Team MembersKashiar Aminian, WVU, Petroleum & Natural Gas EngineeringSeth Blumscak, PSU, Energy & Mineral EngineeringR.J. Briggs, PSU, Energy & Mineral EngineeringDustin Crandall, URS, EngineerRobert Dilmore NETL ORD Engineer

f S ( )

Robert Dilmore, NETL ORD, EngineerCorinne Disenhoff, URS, GeochemistTurgay Ertekin, PSU, Energy & Mineral EngineeringAngela Goodman, NETL ORD, Physical ScientistGeorge Guthrie, NETL ORD, Geochemist, Lead -Geologic and Environmental Sciences Focus AreaChristopher Jursa, URS, GIS analyst

ICMI - CO2 Storage in Depleted Shale Gas Reservoirs

Image from: Dan Soeder (2011) p , , y

Christina Lopano, NETL ORD, GeochemistDustin McIntire, NETL ORD, EngineerShahab Mohaghegh, WVU, Petroleum & NGEng.Tom Mroz, NETL ORD, GeologistSlava Romanov, NETL ORD, Physical ScientistJoel Siegel, URS, Project ManagerH Si i d WVU Ci il & E i t l

Robert Dilmore, Ph.D., P.E.Research Engineer

Hema Siriwardane, WVU, Civil & Environmental EngineeringDan Soeder, NETL ORD, Geologist

CoalSeq VIII ForumOctober 23, 2012, Pittsburgh, PA

Outline

• Acronyms (NETl, NETL-RUA, ICMI, EDX, TRS, etc.)• ICMI Project OverviewICMI Project Overview• Scope of work: CO2 storage in/enhanced gas recovery from

shaleExperimental progress to date– Experimental progress to date

– Simulation approach – Techno-economic assessment

• Summary

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Source: Marcellus Shale: A blog dedicated to investment opportunities in the Marcellus Shale. “Range Resources Increases EURs for Marcellus Shale Wells 7/18/2011 from Marcellus” 7/18/2011. Accessed online from: http://shale.typepad.com/marcellusshale/2011/07/range-resources-increases-eurs-for-marcellus-shale-wells.html Image Credit: OilOnline.com

NETL-Regional University Alliance

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Industrial Carbon Management Initiativeg

CO2 & H2

Carbon CaptureChemical Looping Combustion

CH3OH

Carbon UtilizationPhotocatalytic Conversion

Carbon StorageDepleted Shale Fields

Chemical Looping Combustion

CCUS for

Industrial assessment

Industrial Applications

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and systems analysis

CO2 Storage in and Enhanced Gas Recovery from Shale Gas Formationsfrom Shale Gas Formations

Research Goal:Develop robust assessment of

Experimental Characterization

Develop robust assessment of CO2 storage in shale gas formations that have been

Numerical ModelingCO2 storage in shale

Dat

a an

ge)

depleted through primary production, and develop a preliminary assessment of

Surrogate Reservoir Modeling (SRM)R

elat

ed D

ata

Exch

a

p ypotential for enhanced gas recovery through CO2injection

g ( )

SRM ApplicationSpat

ially

-En

ergy

Da

injection S (ETechno-Economic

A t

5

Assessment

Experimental Plan• Marcellus Shale• 10 ICMI-specific

samples, 5 facies represented

• All outcrop samples– Cores/plugs– Powders– Other

• Interim experimentalInterim experimental report completed 9/12

• Results will also be disseminated via EDXdisseminated via EDX and/or NETL TRS

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High-Resolution Computed Tomography Industrial Scanner (NETL MGN)Industrial Scanner (NETL MGN)

• 5 μm resolution• flow, temperature & pressure controls

Single cross-sectional slice of Marcellus Shale core showing imbedded shell

Computed Tomography: Imaging a non-calcareous black shale with core plug oriented

showing imbedded shell

p g p y g g p gsub-parallel to bedding (sample F4HA)

Photograph of plug F4HA

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Photograph of plug F4HA

Precision Petrophysical Analysis Laboratory

Effective porosity and permeability ofshale to CO2/CH4 over range ofeffective stress, and characterization ofhysteresis effects

• Steady-state flow measurement, research quality data• Capable of running different gases under different pressures, including

nitrogen methane and carbon dioxidenitrogen, methane and carbon dioxide.• Capable of reproducing in-situ net stress, and measuring gas flow

under partial liquid saturation.• Can also measure pore volume to gas, adsorption isotherms and PV p g , p

compressibility using N2, CH4 or CO2• Uses stable gas pressure as a reference for flow measurement

• Temperature controlled

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• Stable to one part in 500,000• Target flow measurement is 10-6 standard cm3 per second

Image from: Kashiar Aminian; Discussion of PPAL capability at: SPE/DOE 11765, Symposium on Low Permeability Gas Reservoirs, Denver, CO, March 13-16, 1983

Petrophysical AnalysisMatrix porosity and permeability as function of net stress in an shaley limestone (sample F2HA)Matrix porosity and permeability as function of net stress in an shaley limestone (sample F2HA)

Effective porosity of shale to CO2 decreases with increasing net stress, but rebounds as net stress declines

Effecti e permeabilit of shaleEffective permeability of shale exhibits hysteresis with respect to net stress

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Sorption capacity as function of %TOC

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Reservoir Simulation

• History matched commercial reservoir simulator with AI (Mohaghegh, WVU)(Mohaghegh, WVU)

• Modified dual porosity, multiphase, compositional,

l idi i l fl d lmultidimensional flow model (Ertekin, PSU)

• Discrete fracture network andDiscrete fracture network and flow modeling (NETL ORD/URS)

• Coupled geomechanical/flow model parametric study (Si i d WVU)

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(Siriwardane, WVU)

Design Basis Document

• Outline modeling approach and scope• Defines properties of base-case

scenarioscenario– Appropriate temperatures/pressures– Matrix porosity/permeability

F t t k ti– Fracture network properties– Rock geomechanical properties– Single lateral natural gas production

for history match• Develop consensus among modelers• Report issued in July, 2012p y,• To be revised as better information

becomes available

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Conventional Simulation & AI-based modeling(Mohaghegh et al.)

• Acquire real data on gas production from a set of shale gas wells• Use that set of data to develop population statistics • Develop a history-matched model of shale gas production (29 month production

( g g )

p y g p ( phistory) using a conventional reservoir model

• Project forward to economic limit before initiating CO2 injection• Develop a surrogate reservoir model based on the history matched model to

predict wellpad performance under CO loadingpredict wellpad performance under CO2 loading

77 wells ,652 stages and 1893 clusters

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Content Contributed by: Shahab Mohaghegh, West Virginia University Department of Petroleum & Natural Gas Engineering

Selected Study area

Developing Surrogate Models from Numerical Reservoir ModelsNumerical Reservoir Models

Pattern Recognition Database

SRM Training

Numerical ReservoirSimulation g

(fuzzy set theory and Artificial Neural Networks)

of 10-20 Simulation

Runs

SRM validation

E l R i

SRM Mimics Behavior of Numerical Simulation

Explore Reservoir Behavior

(Sensitivity and Uncertainty Analyses, and Scenario

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Evaluation)

PSU-SHALECOMP model (Ertekin PSU)(Ertekin, PSU)

Define a “crushed zone” with same gas production performance) as an equivalent discrete fracture network model

Apply this fracture zone representation in simulations using dual porosity, dual pp y p g p ypermeability compositional model of fractured low perm reservoirs

Validate “crushed zone” model using available production data Use the validated “crushed zone” model to predict CO2 storage potential

Horizontal wellHorizontal well

Discrete transverse Crushed zone ?

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Content Contributed by: Turgay Ertekin, Penn State University Department of Energy and Mineral Engineering

fracture representation representation

PSU-SHALECOMP Single lateral Multi-lateral Well Pad

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Content Contributed by: Turgay Ertekin, Penn State University Department of Energy and Mineral Engineering

Fracture Network Modeling (Mysakin et al., URS)NETL’s fractured reservoir modeling software simulates gas flowNETL s fractured reservoir modeling software simulates gas flow and drainage in fractured reservoirs with a stochastic network of discrete fractures, and includes:• a fracture network generator (FRACGEN)• a fracture network generator (FRACGEN), • a flow simulator (NFFLOW),

Reservoir modeling with FRACGEN/NFFLOW is appropriate if: • Injecting/producing relatively dry gas, with little interference from

water or oil. • Matrix has less than 1 millidarcy permeability. y p y• Variations in fracture apertures, density and connectivity are the

predominant factors effecting gas flow migration. • Flow conductors are oriented nearly vertical and are strata-boundFlow conductors are oriented nearly vertical and are strata bound

(extend from bottom to top of beds that can be modeled individually).

• Faults do not divide the reservoir into tightly sealed compartments

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Faults do not divide the reservoir into tightly sealed compartments or produce significant offsets in the productive strata.

NFFLOW Solves Mass Balance for Three Types of DomainsTypes of Domains

N QRC

N

n

~~

I

nI

( (x

AtA

0

(

+

(

u

~~W

ES

xtFlow from Rock Matrix

e EI

dh

n

Iwe

dPhw3 RC

LRC

REeeIEI

QQQQdlZP

dtd

RThw

s

eIwInIsI QQQQ 0dsdPhwQ

12

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Flow at IntersectionsFlow in Fracture Segments

NFFLOW Uses an Unconventional ApproachApproach

• Properties of NFFLOW– Fracture Q vs p controlled by fracture aperture– Fracture Q vs. p controlled by fracture aperture– Fracture connectivity– Matrix fluid capacity (pore volume)– Matrix permeability– Matrix flow path length

• Data Requirements– Reservoir length, width, thickness (design problem statement)– Fracture network (defined stochastically or deterministically)– Well geometry (design problem statement)g y ( g p )– Matrix porosity and permeability (PPAL)– Fluid properties (equations of state, LUTs)– Well operation parameters (E&P company proprietary data)

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p p ( p y p p y )

Initiated Development of Fracture Network-Based Simulation of CO2 Storage in Shale

2D view of FracGen/NFFlow realization for Marsellus shale.

Engineered hydraulic fractures (in this case a single lateral with 20 fractured stages) are introduced into a network of pre-existing natural fractures

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fractures.

.

Parametric Study: Coupled Flow/Geomechanical Response(Siriwardane et al., WVU)

• Investigate the geomechanical response (pressure and stress changes) of the reservoir and ground surface during CO2 injection and migration in the depleted shale reservoir. p

• Characterization of reservoir deformation and fracture aperture change with CO2 loading

• Estimate capacity and injectivity of CO2

G h i B dGeomechanics-Based Fracture Model

Flow Model (Simulated Vertical Fractures)

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)

Content Contributed by: Hema Siriwardane, West Virginia University Department of Civil & Environmental Engineering

Techno-Economic Assessment(Blumsack et al., PSU)

Phases of Activity Considered

Site EvaluationSite DevelopmentSite DevelopmentInjection OperationsClosure (Plug & Abandon)Post-Closure MVA

Experimental and modeling focus

TEA scope

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g

Circuity Factor Analysis

• Use set of known wells and industrial sources of CO2 (EPA, 2011)2011)

• Use available information on existing rights of way (rail, major roads, existing pipeline)roads, existing pipeline)

• Route between sinks/sources for ~9,000 permitted wells

• Result is a region specific• Result is a region-specific distribution of non-linearity between industrial sources and sinkssinks

• Distribution will be used directly in stochastic techno-economic assessment

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assessment

Summary

Experimental Preliminary Findings• Marcellus CO2 sorption capacity ranges from 50 to 325 SCF/short ton

Organic rich facies have highest CO and methane sorptive capacity• Organic rich facies have highest CO2 and methane sorptive capacity –both correlate strongly to sample TOC and not to clay content

• CO2/CH4 sorption ratio ranges from 1.32 to 4.20H i i h l bili f i f• Hysteresis in shale permeability as a function of net stress

• Effective porosity of shale to CO2 decreases with increasing net stress

Reservoir Simulation and Assessment• Applying different modeling approaches to characterize fractured

shale gas productionshale gas production• Reduced-order model to describe CO2 and EGR performance• Couple reduced-order model to screening-level tecno-economic

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assessment

Thanks!Thanks!

Robert Dilmore, Ph.D., PERobert Dilmore, Ph.D., PENETL ORD, Geosciences Division

dilmore@netl.doe.gov(412)386 5763(412)386-5763Geo Richards, Ph.D., PE

NETL Office of Research and DevelopmentFocus Area Lead, Energy Systems DynamicsFocus Area Lead, Energy Systems Dynamics

Project Director, Industrial Carbon Management

George Guthrie, Ph.D.NETL Office of Research and Development

Focus Area Lead Geologic & Environmental SciencesFocus Area Lead, Geologic & Environmental Sciences

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