THE SECARB THE SECARB ANTHROPOGENIC TEST: The First U.S. Integrated - - PowerPoint PPT Presentation

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THE SECARB THE SECARB ANTHROPOGENIC TEST: The First U.S. Integrated CO 2 Capture, Transportation and Storage Test g George Koperna, Jr., Vello Kuuskraa, and David Riestenberg, Advanced Resources International, Inc. Richard Rhudy and Robert

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THE SECARB THE SECARB ANTHROPOGENIC TEST:

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

George Koperna, Jr., Vello Kuuskraa, and David Riestenberg,

Advanced Resources International, Inc.

Richard Rhudy and Robert Trautz,

Electric Power Research Institute

  • Dr. Richard Esposito

Southern Company

Dr Gerald Hill

  • Dr. Gerald Hill

Southern States Energy Board

28th Annual International Pittsburgh Coal Conference September 12-15, 2011

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SLIDE 2

Acknowledgement

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

Acknowledgement

gy gy y p p

  • f work sponsored by an agency of the United States Government. Neither the United States

Government 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, or p , y , pp , p , p , represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or

  • therwise does not necessarily constitute or imply its endorsement, recommendation, or

favoring by the United States Government or any agency thereof. The views and opinions of g y y g y p authors expressed herein do not necessarily state or reflect those of the United States Government or any agency thereof.

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Presentation Outline

1. The Goals, Objectives and Plans for the Anthropogenic Test Anthropogenic Test 2. Project Design

  • Capture
  • Transport
  • Storage

3 Geologic Assessment 3. Geologic Assessment

  • Detailed Reservoir Characterization
  • Conducting Rigorous Reservoir Modeling

g g g

4. CO2 Monitoring, Verification and Accounting 5. 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 ti Ambitious 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 regionally 2. 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 CO2 maximize 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,

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

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SLIDE 5

SECARB’s Phase III Anthropogenic Test p g

Washington County

Th 25 MW CO t it t

Project Schedule and Milestones

The 25 MW CO2 capture unit at Alabama Power’s (Southern Co.) Plant Barry 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 to transport CO2 from Plant Barry to the Citronelle Dome is under construction. A characterization well was drilled in Alaba Mississ

Mobile County

A characterization well was drilled in 1Q 2011 to confirmed geology From 100 to 300 thousand metric tons

  • f CO

will be injected into a saline

Plant Barry

  • f CO2 will be injected into a saline

formation (Paluxy Fm) over 2 to 3 years. Advanced Resources and supporting researchers will conduct 3 years

  • f

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Mobile

researchers will conduct 3 years

  • f

monitoring after CO2 injection and then close the site.

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The Anthropogenic Test Schedule The Anthropogenic Test Schedule

  • Well drilling operations began in late December 2011

g 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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SLIDE 7

Diverse Project Team

St Storage Capture

DOE

  • SO. STATES ENERGY BOARD

Transport p

Permitting Plant Integration & Construction Site Host

Mitsubishi Heavy

NEPA Preparation

Advanced Resources International Industries

Design Technology Provider Advanced Amines NEPA Preparation MMA Activities Field Operations Reservoir Modeling Public education/

  • utreach

UIC Permitting Geologic Modeling

Denbury Resources Denbury Resources

Pittsburgh_SP091211 Site Prep/ Drilling Contractors Field Operations Site Host Pipeline Permitting & Construction Field Operations Pipeline Design Economic Evaluation Knowledge Transfer 3rd Party Evaluation 7

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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 CO2

A 4 diameter, 12 mile long pipeline (X70 carbon steel) will be used to transport CO2 from 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 Oilfield Citronelle Oilfield Southeast Unit Alabama Power

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Plant Barry

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  • 2. Project Design – Storage

Gulf Coast Region Saline Reservoirs and Seals

The saline formation selected for CO injection

The Anthropogenic Test’s CO2 Storage 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 lines

Injection Zone

reinterpretation 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-9-7

Log 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

  • n 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 confining intervals) 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#2

Above-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 Confining Zone

  • 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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SLIDE 15

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

9500

Permeability 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 Model

2

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

  • f CO2 Plume

CO2 Injection Well

CO2 Saturation (v/v)

  • Plume extent nearly 1,700 ft
  • Due to higher permeability in upper

Paluxy sandstones Paluxy 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

  • f Injection

Pressure Increase from Initial Conditions (psia) (2% of native pressure)

77 82 86

1mile radius

As a result of the high transmissivity and lateral extent

  • f

the Paluxy formation’s sandstones, the resultant simulation model indicates very little

56 60 65 69 73 77 GasInj1

simulation model indicates very little pressure gain in the reservoir and a rapid return to near native pressure after the injection

  • perations

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 Design CO2 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 14 In-zone montoring Above-zone monitoring Fluid 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 Injector Injection Surveys Pressure New Characterization Well Neutron logging Pressure Fluid sampling

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

Seismic p g Seismic

Monitoring plan utilizes proven CO2 monitoring methods within and beyond the estimated plume area

D-9-11 Neutron Proposed Inj/Obs Well Neutron logging Seismic

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 impacts

Army 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 (gopher

tortoises)

  • Over 30 gopher tortoise burrows encountered long pipeline easement

g 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 impacts

Cultural 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
  • f hours, ranging from 40% to 100% capacity
  • Operational constraints on transport and storage
  • Dynamic transportation operations due to variations in capture unit PVT
  • utput
  • utput
  • Active management of pipeline and pump operations to maintain liquid

phase

  • Effects of periodic capture unit downtime on transportation and storage

ti

  • perations
  • 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?

Office Locations

Washington, DC 4501 Fairfax Drive, Suite 910 Arlington, VA 22203 USA Phone: (703) 528-8420 Fax: (703) 528-0439 Houston, TX 11490 Westheimer Rd., Suite #520 Houston, TX 77077 USA Phone: (281) 558-9200 Fax: (281) 558-9202 Fax: (281) 558 9202 Knoxville, TN 603 W. Main Street, Suite 906 Knoxville, TN 37902 USA Phone: (865) 541-4690 Fax: (865) 541-4688 Cincinnati, OH 1282 Secretariat Court Batavia, OH 45103 Phone: (513) 460 0360

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Phone: (513) 460-0360 Email: scarpenter@adv-res.com

http://adv-res.com/

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