Ensuring & Monitoring Secure Storage for Carbon DioxideStorage for Carbon Dioxide
Carbon Capture and Storage (CCS) Projects
Susan D. HovorkaGulf Coast Carbon Center
Bureau of Economic geologyJackson School of GeosciencesThe University of Texas at Austin
Presented to Carbon Capture & SequestrationPublic Workshop, June 10, 2010 Sacramento, CA
Ensuring storage is permanent irequires..
• Characterization and predictiveCharacterization and predictive modeling to select a geologic site that will accept and retain CO2p 2
• Operation of the injection process to conserve site geologic integrity g g g y
Monitoring can be used to document fthe correctness of characterization,
modeling, and operationode g, a d ope at o
Characterization shows where and h CO ill b t d
Capture Land surfacehow CO2 will be stored
Pore scale trapping> 800 m
Pore-scale trapping
Confining system limits CO rise
CO2
limits CO2 rise
Brine displacedInjection ZoneInjection zone
p
Safe Operation of Injection wellsSafe Operation of Injection wells
• Management of wells to These activities areManagement of wells to insure that fluids are retained
These activities are required by federal law for all injection wellsretained
• Management of pressure to insure that
injection wells under the Safe Drinking Water Act of 1974 pressure to insure that
integrity of the geologic system is retainedsystem is retained
Monitoring to test the correctness of characterization modeling andof characterization, modeling, and
operation
• Imaging CO2 in the subsurfaceImaging CO2 in the subsurface• Measuring pressure changes
Tools to assess compositional changes• Tools to assess compositional changesMatch to predictive model
•Surveillance of protected resources
Settings that can be monitored• Atmosphere
– Ultimate receptor but dynamic
Settings that can be monitored
Complex!
Ultimate receptor but dynamic• Biosphere
– Assurance of no damage but dynamic
• Soil and Vadose Zone
AtmosphereBiosphere
V d & il – Integrator but dynamic• Aquifer and USDW
– Integrator, slightly isolated from ecological effects
Ab i j i i i
Aquifer and USDW
Vadose zone & soil
• Above injection monitoring zone– First indicator, monitor small
signals, stable. • In injection zone - plume
Oil field type technologies Will
Seal
Monitoring ZoneComplex!
– Oil-field type technologies. Will not identify small leaks
• In injection zone - outside plume– Assure lateral migration of CO2
Seal
Monitoring Zone
CO2 plume Assure lateral migration of CO2and brine is acceptable
2 p
Monitoring box
Gulf Coast Carbon Center Field Tests
SECARB Phase II&II
Frio I and II Test SiteTexas American Phase II&II
DenburyCranfield
Texas American Resources
SACROCSouthwestSouthwestPartnershipKinderMorganNM Tech
Other projects with strong monitoring programs providemonitoring programs provide
experience• Sleipner, North Sea• Weyburn SaskatchewanWeyburn, Saskatchewan• Nagaoka, Japan
K t i G• Ketzin, Germany• Gaylord, Michigan• In Salah, Algeria• Otway AustraliaOtway, Australia
Example of a research project DOE funded SECARB Phase III at Cranfield, MississippiPhase III at Cranfield, Mississippi
3,000 m depth (10,300 ft)Gas cap, oil ring, downdip water legOriginal production in 1950’sOriginal production in 1950 sStrong water driveShut in since 1965Returned to near initial pressureCO2-EOR initiated 2008 with coincident
pressure monitoringHosted by Denbury Resources
Southern States Energy BoardKen Nemeth Dir, Jerry Hill PI, yBruce Brown NETL manager
Research collaborators: Denbury Onshore LLC site hostLBNL, LLNL, ORNL, USGS NETL, Mississippi State,LBNL, LLNL, ORNL, USGS NETL, Mississippi State, University of Mississippi, Schlumberger, Sandia Technologies, Pinnacle, QEA
Cranfield DAS MonitoringgInjectorCFU 31F1
Obs CFU 31 F2
Obs CFU 31 F3
Above-zonemonitoringF1 F2 F3Closely spaced well
array to examine Above Zone Monitoring
10,500 feet BSL
flow in complex reservoir
Injection Zone
68m
112 m
Cross Well ERT tells us how flow doccurred
sx ec
trode
s
elec
trode
Secondx
x
x
wel
l F3
ele
on w
ell F
2 Resistive plume out of section migration
Direction of CO2 plume x
x serv
atio
n w
Obs
erva
tio
migration
Injectorx 50ft
ObsO
Resistive plume = CO2 in reservoir
Charles Carrigan, LLNL
Fluid flow observed falls in the modeled range
Breakthrough time at F20.4
Set #1 at Ly14 (12/16/2009)
Set #2 at Ly17(12/20/2009)
Set #3 at Ly17(12/8/2009)
Set #4 at Ly10(12/15/2009)Observed CO2 movement
0.2
0.3
atur
atio
n
y ( )
Set #5 at Ly19(12/29/2009)
Set #6 at Ly10(12/23/2009)
Set #7 at Ly10(12/23/2009)
Set #8 at Ly10(12/7/2009)
0.1
Gas
sa y ( )
Set #9 at Ly7(12/7/2009)
Set #10 at Ly10(12/11/2009)
0
12/1/09
12/3/09
12/5/09
12/7/09
12/9/09
12/11/09
12/13/09
12/15/09
12/17/09
12/19/09
12/21/09
12/23/09
12/25/09
12/27/09
12/29/09
12/31/09
1/2/10
1/4/10
1/6/10
Date
Jong-won Choi and JP Nicot BEG
Frio Brine Pilot Sit t tSite tests
Near Houston TX
• High Fresh water (USDW) zoneprotected by surface casing
Permeability – 4.4 to 2.5 Darcys
• Steeply dipping – 11 to 16 degrees
Injection zones:First experiment
2004: Frio “C”Second experiment 11 to 16 degreesp
2006 Frio “Blue”
Oil productionOil production
Injection well
Observation well
Frio Test Site Houston Texas 2004 -2006Frio Test Site, Houston Texas, 2004 -2006
CO2 Saturation Observed with Cross-well S i i T h M d l dSeismic Tomography vs. Modeled
Tom Daley and Christine Doughty LBNL
Pressure as a powerful tool for monitoringp g
Start injection at DAS Dec 1, 2009
I j t BHP Ob ti
e
bar psi
Injector BHP Observation well BHP
e pr
essu
re 400
otto
m h
ole
340Bo
Dec 1
340
It’s all about pressure
Elapsed time
Real-time data from DASReal time data from DAS• Mass flow increased to 507
Injection well BHP 5 818 psiInjection well BHP 5,818 psi BPT injection well 162 degrees F (252 F original)degrees F (252 F original)
Fluid Displacement as a Limit on CapacityCapacity
D d• Depends on boundary
diticonditions
Model –history match pressure at real-time monitoring well
BEG Observation well
at real-time monitoring well14,000 CFU 29-10 CFU 29-12
CFU 26-1 CFU 25-2
CFU 24 2 CFU 29 2Injection ratesResults of 1 year model6000
6,000
8,000
10,000
12,000
ectio
n ra
te (M
scfd
)
CFU 24-2 CFU 29-2CFU 28-1 CFU 27-1CFU 29-4 CFU 48-1
CFU 29-7
jcontinuous pressure data
5500
e (p
si)
-
2,000
4,000
,
7/1/2008 8/20/2008 10/9/2008 11/28/2008 1/17/2009 3/8/2009 4/27/2009 6/16/2009
CO
2 in
je
5000
Pres
sure
Measurement
Date
Rock and fluid properties in simulator
Obs well EGL7
Simplified CO2 injection rate4000
4500Calculated
Modeled pressureMeasured pressure4000
2/22/2008 11/18/2010 8/14/2013 5/10/2016 2/4/2019
Date
p
7/2008 12/2009JP Nicot Jong Won Choi BEG
Assurance Permanence via Phase Trapping the power of capillaryTrapping – the power of capillary
pressure2
of C
O2 Phase-trapped
CO2
ject
ion
G i B i fill d
Inj
Grains Brine – filled pores
Measurement at a Well:Saturation logging (RST ) Observation well to measure
changes in CO saturation – match to modelchanges in CO2 saturation – match to model
Lithology
DEPTHFEET
RST gas sat
Model gas sat.V/V1 0
RST gas satV/V1 0
RST gas satV/V1 0
RST gas satV/V1 0
RST gas satV/V1 0
RST gas sat Log porosity
Model porosityV/V0.4 0
Model permmD10000 1
Day 4 Day 10 Day 29 Day 69 Day 142 Day 474Model gas sat. Model gas sat. Model gas sat. Model gas sat.
LithologyV/V0 1
5010
5000
RST gas sat.V/V1 0
RST gas sat.V/V1 0
RST gas sat.V/V1 0
RST gas sat.V/V1 0
RST gas sat.V/V1 0
RST gas sat.V/V1 0
Log porosityV/V0.4 0
5010
5020
5030
5040
Shinichi Sakurai, Jeff Kane, Christine Doughty
5050
How CO2 dissolved in aquifers ld d licould damage water quality
CO2 dissolves in water = dissolution trappingCO2 dissolves in water = dissolution trappingCO2(g) + H2O ↔ H2CO3(aq) H2CO3(aq) ↔ HCO3(aq)– + H+
HCO (aq)– ↔ CO (aq)-– + H+(aq) Acid= tang in HCO3(aq) ↔ CO3(aq) + H+(aq) gcarbonated water
Acid is buffered by rock-water interactionincrease Ca Mg Fe Na Si HCO SO etc in solutionincrease Ca, Mg, Fe, Na, Si, HCO3, SO4, etc. in solution
What could the etc. be?Mn, As, Pb, Sr, Ni, Zn, Ag, U, Ni, Cd……, , , , , , g, , ,
SACROC- testing fresh water after 35 years large-scale injectiony g j
Smyth, BEG 2009
Fresh water quality at SACROC d dundamaged
• CO2 injection at 6000-7000 ftCO2 injection at 6000 7000 ft • Fresh water at <1000 feet
N t ti iti l h i• No systematic compositional changes in fresh water through time or by comparison t ito region
• However, complex natural and manmade processes in fresh water limit ability to detect CO2, should it leak into fresh water.
Goals of monitoring at a long term, f ll l i l jfull scale commercial project
• Confirm that the predictions of containment made based pon site characterization at the time of permitting are valid
• Confidence to continue injection is gained from monitoring observations that are reasonably close tomonitoring observations that are reasonably close to model predictions
• Confirm that no unacceptable consequences result from injectioninjection.
• Monitoring during injection should be designed to prove-up confinement so that monitoring frequency could be di i i h d th h th lif f th j t d t lldiminished through the life of the project and eventually stopped, allowing the project to be closed.
Gulf Coast Carbon Center (GCCC)Collaborators IA sponsors
BEG Team
Collaborators
BEG Team Scott TinkerIan DuncanSue Hovorka
BEG- CEELBNLLLNL
Tip MeckelJ. P. Nicot
Rebecca SmythRamon Trevino
ORNLUSGSNew Mexico TechMississippi State URamon Trevino
Katherine RomanakChangbing Yang
Dave Carr
Mississippi State UU of MississippiSECARBSWP
Jiemin LuJong Won ChoiWoodong Yung
Carey King students
UT-PGEUT- CCEPUT- DoGSUniv EdinburghCarey King students
and othersUniv Edinburgh
If you use carbon .. Put it backIf you use carbon .. Put it backTo reduce CO2 emissionsto air from stationary (point) sourcesy (p )
is currently burned and emitted to air
CO2 is captured as concentratedhigh pressure fluid by one of severalmethods..emitted to air methods..CO2 is shipped as supercritical fluid via pipeline to a selected, permitted injection site
Carbon extractedfrom a coal or other
CO2 injected at pressure intopore space at depths below and isolated (sequestered)
fossil fuel…below and isolated (sequestered)from potable water.
CO2 stored in pore space over geologicallyover geologicallysignificant time frames.
www.gulfcoastcarbon.org
