Pilot experiments in Australia. Jonathan Ennis-King CSIRO

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1 Pilot experiments in Australia Jonathan Ennis-King CSIRO Webinar on Geologic Capture and Sequestration of Carbon Nov 15, 2017

2 Location of CO2CRC Otway Project

3 Otway Site Operations Current Site Layout 3

4 Stages of the project: past and future Completed Stage 1: March 2008 to September 2009 injection of 65,400 tonnes of CO 2 - rich gas into depleted gas field. Stage 2B: Residual saturation and dissolution test: June 2011 to September 2011 single well injection of 150 t of CO 2 into saline aquifer Stage 2Bext: Repeat of simplified single well test with improved methodology, and additional gas impurities, November-Dec 2014 In progress Stage 2C Seismic detection test injection of 15,000 tonnes of CO 2 -rich gas into saline aquifer; buried geophone array, December 2015-April In development Stage 3: Test of reservoir-level monitoring technologies e.g. above zone geophysical detection and pressure monitoring

5 Key achievements of Stage 1 Obtained approvals and support for the project Assisted in developing a regulatory regime Resolved long-term liability issues Safely injected 65,400 tonnes of CO 2 -rich gas Verified science of CO 2 storage in depleted gas field Performed extensive pre-injection modeling of site Showed agreement of predictions with reservoir-level monitoring Directly measured the storage efficiency Confirmed storage integrity Verified no detectable leakage in overlying formation or surface

6 Prediction vs field data for CO 2 concentration at U2 monitoring point

7 What did we learn from Stage 1 reservoir-level monitoring? Value of downhole P/T gauge in the injection well aquifer properties well test pressure buildup during injection Value of fluid sampling at the crestal well (Naylor-1) arrival of injected gas through tracers and gas composition sensitive probe of the models. filling efficiency (56-84% of pore volume produced)

8 Stage 2B: Residual saturation and dissolution test Residual trapping is a key mechanism for the storage of carbon dioxide in saline formations The test measures field-scale residual trapping using a single well configuration and six different methods pressure, temperature, RST logging, noble gas tracers, reactive tracers and a dissolution test. The field results enable us to evaluate the effectiveness of each method, and to recommend how such a test could be improved.

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10 What did we learn from Stage 2B reservoir-level monitoring? The pressure test has a large range of investigation, but wellbore storage and near-well effects complicate interpretation. S gr = 15-19% DTS data gives information about distribution of injection over the completion. Noble gas tracers give good estimate of residual, but are complicated to sample and analyze. S gr = 11-20% Pulsed neutron logging has a shallow depth of investigation ~ 0.5m. S gr = 18-23%

11 Stage 2C Project Goals Detect injected CO 2 -rich gas in the subsurface: ascertain minimum seismic detection limit Observe the gas plume development using time-lapse seismic Verify stabilisation of the plume in the saline formation using time lapse seismic Secondary opportunities Monitor in-zone and above-zone pressure responses Examine effect of harmonic injection on pressure 11

12 Stage 2C Project Overview monitoring strategy 4D seismic with buried receiver array acquired concurrently with 4D VSP Baseline: March 2015 Monitor surveys: 5 kt, 10kt, 15 kt of injection (January-April 2016), 1&2 years post injection (January 2017&2018) Offset VSPs Passive seismic using buried receiver array LBNL group lead: Trialing 4D seismic with buried DAS array, 4D VSP in CRC-2 (optical fiber on the tubing) and continuous seismic sources 12

13 RMS amplitudes of the differences computed in 24 ms window centred at the plume level (1210 ms). The differences are computed between B and (top-left to bottom-right): M1, M2, M3, M4 5,000 t 10,000 t 15,000 t 1 year

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15 What have we learnt from Stage 2C monitoring? Above-zone pressure monitoring is sensitive to a small-scale injection, and is able to detect large variations in injection rate. The presence of multiple pressure signals barometric, earth tide, pressure diffusion complicates analysis. Repeat seismic can track the development of small plumes Buried seismic array improves signal-to-noise New technologies (e.g. Optical fibre sensors (DAS)) may enable continuous geophysical monitoring with low impact

16 Otway Stage 3: Reducing cost through subsurface monitoring 1. To deliver a permanently deployed subsurface and costeffective real-time monitoring solution for industry 2. To increase the efficiency of CO 2 monitoring with new and adapted technologies 3. To reduce the surface footprint and impact of monitoring activities 16

17 Probable Subsurface Monitoring Techniques Pressure Tomography Low cost monitoring solution Baseline pressure measurement with conventional quartz gauge in-well (experience from Stage 2C) Trial of fibre-optic deployed pressure gauge behind casing (focus on cost reduction) Cross-well seismic Fibre optic deployed external to casing all wells Multiple permanent surface sources Validated via conventional surface seismic and existing buried seismic array Electromagetic Cross-well using casing as electrode 17

18 Options for pressure monitoring Passive Pressure Inversion: infer distance and rate of a source (above-zone or in-zone) Compressibility monitoring from earth tide signals can detect CO 2 plume Interface tracking from multiple gauges Active Pressure tomography: time-lapse detection of CO 2 from response to water injection. 18

19 Synthetic inversion in Otway Stage 3 project m (8) (9) (10)

20 Difficulties for CCS in Australia Political and economic factors e.g. carbon pricing, energy policy, scepticism about climate change Rapid technological change in renewables, and transition in the electricity system vs CCS timeframe. Very limited prospects for CCUS in enhanced recovery e.g. EOR, ECBM etc Resources conflicts in sedimentary basins e.g. hydrocarbons, groundwater Uncertainty about social license to operate, especially onshore. Source-sink matching difficult for some areas e.g. Sydney 20

21 Prospects for CCS in Australia Abundant coal resources so there s incentive for CCS. Gorgon CO 2 project (from natural gas production) close to start of injection (peak storage of 3 million tonnes/year) Good opportunities for large volume saline aquifer storage in most parts of the country Three flagship projects for industrial-scale demonstration of CCS CarbonNet, CTSCo, SW Hub Possibilities for hydrogen from coal with CCS ( KHI ) 21

22 ACKNOWLEDGEMENTS We would like to acknowledge the funding provided by the Australian government to support this CO2CRC research project. We also acknowledge funding from ANLEC R&D and the Victorian Government for the Stage 2C project. Funding for LBNL was provided through the Carbon Storage Program, U.S. DOE, Assistant Secretary for Fossil Energy, Office of Clean Coal and Carbon Management through the NETL. We thank the National Geosequestration Laboratory (NGL) for providing the seismic sources (INOVA Vibrators) for this project. Funding for NGL was provided by the Australian Federal Government. The authors also thank the contributions by the various research members of the CO2CRC Otway project teams, including Geoscience Australia, CSIRO, The Universities of Adelaide, NSW, Melbourne & Western Australia.

23 Stage 2C project team Curtin University: S. Yavuz, R. Pevzner, K. Tertyshnikov, A. Dzunic, S. Ziramov, M. Urosevic, B. Gurevich, D. Popik, J. Correa, Lawrence Berkeley National Laboratory: B.M. Freifeld, M. Robertson, T.M. Daley, S. Dou, J. Ajo-Franklin, T. Wood CSIRO: T. Dance, V. Shulakova, T. LaForce, J. Ennis-King, L. Paterson CO2CRC: R. Singh, M. Watson, M. Raab. Geoscience Australia: E. Tenthorey

24 Government, Industry and Research Partners 24

25 Thank you CO2CRC Limited 2017