Overview of the Nagaoka Pilot Project Storing CO 2 in Saline Aquifer Ziqiu Xue (xue@rite.or.jp) Research Institute of Innovative Tech. for the Earth
Purpose of Nagaoka Pilot Project World CCS Projects （＠２０００） ・ Sleipner （ Norway, Aquifer, Associated CO 2 ） ・ Weyburn （ Canada, EOR, Coal Gasification ） ー Nagaoka Project ー 1st on-shore aquifer CO 2 injection test （ Verification of CO 2 Storage in Complex Geology)
Nagaoka CO 2 Storage Project Workflow Nagaoka (pilot test site) Commercialized CCS Pre-Injection Phase: 3-5 years 2000.12 - Site selection - Characterization - Design (2.5 years) Injection Phase: 10-50 years - Construction - Monitoring - CO 2 injection 2003.7 (1.5 years) 10,400 Ton Post-Injection Phase: 100+ years - Ceasing injection 2005.1 - Decommissioning (10 years) - Surveillance 2015.3 The First Case on Post-Injection Monitoring
Overview and Objectives of the Project - A Pilot-scale Demonstration - Improved Understanding of the CO 2 Movement in the Porous Sandstone Reservoir ► Seismic Wave Velocity Response to CO 2 Injection ► Mechanism for the Injected CO 2 Displacing the Formation Water ► Crosswell Seismic Tomography and Well Logging ► Measurements of the Formation Pressure Buildup ► 3D Surface Seismic Survey ► a simulator for the long-term behavior predication ► system studies on modeling and public outreach
Site Selection Active gas field at Minami Nagaoka Geological Factors (INPEX Co.) ・ Continuity of cap rock ・ Gentle tilted reservoir ・ Depth （ 800-1200m ） , ・ Thickness （ >10m ） ・ No faults within 1.5km 2 1100m ・ Details data for subsurface Reservoir Operational Factors Social Acceptance, Well yard etc. 5000m Gas production
Overview of the Nagaoka Site Well Configuration at the Reservoir Depth • Injec. Period; Jul. 2003~Jan. 2005 OB-4 Injec. Well • Total amount; 10,400 ton CO 2 Obs. Well 60m • Rate; 20~40 ton/day 40m OB-2 IW-1 120m CO 2 Tank OB-3 Compressor Lorry Pump • Reservoir; Haizume Formation (Pleistocene Sand) • Injec. Layer; Zone 2, 12m-thick • Porosity; 23% • Permeability; ave. 7mD (Pump-test) • Conditions; 48 o C, 11MPa
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 ）
Detection of CO 2 breakthrough by time-lapse logging OB-4 OB-3 OB-2
Sonic Logging @ OB-2 Vp changes -1.0 0.5 37th 24th 14 th 16 th 18 th 20 th 22 nd 24 th 26 th 28 th 30 th 32 nd 34 th 36 th 14 th Post-injection End of CO 2 injection (24 th ) BL Average up to 13th 37th Vp: -23%
Neutron Logging @ OB-2 f n changes -0.15 0.05 14 th 16 th 18 th 20 th 22 nd 24 th 26 th 28 th 30 th 32 nd 34 th 36 th Post-injection End of CO 2 injection (24 th ) BL 37th
Induction Logging @ OB-2 Resistivity changes -0.5 1.5 15 th 17 th 19 th 21 st 23 rd 25 th 27 th 29 th 31 st 33 rd 35 th 37 th 37th 24th 14 th 16 th 18 th 20 th 22 nd 24 th 26 th 28 th 30 th 32 nd 34 th 36 th Post-injection 37th BL End of CO 2 injection (24 th )
Time Series of Logging Data (1116.0m @ OB-2) Breakthrough Imbibition 3 Vp (km/sec) 2 1 7 (ohm-m) 6 5 4 S CO 2 max. 63% 0.8 S CO 2 0.4 0.0 2003/01/01 2005/01/01 2007/01/01 2009/01/01 2011/01/01 Date CO 2 injection period
P-wave Velocity and Resistivity vs CO 2 saturation (1116.0m @ OB-2) 3.0 3.0 6.5 2.5 2.5 6.0 5yr 3yr Vp Vp (km/sec) Vp (km/sec) (ohm-m) 2.0 2.0 5.5 2yr 1.5 1.5 5.0 Joint monitoring is key to ρ understand CO 2 behavior. 1.0 1.0 4.5 0.0 0.2 0.4 0.6 0.8 0.0 0.2 0.4 0.6 0.8 S CO 2 max. 63% CO 2 Saturation CO 2 Saturation
Time-lapse Tomography OB2 – OB3 Section (160m) Elapsed Time (day) -500 0 500 1000 1500 BLS:Base Line MS1:After 3,200t MS2 ： After 6,200t MS3 ： After 8,900t MS4 ： After 10,400t(End Injection) 1Section MS5 ： After 9 months MS6 ： After 2year 3Section Injection Period 9 months Post-Injection Injection Rate(t-CO 2 /day) Cumulative Injection 40 200 Injection Rate ： 20~40 ton/day 20 100 Total Injection ： 10,400 ton 0 0 2002/01/01 2003/01/01 2004/01/01 2005/01/01 2006/01/01 2007/01/01 2008/01/01
Seismic Tomography
Time – lapse seismic tomography Post-Injection ： 10,400 t-CO 2 IW-1 (m) 900 Top of Reservoir 3.30 1000 2.85 BLS Velocity Change 2.50 (%) 速度 (km/sec) 1100 0 - 1 - 2 1200 - 3 - 4 - 5 OB-3 OB-2 - 10 3.30 2.85 Max. Velocity Change= -3.5% MS4 2.50 速度 (km/sec) 10,400 t-CO 2 Velocity Change= (V MS4 -V BLS ) / V BLS
3D Reservoir Model k h = (k x ·k y ) -0.5 , k y /k x = 1.2
Results of Reservoir Simulation CO 2 Distribution at Terminating Injection OB-2 IW-1 OB-3 OB-4
Distribution of Injected CO 2 （ Comparison Reservoir simulation and Tomography ） Ray paths : no travel time difference Simulation Results OB-3 OB-2 OB-3 OB-2 Garcia (2009)
Evolution of Reservoir Model by History Matching Reservoir Model CO 2 Distribution Simulation History Matching ・ CO2 Breakthrough time ・ Bottom hole pressure ・ Seismic tomography ・ Reservoir pressure Accurate Reservoir Model Evolution of Reservoir Anisotropic Permeability Model
Resistivity Changes with Time @ OB-2 Geochemical monitoring: Fluid sampling by Cased Hole Dynamics Tester Delta from 1108 the base CHDT @ 1108.6 m line data 0.8 CO 2 Migration Depth (mMD) 0.4 CHDT @ 1114.0 m 0 ohm-m -0.4 CHDT @ 1118.0 m CO 2 Breakthrough 1120 0 1600 Elapsed time from 7 July 2003 (day) CO 2 injection Post-injection
- , Ca, Mg and Fe @1118m Increased: HCO 3
Injection History and Formation Pressure Elapsed Time from 7 July 2003 (day) 0 500 1000 1500 2000 2500 13 Driving force of CO 2 at post-injection phase : Pressure (MPa) Buoyancy due to density difference 12 between CO 2 and formation water OB-4 11 Cumulative amount (t-CO 2 ) Cumulative amount Injection Rate Injection rate (t-CO 2 /day) IW-1 (t-CO 2 /day) 40 20000 (t-CO 2 /day) Rate; 20~40 ton/day 20 10000 Total; 10,400 ton 0 0 2003/01/01 2005/01/01 2007/01/01 2009/01/01 2011/01/01 Date
Residual CO 2 trapping is happening at Nagaoka? (Juanes et al., 2006)
Residual CO 2 at the down-dip in the reservoir (1116.0m @ OB-2) Injection Post-injection 0.8 S CO 2 0.4 Sgr(max) ~20% 0.0 2003/01/01 2005/01/01 2007/01/01 2009/01/01 2011/01/01 Date
Main Shock: 2004/10/23 17:56 M6.8 time (sec) 地表地震計による地震波形 0 5 10 15 20 25 30 35 40 45 50 time (sec) 800.0 600.0 400.0 200.0 NS 0.0 - 200.0 (gal) - 400.0 - 600.0 - 800.0 0 5 10 15 20 25 30 35 40 45 50 800.0 600.0 400.0 200.0 Vertical 0.0 - 200.0 (gal) - 400.0 - 600.0 - 800.0 0 5 10 15 20 25 30 35 40 45 50 800.0 600.0 400.0 200.0 EW 0.0 - 200.0 (gal) - 400.0 - 600.0 - 800.0 Max ： 705 gal
Liquid CO 2 Tank Diameter: 3.8 m Height : 18 m No Damages !
Injection Well Observation Wells
CO 2 Pipeline
After the Earthquake (Oct. 25, 2004) Near the Observation Wells
Nagaoka pilot test: targets and results Primary targets Major results Investigation for the 10,400 t-CO 2 was successfully injected at rate of 20-40t-CO 2 /day into a saline aquifer of 1,100 m depth possibility of Any CO 2 leakage sign by the earthquakes didn't be CO 2 geological storage in complex stratum, Japan detected ＋ Measurement of temperature and pressure at top and Study on the underground bottom of the reservoir formation Micro-seismicity measurement behavior of injected CO 2 Time-lapse Well logging and fluid sampling Time-lapse Cross-well seismic tomography ＋ CO 2 behavior was simulated with history matching Modeling of CO 2 behavior using monitoring results Safety assessment of CO 2 Basic knowledge of aquifer storage in Japan is obtained. Test results are utilized for the development of safety injected underground assessment and storage potential evaluation.
Acknowledgements • This project is funded by Ministry of Economy, Trade and Industry (METI) of Japan. • We appreciate staff of ENAA, INPEX Co., Geophysical Surveying Co. Ltd., OYO Co., GERD and RITE involved in the Nagaoka pilot CO 2 injection project.
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