CO2 Enhanced Oil Recovery in the Illinois Basin

Scott M. Frailey, Ph.D., P.E.Illinois State Geological Survey

Indiana Center for Coal Technology

April 5, 2012Bloomington, Indiana

Midwest GeologicalSequestration Consortium

www.sequestration.org

Acknowledgements The Midwest Geological Sequestration Consortium is funded by the

U.S. Department of Energy through the National Energy Technology Laboratory (NETL) via the Regional Carbon Sequestration Partnership Program (contract number DE-FC26-05NT42588),

The Illinois Department of Commerce and Economic Opportunity, Office of Coal Development through the Illinois Clean Coal Institute (cost share agreement), and

The Commonwealth of Kentucky, through the Kentucky Consortium for Carbon Storage (KYCCS) at the University of Kentucky, Lexington.

The Midwest Geological Sequestration Consortium (MGSC) is a collaboration led by the geological surveys of Illinois, Indiana, and Kentucky

Gallagher Drilling, Inc and Petco, Inc. field operation partners

CO2 EOR Basics

Oil Reservoirs: General CO2 EOR At specific pressure and temperature, CO2

is a solvent to crude oil Core labs use CO2 as low temperature solvent

Displacement conditions in an oil reservoir Miscible Immiscible

General Oil Recovery: Microscopic Displacement

Oil

WaterMatrix

Pore Throat

Pore Throat

Pore Body

Oil Residual Oil

Water

CO2CO2

Scale: Microns

CO2 Phase Behavior

Temperature < 88 F gas or liquid

Temperature > 88 F Neither gas or liquid

Miscible: complete mixing

Immiscible: incomplete mixing

600

650

700

750

800

850

900

950

1000

1050

1100

50 60 70 80 90

Temperature (deg F)

Pres

sure

(psi

)

Liquid

Gas

Saturation Line

Midwest Geologic Sequestration Consortium

General CO2 Injection

General Injection: Heterogeneity-Layering effects

Layer 1

Layer 2

Layer 3

Layer 4

Layer 5

CO2 (red)

Oil (green)

Scale: Feet

CO2

(Cross Section)

Midwest Geologic Sequestration Consortium

General Injection: Heterogeneity-Anisotropy

Scale: Acres

Oil Producer Oil Producer

CO2 Injector

(Plan View)

Illinois Basin Oilfields

Annual Oil Production 1906-present

1940 Peak: 148 MMstb

No Historical, Commercial-Scale EORCurrent annual:

9 MMstb

.

Stratigraphic Column, Paleozoic Era

Red square – shale resource plays

• Pennsylvanian to Ordovician productive zones

• Over 50 producing horizons -3 prolific

• Reservoirs - porous sandstone and limestone

• Relative shallow• Highly

compartmentalized .Black dot size - relative oil production from each zone

Illinois Basin Oilfields

Oil Production 4.2 BstbOOIP 14.1 Bstb

Illinois

Indiana

Kentucky

0 30 6015Miles

Illinois Basin Oil FieldsOOIP bbls per field

greater than 750,000,000

100,000,000 - 750,000,000

50,000,000 - 10,000,0000

25,000,000 - 50,000,000

less than 25,000,000

Annual Oil Production 9 MMstb19 fields greater than 100 MMstb

OOIP MMstb

Number of Fields

>750 4

100-750 15

50-100 24

25-50 38

<25 >1000

Illinois Basin CO2 EOR Assessment

CO2 EOR Assessment Methodology

Volumetric estimate of original oil in place OOIP CO2 EOR oil recovery (% OOIP)

Reservoir simulation for recovery and storage factors based on Illinois Basin geologic formations (Cypress, Aux

Vases, St. Genevieve) Miscibility type: miscible and immiscible

Deterministic Modeling

Geostatistical Modeling

-2856

-2840

-2824 -2856

-2840

-2824

3265441

3265769

3266097

3266425

3266753

3267081

3267409

1817216

1817544

1817872

1818200

1818528

1818856

1819184

Image

N/A

20.0019.3818.7518.1217.5016.8816.2515.6215.0014.3813.7513.1212.5011.8811.2510.6210.00 9.38 8.75 8.12 7.50 6.88 6.25 5.62 5.00 4.38 3.75 3.12 2.50 1.88 1.25 0.62 0.00

Percent porosity Average porosity = 14.12

North

Reservoir Modeling

01/40 05/67 10/94 02/22 07/4910

20

30

40

50

60

70

OIL

REC

OVE

RY

(PER

CEN

T)

Dale_CO2_CC OREC

OREC ROOT Dale_CO2_CC OREC ROOT Dale_CO2_CB OREC ROOT Dale_CO2_DAAA OREC ROOT Dale_CO2_DAAB

Oil Recovery and CO2 Storage Factors via Modeling

Zone Imm Misc

Cyp 1.7-3.1 4.6-9.0

A-V 1.5-3.3 4.6-8.8

St.G 1.4-5.4 4.6-9.2

W Tx 5-10

CO2 Net Utilization

Zone Imm Misc

Cyp 4.5-5.9 8.6-11

A-V 5.6-7.1 11-15

St.G 5.0-6.5 8.6-16

W Tx 4-10 8-16

Oil Recovery Factors

Bbl of oil produced per bbl of OOIP Mscf of CO2 stored per bbl oil produced

Miscible, Near Miscible and Immiscible Map

Field depth: bulk volume weighted by formation

Pressure: 0.433-1.0 psi/ft

Temperature: 1.0-1.2 F/100 ft

Classification based on anticipated pressure and temperature using gradients observed in the Basin

Illinois

Indiana

Kentucky

0 30 6015Miles

Illinois Basin Oil FieldsEOR Class

Predominately Miscible

Predominately Near-Miscible

Predominately Immiscible

GIS Analysis: OOIP &

Miscibility Map

Illinois

Indiana

Kentucky

0 30 6015Miles

Illinois Basin Oil FieldsOOIP bbls per field

greater than 750,000,000

100,000,000 - 750,000,000

50,000,000 - 10,000,0000

25,000,000 - 50,000,000

less than 25,000,000

EOR ClassPredominately Miscible

Predominately Near-Miscible

Miscibility Condition

OOIPBstb

Miscible 2.1-2.5Near 3.5-4.1

Immiscible 6.4-7.5

CO2 EOR and CO2 SV Maps(Distribution)

Illinois

Indiana

Kentucky

Illinois Basin Oil FieldsOOIP bbls per field

greater than 750,000,000

100,000,000 - 750,000,000

50,000,000 - 10,000,0000

25,000,000 - 50,000,000

less than 25,000,000

EOR ClassPredominately Miscible

predominately Near-Miscible 0 10 205Miles

Condition CO2Mtonne

EORBstb

Miscible 58-180 0.24-0.38Near 53-153 0.28-0.40

Immiscible 29-110 0.34-0.49Total 140-440 0.86-1.3

Maps and tables for EOR and CSV based on geologic and reservoir modeling

MGSC CO2 EOR Pilots

EOR: CO2 Sequestration Pilots

Field demonstrations: DOE Regional Sequestration Partnership Program S/EOR I: huff n puff S/EOR II: inverted 5-spot, liquid S/EOR III: area flood, gas S/ECBM: injector with monitoring wells

CO2 EOR II: Miscible (Liquid) Flood(Mumford Hills Field, Indiana)

Field History (1974) OOIP 2,100,000 bbl Edgewater injection 1976 Pre-CO2, one water injector; two

active oil producers on pump Production History

Primary oil production 41,000 bbl Waterflood oil production 794,000 bbl Total 835,000 bbl; 40% oil recovery

Injection zone Reservoir pressure 1,200-1,500 psi;

wells can flow to surface 1,000 bbl/day water injection; 3-5

bopd

Isopach Map 2 foot

contour interval

EOR II: Geology

Depth 1,900 ft Small structure w/

stratigraphic pinchout

Channel sand; 10-40 ft thick 20 ft oil column Small bottom aquifer

Porosity 19% Perm 155 md

Good communication

EOR II Cumulative Injection

120 MMscf (6,900 tons) Injected 50 MMscf (2,950 tons) before water; 70

MMscf (3,950 tons) after water 340-600 Mscf/d (20-35 tons/day)

Cumulative Water Injection 1/1/10-5/15/10: 13,000 bw @ 150 bwpd 12/15/10 – present: 7,500 bw @ 150 bwpd

Oil Production Related to Pilot & CO2

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Time

Oil

Prod

uctio

n (s

Oil_bblBaseline Project oil production 2,700 stb

CO2 oil recovery 2,100 stb

Model Projections20 yr Fullfield: 140-190 Mstb 18-20 % OOIP

600 scf/stb (net)

CO2 EOR III: Immiscible Flood(Sugar Creek Field, Kentucky)

Field History (1963) OOIP 2,410,000 bbl Waterflood 1993

Oil Production History Primary 475,000 bbl Waterflood 314,000 bbl Total 793,000 bbl 33% oil recovery

Water injection low reservoir pressure, not

depleted (500-600 psi) 100 bbl/day water injection;

36-42 bopd

Isopach Map 1 foot

contour interval

EOR III Geology

Depth: 1,900 ft Modest structure Lenticular sands

5-10 ft thick Poor to good

communication Porosity 15 %;

perm 15 md

EOR III Cumulative Injection

125 MMscf (7,300 tons) injected (5/26/10) 425 – 515 Mscf/d (25-30 tons/day)

Produced approximately 20% of injected CO2; predominantly from two wells

25,000 bbl water injected 6/7/10-9/30/10 100-150 bwpd

CO2 EOR Estimates

Model Projections

20 yr Fullfield:

113-174 Mstb

2.8-5.5% OOIP

0.88-1.2 Mscf/stb (net)

Pilot: 2.7-3.2 Mstb

CO2 EOR Summary

Typical operational problems: Early breakthrough & handling high gas rate Scale Flow line leak

Atypical operations: Corrosion managed Reduced annual workovers No reduced water or CO2 injectivity following

CO2 or water

Illinois Basin CO2 EOR: Challenges to Commercial

Deployment

Challenges to Commercial Scale CO2 EOR in the Illinois Basin

No demand for CO2 by oilfield operators No Illinois Basin commercial scale CO2 EOR

analog (too few, too small pilots) Oilfield Owner Perceptions

Corrosion and loss of wellbores Wellbore age and condition

Capital intensive No CO2 EOR experienced staff

Available, reliable source: Transportation

Challenges to Commercial Scale CO2 EOR in the Illinois Basin

Existing Illinois Basin Oilfield operator Large-scale demonstration project

CO2 EOR operators (outside of ILB) Increase familiarity with Illinois Basin

CO2 source and pipeline

CO2 Enhanced Oil Recovery in the Illinois Basin

Scott M. Frailey, Ph.D., P.E.Illinois State Geological Survey

Indiana Center for Coal Technology

April 5, 2012Bloomington, Indiana

Midwest GeologicalSequestration Consortium

www.sequestration.org