THE SECARBTHE SECARB ANTHROPOGENIC TEST:

The First U.S. Integrated CO2 Capture, Transportation and Storage Testg

George Koperna, Jr., Vello Kuuskraa, and David Riestenberg, Advanced Resources International, Inc.

Richard Rhudy and Robert Trautz, Electric Power Research Institute

Dr. Richard EspositoSouthern CompanyDr Gerald HillDr. Gerald Hill

Southern States Energy Board

28th Annual International Pittsburgh Coal ConferenceSeptember 12-15, 2011

AcknowledgementThis presentation is based upon work supported by the Department of Energy NationalEnergy Technology Laboratory under DE-FC26-05NT42590 and was prepared as an account

Acknowledgement

gy gy y p pof work sponsored by an agency of the United States Government. Neither the United StatesGovernment nor any agency thereof, nor any of their employees, makes any warranty,express or implied, or assumes any legal liability or responsibility for the accuracy,completeness, or usefulness of any information, apparatus, product, or process disclosed, orp , y , pp , p , p ,represents that its use would not infringe privately owned rights. Reference herein to anyspecific commercial product, process, or service by trade name, trademark, manufacturer, orotherwise does not necessarily constitute or imply its endorsement, recommendation, orfavoring by the United States Government or any agency thereof. The views and opinions ofg y y g y pauthors expressed herein do not necessarily state or reflect those of the United StatesGovernment or any agency thereof.

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Presentation Outline

1. The Goals, Objectives and Plans for the Anthropogenic TestAnthropogenic Test

2. Project Design• Capture• Transport• Storage

3 Geologic Assessment3. Geologic Assessment• Detailed Reservoir Characterization• Conducting Rigorous Reservoir Modelingg g g

4. CO2 Monitoring, Verification and Accounting5. Permitting

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6. Integrated Test Plan

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1. The Anthropogenic Test Is Pursuing A biti G l d Obj tiAmbitious Goals and Objectives

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:

1. Support a fully integrated, commercial prototype CCS project (capture, transport and storage)

2 Test the CO flow trapping and storage mechanisms of a regionally2. Test the CO2 flow, trapping and storage mechanisms of a regionally extensive Gulf Coast saline formation.

3. Demonstrate how a saline reservoir’s architecture can be used to maximize CO2 storage and minimize the areal extent of the CO2maximize CO2 storage and minimize the areal extent of the CO2plume.

4. Test the adaptation of commercially available oil field tools and techniques for monitoring CO2 storage (e.g., VSP, cross-well seismic,

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2cased-hole neutron logs, tracers, pressure, etc.)

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SECARB’s Phase III Anthropogenic Testp g

Washington County

Th 25 MW CO t it t

Project Schedule and Milestones

The 25 MW CO2 capture unit atAlabama Power’s (Southern Co.) PlantBarry became operational in 3Q 2011.

A newly built 12 mile CO pipeline to

Core Area of Citronelle Dome

CO2 Injection Site

ama

sippi CO2 Pipeline

A newly built 12 mile CO2 pipeline totransport CO2 from Plant Barry to theCitronelle Dome is under construction.

A characterization well was drilled in

Alab

a

Miss

iss

Mobile County

A characterization well was drilled in1Q 2011 to confirmed geology

From 100 to 300 thousand metric tonsof CO will be injected into a saline

Plant Barry

of CO2 will be injected into a salineformation (Paluxy Fm) over 2 to 3 years.

Advanced Resources and supportingresearchers will conduct 3 years of

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Mobile

researchers will conduct 3 years ofmonitoring after CO2 injection and thenclose the site.

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The Anthropogenic Test ScheduleThe Anthropogenic Test Schedule

• Well drilling operations began in late December 2011g p g

• 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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6

6

Diverse Project TeamStStorage

Capture DOE

SO. STATES ENERGY BOARDTransport

p

Permitting Plant Integration& Construction

SiteHost

Mitsubishi Heavy NEPA Preparation

Advanced ResourcesInternational

Industries

Design TechnologyProvider

AdvancedAmines

NEPA Preparation

MMAActivities

FieldOperations

ReservoirModeling

Publiceducation/outreach

UICPermitting

GeologicModeling

DenburyResources

DenburyResources

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Site Prep/DrillingContractors

FieldOperations

SiteHost

PipelinePermitting &Construction

FieldOperations

PipelineDesign

EconomicEvaluation

KnowledgeTransfer

3rd PartyEvaluation

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2. Project Design –Capture and Compression

• Scope: Demonstrate 25 MW equivalent post-combustion capture of CO2 from Plant B fl i MHI’ d d i (KS 1 l t)Barry flue gas using MHI’s advanced amine (KS-1 solvent) process

• Objectives:– Demonstrate integrated CO2 capture under realistic coal-fired plant operating conditions

– Economics: Establish realistic values for the energy penalty and implementation costs

– Test reliability of solvent-based capture

• Status:– Engineering and procurement completed in July 2010

– First shipment to Plant Barry in September 2010

– Capture unit reached full operational capacity in June 2011– Capture unit reached full operational capacity in June 2011• Capture rates of up to 650 metric tonnes per day

• Over 33,000 metric tonnes captured to date

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2. Project Design –Capture and Compression

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2. Project Design – Transportation• A 4” diameter 12 mile long pipeline (X70 carbon steel) will be used to transport CO2A 4 diameter, 12 mile long pipeline (X70 carbon steel) will be used to transport CO2from the capture unit at Plant Barry to the injection site located at the Citronelle Dome

• Right-of-way – Utility corridor for 80%; multiple landowners

•Right of way habitat (pine forest in the Mobile River watershed; some wetlands)•Right-of-way habitat (pine forest in the Mobile River watershed; some wetlands)

Citronelle OilfieldCitronelle OilfieldSoutheast Unit

Alabama Power

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Plant Barry

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2. Project Design – StorageGulf Coast Region

Saline Reservoirs and Seals

The saline formation selected for CO injection

The Anthropogenic Test’s CO2Storage Site

• Proven four-way closure at Citronelle Dome

The saline formation selected for CO2 injection has many favorable characteristics, is regionally significant, but is geologically challenging.

• Proven four-way closure at Citronelle Dome.• Deep Lower Cretaceous Paluxy Fm (at 9,400’).• 1,100 foot interval of stacked fluvial sands and

shales.

Confining Zone

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

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

Zonereinterpretation of existing 2D seismic lines.

However, prior to drilling the characterization well, only limited data exist on the sand

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continuity, porosity and permeability of the Paluxy Fm at Citronelle Dome.

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3. Geologic Assessment - Detailed Reservoir Characterization(9400

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

Top of Paluxy

Establishing Reservoir Continuity(

(

9500

9600

‘Upper Paluxy’

Sand Layer 9620

Given the challenges posed by a thick, fluvial sequence of sands and shales, the project invested

(

(

9700

9800

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

considerable time and effort on reservoir characterization:(

(

9900

10000

‘Middle Paluxy’

Sand Layer 10060 porosity and depositional style.• Sand continuity mapping of nearly 30

sand intervals to determine “open” or “closed” sand units.

(

(

(

10100

10200

y

We also collected and analyzed data on the Paluxy Fm in other parts of the Gulf Coast region.

(-

(-10300

10400 ‘Lower

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(-

(-10500

0 00 ‘Lower Paluxy’

Top of Mooringsport

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3. Geologic Assessment -Detailed Reservoir Characterization

Confirming and Refining Our Reservoir Characterization

Detailed Reservoir Characterization

At the end of December 2010, we began drilling the characterization well, D9-8 #2, at the Citronelle Dome.

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

• Recovered extensive whole core (98 feet in two intervals) plus 45 sidewall cores in the two confiningintervals) plus 45 sidewall cores in the two confining units, the above primary seal zone and the remaining CO2 storage zone.

• Ran full set of logs (Triple Combo, MRI, Mineralogy, Dipole Sonic, CBL, etc.).

Well was cased and cemented in January, 2011 and will be used as an observation/monitoring well, particularly

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for working with the CO2 Capture Project (CCP) to test their innovative modular borehole monitoring (MBM) system.

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• Recovered extensive Paluxy Formation whole core (98

Data Collection at D-9-8#2Above-Zone Monitoring

• 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:

Top Paluxy

ConfiningZone

• Recovered a total of 45 percussion sidewall cores from:• Overlying confining units,• Overlying saline reservoirs• Paluxy Formation• Paluxy Formation

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

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Base Paluxy

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Porosity and Permeability Ranges, Core #1

9350

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

Porosity Average: 13 %P bili A 8 d

9400

Permeability Average: 8 md

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

9450

Porosity Average: 18%Permeability Average: 440 md

9450 Porosity Range: 8-22%Permeability Range: 1 – 1,900 md

Porosity Average: 18%Permeability Average: 500 md

9500Permeability Average: 500 md

Medium to coarse grained sandstones of the upper Paluxy appear to represent

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9550

the upper Paluxy appear to represent excellent CO2 injection targets

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3. Geologic Assessment – Conducting Rigorous Reservoir Modeling

CO2 Injector

g g

Building the Geologic Model2 j

(Near Well D9-7) Based on detailed characterization of the thick Paluxy sand/shale interval, we selected 17 sand units for CO2 injection:• 280 net feet of “clean” sand

• Average porosity of 19%

• Average permeability of >100md

• Normal pressure and temperature gradients

Subsequent reservoir characterization q(currently underway) will help confirm and update the key CO2 injectivity and storage capacity parameters.

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3. Geologic Assessment – Conducting Rigorous Reservoir Modeling

Understanding CO2 Flow and Optimizing Storage Capacity

3D View

Modeling the CO2 Plume

of CO2 PlumeCO2 Injection Well

CO2 Saturation (v/v)

• Plume extent nearly 1,700 ft

• Due to higher permeability in upper Paluxy sandstonesPaluxy sandstones

• Monitoring plan designed to test and confirm model results

N t t i t bilit• Next step incorporate permeability variation within each sandstone –how does that affect the plume behavior?

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Injection Forecast (cont’d)

Pressure Build‐up Three Years after End of Injection

Pressure Increase from Initial Conditions (psia)

(2% of native pressure)

77

82

86

1mile radius

As a result of the high transmissivityand lateral extent of the Paluxyformation’s sandstones, the resultantsimulation model indicates very little56

60

65

69

73

77

GasInj1

simulation model indicates very littlepressure gain in the reservoir and arapid return to near native pressureafter the injection operations are

(1% of native pressure)43

47

52

56

completed.

GasInj1

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

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4. CO2 Monitoring, Verification and Accounting

The anthropogenic test will use five

CO2 Monitoring DesignCO2 Injection and Storage Site

D-4-13 and/or D-4-14

• Near surface and deep reservoir fluid

The anthropogenic test will use five deep wells to track the CO2 plume plus three shallow water monitoring wells:

D 4 13 and/or D 4 14In-zone montoringAbove-zone monitoringFluid sampling

• Near-surface and deep reservoir fluid sampling.

• In-zone and above-zone pressure and temperature monitoring.C d h l t l i

Proposed InjectorInjection SurveysPressure

New Characterization WellNeutron loggingPressureFluid sampling

• Cased-hole neutron logging.• Crosswell seismic and VSP.• Surface soil flux and tracer surveys

Seismicp g

Seismic

Monitoring plan utilizes proven CO2monitoring methods within and beyond the estimated plume area D-9-11

Neutron

Proposed Inj/Obs WellNeutron loggingSeismic

Plume

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Neutron Logging

Plume Extent Results will be used to periodically

update the reservoir model

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5. Permitting

Capture Facility Permitting• Alabama Department of Environmental Management (ADEM) Air Permit

Transportation Permitting• Army Corps of Engineersauthorization due to wetlands impactsArmy Corps of Engineersauthorization due to wetlands impacts

• Pipeline crosses 15 acres of wetlands• Horizontal drilling under wetlands is preferred over “open-cutting” and

mitigation

• U.S. Fish and Wildlife permit due to impacts to threatened species (gophertortoises)

• Over 30 gopher tortoise burrows encountered long pipeline easementg p g p p• Directional drilling under tortoise burrows/colonies is preferred over

temporary relocation• Permitting process began in April 2011 and was completed in August 2011• SHPO (State Cultural/Archaeological Assets)

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• SHPO (State Cultural/Archaeological Assets)

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5. Permitting

Injection Permitting• USDOE NEPA Assessment

• Environmental impacts - air quality, surface and subsurface water, land and wildlife

• Socioeconomic impacts • Cultural resource impactsCultural resource impacts• NEPA process began in early 2010, Finding of No Significant Impacts

(FONSI) issued in March 2011•Army Corps of Engineers permit covering wetlands impacts

C it (i l di i li ) l t d i A t 2011• Corps permit (including pipeline) completed in August 2011 • Wetland impacts during well pad construction operations (fill) mitigated after

well drilling completed

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6. Integrated Test Plan

• Numerous parametric tests on capture unit • Variations in flue gas processing volume (variations to occur over a matter

of hours, ranging from 40% to 100% capacity•Operational constraints on transport and storage

• Dynamic transportation operations due to variations in capture unit PVT outputoutput

• Active management of pipeline and pump operations to maintain liquid phase

•Effects of periodic capture unit downtime on transportation and storage tioperations

• Minimize CO2 residency in transport and injection junctures• Opportunity for safety inspections• Collection of pressure transient data in the project injection and observation p p j j

wells

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Questions?

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