ /01/ /01/ /01/01 MS6:After 2year 9 months Cumulative Injection

13 Seismic Tomography

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16 Time lapse seismic tomography Post-Injection 10,400 t-co2 IW-1 (m) 900 Top of Reservoir BLS 1000 Velocity Change (%) 2.50 速度(km/sec) MS4 速度(km/sec) 10,400 t-co2 OB-3 OB Max. Velocity Change= -3.5% Velocity Change= (VMS4-VBLS) / VBLS

17 3D Reservoir Model k h = (k x k y ) -0.5,k y /k x = 1.2

18 Results of Reservoir Simulation CO2 Distribution at Terminating Injection OB-2 IW-1 OB-3 OB-4

19 Distribution of Injected CO2 (Comparison Reservoir simulation and Tomography) Simulation Results Ray paths : no travel time difference OB-3 OB-2 OB-3 OB-2 Garcia (2009)

20 Evolution of Reservoir Model by History Matching Reservoir Model CO2 Distribution Simulation History Matching Bottom hole pressure Reservoir pressure CO2 Breakthrough time Seismic tomography Accurate Reservoir Model Anisotropic Permeability Evolution of Reservoir Model

21 CHDT*(Cased Hole Dynamic Tester) Arm to fix Drill Fluid sampling from reservoir Geochemical Reactions 21

22 Formation Fluid Sampling at OB-2 (mmd) Injection Time since injection started (year) 1 st fluid sampling Post-injection Without CO 2 Free CO 2 Dissolved CO 2 Resistivity change 30 (%) nd fluid sampling 22

23 Successful measurement of dis-co 2 & ph under in-situ pressure condition Partial pressure at the reservoir depth m m m dis-co (mm) 4 7 ph@hp CO 2 (MPa) 23

24 Dissolution of Minerals m m m 0 10 Ca (mm) Mg (mm) Fe (mm) Si (mm) 4 Concentrations of Ca, Mg, Fe and Si in fluid sampled at m are much higher than other two depths. Neutralization of ph by mineral dissolution 24

25 Saturation Index (SI) of Calcite (CaCO 3 ) Dissolution Precipitation m m m Calcite shows a tendency of reprecipitate at m. Mineral trapping of CO2? SI(Calcite) 25

26 Nagaoka CO 2 Storage Project Workflow Commercialized CCS Pre-Injection Phase: 3-5 years - Site selection - Characterization -Design Injection Phase: years - Construction - Monitoring -CO 2 injection Post-Injection Phase: 100+ years - Ceasing injection - Decommissioning - Surveillance Nagaoka (pilot test site) (1.5 years) 10,400 Ton (2.5 years) (10 years) The First Case on Post-Injection Monitoring

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30 Main Shock: 2004/10/23 17:56 M6.8 地表地震計による地震波形 NS (gal) Vertical (gal) time (sec) time (sec) EW (gal) Max:705 gal

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33 Pilot scale, Large scale, Commercial scale (1) CO2 plume size (the reservoir scale vs CO2 plume size, reservoir heterogeneity, permeability anisotropy) formation pressure buildup (fracture pressure, micro-seismicity, geo-mechanical deformation, controlled injection) Alarm system according to magnitude and number of microseismic events. 33

34 Pilot scale, Large scale, Commercial scale (2) CO2 trap mechanism (field or lab data of residual CO2 saturation, CO2 dissolution, geo-chemical reaction) technical feasibility of CO2 monitoring (geo-physical and -chemical monitoring, quantitative evaluation of CO2) Same technology but Different geology, Different interpretation. No Silver Bullet! 34

35 Large-scale Demonstration: Offshore Tomakomai Capture Transportation Storage Tanase et al.,

36 Overview of the Tomakomai Project Tanase et al.,

37 Time Schedule for the Tomakomai Project Tanase et al.,

38 ACKNOWLEDGEMENTS This project is funded by Ministry of Economy, Trade and Industry (METI) of Japan under the research contract Development of Safety Assessment Technology for Carbone Dioxide Capture and Storage. We thank staff of ENAA, Teikoku Oil Co.(INPEX), Geophysical Surveying Co. OYO Co., and RITE involved in Nagaoka pilot CO 2 injection project. 38