CO 2 Saturation and Movement during Post-Injection Period

Transcription

1 CO 2 Saturation and Movement during Post-Injection Period Nagaoka Project, Japan Tsukasa Yoshimura 1), Koji Kano 1), Jiro Watanabe 2), Hiroyuki Azuma 3),Daiji Tanase 4),Ziqiu Xue 5),Saeko Mito 6) 1: Engineering Advancement Association of Japan (ENAA) 2: Geophysical Surveying Co., Ltd. 3: Oyo Corporation 4: J-Power 5: RITE (Present:Kyoto University) 6: RITE 4th MEETING of the MONITORING NETWORK November 7-9, 2007

2 Discussion Points CO2 saturation occurred at Patchy condition? Resistively and Porosity become decreasing one year after stopping injection of CO2, not velocity. Why and How?

3 Contents Review of Nagaoka Project and New Findings CO2 saturation Movement of CO2 Summary

4 Nagaoka General Information

5 Location Central Japan Nagaoka Site RITE (Kyoto) ENAA (Tokyo) Copyright JWA. All Rights Reserved.

6 Nagaoka Site Cross Section Minami-Nagaoka Gas Field Aquifer Quaternary

7 Project General Information

8 Chronicle of Nagaoka Project FY2000 : Site Selection South Nagaoka Gas Field Drilling of Wells, Well logging and Test of Core Sample FY : Injection well (IW-1) and Three observation wells (OB-2, OB-3, OB-4) drilled FY : Construction of the Facilities FY : Injection of CO 2 10,405t FY 2002 present :Monitoring: of CO 2 for 5 years FY 2000 present : Simulation Study (now on progressing) FY : Simulation prior to the injection start FY present : History matching simulation after the injection start Future prediction for 1000 years FY 2007 RST, CBL and No Blockage of Wells, End of Project

9 Well Configuration Injection well : IW-1 Observation well :OB-2, OB-3, OB-4 IW-1 OB-2 OB-3 OB-4 IW-1

10 Well Configuration Arrangement of Wells at Reservoir Level Logging Bottom-hole pressure and temperature OB-4 OB-3 Logging 60m Formation dip: 15 IW-1(Injection well) 120m 40m Cross-well Seismic Tomography Bottom-hole pressure and temperature OB-2 Logging Fluid sampling Injection well : Perforated at Zone-2 (12m) Observation wells : FRP Casing at reservoir interval

11 Main Features of CO 2 Injection Reservoir: Aquifer of 1,100m deep Duration of Injection: About 18 months Injection started on 7 July 2003, ended 11 January 2005 Total Amount of CO2 : 10,405 t Injection Rate: 20-40t /day CO 2 Phase: kept to be Supercritical Phase (at Well Bottom) Injection Pressure Well Head MPa Well Bottom MPa Temperature of CO 2 Well Head Well Bottom CO 2 Phase: kept to be Supercritical Phase (at Well Bottom)

12 Sketch of Injection IW-1 OB-3 OB-4 OB-2 About 100m wide

13 Flow of Investigation & Monitoring Earthquake No Earthquake Fluid sampling (FY2005)

14 Progress of Injection and Monitoring End : Jan. 11, 2005 Start : July 7, 2003 FY2003 FY2004 FY2005 Seismicity Observation

15 Pressure & Temperature Measurement Continuously at well bottom and well head) Time-lapse Logging (Baseline + 22 times during injection times after the end of injection ) Induction Log Neutron Log Acoustic Log Time-lapse Cross-well Seismic Tomography Seven times : Before the injection After the injection Seismicity observation (during and after injection) Micro earthquake (3years) Fluid Sampling 11 months after the end of injection (CHDT) Borehole optical TV

16 Seismic Tomography

17 Earthquake Jul.16, ,530 1,470 1,410 1, In jection R ate(t-c O 2/day) Seismic Tomography BL Seismic Tomography MS6 Oct months afer 03/06/07 03/08/06 03/10/05 03/12/04 04/02/02 04/04/02 04/06/01 04/07/31 04/09/29 04/11/28 05/01/27 05/03/28 05/05/27 05/07/26 05/09/24 05/11/23 06/01/22 06/03/23 06/05/22 06/07/21 06/09/19 06/11/18 07/01/17 07/09/14 07/07/16 07/05/17 07/03/18 Pressure Measurement & Seismic Tomography Elapsed D ay from July 7th,2003 Date 40 0 Pressure(MPa) ,050 1,110 1,170 1,230 1,290 Earthquake Oct.23, 2004 W ellb ottom P ressure IW-1 Seismic Tomography MS3 : 8900t Fluid sampling Dec., months after WellB ottom P ressure O B -4 Injection Rate Seismic Tomography MS1 : 3200t Seismic Tomography MS2 : 6200t Seismic Tomography MS4 : 10405t Seismic Tomography MS5 Oct months afer

18 Time-lapse Crosswell Seismic Tomography OB-3 IW-2 OB-2 3,200 t Max 3.0% OB-3 IW-2 OB-2 10,400 t Max 3.5% MS1/BLS MS4/BLS

19 Time-lapase W ell Logging

20 Time-lapse Well Logging Monitoring after CHDT Breakthrough Breakthrough CHDT

21 CO 2 Breakthrough at OB-2,3,4 16th logging on May 12 (4,300t-CO 2 ) No Change 17th logging on June 14 OB-4 (5,400t-CO 2 ) P-wave velocity : decrease 0.33 km/sec, 13% Neutron porosiry : decrease 6 % No Big Change after Breakthrough 60m 120m 40m 13th logging on Feb. 12 (3,500t-CO 2 ) No Change 14th logging on Mar. 10 (4,000t-CO 2 ) P-wave velocity : decrease 0.71 km/sec, 28% Resistivity : increase 0.54Ω m Neutron porosiry : decrease 10 % Small Interesting Opossite Change after 28 th logging on Sept. 24, 2004 OB-2 OB-3 No Change by Now IW-1(Injection well) Induction Log Neutron Log Acoustic Log Gamma Ray Log

22 CO 2 Breakthrough at OB-2 Vp Neutron Porosity Resistivity Vp : km/sec 0.71km/sec, 28% φn : , 42% R : Ω m 0.54Ω m, 11% Feb Mar

23 Change of Resistivity at OB-2 and Sampling Points m Ω( m) Zone m -0.8 Breakthrough m CHDT

24 History of CO 2 Saturation at OB-2 and Sampling Points m - Zone m m Breakthrough CHDT

25 CHDT Result

26 Fluid sampling OB m : Mostly free CO m m m Gas: 3,500ml Water: 50ml - 280ml (Contamination 96%) Gas composition mol% H O N CH C 2 H CO Sample Chamber (volume 3,786ml)

27 1108.6m Fluid sampling OB m & 1118m : Water m m Gas: None Before injection At 1118m, formation water rich in dissolved CO 2. Water: 3430ml -3540ml (Contamination <1%) m 1118m HCO 3 (ppm) Sample Chamber (volume 3,786ml)

28 Fluid sampling OB m & 1118m : Ca, Mg & Fe Before injection m 1118m Ca (ppm) Mg (ppm) Fe (ppm) At the depth of 1118m (HCO - 3 conc. increased), concentrations of Ca, Mg and Fe also increased.

29 BHTV Result

30 BHTV(Optical) Tool Camera

31 BHTV(Optical) at depth of CHDT m 1,117.8mMD

32 BHTV(Optical) at depth of CHDT m 1,113.8mMD

33 BHTV(Optical) at depth of CHDT 3 1,108.0mMD m

34 CO2 saturation

35 Sonic Velocity(OB OB-2) Vp(km/s) Vp(km/s) st Vp(km/s) th Vp(km/s) th nd 7th th 15th th 22th 8th 16th 23th th 10th th 18th th 25th th 12th th th Analized Zone All data 1-12 th data th data th data At 14 th,observed for CO2 arrival

36 Neutron Porosity (OB-2) 1100 Neutron Porosity Neutron Porosity st 1100 Neutron Porosity th 1100 Neutron Porosity th nd 3rd th 15th th 22nd 4th 16th 23rd th 6th th 18th th 25th th 8th 9th 10th th th Analized Zone 11th th All data 1-12 th data th data th data At 14 th,observed for CO2 arrival

37 CO2 Saturation from Neutron log Porosity at base line log: Porosity after CO2 injection: φ b φ m CO2 Saturation: = φ φ 2 φ S CO b m b 1107 Gas Saturation Gas Saturation Gas Saturation th 14th th 21th th nd th 17th rd 24th th th th th Changed Zone ~1118m All data th data th data

38 Modeling and Calculation Determining Skeleton rock modulus from Rock physics model - friable-sand model (Dvorkin and Nur(1996)) Substitution fluid for Gassmann theory <Gassmann formula> K K mineral sat K sat = K K mineral dry K dry + φ K ( K K ) mineral fluid fluid

39 Three state of CO2 saturation Uniform saturation All pores have same saturation Patchy saturation Partially saturation Patchy (fluid) saturation Several pores have different saturation 1 K fl = S K gas gas + S K water water 1 K = V water Kpart water + V gas Kpart gas K = S K + fl gas gas S water K water

40 Brie empirical fluid mixing equation K fl = S e water K water + ( 1 S e water ) K gas The e is empirical coefficient. K = S K + S K (e=1) fl gas gas water water 1 / K = V / K + V / fl water water gas K gas (e= ) Brie.et.(1995):Shear sonic interpretation in gas bearing sands, Proc,SPE

41 Schematic diagram of three state saturation Patchy saturation (fluid) max Patchy saturation Rock Modulus Brie s empirical formula Uniform saturation CO2 saturation

42 Comparison model calculation and observed data P-wave Velocity(km /s) V p - C O 2 S atu ratio n (c riticals atu ration :0.6) ( from Friable-Sand model m) uniform Patchy P athcy_voigt Brie(e=3) Brie(e=2) log(18-26th) C O 2 saturation Good agreement with Patchy and Brie model

43 Movement of CO2 after CHDT

44 Change of Resistivity at OB-2 between 29th-36th

45 Change of Resistivity at each zone of OB-2

46 Vp- CO2 Saturation at OB-2 (1116m depth)

47 OB-3 OB-4 IW-1 OB-2 3md 10md 60m 40m 120m CO 2 Movement Model(1) SC CO 2 Disolluted CO 2 Buoyancy Dissolution Upper Zone2a Lower Zone2b 6m 6m

48 CO 2 Movement Model(2) OB-3 OB-4 IW-1 OB-2 SC CO 2 Dissolved CO 2 3md 10md 60m 40m 120m Buoyancy Dissolution Upper Zone2a Lower Zone2b 6m 6m

49 Host rock Dissolution and Mineral trapping of CO 2 in saline aquifers Gas trapping Formation water CO 2 (sc) Dissolution Clay minerals Feldspar CO 2 (aq) + H 2 O H 2 CO 3 Solubility trapping H + + HCO 3-2H + + CO Ionic trapping Mineral trapping Cation (Ca 2+, Mg 2+, Fe 2+ etc.) Carbonate (CaCO 3, MgCO 3, FeCO 3, etc.) + H 4 SiO 4

50 Additional Study Plan in 2007 Additional data acquisition: Logging at the injection well IW-1 (RST and NL) Logging at the observation well OB-2,3,4 (usual logging and CBL) History-match simulation incorporating these additional data is expected to improve our understanding of CO 2 movement and distribution.

51 Summary(1) Patchy Saturation From the relation between the velocity and CO2 saturation rate calculated by neutron log, we concluded that the state of CO2 saturation during CO2 injection might be almost Patchy saturation not uniform at Nagaoka Site.

52 Summary(2) CO2 Movement The resistivity and porosity have become decreasing one year after stopping injection of CO2 while velocity does not increase. The reason of the decrease which was detected by time-lapse well loggings is that the distribution area of CO2 might be shrinking by dissolution of CO2 and moving upward because of buoyancy.

53 ACKNOWLEDGMENTS The authors would like to express their most sincere gratitude to the continuous advice provided by Professor K. Sato. The project Research and Development of Underground Storage for Carbon Dioxide is funded by Ministry Economy, Trade and Industry (METI) of Japan under the contract of between RITE and METI. ENAA, in the process of conducting the field test of CO2 injection as a branch office of RITE, owed much to RITE staff members for their enthusiastic involvement and assistance.