Geologic Sequestration in Saline Formations Frio Brine ... Papers/05...2 8 9 0. 2 89-3 0 7 0. 3 07-3...

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

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.

OutlineOutline

• Geologic setting• Depositional system and lithology’• Structure• Petrophysical properties• Aquifer model• Conclusions

Regional Geological SettingRegional Geological Setting

Texas Gulf Coast Regional Geologic Setting

Pilot site

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

Pilot Site

OutlineOutline

Injection well Observation well

Top A ss

Top B ss

Top C ss

Injectionzone

Anahuac shale•MFS 43

•MFS 44

•MFS 45

•MFS 47

Upper C Sandstone Core DescriptionUpper C Sandstone Core Description

““C” SANDSTONEC” SANDSTONEISOPACHISOPACH

Pilot area

Frio Sandstone LithologyFrio Sandstone Lithology

•General Frio Lithology•Subarkose( > 70 % quartz, and Feldspar)

OutlineOutline

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

Structure ComponentsStructure Components

Seismic MappingTime structure on top of MFS-43

InjectorMonitor

Salt dome

OutlineOutline

Upper Gulf Coast Frio PorosityUpper Gulf Coast Frio Porosity

-0.109

-0.127

-0.145

-0.163

-0.181

-0.199

-0.217

-0.235

-0.253

-0.271

-0.289

-0.307

-0.325

-0.343

-0.361

-0.379

-0.397

Porosity (fraction)

Injection well core mean

Injection well core range

Permeability DistributionUpper Gulf Coast Frio Formation

Permeability (md)

Geometric mean 243 md

Frio injection well core

Permeability VariabilityPermeability Variability

Dykstra Parson Coefficient Probability Plot: Injection Well Core Data

y = 0.0135x + 2.4089R2 = 0.7005

0 20 40 60 80 100

Probability (%)

DP = 0.15

Permeability-Porosity relationshipUpper Gulf Coast Frio Formation

Porosity - Permeability Relationship

0.000 0.100 0.200 0.300 0.400 0.500Porosity (fraction)

Series1injection well

Vertical/Horizontal Relationship as a Function of Porosity

y = 22.679x - 5.3601R2 = 0.6817

0.24 0.25 0.26 0.27 0.28 0.29 0.3Porosity (fraction)

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

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

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)

Sample 3ASample 2ASample 1A

0.082 md, 0.108 φ

2.74 md, 0.174 φ0.093 md, 0.11 φ

Capillary Pressure CharacterUpper Frio Formation

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)

Clean Sandstone Shaly SandstoneDepth 5051.2Permeability 44.8 mdPorosity 0.244Swi = 0.53

Depth 5051.75Permeability 837 mdPorosity 0.308Swi = 0.08

Comparison of Frio Sgr With Published Data

y = -0.3136Ln(x) - 0.1334R2 = 0.8536

0 0.1 0.2 0.3 0.4 0.5 0.6Porosity (fraction)

Gas Residual saturation to water (fraction)

Frio Barrier bar

Log. (Gas Residual saturation to water(fraction))

N = 143

Relationship Between Natural Gamma and Porosity

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

Sandstone

Liberty Vshale–Porosity ModelLiberty Vshale–Porosity Model

r = – 0.91r = – 0.91

φsc = 0.357 – 0.3824 * Vshφsc = 0.357 – 0.3824 * Vsh

0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1Vshale (fraction)

OutlineOutline

Proportional Cell-Layering Character Applied to Liberty Model

Proportionallayering

Genetic unit(Sequence)Boundaries

A Sandstone

B Sandstone

Upper C

Lower C

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

Net Sandstone Distribution ModelingC Sandstone

C Sandstone

Geologic trend weighting

Bulk volume shaleLow High

Study area

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

Reservoir ModelReservoir Model

Porosity

A sandB sandC sand

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

Geologic Sequestration in Saline Formations Frio Brine ... Papers/05...2 8 9 0. 2 89-3 0 7 0. 3 07-3...

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