# Categ orical Ex clusion B5.13 Supporting I nformation for DOE Notice of Proposed Rulemaking Page 1 

# Experience from Geo logic CO 2 

# Storage Field Projects

Support ed by DOE’s Sequestration Program

Background: The U.S. DOE’s Sequestration P rogram began with a small appropriation

of $1M in 1997 and has grown to be the largest most comprehensive CCS R& D program

in the world. The U.S. DOE’s sequestration program has supported a number of projects

implementing CO 2 

# injection in the United States and other countries including, Canada,

Algeria, Norway, Australia, and Germany . The program has also been supp orting a

number of complementary R&D projects investigating the science of storage, simulation,

risk assessment , and monitoring the fate of the injected CO 2 

# in the subsurface.

The program supports a number of field activities in the United States which would be

considered small scale < 1,000,000 tons of CO 2 

# injected during the life of the projects

(typically 1

- 4 years) . Environmental Assessment s have been prepared one of the first

small scale injection projects and large scale injection projects injectin g more than

1,000,000 tons of CO 2 

# . Most of the small scale projects underwent NEPA review and

were granted categorical exclusions (CX). All of these projects were required to receive

and operate their facilities according to the U.S. EPA’s Underground In jection Control

(UIC) permit requirements to protect underground sources of drinking water (USDW).

In addition, several of the projects located on state lands in the w estern United States

received a CX only after satisfying the s tate agencies ’ requirements to perform historical

studies or biological impact assessments before being granted approval to perform

surface operations.

Much of the information on these other projects is located in the 2010 Sequestration

Project Portfolio . Additional scientific reports from the projects are available through the

OSTI website.

Frio Brine Field Test:

T he Frio Brine Sequestration Project was the first field project in the United States to

i nject CO 2 

# into a saline formation for the sole purpose of CO 2 

# storage . The project

inject ed approximately 5,000 tonnes of CO 2 

# over two separate time periods (~2 weeks

each) into the deep saline Frio formation i n Texas . Crosswell seismic and tracers with

U

- tube fluid sampling were the primary methods used to measure

, monitor , and validate

the research team’s predictions of the fate of the injected CO 2



# . Th e results of this project

also showed that the CO 2 

# would remain in the target formation and would be contained

by the cap rock

. The project was permitted under the Underground Injection Control

(UIC) Program , with a Class I non

- hazardous injection well permit

. An E nvironmental

Assessment was prepared an d FONSI issued for this project prior to field operations.

Additional information on the Frio project is available at:

http://www.netl.doe.gov/publications/others/nepa/ea.html

# Categ orical Ex clusion B5.13 Supporting I nformation for DOE Notice of Proposed Rulemaking Page 2 

# Sma ll Scale Field Tests

- Regional Carbon Sequestration Partnerships Phase II:

The U.S. DOE has been supporting the implementation of 20 small scale projects

(< 700 ,000 tones) through the Regional Carbon Sequestration Partnerships (RCSP)

Initiative

. These pr oject s began in 2005 and are focused on understanding the science

behind CCS in different regions of the country, geologic settings (injection zones,

caprocks, fluids, and diagenetic processes), and determining the fate of the injected CO 2



# in the subsurfac e. The projects include storage in ( tons injected at each site):

**•** 5 unmineable coal seams (from 100 to 18,000 tons)

**•** 8 depleted oil fields (from 40 to 637,000 tons), and

**•** 7 saline formations (from 55 to 60,000 tons).

DOE’s involvement in each of these projects depends on the extent of existing CO 2 

# injection operations at the sites. DOE was providing the various projects with support for

well field development, drilling operations, workover of existing wells, simulation

modeling, injection operations, m onitoring of injected CO 2 

# , injection operations, and

closure of the site s

. At some of the oil field enhanced recovery sites, the DOE was only

providing support for measurement and monitoring efforts. The projects deploy ed a

portfolio of technologies to measure, monitor and verify the fate of the CO 2 

# in these

formations. In all cases, the CO 2 

# remained in the subsurface with no measureable

impacts to the surface water or underground sources of groundwater. Limited

disturbance at the surface is necessary to drill new wells, build short spur pipelines, and

conduct seismic and other monitoring surveys.

Fifteen (15) of the small scale projects have completed their injection operations in the

past four years, two are currently injecting, and one is planning t o begin injection

operations in November 2010. Similar to the Frio Brine project

, these tests have

deployed a number of measurement tools , simulation packages, and monitoring protocols

to validate that CO 2 

# remain s in the for mations developed for storage

. A summary of the

partnerships ’ best practices with Monitoring

, Verification and Accounting (MVA) is

available at: DOE MVA Best Practices Manual

A summary of the Phase II projects and their accomplishments is provided in

Attachment 1 (PhaseIIProjects.xls) . Project details for each site are also located in

2010 Sequestration Project Portfolio and through OSTI website.

The partnerships are required to present to DOE the results of their injection proj ects at

an annual review meeting . Each project is required to develop a summary of p roject

activities and to present project findings during the meeting . From these reviews

, it is

evident that the projects have been successful in being able to validate t hat the CO 2 

# is

safely injected and store d in these deep geologic formation s

. Presentations and factsheets

from each review can be viewed by clicking on each of the following years: 2006

, 2007

, 2008

, 2009

.

# Categ orical Ex clusion B5.13 Supporting I nformation for DOE Notice of Proposed Rulemaking Page 3 

# Large

- Scale Field Tests

- Regional Carbon Sequestration Partnerships Phase III:

Nine large

- scale (>1,000,000 tones) CO 2 

# injection projects through the Regional Carb on

Sequestration Partnerships are in various stages of development and environmental

review. Eight projects are injecting CO 2 

# in deep saline formations and one will be

conducting extensive MVA activities at a depleted oil field to determine the fate o f th e

injected CO 2



# . Field activities for these projects are very similar to the small

- scale field

projects, but at a larger scale. Two of the large

- scale projects have completed

Environmental Assessments

, which resulted in FONSIs

, and one of these projects has

currently injected more than 1 million tones of CO 2 

# in a saline formation. A summary of

the Phase III projects and their accomplishments is provided in Attachment 2

(PhaseI I IProjects.xls) . Project details for each site are also located in the 2010

Sequestration Project Portfolio and at the 2009 RCSP review meeti ng proceedings

.

International Field Tests:

DOE also support s several activities through National Laboratories and other research

institutions that are providing support to monitoring and simulation activities for several

international carbon sequestration projects. These projects are all considered near

commercial

- scale integrated CCS Operations

, which are injecting at least 1MMT of CO 2 

# each year for either enhanced oil recovery or storage in saline formations. The Sleipner

and Weyburn projects have both been operating for more than 10 years without incident.

Ove r 30 million tons of CO 2 

# ha ve been stored at these projects sites combined . Our

collaborative effort s with these and other international projects ( e.g., Snohvit, In

- Salah,

and Otway) have provided decades of cumulative operational experience to show that

CCS is a safe and effective technology to reduce CO 2 

# emissions to the atmosphere.TestNumberRP Test Name Project Goals Vendors/Utilities/Other Formation Type Test SiteSource of CO2Geologic Province Geologic SettingAmt Scheduled forInjectionmetric tonnes(short tons)Amt Injectionmetric tonnes(short tons)InjectionScheduledBegin(Month/Yr)InjectionCompleted(Month/Yr)EPA UIC Permit Outcomes of Project1 Big Sky Basalt and Mafic Rock Field Validation Test▪Assess basalt formation and adjacent formation response to injection▪Validate CO2dispersion, dissolution, and trapping in basalt formations▪Verify mineralization reactions with post- injection core sampling▪Pacific Northwest National Lab▪Idaho State University▪Idaho National Lab▪Boise White Paper, L.L.C.▪Shell Oil Company▪Port of Walla Walla▪Portland General ElectricSaline (basalt/mafic) Walulla Township, WA Commercial Source Columbia River Basalt Group Grande Ronde Basalt Formation1,000(1,100 tons)0(2010 Injection)2010 - Q2 2010 - Q3 V3-D Seismic survey conducted and test well drilled. No faults identified. Reservoir and sealformations identified. Characterization well drilled and completed April 2009. Targetinjection formation identified at 2,720 feet. Injection planned for November 2010.2 MRCSP Appalachian Basin Geologic Test▪Feasibility/safety ofsalineformation storage▪Characterization of regional saline storage opportunities▪Information gained rock properties and formation behavior in region▪Establish familiarity with CO2injection operations at active power plants▪Ohio Geological Survey▪Ohio Dept. of Natural ResourcesSaline Shadyside, OH Commercial Source Appalachian Basin Oriskany, Salina, and Clinton Sandstone1,000(1,100 tons)<50(55 tons)2008 - Q3 2008 - Q4 VSite characterization and 2-D seismic survey performed. Well drilled to just over 8,300 feet.Injection difficulty due to extremely low porosity and permeability in target formations.3 MRCSP Cincinnati Arch Geologic Test▪Inject at bottom of Mt. Simon Formation and track CO2migration upwards▪Feasibility/safety of saline formation storage▪Regional characterization of saline storage opportunities▪Demonstration of CO2capture from coal-fired power plant source▪Kentucky Geologic Survey▪Indana Geologic Survey▪Duke EnergySaline Rabbit Hash, KY Commercial Source Cincinati Arch Mt. Simon Sandstone1,000(1,100 tons)1,000(1,100 tons)2009 - Q3 2009 - Q3 VSuccessful completion of 1,000 tons of CO2at depths between 3,200 and 3,600. Post-injection MVA occurring for two years to ensure CO2does not migrate to drinking water.Predictive modeling indicates no leakage above the Eau Clair caprock layer.4 MRCSP Michigan Basin Geologic Test▪Feasibility/safety of saline formation storage▪Regional characterization of saline storage opportunities▪Assess feasibility of possible CO2CCS from nearby gas processing plants▪DTE Energy▪Core Energy, L.L.C.▪Western Michigan UnviersitySaline Ostego County, MI DTE Turtle Lake Gas Plant Michigan Basin Bass Islands Dolomite10,000-30,000(11,023 - 33,069 tons)60,000(66,000 tons)2008 - Q3 2009 - Q3 VInitial injection of 11,000 tons of CO2completed in March 2008. An additional 55,000 tons ofCO2has been injected by July 2009. Post-injection monitoring included including acombination of cross-well seismic, hydraulic monitoring, PFT tracers, microseismic array,and wireline logging, and made publically available.5 MGSCCO2Single Well Injection/Soak/Produce Test▪Inject CO2into single producing well [huff]▪Allow CO2to dissipate/dissolve [soak]▪Measure the response [puff]▪Feasibility/safety of EOR sequestration in mature oil fields▪Air Liquide▪Petco Petroleum CorporationOil Bearing - Heavy Fayette County, ILCommercial Source-AirLiquideLoudon Oil Field Mississippi Weiler Sandstone272(300 tons)39(43 tons)2007 - Q2 2007 - Q2 IIInjection of 43 tons of CO2in the gas phase resulted in 93 barrels of oil produced.7 MGSC Enhanced Coalbed Methane▪Feasibility/safety of coal seam sequestration▪Changes in CO2injectivity of Illinois Coal▪Measurement of methane displaced by CO2▪Measure amount of CO2retained in the coal seam▪Gallagher Drilling Company▪Air LiquideCoal Seam Wabash County, ILCommercial Source-AirLiquideIllinois Basin Pennsylvania Carbondale Formation680(750 tons)91(100 tons)2008 - Q3 2008 - Q4 II100 tons of CO2had been injected into the Pennsylvania Carbondale formation at a rate of23 tons per day. Methane gas production was noted at the face and butt cleat monitoringwells, and CO2was observed at all monitoring wells.8 MGSC Oil-bearing Well Conversion▪Employ advanced MVA protocol to understand sequestration potential▪Understand EOR/Sequestration options in a complex reservoir▪Gallagher Drilling Company▪Air LiquideOil Bearing Hopkins County, KYCommercial Source-AirLiquideSugar Creek Oil Field Jackson Sandstone7,272(8,000 tons)5,850(6,448 tons)injecting2009 - Q3 2010 - Q2 IIInjection began in July 2009 into a converted water flood well. Current rate of injection isabout 25 tons CO2per day. CO2breakthrough at two production wells occurred sooner thanexpected and therefore an in-fill well will be drilled to understand the formation characteristicsof the reservoir,which will improve the reservoir mode9 MGSC Oil-bearing Pattern Flood▪Employ advanced MVA protocol to understand sequestration potential▪Understand EOR/Sequestration options in a complex reservoir▪Gallagher Drilling Company▪Air LiquideOil Bearing Posey County, INCommercial Source-AirLiquideMumford Hills Oil Field - Bald Unit Clore Formation5,454 - 7,272(6,000 - 8,000 tons)2,850(3,590 tons)injecting2009 - Q4 2010 - Q3 IIInjection began in September 2009 into a converted production well forming an inverted 5-spot configuration. Current rate of injection is about 35 tons CO2per day. Injectionanticipated for 6 - 8 months followed by 3 - 5 months of water injection.10 PCOR Williston Basin EOR Field Test▪Evaluate use of CO2 for EOR in a deep (>8000 ft) carbonate reservoir▪Test geophysical technologies to monitor CO2 in deep carbonate reservoir▪Determine the potential for deep carbonate rocks to permanently sequester CO2▪ND Oil & Gas Research Council▪ND Dept. of Mineral Resources▪Eagle Operating, Inc.▪Schlumberger▪PraxairOil Bearing Western North Dakota Commercial Williston Basin Mississippian Mission Canyon Formation4536(5,000 tons)400(440 tons)2009 - Q3 2009 - Q3 IICO2was injected into an oil-bearing zone at 8,050 feet. The activity will be used to determinethe efficacy of CO2sequestration and the use of CO2to produce additional oil from otherdeep carbonate source rocks. Results of the RST and VSP indicated that the CO2migratedapproximately 300 ft (90 m) horizontally and 50 ft (15 m) vertically into the reservoir andsuggest that the RST and VSP technologies may be effective MVA tools for deep carbonatereservoirs.11 PCOR Zama Field Validation Test▪Predict, monitor, and evaluate fate of the injected acid gas▪Determine effect of H2S on CO2sequestration▪Best practices manual for the use of H2S with EOR and CO2sequestration▪Apache Canada Ltd.▪Alberta Energy and Utilities Board▪Natural Resources CanadaOil Bearing Zama City, Alberta Canada Zama Gas Plant Zama Oil Field Middle Devonian Keg River Formation208,600 metric tonnesCO272,560 metric tonnesH2S25,400(28,000 tons)2006 - Q4 2009 - Q4Canada Acid GasPermitAcid gas (approximately 70% CO2, 30% hydrogen sulfide [H2S]) from natural gas-processingplants in northern Alberta, Canada, were injected into an oil-producing zone in anunderground pinnacle reef structure. 25,000 barrels of produced oil resulted. Results will helpto determine the best practices to support sequestration in these geologic structures as wellas further our understanding of the effects of H2S on tertiary oil recovery and CO2sequestration.12 PCOR Lignite in North Dakota Field Validation Test▪Gauge ECBM production from coal resulting from CO2injection▪Employ MVA technologies for ECBM and CO2storage in coal▪Determine the potential for lignite coal to permanently sequester CO2▪Flatland Exploration Company▪ND State Land Department▪Eagle Operating, Inc.▪Schlumberger▪PraxairCoal Seam Burke County, NDCommercial Source -PraxairWilliston Basin Harmon Coal Fort Union Formation<907(1,000 tons)80(90 tons)2009 - Q1 2009 - Q2 IICO2will be injected into unminable lignite seams in northwestern North Dakota. The injectedCO2is trapped by naturally bonding to the surfaces of the fractured lignite. The injected CO2also has the potential to displace methane occupying the coal fractures. This validation testwill give valuable information regarding lignite for both CO2sequestration and enhancedcoalbed methane production. • Indications are that the injected CO2migrates along the pathof the coal and was contained within the expected injection zone.13 SECARB Saline Reservoir Test▪Test deep saline reservoirs near large, coal-fired power plants▪Build geologic and reservoir maps and conduct reservoir simulations▪Estimate injectivity, storage capacity, and long-term fate of injected CO2▪Advanced Resources International▪EPRI▪Southern Company▪Denbury▪Mississippi Power▪Praxair▪Schlumberger▪HalliburtonSaline Jackson County, MS Jackson Dome Mississippi Gulf Coast Lower Tuscaloosa Massive Sand Unit2,720(3,000 tons)2,740(3,020 tons)2008 - Q4 2008 - Q4 VSuccessful injection of 3,020 tons of CO2. Currently, variety of surface and subsurfacemonitoring tasks are underway to track and model the location and movement of the CO2plume.14 SECARB Black Warrior Basin Project▪Feasibility/safety of CBM reservoir storage▪Determine optimal injectivity for ECBM recovery▪Denbury Resources, Inc.▪Electric Power Research Institute▪El Paso Exploration and Production▪Southern Company▪Southern Natural Gas▪Vigrinia TechCoal Seam Tuscaloosa County, AL Jackson Dome Black Warrior Basin Multiple Coal Zones of Pottsville Formation907(1,000 tons)360(397 tons)2010 - Q2 2010 - Q2 IIProject still undergoing extensive pre-injection site activities, including characterization.Injected expected to begin in April 2010. Injection redesigned to 218 metric tonnes with waterinjection prior CO2.15 SECARB Central Appalachian Basin Test▪Identify areas for CO2coal seam sequestration▪Expand ECBM production in Central Appalachian Basin▪Marshall Miller & Associates▪Advanced Resources International▪Geologic Survey of Alabama▪Kentucky Geological Survey▪Eastern Coal Council▪Vigrinia TechCoal Seam Russell County, VA Commercial Source Central Appalachian Basin Pocahontas and Lee Formations907(1,000 tons)907(1,000 tons)2009 - Q1 2009 - Q1 IIAccomplished injection of approximately 1,000 tons (907 metric tons) of CO2from January15, 2009 to February 9, 2009, with monitoring activities at the site continuing. Post-injectionmonitoring continuing. In addition, technology transfer and outreach program has beeninitiated that includes a website, publications and numerous technical and non-technicalpresentations at conferences and workshops.16 SECARB Gulf Coast Stacked Storage Project▪Conduct a stacked storage project: EOR and underlying brine formation▪Employ advanced MVA protocol to understand sequestration potential▪Schlumberger Carbon Services▪Advanced Resources International▪Praxair▪Denbury Resources▪Etergy▪Marathon Oil Corporation▪Pinnacle Technologies▪Southern CompanyOil Bearing Cranfield, MS Jackson Dome Cranfield Oilfield Tuscaloosa Formation500,000(551,150 tons)637,000 ton at endof April 20092008 - Q3 2009 - Q2 IIInjection of CO2for EOR initiated in July 2008. Post-injection monitoring activitiescontinuing, including soil gas studies and reservoir modeling.17 SWP Aneth Oil Field Test - I▪Conduct large-scale EOR project with CO2sequestration▪Employ advanced MVA protocol and reservoir simulation▪Resolute Natural Resources Co.▪Navajo Nation Oil and Gas Co.Oil Bearing San Juan County, UT McElmo Dome Paradox Basin Deep Creek and Ismay Zones408,240 - 680,400(450,000 - 750,000 tons)630,000(694,449 tons)2007 - Q3 2010 - Q1 IIProject accomplishments include baseline and repeat surface fluxes and VSP, assessmentof baseline reservoir groundwater (brine) compositions, and testing of reservoir tracer beganin July 2007; analyses are ongoing. Monitoring activities continuing.18 SWP SACROC EOR Project▪Post-audit modeling of Kinder Morgan injections▪Test efficacy of CO2subsurface monitoring technologies▪Track fate of injected CO2at SACROC▪CO2storage history matched with large-scale MVA at SACROC▪Results will aid plans for new CO2EOR injections in nearby Claytonville Field▪KinderMorgan CO2CompanyOil Bearing Snyder, TX McElmo Dome Permian Basin Horseshoe Atoll and Pennsylvanian Reef/Bank Play86,000(88,184 tons)86,000(88,184 tons)2008 - Q3 2009 - Q4 IICO2injection in first 2 wells started in September 2008 and injections in the second 2 wellsbegan in November 2008. This test includes a post-audit modeling analysis of injected CO2for EOR over the last 30 years at the SACROC Unit in the Permian Basin of Texas, inaddition to intense MVA analyses of ongoing CO2injection at SACROC. Results will be usedby Kinder Morgan to define an optimized commercial approach to EOR with sequestration inthe Claytonville field, a nearby field with similar geology that has not yet been subjected toCO2injection.19 SWP San Juan Basin ECBM Test▪Evaluate ECBM production efficiency with concomitant CO2storage efficacy▪Identify regulatory gaps for ECBM and CO2sequestration▪Develop detailed risk assessment and mitigation plans▪ConocoPhillips▪KinderMorgan CO2CompanyCoal Seam San Juan Basin McElmo Dome San Juan Basin Upper Cretaceous Fruitland Formation68,040(75,000 tons)16,700(18,400 tons)2008 - Q3 2009 - Q3 IIAdditional project goals include desalination of produced water from the ECBM pilot and usethe water for irrigating a riparian restoration project, forming a combined ECBM/terrestrialsequestration project. Began CO2injection operations during July 2008 and ended in July2009. A total of approximately 18,400 tons (16,700 metric tons) of CO2was injected. Thewell has since been plugged and abandoned. Conducting a multi-scale investigation ofsealing behavior of the overlying Kirtland shale. Preliminary results show good sealing thusfar. The study is yet to be completed.TestNumberRP Test Name Vendors/Utilities/Other Formation Type Test SiteSource of CO2Geologic Province Geologic SettingAmt Scheduled forInjectionmetric tonnes(short tons)Amt Injectionmetric tonnes(short tons)InjectionScheduledBegin(Month/Yr)InjectionCompleted(Month/Yr)NEPA1 Big Sky Large-Volume CO2 Injection on Kevin Dome▪Montana State University▪University of Wyoming▪Schlumberger▪Los Alamos National Laboratory▪Lawrence Livermore National LabSaline Northern Montana Kevin Dome - Natural Source Madison Formation Kevin Dome2,000,000(2,200,000 tons)0 2012 - Q4 2015 - Q4 EA Pending2 MRCSP Large Scale Geologic Injection Test▪Core Energy Saline Otsego County, MichiganNatural Gas ProcessingFacilityMichigan BasinSt. Peter SandstoneBass Islands Dolomite1,000,000(1,100,000 tons)0 2011 - Q4 2015 - Q4 EA Initiatied3 MGSCDemonstrating CO2 Storage in the Mount SimonSandstone of the Illinois Basin▪Archer Daniels Midland Saline Decatur, ILADM's Ethanol ProductionFacilityIllinois Basin Mt. Simon Sandstone1,000,000(1,100,000 tons)0 2011 - Q1 2014 - Q1EA Complete -FONSI Issued4 PCOR Fort Nelson Demonstration - British Columbia, Canada▪British Columbia Ministry of Energy,Mines, and Petroleum Resources▪Natural Resources Canada▪Spectra EnergySaline British Columbia, CanadaSpectra Energy's Fort NelsonNatural Gas ProcessingFacilityAlberta Basin Elk Point Formation6,500,000(7,150,000 tons)0 2012 - Q3 2017 - Q4CX (monitoringactivities only)5 PCOR Bell Creek Demonstration - southeastern Montana▪Denbury ResourcesOil Bearing Bell Creek Oil FieldNatural Gas ProcessingFacilityPowder River Basin -MontanaCretaceous Muddy Formation1,500,000(1,650,000 tons)0 2013 - Q1 2017 - Q4NEPADeterminationPending6 SECARB Early Test▪Advanced Resources International▪EPRI▪Denbury Resources, Inc.▪Southern Company▪Gulf Coast Carbon Center (BEG)▪Mississippi State University▪Lawrence Berkeley National Lab▪Schlumberger Carbon Services▪Lawrence Livermore National Lab▪Southern Company▪QEA▪University of Mississippi▪U.S. Geological SurveySaline Cranfield, MSJackson Dome(natural source)Lower Tuscaloosa Cranfield Unit1,500,000(1,650,000 tons)~1.4 miilion tons<Amt injected as ofend of Agust 2010based on injectioninitiated 4/1/09>2009 - Q2 2011 - Q3EA Complete -FONSI Issued7 SECARB Anthropogenic Test▪Advanced Resources International▪EPRI▪Denbury Resources, Inc.▪Southern Company▪Gulf Coast Carbon Center (BEG)▪Mississippi State University▪Lawrence Berkeley National Lab▪Schlumberger Carbon Services▪Lawrence Livermore National Lab▪Southern Company▪QEA▪University of Mississippi▪U.S. Geological SurveySaline Citronelle, ALSouthern Company's PlantBarry Coal-Fired Power Plant(Bucks, AL)Paluxy Formation Citronelle Field300,000(330,000 tons)0 2011 2014EA Draft indevelopment8 SWPDemonstration of Storage in Deep Jurassic/TriassicFormations of the Western U.S.▪Thunderbird Energy Corp.▪Pacificorp▪Rocky Mountain Power▪Southern California Edison▪Schlumberger▪Baker HughesSaline AquiferGordon Creek Field; Edge ofUinta Basin; < 20 miles Westof Price, UT; <100 milessoutheast of Salt Lake City,UTNatural CO2 Colorado Plateau Intermontane Sedimentary Basin2,600,000(2,900,000 tons)0 2012 - Q1 2016 - Q19 WESTCARB California Development Phase Test▪California Energy Commission▪C6 Resources, LLC▪Shell Martinez Refinery▪Schlumberger Carbon Services▪Clean Energy Systems IncSaline CaliforniaNorthern California or CentralValley, CA (Currentlydownselecting site)TBD TBD TBD 0 2015 TBD