ARB Contract Interim: Important Site Selection Traits (With ... · fracturing, abandoned wells,...
Transcript of ARB Contract Interim: Important Site Selection Traits (With ... · fracturing, abandoned wells,...
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ARB Contract Interim: Important Site Selection Traits (With Quantification
and Monitoring Implications)
Preston Jordan Curt Oldenburg
ARB GCS Site Selection Technical Discussion
20160926
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•historical use considerations (oil and gas production, hydraulic fracturing, abandoned wells, etc.);
•minimum injection depth; •minimum cap-rock thickness; •delineation of an area of review; •minimum pore-space capacity in relation to estimated injection volumes;
• identification of potential leakage pathways for CO2; •proximity to emission sources and potential of source for CO2 capture
•proximity to population centers; •seismic hazard considerations; •establishing pipeline or other transportation rights-of-way; •setting requirements for baseline data collection, including levels and other sources of CO2 emissions, groundwater chemistry, and micro-seismicity; and
•necessary geologic models and CO2 flow simulations
Criteria List for Review From ARB
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Modified from Buschback, T.C., and D.C. Bond (1973). Underground storage of natural gas in Illinois – 1973, Illinois Petroleum 101, Illinois Geological Survey, Urbana, Illinois, 71 pp.
Natural gas storage in Illinois as of 1973
“Finding suitable storage in aquifers is difficult, and the ultimate testing of aquifers can be done only by injecting gas. Therefore, we can expect to encounter, from time to time, a structure that appears to be worthy of testing but later proves unsatisfactory for gas storage.”
~25% of saline leak
~15% early in operation (mitigation allows continued operation: 1 backup interval, 3 active management)
Historical Use
0% of depleted fields leak
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Statoil exploration results as of 1996
Hermanrud, C., K. Abramsen, J. Vollset, S. Nordahl, and C. Jourdan (1996). Evaluation of undrilled prospects – sensitivity to economic and geologic factors. In: A.G. Dore and R. Sinding-Larsen (editors), Quantification and Prediction of Hydrocarbon Resources, Proceedings of the Norwegian Petroleum Society Conference, 6-8 December 1993, Stavanger, Norway. Norwegian Petroleum Society (NPF) Special Publication No. 6, Elsevier, Amsterdam, pp. 325-337.
Historical Use: None (Saline)
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Project Location Start Capacity (Mtpa)
Sleipner Norway 1996 0.9
In Salah Algeria 2004 0.0 (injection suspended)
Snøhvit Norway 2008 0.7 Quest Canada 2015 1.0
Saline aquifer carbon storage as of now
Global CCS Institute (2016). Large scale storage projects. http://www.globalccsinstitute.com/projects/large-scale-ccs-projects accessed on 20160923
Insufficient injectivity
Historical Use: None (Saline)
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Project Location Start Capacity (Mtpa)
Sleipner Norway 1996 0.9
In Salah Algeria 2004 0.0 (injection suspended)
Snøhvit Norway 2008 0.7 Quest Canada 2015 1.0
Saline aquifer carbon storage as of now
Global CCS Institute (2016). Large scale storage projects. http://www.globalccsinstitute.com/projects/large-scale-ccs-projects accessed on 20160923
Insufficient injectivity Backup zone
Historical Use: None (Saline)
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Jordan, P. D., and J. Wagoner (2016). Kimberlina Site: Existing Wells to the Storage Target;; NRAP-TRS-III-XXX-2016; NRAP Technical Report Series; U.S. Department of Energy, National Energy Technology Laboratory: Morgantown, WV, 2016; In Press.
Blue segments are plugs Red segments are unsealed borings
Historical Use: Oil and Gas Production
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Minimum Injection Depth
Benson, S. M., and P. Cook (coordinating authors, 2005). Underground geological storage. In: Intergovernmental Panel on Climate Change Special Report on Carbon Dioxide Capture and Storage, P. Freund (coordinating author). Cambridge University Press, Cambridge, U.K., pp. 195-276.
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Minimum Injection Depth
800 m
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Minimum Injection Depth
900 m
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Minimum Injection Depth
0
1000
2000
3000
4000
5000
6000
7000
32 82 132 182 232 282
0
5
10
15
20
25
30
35
40
45
50
0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150
pres
sure
(psi
)
pres
sure
(MPa
)temperature (°F)
temperature (°C)
Benson, S. M., and P. Cook (coordinating authors, 2005). Underground geological storage. In: Intergovernmental Panel on Climate Change Special Report on Carbon Dioxide Capture and Storage, P. Freund (coordinating author). Cambridge University Press, Cambridge, U.K., pp. 195-276.
900 m
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0
2000
4000
6000
8000
10000
12000
14000
16000
18000
0 100 200 3000
1000
2000
3000
4000
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60000 50 100 150
dept
h (ft
)
average initial pool temperature (degrees F)
dept
h (m
)
average initial pool temperature (degrees C)
initial reservoir temperaturemean (21.7 C/km)trend extrapolated
Minimum Injection Depth
0
2000
4000
6000
8000
10000
12000
14000
16000
18000
0 5000 10000
0
1000
2000
3000
4000
5000
6000
0 20 40 60 80
dept
h (ft
)
average initial pool pressure (psi)
dept
h (m
)
average initial pool pressure (MPa)
initial reservoir pressure
mean (101% hydrostatic)
anomalous point not considered for trend
Jordan, P.D., and Doughty, C. (2009). Sensitivity of CO2 migration estimation on reservoir temperature and pressure uncertainty. In: Gale, J., Herzog, H., and Braitsch, J. (eds), Greenhouse Gas Control Technologies 9, Proceedings of the 9th International Conference on Greenhouse Gas Control Technologies (GHGT-9), 16–20 November 2008, Washington DC, US, Energy Procedia, February 2009, 1: 2587-2594.
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Minimum Injection Depth
Jordan, P.D., and Doughty, C. (2009). Sensitivity of CO2 migration estimation on reservoir temperature and pressure uncertainty. In: Gale, J., Herzog, H., and Braitsch, J. (eds), Greenhouse Gas Control Technologies 9, Proceedings of the 9th International Conference on Greenhouse Gas Control Technologies (GHGT-9), 16–20 November 2008, Washington DC, US, Energy Procedia, February 2009, 1: 2587-2594.
R² = 0.0022
5 7 9 11 13 15 17 19 21 23
40%
60%
80%
100%
120%
140%
160%
180%
10 15 20 25 30 35 40
geothermal gradient (⁰F/1,000 ft)pr
essu
re g
radi
ent (
% h
ydro
stat
ic)
geothermal gradient (⁰C/km)
<1,200 m (3,940 ft) deep
1,200 - 3,200 m (3,940 - 10,500 ft) deep
>3,200 m (10,500 ft) deep
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Reservoir
Basement
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Leak
age
Path
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Overpressure in leakage path
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Dissipation Interval
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir
CO2
Dissipation Interval
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir
CO2
Dissipation Interval Overpressure in leakage path
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Overpressure in leakage path
Dissipation Interval
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Minimum Injection Depth
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Overpressure in leakage path
Dissipation Interval
Preference for sites with overlying dissipation interval (transmissivity and capillary entry pressure sufficient to fully dissipate overpressures along hypothetical leakage pathways; similar to AZMI, but with specific hydraulic requirements).
Dissipation Interval
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Dissipation Interval Bypass
Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Dissipation Interval
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Seismic Hazard Considerations
Goebel, T. H. W., S. M. Hosseini, F. Cappa, E. Hauksson, J. P. Ampuero, F. Aminzadeh, and J. B. Saleeby (2016), Wastewater disposal and earthquake swarm activity at the southern end of the Central Valley, California, Geophys. Res. Lett., 43, doi:10.1002/2015GL066948.
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Keranen, K. M., H. M. Savage, G. A. Abers, and E. S. Cochran (2013). Potentially induced earthquakes in Oklahoma, USA: Links between wastewater injection and the 2011 Mw 5.7 earthquake sequence. Geology, 41:699-702, doi:10.1130/G34045.1.
Seismic Hazard Considerations
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Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Dissipation Interval
Seismic Hazard Considerations
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Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Overpressure in basement fault
Dissipation Interval
Seismic Hazard Considerations
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Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Dissipation Interval
Damaging earthquake
Seismic Hazard Considerations
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Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Dissipation Interval
Seal
Dissipation Interval
Seismic Hazard Considerations
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Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Dissipation Interval
Seal
Dissipation Interval
Overpressure cutoff along fault
Seismic Hazard Considerations Dissipation Interval
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Capacity Injectivity
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West East Bakersfield
Capacity Injectivity
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West East Bakersfield
Capacity Injectivity
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0%
20%
40%
60%
80%
100%
120%
140%
0.0
0.3
0.6
0.9
1.2
1.5
1.8
2.1
1930 1940 1950 1960 1970 1980 1990 2000 2010
% h
ydro
stat
ic
prod
uctio
n or
inje
ctio
n ra
te (R
m3 /y
ear)
oilproduced waterinjected waterproduced free gasinjected gasnet producedinitial pressurevarious pressures dataidle well median
30%
0.7
Jordan, P., and J. Gillespie (2013). Potential impacts of future geological storage of CO2 on the groundwater resources in California’s central valley: southern San Joaquin basin oil and gas production analog for geologic carbon storage. Prepared for the California Energy Commission. CEC-500-2014-029. 122 p.
Capacity Injectivity
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Capacity Injectivity
Temblor – ~0.5 Mtpa/100 km2
Stevens – ~1.5 Mtpa/100 km2
Vedder – ~2.5 Mtpa/100 km2
+ Aquifer storage projects to date
(including Gorgon) =
Brine production typically needed for power-plant scale injection
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•strategy for detecting and quantifying surface leakage of CO2; •strategy for detecting and monitoring subsurface migration of CO2; •strategy for establishing baseline levels of CO2 emissions; • technology to be used and the relative merits of the technology (i.e., sensitivity and accuracy);
•area to monitor; • frequency of measurement; •spatial coverage in terms of both region and intensity (e.g., number of points per area of ground);
•schedule of monitoring, including phased approaches for different project phases;
•attribution assessment and related monitoring, proxy and/or companion gas monitoring;
•use of gas or groundwater tracers; •determination of how the monitoring program data can best be utilized to provide annual quantification of the amount of CO2 stored;
•definition of and techniques to determine CO2 plume stability.
Monitoring for Quantification
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Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Dissipation Interval
“Positive accounting”
Monitoring for Quantification
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TT
zz
pp
VV
II ∆
+∆
+∆
+∆
=∆
>2% in total
>10% as calculated from porosity and reservoir
volume
Modified from Tek, M. R. (1991). Errors and uncertainty in inventory verification in underground storage. SPE manuscript 23829. 24 pp. Available at https://www.onepetro.org/download/general/SPE-23829-MS?id=general%2FSPE-23829-MS.
>15%
Uncertainty in “positive accounting” >150,000 Mt on 1 MMt for example
Monitoring for Quantification
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Water table
Base of protected groundwater
Aquifer
Seal
Basement
Reservoir CO2
CO2
Dissipation Interval
“Negative accounting”
Seismic detection limit < 10,000 t
Hoversten, M. E. Gasperikova, and S. M. Benson (2005). Theoretical Limits for Seismic Detection of Small Accumulations of Carbon Dioxide in the Subsurface. LBNL Report No. 59080. Presented at GHGT-8, 19-22 June 2006 in Trondheim, Norway.
Monitoring for Quantification
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Recommend “negative accounting”
Monitoring for Quantification
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Monitoring for Quantification
Buoyant phase plume
Inactive well blowout risk greatest
at the plume front
Jordan, P.D., and J. W. Carey (2016). Steam blowouts in California Oil and Gas District 4: Comparison of the roles of initial defects versus well aging and implications for well blowouts in geologic carbon storage projects. Int. J. Greenh. Gas Control , 51:36-47.
Start of chronic well leakage most likely at the plume front
Watson, T. L, and S. Bachu (2007) Evaluation of the potential for gas and CO2 leakage along wellbores. SPE Drilling \& Completion, March:115-126.
Leakage exterior to casing likely results in secondary accumulation,
McKenna, G.T. (1995). Grouted-in installation of piezometers in boreholes. Canadian Geotechnical Journal, 32:355-363.
And likely decreases through time.
Brunet, J.-P.L. , L. Li, Z.T. Karpyn, and N.J. Huerta (2016). Cement fracture opening or self-sealing: critical residence time unifies diverging observations under geological carbon sequestration conditions. Int. J. Greenh. Gas Control 47: 25-37. http://dx.doi.org/10.1016/j.ijggc.2016.01.024
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Monitoring for Quantification
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Plume: remote sensing
Monitoring for Quantification
t = 1
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Plume: remote sensing Plume front: surface geophysics
Monitoring for Quantification
t = 1
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Plume: remote sensing Plume front: surface geophysics Prior wells at plume front: atmospheric, groundwater
Monitoring for Quantification
t = 1
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Plume: remote sensing Plume front: surface geophysics Prior wells at plume front: atmospheric, groundwater Injector(s): atmospheric, groundwater, downhole geophysics
Monitoring for Quantification
t = 1
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Plume: remote sensing Plume front: surface geophysics Prior wells at plume front: atmospheric, groundwater Injector(s): atmospheric, groundwater, downhole geophysics
Monitoring for Quantification t = 2
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Plume: remote sensing Plume front: surface geophysics Prior wells at plume front: atmospheric, groundwater Injector(s): atmospheric, groundwater, downhole geophysics
Monitoring for Quantification t = 3