Update of Carbon Storage Field Projects
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Transcript of Update of Carbon Storage Field Projects
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Update of Carbon Storage Update of Carbon Storage Field ProjectsField Projects
Susan D. HovorkaBureau of Economic Geology
Jackson School of GeosciencesThe University of Texas at Austin
Presentation to Underground Injection Control (UIC) Educational Track 2007 Texas Commission on Environmental Quality Trade Fair & ConferenceWednesday, May 2, 2007
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Status of Knowledge About CCS**Carbon Capture and Storage
Well Known• Trapping mechanisms• Monitoring strategies to image
and quantify plume evolution• Validity of modeling
approaches – modification of existing simulators
• Major leakage risks• Volume of storage US,
Australia, Japan, Europe
Poorly Known• Modeling/monitoring in low
permeability rocks• Monitoring to detect low rates
of leakage over long time frames
• Performance of non-matrix systems (coal, basalt)
• Risks resulting from very large scale-up
• Volume of storage in developing nations
• Performance of faults, wells
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Sources of Knowledge
• IPCC Special Report on Geologic Storage– Rapidly evolving field, IPCC report used only peer
reviewed literature
• US and international networks – NETL updates www.netl.doe.gov/publications/carbon_seq/
– CO2 GeoNet www.co2geonet.com/
– CCP www.co2captureproject.org
– IEA Greenhouse http://www.co2captureandstorage.info
• Large number of meetings– examples: GHGT, NETL annual CCS meeting, EPA
working groups, IEA GHG R&D Networks
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Contributions to Knowledge From Selected Field Projects
Otway
US DOE RCSP projects
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Observed performance of siltstonesin retarding CO2 migration, Utsira FM,Sliepner field, North Sea
http://www.bgs.ac.uk/science/co2/Sleipner_figs_02.html
Bright injected CO2
in sandLight siltstone baffles
Top seal
Trapping Mechanisms: Structural Traps
Cornelius Reservoir Markham No. Bay City No. field Tyler and Ambrose (1986)
Well known performance ofshale seals in trapping oil and gas,
Texas Gulf Coast
Shale sealsIn white
Sandstones
Successful use of 4-D seismicfor monitoring CO2 plume
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Trapping: Regional Setting of Utsira
Source: SACS Best Practices Manualhttp://www.co2store.org/TEK/FOT/SVG03178.nsf/Attachments/SACSBestPractiseManual.pdf/$FILE/SACSBestPractiseManual.pdf
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Frio Brine Pilot Sitetwo test intervals
• Injection intervals: mineralogically complex Oligocene fluvial and reworked fluvial sandstones, porosity 24%, permeability 4.4 to 2.5 Darcys
• Steeply dipping 11 to 16 degrees
• Seals numerous thick shales, small fault block
• Depth 1,500 and 1657 m• Brine-rock system, no
hydrocarbons• 150 and 165 bar, 53 -60
degrees C, supercritical CO2
Injection interval
Oil production
Fresh water (USDW) zoneprotected by surface casing
Injection zones:First experiment
2004: Frio “C”Second experiment
2006 Frio “Blue”
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Porosity
Fault planes
Monitoringinjection and monitoring
Observation wellInjection well
Trapping Mechanism:Frio Site Reservoir Model
Knox, Fouad, Yeh, BEG
In context of the plume, injection was in an open aquifer
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Two-Phase Residual Gas Trapping
Grains Brine – filled pores
Inje
ctio
n o
f C
O2 Phase-trapped
CO2
Imbibition Drainage
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Representative realistic imbibition and drainage curves for two-phase flow
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CO2 Trapping as a Residual Phase
• Plume in open aquifer spreads quickly updip
• Plume in an open aquifer is trapped before it moves very far
Residual gas saturation of 5%
Residual gas saturation of 30%
TOUGH2 simulations C. Doughty LBNL
Injection well
Observation well
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Monitoring Using Oil-field Type Technologies is Successful in Tracking CO2
Downhole P&T
Radial VSPCross well Seismic, EM
Downhole samplingU-tubeGas lift
Wirelinelogging
Aquifer wells (4)Gas wells Access tubes, gas sampling
Tracers
Frio Brine Pilot: Determine the subsurface distribution of injected
CO2 using diverse monitoring technologies
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Monitoring Design Frio 2
Injection Well Observation Well
50 m
U-tubes
RST logs
Frio “Blue”
Sandstone
15m thick
PackersDownhole P and T
Tubing hung seismic source
and hydrophones
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Injection well
Observation well
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Real-time Downhole Pressure and Temperature Monitoring
CO2 breakthrough
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Measurement of Perminace
5450
5500
DEPTHFEET
LithologyEff. porosity
V/V0 0.5
Seismic source
Packer
Perfs
BH Sal. - 1PPM0 400000
BH Sal. - 2PPM0 400000
BH Sal. - 3PPM0 400000
BH Sal. - 4PPM0 400000
Sigma - 1CU35 15
Sigma - 2CU35 15
Sigma (Sg = 60%)CU35 15
Sigma (Sg = 40%)CU35 15
Sigma (Sg = 20%)CU35 15
Sigma - 1CU35 15
Sigma - 3CU35 15
Sigma (Sg = 60%)CU35 15
Sigma (Sg = 40%)CU35 15
Sigma (Sg = 20%)CU35 15
Sigma - 1CU35 15
Sigma - 4CU35 15
Sigma (Sg = 60%)CU35 15
Sigma (Sg = 40%)CU35 15
Sigma (Sg = 20%)CU35 15
Temp. - 1DEGF125 145
Temp. - 2DEGF125 145
Temp. - 3DEGF125 145
Temp. - 4DEGF125 145
Pressure - 1PSI2340 2420
Pressure - 2PSI2340 2420
Pressure - 3PSI2340 2420
Pressure - 4PSI2340 2420
We
llbo
re s
ketc
h
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West Pearl Queen
• Injection interval 7 m arkosic sandstone, oil reservoir, Permian Queen Formation
• 18% porosity, 5 -30 md• Structural dome trap -
carbonate/evaporite seals• Depth - 1350 m• 96 bar• CO2 trapped by residual
saturation + dissolution in water and oil– 62% retained under
production
%
Representative of thePermian Basin
Los Alamos National LaboratoryBill Cary
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Trapping Dissolution of CO2 into Brine
1yr
5 yr
30 yr
40 yr
130 yr
330 yr
930 yr
1330 yr
2330 yr
Jonathan Ennis-King, CO2CRCJonathan Ennis-King, CSIRO Australia
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Tracer Breakthrough Curves
-0.2
0
0.2
0.4
0.6
0.8
1
10/10/2004 10/11/2004 10/12/2004 10/13/2004
C/C
max
SF6 C/Cmax
Krypton C/Cmax
PFT C/Cmax
2nd Tracer Breakthrough
3rd Tracer Breakthrough
Trapping: Frio Tracer Breakthough Curves Show Significant Dissolution of CO2 into
Brine
Barry Friefeld, LBNL; Tommy Phelps ORNL
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Setting the Standard for Monitoring:IEA Weyburn project
• Devonian Midale carbonate
• Successful semi-quantitative monitoring of CO2 plume migration using 4-D seismic: 20% P-wave difference post injection
IEA Weyburn CO2 Storage and Monitoring Project
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Combining CO2 storage research with oil production
• Large, high technology, well-supported research Phase I , $21 M, numerous international partners
• Complex environment containing oil, production, field operations
Petroleum TechnologyResearch Centre (PTRC)Encana, governmentsUniversity, Provincial, private
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No Suitable Method for Detecting Slow Leakage
• Current monitoring: noise is large, precision is moderate
• If flux is low, .01 to 1 % of stored volume/year
• Cumulative impact to atmosphere would be unacceptable
Weyburn Soil Gas Survey
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Monitoring Techniques at Nagaoka site: injection into a heterogeneous rock volume
Research Institute of Innovative Technology for the Earth (RITE) and collaboratorshttp://uregina.ca/ghgt7/PDF/papers/nonpeer/273.pdf
• Pleistocene Haizume Fm: 12 m thick mineralogically immature submarine sandstone
• 10’s mD core analysis, <10 mD hydrologic test, about 20% porosity
• 15 degree dip on flank of anticline
• 10,400 tones CO2
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http://www.rite.or.jp/English/about/plng_survy/todaye/todaytre/RTtr_co2seq.pdf
Monitoring using cross well-seismic at Nagaoka site
• Logging though non-metallic casing using induction, neutron, sonic detected breakthough after injection 4000 tones 40 m away
• Cross well tomography imaged plume but failed to detect breakthough
• 4-D seismic suggests strongly anisotropic CO2 movement
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Subsurface Monitoring Above Injection Zones – a Proposed Solution to Complexity
• Close to perturbation
• Quiescent relative to the surface
• High signal to noise ratio
Aquifer and USDW
Atmosphere
Biosphere
Vadose zone & soil
Seal
Seal
Monitoring Zone
CO2 plume
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Adequacy of Modeling: CO2 Saturation Observed with Cross-well Seismic Tomography
vs. Modeled: Frio example
(B)
Tom Daley and Christine Doughty LBNL
Injection well
Observation well
10
0 f
t
X-well is a cross section of the plume
Cross-Well Seismic Tomogram
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Adequate US Storage Volume: Preliminary “Fairways” Map
Com
plex
geo
logy
No
inve
ntor
y at
tem
pted
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Low Permeability is Typical:more studies needed in tight rocks
<.0.01.01-0.10.1 -11 – 10>10
Hydraulic conductivitym/day
Mixed data types – core, well tests, and models
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Successful Use of Horizontal Well Technology in Low Permeability Sandstones
– BP In Salah Project, Algeria
• Inject 1 million tones/year of CO2 from gas processing facility
• Injection into water leg of same reservoir
• 800 m-ling horizontals
• 5-10 mD Pennsylvanian sandstone
• Injection underway• Large monitoring project
mobilized – 4-D seismic, soil gas, microseismic array
http://ior.rml.co.uk/issue11/events/past/spe/Ian Wright, BP
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PNNL and Geothermal EnergyIndia.
Example of the Global Question of Capacity: Deccan Traps, India
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Layered Basalt – Role for Geochemical Trapping?
• Thick section – > 2000 m, large volume
• Layered lower and higher permeability
• Seal performance is uncertain
• High reactivity with CO2 - formation of minerals
• So could CO2 be retained long enough to be trapped by mineral reactions? Fill and Spill with reaction with Basalt
An example of need for assessment of quality and quantity of geologic storage outside of the US
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Otway Basin Project -Australia• Planned injection of
100,000 tones of natural CO2 into Cretaceous Warre sandstone depleted gas reservoir
• Large volume injection
• Fault seal – will test fault stability under injection
• Test monitoring in the presence of gas
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Well Understood Risk:Unexpected Results of Injection
Water tableUnderground source of drinking water
Earthquake
Escape to groundwater,surface water, or air via long flowpath
Substitute undergroundinjection for airrelease
Escape of CO2 or brine togroundwater,surface wateror air throughflaws in the seal
Failure of well cement orcasing resulting in leakage
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Risk in Terms of Exceeding Capacity
• Spill from structure
• Exceed fracture pressure of seal
• Far-field effects – leakage of brine from injection interval
Large scale-up
Very large scale-up
Reservoir
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Status of Knowledge About CCS
Well Known• Trapping mechanisms• Monitoring strategies to image
and quantify plume evolution• Validity of modeling
approaches – modification of existing simulators
• Major leakage risks• Volume of storage US,
Australia, Japan, Europe
Poorly Known• Modeling/monitoring in low
permeability rocks• Monitoring to detect low rates
of leakage over long time frames
• Performance of non-matrix systems (coal, basalt)
• Risks resulting from very large scale-up
• Volume of storage in developing nations
• Performance of faults, wells