Microseismic Monitoring and Geomechanical Modelling of CO2 - bris

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CHAPTER 2. THE WEYBURN CO 2 INJECTION PROJECT Phase IB Phase II 450 Not recording CO2 Injection (Mscm/D) 45 400 Water Injection (m^3/D) 40 350 35 300 30 250 200 150 25 20 15 100 10 50 5 0 0 Sep-03 Nov-03 Jan-04 Mar-04 May-04 Jul-04 Sep-04 Nov-04 Jan-05 Injection Rate Mar-05 May-05 Jul-05 Number of Events Sep-05 Nov-05 Jan-06 Mar-06 May-06 Jul-06 Sep-06 Nov-06 Jan-07 Mar-07 May-07 Jul-07 Sep-07 Nov-07 Jan-08 Figure 2.6: CO 2 (red) and water (blue) injection rates through well 121/06-08, as well as the rate of reliably located microseismic events (bars). The array was installed in August 2003. The periods when the geophones were not recording are marked in light blue. 500 Event Geophones Injector Producers 1000 1100 1200 Event Reservoir Injector Geophones Northing (m) 0 Depth (m) 1300 1400 1500 −500 −500 0 500 Easting (m) (a) 1600 −500 0 500 Easting (m) (b) Figure 2.7: Map (a) and East-West cross-section (b) views of Phase IB events. This plot shows all events located by ESG, including completion related activity and events that I deem unreliable in Section 2.4.1. The horizontal oil production wells, the vertical injection well, the observation well, and the reservoir interval are all marked. event depth and radial distance. The events are characterised by a low dominant frequency (15-80Hz) and poor signal-to-noise ratio. As such, the quality of event location is not good, and the errors associated with location are in some cases as large as 100m. As systematic event location errors were not provided by ESG, I am unable to plot error bars on the location plots. Furthermore, a sensitivity analysis of the velocity model, where velocities were varied by ±250ms −1 resulted in location changes of up to 75m (Verdon et al., 2010c). The event locations for all events located by the ESG automated picking algorithm are shown in Figure 2.7. 16
2.4. EVENT TIMING AND LOCATIONS 500 1000 1100 Northing (m) 0 Depth (m) 1200 1300 1400 1500 −500 −500 0 500 Easting (m) (a) 1600 −500 0 500 Easting (m) (b) Figure 2.8: Map (a) and EW cross-section (b) views of seismic emissions detected during drilling and completion activities in injection well 121/06-08. The events are all located near the injection well, marked on (b) in blue. Wells are marked as per Figure 2.7. Month No. of ESG ‘events’ Locatable microseisms Notes Aug-Sep 2003 6 2 Including 3 calibration shots Oct 03 6 3 Nov 03 15 2 Most of these ‘events’ were drilling noise and completion of the injection well Dec 03 2 1 Recording array was shut down for 2 weeks during December 2003 Jan 04 15 15 All 15 events occur at the onset of injection Feb 04 4 2 Two ‘events’ are from perforation shots in distant wells Mar 04 15 0 These events cannot be reliably identified as microseismic events Apr 04 2 2 May 04 Array was not recording during May 2004 Jun 04 Array was not recording during June 2004 Jul 04 23 23 This period has an increased CO 2 injection rate Aug 04 11 11 Sep 04 1 1 Oct 04 3 3 Nov 04 3 3 The Phase IB recording stage ended November 2004 Table 2.3: Microseismic activity rates during Phase IB. I have listed the total number of ‘events’ listed by ESG, some of which are produced by completion and drilling activities, or whose waveforms are not indicative of microseismic events (see Section 2.4.1). Therefore I have also listed the events that are genuine, reliably located microseismic events. 17
Page 1: Microseismic Monitoring and Geomech
Page 5 and 6: Abstract Capture of CO 2 produced a
Page 7 and 8: Author’s Declaration I declare th
Page 9 and 10: Acknowledgments There are many thin
Page 11 and 12: Table of Contents Abstract Author
Page 13 and 14: TABLE OF CONTENTS 5.4 Results . . .
Page 15 and 16: Preface ‘Research is not an end i
Page 17 and 18: 6. D. Angus, J-M. Kendall, J.P. Ver
Page 19 and 20: 1 Introduction A technology push ap
Page 21 and 22: 1.2. CCS OVERVIEW Figure 1.2: CCS s
Page 23 and 24: 1.3. THESIS OVERVIEW for CO 2 to be
Page 25 and 26: 1.3. THESIS OVERVIEW as microseismi
Page 27 and 28: 2 The Weyburn CO 2 injection projec
Page 29 and 30: 2.2. WEYBURN GEOLOGICAL SETTING Fig
Page 31 and 32: 2.2. WEYBURN GEOLOGICAL SETTING N F
Page 33: 2.4. EVENT TIMING AND LOCATIONS 500
Page 37 and 38: 2.4. EVENT TIMING AND LOCATIONS Nor
Page 39 and 40: 2.4. EVENT TIMING AND LOCATIONS Fig
Page 41 and 42: 2.5. DISCUSSION 500 1000 1100 North
Page 43 and 44: 2.6. SUMMARY 2.6 Summary • CO 2 s
Page 45 and 46: 3 Inverting shear-wave splitting me
Page 47 and 48: 3.2. INVERSION METHOD the additiona
Page 49 and 50: 3.2. INVERSION METHOD 1. P-wave inc
Page 51 and 52: 3.2. INVERSION METHOD 180 160 140 C
Page 53 and 54: 3.2. INVERSION METHOD 2800 2800 260
Page 55 and 56: 3.2. INVERSION METHOD Loop over γ,
Page 57 and 58: 20 10 5 5 1 20 30 40 80 100 60 40 1
Page 59 and 60: 3.4. SWS MEASUREMENTS AT WEYBURN th
Page 61 and 62: 3.4. SWS MEASUREMENTS AT WEYBURN ei
Page 63 and 64: 3.4. SWS MEASUREMENTS AT WEYBURN ξ
Page 65 and 66: 3.4. SWS MEASUREMENTS AT WEYBURN da
Page 67 and 68: 4 2 2 3.4. SWS MEASUREMENTS AT WEYB
Page 69 and 70: 1 1 1 1 1 1 1 1 1 1 3.5. DISCUSSION
Page 71 and 72: 3.6. SUMMARY 3.6 Summary • I have
Page 73 and 74: 4 A comparison of microseismic moni
Page 75 and 76: 4.2. EVENT LOCATIONS 2400 Velocity
Page 77 and 78: 4.2. EVENT LOCATIONS 200 150 Northi
Page 79 and 80: 4.3. EVENT MAGNITUDES Pressure (MPa
Page 81 and 82: 4.3. EVENT MAGNITUDES 160 140 120 N
Page 83 and 84: 4.4. SHEAR WAVE SPLITTING 50 −3 E
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4.5. INITIAL S-WAVE POLARISATION In
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4.5. INITIAL S-WAVE POLARISATION 6
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4.5. INITIAL S-WAVE POLARISATION of
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4.6. INTERPRETATION OF SHEAR WAVE S
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1 1 5 5 30 4.6. INTERPRETATION OF S
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80 4.6. INTERPRETATION OF SHEAR WAV
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2 3 3.5 4 5 2 1.8 1.4 4 4.6. INTERP
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4.7. DISCUSSION 4.7 Discussion The
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pressure, P fl σ ′ ij = σ ij
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5.2. EFFECTIVE STRESS AND STRESS PA
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5.3. NUMERICAL MODELLING 5.3.1 Flui
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5.3. NUMERICAL MODELLING MORE FLUID
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5.3. NUMERICAL MODELLING (a) (b) Fi
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5.4. RESULTS 0 500 1000 Depth (m) 1
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5.4. RESULTS 1 0.9 0.8 Soft Med Sti
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5.4. RESULTS Overburden Extension i
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5.4. RESULTS 1z:100x:100y 1z:100x:5
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5.5. SURFACE UPLIFT 1 0.9 0.8 Soft
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5.5. SURFACE UPLIFT Figure 5.17: Ma
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6 Generating anisotropic seismic mo
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6.2. STRESS-SENSITIVE ROCK PHYSICS
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6.3. A MICRO-STRUCTURAL MODEL FOR N
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6.4. CALIBRATION WITH LITERATURE DA
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6.4. CALIBRATION WITH LITERATURE DA
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6.5. COMPARISON OF ROCK PHYSICS MOD
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6.5. COMPARISON OF ROCK PHYSICS MOD
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7 Forward modelling of seismic prop
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7.2. SEISMODEL c⃝ WORKFLOW time s
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7.3. RESULTS FROM SIMPLE GEOMECHANI
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7.4. SUMMARY 7.4 Summary • I have
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8 Linking geomechanical modelling a
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8.2. MODEL DESCRIPTION Layer Thickn
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8.2. MODEL DESCRIPTION Unit E (GPa)
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8.3. RESULTS Marl Vugg 0.8 0.8 Norm
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8.3. RESULTS 15 10 Injector Produce
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8.3. RESULTS 2000 15 2000 15 1500 1
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8.4. A SOFTER RESERVOIR 8.4 A softe
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8.4. A SOFTER RESERVOIR 2000 15 200
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8.4. A SOFTER RESERVOIR 2000 Max SW
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8.5. DISCUSSION pore-pressure being
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8.6. SUMMARY 8.6 Summary • I appl
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9 Conclusions Geological storage wi
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calibrate. This model has been cali
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9.1. NOVEL CONTRIBUTIONS techniques
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9.2. FUTURE WORK Finally, the compa
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Bibliography Abt, D. L., Fischer, K
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BIBLIOGRAPHY Gassmann, F., 1951. Ub
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BIBLIOGRAPHY Kendall, J.-M., Pilido
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BIBLIOGRAPHY Sayers, C. M., 2002. S
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BIBLIOGRAPHY White, D., 2009. Monit
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A List of Symbols The table below l
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B In Support of Carbon Capture and
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Both China and India are aggressive
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Utsira rock properties vary signifi
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