Dave Riestenberg Presentation

6/13/11

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Diverse Project Team

Advanced Resources International

SO. STATES ENERGY BOARD

Storage

Transport Capture

Permitting Plant Integration & Construction

Site Host

MMA Activities

Field Operations

Reservoir Modeling

Public education/ outreach

UIC Permitting

Geologic Modeling

Site Prep/ Drilling Contractors

Field Operations

Site Host

Denbury Resources

Denbury Resources

Pipeline Permitting & Construction

Field Operations

Pipeline Design

Mitsubishi Heavy Industries

Design Technology Provider

Advanced Amines

Economic Evaluation

Knowledge Transfer

3rd Party Evaluation

NEPA Preparation

DOE

2 0 40 80 120 160 Miles

MS

Building on a Foundation of Success

Image Source: Google Earth

Ash pond

Ash pond

Coo

ling

wat

er re

circ

ulat

ion

Test Site Obs Well Inj Well

SECARB’s Phase II Mississippi Test Site (Mississippi Power’s Plant Daniel)

•  Established viability of regionally significant

and areally extensive Tuscaloosa Massive Sand for CO2 injection and storage.

•  Built experience and confidence for operating CO2 storage at an operating power plant site.

–  Drilled and characterized two deep wells –  Injected 3,027 tons of CO2 at 180 tons per

day (3 MMcfd), trucked to site.

N

2

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The Anthropogenic Test Is Pursuing Ambitious Objectives

1.  Conduct a fully integrated CCS project (capture, transport and storage)

2.  Test the CO2 flow, trapping and storage mechanisms of the Paluxy Fm., a regionally extensive Gulf Coast saline formation.

3.  Demonstrate how a saline reservoir’s architecture can be used to maximizing CO2 storage and minimize the areal extent of the CO2 plume.

4.  Test the adaptation of commercially available oil field tools and techniques for monitoring CO2 storage (e.g., VSP, cross-well seismic, cased-hole neutron logs, tracers, pressure, etc.)

In support of SECARB’s overall goal - - test and demonstrate safe, secure CO2 injection and storage in regionally significant saline reservoirs - - the Anthropogenic Test has four objectives:

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The Anthropogenic Test Schedule

•  Well drilling operations began in late December 2011

•  Baseline monitoring activities will occur in the summer of 2011

•  CO2 injection operations begin in the third quarter of 2011, continue for 2 to 3 years

•  3 years of post-injection monitoring

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SECARB’s Phase III Anthropogenic Test

Mobile

Alab

ama

Miss

issipp

i

Mobile County

Washington County

CO2 Pipeline

The 25 MW CO2 capture unit at Alabama Power’s (Southern Co.) Plant Barry will become operational in 3Q 2011.

A newly built 12 mile CO2 pipeline will transport CO2 from Plant Barry to the Citronelle Dome.

From 100 to 300 thousand metric tons of CO2 will be injected into the Paluxy saline formation over 2 to 3 years.

Advanced Resources and supporting researchers will conduct 3 years of monitoring after CO2 injection and then close the site.

A Fully Integrated CCS Project

Plant Barry

Citronelle Dome

CO2 Injection Site

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SECARB Phase III: Citronelle Dome Geology and Modeling

“Learning While Doing” Prepared by:

David Riestenberg and Karine Schepers Advanced Resources International, Inc., Knoxville TN

2011 RECS Program

June 10, 2011 Citronelle, AL

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Presentation Plan

1.  Storage permanence –  Select a site with geologic closure (i.e. structural trap)

–  Multiple overlying confining units and secondary storage compartments

–  Condition of existing deep wells

2.  Adequate reservoir injectivity and storage capacity –  Conduct detailed reservoir characterization using existing log and core data

–  Reservoir simulation based on initial dataset

This presentation is divided into two parts. First we discuss the purpose and findings from an initial geologic characterization and simulation based on existing field data. Then we will discuss updates to the geologic model and simulation after drilling a characterization well.

Before we drill a new project well ($$) we would generally like to assess the following CO2 storage related items

8 Source: Esposito et al., 2008

Structural Contour Map of the Top of the Rodessa Formation

A A’

Cross Section from Plant Barry to Citronelle Dome

1. Storage Permanence

Regional data and studies show that the Citronelle Dome is: •  A subtle open fold •  Limbs dipping less than 1 degree •  Four-way structural closure

Modified from: Pashin et al., 2008

Sources: Pashin et al., 2008; Cottingham, 1988; Esposito and others, 2008

Plant Barry

Anthro Test Site

Test Site

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Southeast Alabama Saline Reservoirs and Seals

Confining Zone Injection Zone

•  Target reservoir is the Lower Cretaceous Paluxy Fm (at 9,400’).

•  1,100 foot interval of stacked sandstones and shales.

•  Numerous reservoir seals and confining units (at least 5).

•  No evidence of faulting or fracturing, based on reinterpretation of existing 2D seismic lines.

•  Shallower saline reservoirs are promising but condition of existing wells precludes their use in this test

The Anthropogenic Test’s CO2 Storage Site

1. Storage Permanence (Cont.)

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•  Sand continuity mapping to determine “open” or “closed” sand intervals.

•  Detailed analysis of over 80 well logs for porosity and depositional style.

•  Regional core data for porosity and permeability.

•  340 net feet of sand at injector •  What about porosity and

permeability?

2. Injectivity and Capacity

Establishing Reservoir Properties for Paluxy Saline Formation

01-097-19866-00-00CITRONELLE SE UNIT #D-9-7

9200(-9035)

9300(-9135)

9400(-9235)

9500(-9335)

9600(-9435)

9700(-9535)

9800(-9635)

9900(-9735)

10000(-9835)

10100(-9935)

10200(-10035)

10300(-10135)

10400(-10235)

10500(-10335)

10600(-10435)

10700(-10535)

10800(-10635)

LogDepth(ft)

LogDepth(ft)

9100 9100

9200 9200

9300 9300

9400 9400

9500 9500

9600 9600

9700 9700

9800 9800

9900 9900

10000 10000

10100 10100

10200 10200

10300 10300

10400 10400

10500 10500

10600 10600

10700 10700

10800 10800

Citronelle_Project

HS=1

PETRA 12/21/2009 11:57:31 AM

9500

9400

9700

9600

9900

9800

10100

10000

10300

10200

10500

10400

Citronelle SE Unit # D-9-7 Log Depth (ft)

Top of Paluxy

‘Upper Paluxy’

‘Middle Paluxy’

‘Lower Paluxy’ Top of Mooringsport

Sand Layer 10060

Sand Layer 9620

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– 84 spontaneous potential/resistivity logs available in and around the Citronelle SE Unit.

•  Few porosity logs available in the field – Porosity was calculated from resistivity logs

using Archie water saturation model and basic log analysis assumptions

– Regional Paluxy core data that appear to represent similar rock types were used to correlate permeability to porosity

•  Cores are from the Tensaw Lake, Latham and Pleasant Home fields, ~ 20 miles east of Citronelle

2. Injectivity and Capacity Paluxy Porosity and Permeability

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Resistivity-Porosity Algorithm (Archie)

φ  = porosity Rt = formation resistivity (from deep resistivity log) Rw = formation water resistivity (known or assumed) Sw = water saturation (known or assumed) n = ‘saturation exponent’ (assumed or measured from core) m = ‘cementation exponent’ (assumed or measured from core) a = ‘tortuosity exponent’ (assumed or extrapolated from core tests)

m

nw

w

t SRRa

1

⎥⎥⎥⎥⎥

⎦

⎤

⎢⎢⎢⎢⎢

⎣

⎡

⎟⎟⎠

⎞⎜⎜⎝

⎛=φ


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•  Lower trend line (A) represents assumed damaged sidewall core permeability.

•  Higher trend line (B) represents assumed non-damaged sidewall core permeability.

Similar to most saline formations, no data existed on the permeability of the Paluxy Fm at the storage site.

To provide a “first order” assessment of permeability, we compiled sidewall core data for the Paluxy Fm from numerous areas in Alabama to develop a cross-plot of porosity versus permeability:

Establishing Adequate Permeability Cross-Plot of Porosity vs. Permeability

y = 0.013e0.377x

y = 0.02e0.425x

1

10

100

1000

10000

10 15 20 25 30 35

Porosity (%)

Air

Perm

eabi

lity

(mill

idar

cies

)

A

B

2. Injectivity and Capacity (Cont.)

Data provided by the Geological Survey of Alabama

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–  Paluxy resistivity derived porosities range from 17 to 22%

•  Porosity is highest in the ‘Upper’ sands

•  Thickness weighted average is 19%

–  Permeability ranges from 28 to 246 mD

•  Thickness weighted average is 88 md

‘Upper’

Paluxy

‘Middle’ Paluxy

‘Lower’

Paluxy


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CO2 Injector (Near Well D9-7)

•  340 net feet of sand

•  Average porosity of 19%

•  Average permeability of 90 md

•  Normal pressure and temperature gradients

Based on detailed characterization of the thick Paluxy sand/shale interval, we selected 17 sand units for CO2 injection:

Building the Geologic Model

2. Injectivity and Capacity (Cont.) Reservoir Simulation

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Understanding CO2 Flow and Optimizing Storage Capacity

•  Areal extent of CO2 will be limited (~1,000 ft) by injection into multiple sand layers.

•  Low dip results in a near-circular plume and little post CO2 injection up-dip migration.

The information from detailed reservoir characterization was used to model and optimize the CO2 plume:

3D ViewX-sectional View

GasInj1 Well


GasInj1 Well3D ViewX-sectional View

6,000 7,000 8,000 9,000 10,000 12,000 14,000 16,000 18,000 20,000

6,000 7,000 8,000 9,000 10,000 12,000 14,000 16,000 18,000 20,0009,2009,300

9,4009,500

9,6009,700

9,8009,900

10,00010,10010,20010,30010,400

9,10

09,

200

9,30

09,

400

9,50

09,

600

9,70

09,

800

9,90

010

,000

10,1

0010

,200

10,3

00

0.00 0.25 0.50 0.75 1.00 mile

0.00 0.25 0.50 0.75 1.00 km

File: Citronelle_new_geol3.irfUser: computation7Date: 7/9/2010Scale: 1:27784Z/X: 10.00:1Axis Units: ft

0.08

0.17

0.26

0.35

0.44

0.54

0.63

0.72

0.81

0.91

1.00

Gas Saturation 2014-01-01 J layer: 28

GasInj1 Well


6,000 7,000 8,000 9,000 10,000 12,000 14,000 16,000 18,000 20,000

6,000 7,000 8,000 9,000 10,000 12,000 14,000 16,000 18,000 20,0009,2009,300

9,4009,500

9,6009,700

9,8009,900

10,00010,10010,20010,30010,400

9,10

09,

200

9,30

09,

400

9,50

09,

600

9,70

09,

800

9,90

010

,000

10,1

0010

,200

10,3

00

0.00 0.25 0.50 0.75 1.00 mile

0.00 0.25 0.50 0.75 1.00 km

File: Citronelle_new_geol3.irfUser: computation7Date: 7/9/2010Scale: 1:27784Z/X: 10.00:1Axis Units: ft

0.08

0.17

0.26

0.35

0.44

0.54

0.63

0.72

0.81

0.91

1.00

Gas Saturation 2014-01-01 J layer: 28

GasInj1 Well

X-Sectional View of CO2 Plume

CO2 Injection Well

3D View of CO2 Plume

CO2 Injection Well

Modeling the CO2 Plume

2. Injectivity and Capacity (Cont.) Reservoir Simulation

CO2 Saturation (v/

v)

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Project Area of Review

Proposed Injector (D-9-7 #2)

Proposed Inj/Obs Well (D-9-9#2)

New Characterization Well (D-9-8#2)

Modeled Plume Area (AOR)

Existing wells within the Area of Review are on good condition

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Initial Characterization and Modeling Conclusions

•  Storage permanence –  Test site has 4-way geologic closure, unfaulted –  Multiple overlying confining units and secondary storage

compartments •  Adequate reservoir injectivity and storage

capacity –  Reservoir characterization using existing log and core

data suggests Paluxy has capacity –  Initial reservoir simulation shows adequate injectivity,

plume is confined in areal extent •  Now let’s drill a well and get more data!

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•  Well drilled to 11,800’ TD (spud to TD) in 30 days and under budget.

•  Well was cased and cemented in January 2011.

•  Whole and sidewall cores, geophysical well logs

•  Well will be used as an observation/monitoring well

At the end of December 2010, we began drilling the Anthropogenic Test characterization well

Anthropogenic Test Characterization Well (D-9-8 #2)

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•  Recovered extensive Paluxy Formation whole core (98 feet in two intervals)

•  62 Whole core plugs tested •  Recovered a total of 45 percussion sidewall cores from:

•  Overlying confining units, •  Overlying saline reservoirs •  Paluxy Formation

•  Ran full set of well logs (quad combo, array gamma, MRI, mineralogy, dipole sonic, etc.).

Data Collection at D-9-8#2

Top Paluxy

Base Paluxy

Confining Zone

Above-Zone Monitoring

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D-9-8#2 Sidewall Core; What is it Good For?

Sidewall cores can be used to acquire reasonable porosity values for sandstone intervals and confirm lithology for shales. Unreliable for permeability.

9,210 ft Shale

Sample Depth (ft)

Porosity (%)

Lithology

9,120 23.5 SS, fine-grained




Top Paluxy

Confining Zone

Above-Zone Monitoring

9,318 ft Siltstone-Shale

Above-Zone Monitoring Sand Properties

Confining Zone Lithology

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9,390 ft 9,400 ft

Notable Features: •  Fine to coarse grained

sandstone •  Heavily burrowed •  Rip-up clay pebbles •  Root zones •  Prominent cross

laminations •  Multiple soil horizons •  Upper sands are oxidized

(red color) •  Lower sands are not

oxidized

Paluxy Whole Core #1

9,410 ft 9,450 ft

9,450 ft

Top of Px

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9350

9400

9450

9500

9550

Porosity Range: 6-18% Permeability Range: 1 – 50 md Porosity Average: 13 % Permeability Average: 8 md

Porosity Range: 6-23% Permeability Range: 1 – 3,800 md Porosity Average: 18% Permeability Average: 440 md

Porosity Range: 8-22% Permeability Range: 1 – 1,900 md Porosity Average: 18% Permeability Average: 500 md

Porosity and Permeability Ranges, Core #1

Medium to coarse grained sandstones of the upper Paluxy appear to represent excellent CO2 injection targets

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10,440 ft

Notable Features: •  Fine to medium grained

sandstone •  Heavily burrowed •  Rip-up clay pebbles •  Root zones •  Prominent cross

laminations •  Soil horizons •  Pebble conglomerates at

the Paluxy base

Paluxy Whole Core #2

10,460 ft

10,482 ft

Base of Px

10,450 ft

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Porosity Range: 3-19% Permeability Range: 0.05 – 85 md Porosity Average: 12% Permeability Average: 20 md

Porosity Range: 3-18% Permeability Range: 0.005 – 50 md Porosity Average: 14% Permeability Average: 15 md

Porosity and Permeability Ranges, Core #2

Fine to medium grained sandstones of the lower Paluxy appear to represent a marginal CO2 injection target

Base of Px

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•  Calculated sand thickness using new log data.

•  New results suggest Paluxy reservoir thickness of:

278.5 ft of 50% clean sand •  Sand thickness estimates made

using old logs (310 ft) appear to be acceptable

•  However there were notable individual exceptions

Upper Paluxy Sands

Confirming Storage Capacity (Thickness)

SP Induction

Note: thickness values are in feet

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60+

feet

20 to

40

feet

?

Confirming Storage Capacity (Thickness)

•  Previous slide showed comparison of vintage and new logs for the Upper Paluxy •  The basal Paluxy sandstone (one of our whole core targets) appears to be of

lower quality (thickness and vertical continuity) than the old log would indicate

D-9-8#1 Vintage Spontaneous Potential

D-9-8#2 Well Log

10,400 ft

10,500 ft

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Confirming Storage Capacity (Porosity)

Porosity log data and core data were used to develop a Paluxy sandstone porosity curve

•  Averaged porosity of the Paluxy Formation sandstones using this approach is 18.9 %

•  This estimate compares quite well with the prior sandstone estimate of 19%

9380

9390

9400

9410

9420

9430

9440

9450

0 5 10 15 20 25 30

Porosity (%)

Log

Dep

th (f

t)

Porosity Curve Whole Core Data

9,300

9,400

9,500

9,600

9,700

9,800

9,900

10,000

0 10 20 30

Porosity (%)

Log

Dep

th (f

t)

Porosity Curve

Whole Core Data

Who

le C

ore

#1

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Confirming Reservoir Injectivity (Permeability)

Phi (%)

Upper Paluxy SS Perm (md)

Lower Paluxy SS Perm (md)

22 3,000 n/a

20 670 80

18 150 20

16 30 5

14 7 1

12 2 0.3

10 0.4 0.1

Permeability Strongly Correlated to Porosity and Grain Size

Equivalent liquid perm

Upper Core Porosity and Permeability Relationship

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Updating the Geocellular Model


GasInj1 Well


GasInj1 Well

3D View of CO2 Plume End of Injection

Original Model Updated Model

•  The formation’s large net sand thickness (213 feet) and permeability (258 md), easily allow the injection of 9.45 million scf per day of CO2, for three continuous years, into the Paluxy.

•  New model now shows plume extent nearly 1,700 ft due to higher permeability in upper Paluxy sandstones

•  Model plume extent was 1,000 ft radius in original model

•  Note: highest perm sand is actually uncompleted in this version

•  Necessitates updated Area of Review

CO2 Saturation (v/v)

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Injec&on Forecast (cont’d) CO2 Plume Migra&on

GasInj1

284,000 285,000 286,000 287,000 288,000 289,000

284,000 285,000 286,000 287,000 288,000 289,000

387,000388,000

389,000390,000

387,

000

388,

000

389,

000

390,

000

0.08

0.18

0.28

0.39

0.49

0.59

0.69

0.80

0.90

1.00

SECARB Phase 3 - Plant Barry

GasInj1

284,000 285,000 286,000 287,000 288,000 289,000

284,000 285,000 286,000 287,000 288,000 289,000

387,000388,000

389,000390,000

387,

000

388,

000

389,

000

390,

000

0.08

0.18

0.28

0.39

0.49

0.59

0.69

0.80

0.90

1.00

SECARB Phase 3 - Plant BarryGasInj1

284,000 285,000 286,000 287,000 288,000 289,000

284,000 285,000 286,000 287,000 288,000 289,000

387,000388,000

389,000390,000

387,

000

388,

000

389,

000

390,

000

0.08

0.18

0.28

0.39

0.49

0.59

0.69

0.80

0.90

1.00


2,530f t

2,530f t

CO2 Saturation (v/v)

GasInj1

284,000 285,000 286,000 287,000 288,000 289,000

284,000 285,000 286,000 287,000 288,000 289,000

387,000388,000

389,000390,000

387,

000

388,

000

389,

000

390,

000

0.08

0.18

0.28

0.39

0.49

0.59

0.69

0.80

0.90

1.00


1,730f t

1,730f t

(a)

(c)

(b)

(d)

2,930f t

2,930f t 3,330f t

3,330f t

CO2 Plume Extent a) 1 Year; b) 2 Years ; c) 3 Years ; d) 10 Years After

Injection Started

Injec.on into mul.ple sand layers results in a plume of limited areal extent (plume occupies approximately 200 acres ten years a<er injec.on opera.ons have ceased).

The maximum movement of the CO2 is about 1,700 feet up-‐dip in the westward direc.on.

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Injec&on Forecast (cont’d)

Pressure Build-‐up at End of Injec&on

The maximum increase (362 psi) occurs as expected in the gridblock where the injector is located. The overall radius of significant pressure buildup (greater than 5 percent of the na.ve reservoir pressure, or greater than 50 psi) is 1,330 < at the end of the injec.on period.

Pressure buildup (pressure increase at the end of injection compared to initial conditions) in the top sand layer (sand 9460)

Pressure Increase from Ini.al Condi.ons (psia)

GasInj1

280,000 290,000

280,000 290,000

390,000 390,

000

400,

000

0.00 0.50 1.00 miles

0.00 0.50 1.00 km File: Citronelle_Feb2011_h_PhiK_refined_noInj9620.irfUser: computation7Date: 4/21/2011Scale: 1:48163Y/X: 1.00:1Axis Units: ft

43

78

113

148

183

218

253

288

323

358

393

SECARB Phase 3 - Plant BarryPressure_BU_endinj 2012-01-01 K layer: 1

(9% of na.ve pressure)


GasInj1

280,000 290,000

280,000 290,000

390,000 390,

000

400,

000

0.00 0.50 1.00 miles


43

78

113

148

183

218

253

288

323

358

393


1mile radius

GasInj1

284,000 285,000 286,000 287,000 288,000

284,000 285,000 286,000 287,000 288,000

387,000388,000

389,000390,000

387,

000

388,

000

389,

000

390,

000

0.00 585.00 1170.00 feet

0.00 180.00 360.00 meters File: Citronelle_Feb2011_h_PhiK_refined_noInj9620.irfUser: computation7Date: 4/21/2011Scale: 1:9183Y/X: 1.00:1Axis Units: ft

43

78

113

148

183

218

253

288

323

358

393


2,667<

2,667<

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Injec&on Forecast (cont’d) Pressure Build-‐up Three Years aAer End

of Injec&on

As a result of the high transmissivity and lateral extent of the Paluxy forma.on’s sandstones, the resultant simula.on model indicates very liQle pressure gain in the reservoir and a rapid return to near na.ve pressure a<er the injec.on opera.ons are completed.

Pressure buildup in the top sand layer (sand 9460) three years after the end of the injection.

Pressure Increase from Ini.al Condi.ons (psia)



GasInj1

280,000 290,000

280,000 290,000

390,000 390,

000

400,

000

0.00 0.50 1.00 miles


43

47

52

56

60

65

69

73

77

82

86

SECARB Phase 3 - Plant BarryPressure_BU_1yr_endInj 2012-01-01 K layer: 1

GasInj1

280,000 290,000

280,000 290,000

390,000 390,

000

400,

000

0.00 0.50 1.00 miles


43

47

52

56

60

65

69

73

77

82

86


1mile radius

GasInj1

283,000 284,000 285,000 286,000 287,000 288,000 289,000

283,000 284,000 285,000 286,000 287,000 288,000 289,000

387,000388,000

389,000390,000

387,

000

388,

000

389,

000

390,

000

391,

000

0.00 790.00 1580.00 feet

0.00 240.00 480.00 meters File: Citronelle_Feb2011_h_PhiK_refined_noInj9620.irfUser: computation7Date: 4/21/2011Scale: 1:12370Y/X: 1.00:1Axis Units: ft

43

47

52

56

60

65

69

73

77

82

86


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Monitoring within and Beyond the Updated AoR D-4-13 and/or D-4-14 In-zone montoring Above-zone monitoring Fluid sampling

D-9-11 Neutron Logging

Proposed Injector Injection Surveys Downhole Pressure

Proposed Inj/Obs Well Neutron logging Crosswell seismic (source)

New Characterization Well Neutron logging MBM (in-zone pressure, fluid sampling, seismic, temp)

UPDATED AOR

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Next Steps •  Revisit geologic model - Relatively thin nature of shale “interbeds” within sandstone units suggests major upper Paluxy sands may be more continuous than assumed in initial mapping. Channel sand interpretation informs new interpretations.

•  Flow Units - Vary porosity and permeability within sandstones in model. Good porosity-perm relationship gives us confidence here.

•  Update Model Trapping Mechanisms – incorporate core CO2-brine relative permeability and capillary pressure data into model.

•  Mineralogy Data – Update sandstone mineralogy using core XRD and thin section analysis results (more important for long-term fate prediction?).

•  Take more core while drilling injectors!

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Structure1

2’

1’

2

Dave Riestenberg Presentation

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