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Geologic Sequestration in Saline Formations Frio Brine Storage Pilot Project, Gulf Coast, Texas
GCCC Digital Publication Series #05-04g
M. H. Holtz K. Fouad P. Knox
S. Sakurai J. Yeh
Cited as: Holtz, M.H., Fouad, K., Knox, P., Sakurai, S., and Yeh, J., Geologic sequestration in saline formations: Frio Brine Storage Pilot project, Gulf Coast, Texas: presented at the National Energy Technology Laboratory Fourth Annual Conference on Carbon Capture and Sequestration, Alexandria, Virginia, May 2-5, 2005. GCCC Digital Publication Series #05-04g, pp. 1-34.
Keywords: Frio Depositional Systems, Sandstone Lithology, Seismic Mapping, Property Distribution, Interpolation
Bureau of Economic GeologyGeologic Sequestration in Saline Formations
Frio Brine Storage Pilot Project, Gulf Coast Texas
Geologic Sequestration in Saline Geologic Sequestration in Saline FormationsFormations
Frio Brine Storage Pilot Project, Gulf Frio Brine Storage Pilot Project, Gulf Coast TexasCoast Texas
Mark H. Holtz ,Khaled Fouad, Paul Knox, Shinichi Sakurai,Mark H. Holtz ,Khaled Fouad, Paul Knox, Shinichi Sakurai,and Joseph Yehand Joseph Yeh
Gulf Coast Carbon CenterGulf Coast Carbon Center
The University of Texas at AustinThe University of Texas at Austin
Bureau of Economic Geology
Frio Brine Pilot :Tapping the Potential for Large Volume Sequestration
Frio Brine Pilot :Tapping the Potential for Large Volume Sequestration
Project Goal: Early success in a high-permeability, high-volume sandstone representative of a broad area that is an ultimate target for large-volume sequestration.
•Demonstrate that CO2 can be injected into a brine formation without adverse health, safety, or environmental effects.
•Determine the subsurface distribution of injected CO2 using diverse monitoring technologies.
•Demonstrate validity of conceptual models.
•Develop experience necessary for success of large-scale CO2 injection experiments.
Bureau of Economic Geology
OutlineOutline
• Geologic setting• Depositional system and lithology’• Structure• Petrophysical properties• Aquifer model• Conclusions
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Regional Geological SettingRegional Geological Setting
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Texas Gulf Coast Regional Geologic Setting
Texas Gulf Coast Regional Geologic Setting
Pilot site
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Shelf, prodelta, and upper slope
Basinward limit of Frio paleomargin
Slope system
Major fluvial axis
Minor fluvial axis
Shore-zone system
Delta systemFloodplain and lacustrine
Greta/CarancahuaBarrier/Strandplain System
Modified from Galloway (1986)
0 100 mi
Frio Depositional SystemsTexas Gulf Coast
Frio Depositional SystemsTexas Gulf Coast
Pilot Site
Bureau of Economic Geology
OutlineOutline
• Geologic setting• Depositional system and lithology’• Structure• Petrophysical properties• Aquifer model• Conclusions
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Injection well Observation well
Top A ss
Top B ss
Top C ss
Injectionzone
Anahuac shale•MFS 43
•MFS 44
•MFS 45
•MFS 47
Bureau of Economic Geology
Bureau of Economic Geology
Upper C Sandstone Core DescriptionUpper C Sandstone Core Description
Rew
orke
d flu
vial
cha
nnel
Dis
tribu
tary
chan
nel
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Bureau of Economic Geology
““C” SANDSTONEC” SANDSTONEISOPACHISOPACH
Pilot area
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Frio Sandstone LithologyFrio Sandstone Lithology
•General Frio Lithology•Subarkose( > 70 % quartz, and Feldspar)
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OutlineOutline
• Geologic setting• Depositional system and lithology’• Structure• Petrophysical properties• Aquifer model• Conclusions
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Reconnaissance: Seismic Resolution
•Area of 3-D: •Square Miles: 13.46•Acres: 8600•Shot in the early 1990’s•Dynamite source•Bin Size: 82.5 X 82.5 ft
•Resolution:•Max Freq: 80 Hz•Tuning thickness: 43 ft
•Calibration:•2 sonic logs•One Check shot
•Surfaces Mapped•Top of Anahuac•Base o Anahuac•Maximum flooding surface 47
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Structure ComponentsStructure Components
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Seismic MappingTime structure on top of MFS-43
Seismic MappingTime structure on top of MFS-43
InjectorMonitor
Salt dome
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OutlineOutline
• Geologic setting• Depositional system and lithology’• Structure• Petrophysical properties• Aquifer model• Conclusions
Bureau of Economic Geology
Upper Gulf Coast Frio PorosityUpper Gulf Coast Frio Porosity
0
50
100
150
200
250
300
0.091
-0.109
0.109
-0.127
0.127
-0.145
0.145
-0.163
0.163
-0.181
0.181
-0.199
0.199
-0.217
0.217
-0.235
0.235
-0.253
0.253
-0.271
0.271
-0.289
0.289
-0.307
0.307
-0.325
0.325
-0.343
0.343
-0.361
0.361
-0.379
0.379
-0.397
Porosity (fraction)
Num
ber o
f Sam
ples
Injection well core mean
Injection well core range
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Permeability DistributionUpper Gulf Coast Frio Formation
Permeability DistributionUpper Gulf Coast Frio Formation
0
100
200
300
400
500
600
700
800
Permeability (md)
Geometric mean 243 md
Frio injection well core
Bureau of Economic Geology
Permeability VariabilityPermeability Variability
Dykstra Parson Coefficient Probability Plot: Injection Well Core Data
y = 0.0135x + 2.4089R2 = 0.7005
00.5
11.5
22.5
33.5
4
0 20 40 60 80 100
Probability (%)
Log
k
DP = 0.15
Bureau of Economic Geology
Permeability-Porosity relationshipUpper Gulf Coast Frio Formation
Permeability-Porosity relationshipUpper Gulf Coast Frio Formation
Porosity - Permeability Relationship
10
100
1000
10000
0.000 0.100 0.200 0.300 0.400 0.500Porosity (fraction)
Perm
eabi
lity
(md)
Series1injection well
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Vertical/Horizontal Relationship as a Function of Porosity
Vertical/Horizontal Relationship as a Function of Porosity
y = 22.679x - 5.3601R2 = 0.6817
0.2
0.4
0.6
0.8
1
0.24 0.25 0.26 0.27 0.28 0.29 0.3Porosity (fraction)
kV/k
H
kV/kH Arith. Mean: 0.622Porosity (Boyle's law) Arith. Mean: 0.2638kV/kH geo. Mean: 0.5602
Porosity is 0.28; when the ratio equals 1.0
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Anahuac Shale CharacterAnahuac Shale Character
•Entry pressure nearly 4,000 psi•Bulk Mineralogy
•41 % clay• 28 % quartz•20 % calcite•12% other
•Clay Mineralogy•75 % illite/smectite• 11 % illite &mica•11 % kaolinite•3% chlorite
0
10,000
20,000
30,000
40,000
50,000
60,000
0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00
Wetting phase saturation (fraction)
Cap
illar
y pr
essu
re (p
si)
Sample 3ASample 2ASample 1A
0.082 md, 0.108 φ
2.74 md, 0.174 φ0.093 md, 0.11 φ
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Capillary Pressure CharacterUpper Frio Formation
Capillary Pressure CharacterUpper Frio Formation
0.00
1000.00
2000.00
3000.00
4000.00
5000.00
6000.00
0.000 0.100 0.200 0.300 0.400 0.500 0.600 0.700 0.800 0.900 1.000
Wetting phase saturation (fraction)
Pres
sure
(psi
)
Clean Sandstone Shaly SandstoneDepth 5051.2Permeability 44.8 mdPorosity 0.244Swi = 0.53
Depth 5051.75Permeability 837 mdPorosity 0.308Swi = 0.08
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Comparison of Frio Sgr With Published Data
Comparison of Frio Sgr With Published Data
y = -0.3136Ln(x) - 0.1334R2 = 0.8536
0
0.2
0.4
0.6
0.8
1
0 0.1 0.2 0.3 0.4 0.5 0.6Porosity (fraction)
Res
idua
l gas
sat
urat
ion
(frac
tion)
Gas Residual saturation to water (fraction)
Frio Barrier bar
Log. (Gas Residual saturation to water(fraction))
N = 143
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Relationship Between Natural Gamma and Porosity
Relationship Between Natural Gamma and Porosity
0
0.05
0.1
0.15
0.2
0.25
0.3
0.35
0.4
0.00 10.00 20.00 30.00 40.00 50.00 60.00 70.00 80.00 90.00 100.00
Core gamma ray
Poro
sity
(fra
ctio
n)
Shale
Sandstone
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Liberty Vshale–Porosity ModelLiberty Vshale–Porosity Model
r = – 0.91r = – 0.91
φsc = 0.357 – 0.3824 * Vshφsc = 0.357 – 0.3824 * Vsh
0
0.05
0.1
0.15
0.2
0.25
0.3
0.35
0.4
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1Vshale (fraction)
Shal
e co
rrec
ted
poro
sity
(fra
ctio
n)
Bureau of Economic Geology
OutlineOutline
• Geologic setting• Depositional system and lithology’• Structure• Petrophysical properties• Aquifer model• Conclusions
Bureau of Economic Geology
Proportional Cell-Layering Character Applied to Liberty Model
Proportional Cell-Layering Character Applied to Liberty Model
Proportionallayering
Genetic unit(Sequence)Boundaries
A Sandstone
B Sandstone
Upper C
Lower C
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Property DistributionProperty Distribution
Adds direction to intragenetic-unit heterogeneity
1) Geologic template (object modeling)1) Gross sandstone thickness2) Facies template3) Net pay thickness
2) Trend weighting1) High-percentage weighting is applied to primary
direction2) Low-percentage weighting is applied to
secondary direction
Bureau of Economic Geology
Net Sandstone Distribution ModelingC Sandstone
C Sandstone
Geologic trend weighting
Bulk volume shaleLow High
Study area
Bureau of Economic Geology
Basic Attribute InterpolationBasic Attribute Interpolation
Key attribute model(1) Interpolate one key attribute(2) Calculate remaining attributes on the basis of
key attributeVsh is key attribute used
(1) Other attributes derived for key attribute• Porosity• Absolute horizontal permeability• Absolute vertical permeability• Residual gas saturation
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Reservoir ModelReservoir Model
Porosity
A sandB sandC sand
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SummarySummary
• Test site is a highly faulted, steeply dipping, fluvial-deltaic environment.
• Sandstone is a subarkose– moderately sorted – fine grained– Poorly cemented
• Reservoir quality is dependent on bulk volume shale– Clean sandstones are highly porous and permeable
• Shale is Illite/Smectite mix• Residual saturation modeled as a function of porosity• Pilot site is typical of the Upper Gulf Coast Frio