CO Enhanced Oil Recovery in the Illinois Basin

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, 2012 Bloomington, Indiana

Midwest Geological Sequestration 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

Matrix Pore Body Scale: Microns Water Water Oil Residual CO2 Oil CO 2 Oil

Pore Pore Throat Throat CO2 Phase Behavior

 Temperature < 88 F

 gas or liquid 1100

1050  Temperature > 88 F 1000 Liquid 950

900  Neither gas or liquid Saturation Line 850

800 Pressure (psi)  Miscible: complete 750 Gas 700 mixing 650 600 50 60 70 80 90  Immiscible: Temperature (deg F) incomplete mixing General CO2 Injection

Midwest Geologic Sequestration Consortium General Injection: Heterogeneity-Layering effects

Layer 1

Layer 2 CO2 (red) CO 2 Layer 3

Layer 4

Oil (green) Layer 5

(Cross Section) Scale: Feet General Injection: Heterogeneity-Anisotropy

Oil Producer Oil Producer

Scale: Acres

CO2 Injector

(Plan View)

Midwest Geologic Sequestration Consortium Illinois Basin Oilfields Annual Oil Production 1906-present

1940 Peak: 148 MMstb

No Historical, Commercial- Scale EOR Current annual: 9 MMstb Stratigraphic Column, Paleozoic Era

• 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

Red square – shale resource plays Illinois Basin Oilfields

OOIP 14.1 Bstb Oil Production 4.2 Bstb OOIP Number of Illinois MMstb Fields Indiana >750 4 100-750 15 50-100 24

Illinois Basin Oil Fields 25-50 38 OOIP bbls per field greater than 750,000,000 Kentucky 100,000,000 - 750,000,000 50,000,000 - 10,000,0000 25,000,000 - 50,000,000 Miles <25 >1000 0306015 less than 25,000,000

19 fields greater than 100 MMstb Annual Oil Production 9 MMstb 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

 Percent porosity  Average porosity = 14.12

Image

20.00 19.38 18.75 18.12 17.50 16.88 16.25 15.62 15.00 14.38 13.75 13.12 12.50 -2824 11.88 11.25 -2840 10.62 -2824 10.00 -2856 9.38 -2840 8.75 8.12 3 -2856 2 6 7.50 3 5 2 4 6.88 6 4 3 5 2 1 6.25 7 6 6 3 6 6 9 5.62 1 2 4 0

2 6 4 9 2 3 6 5.00 7 7 5 2 7 4 1 0 7 6 8 2 4.38 8 0 3 6 1 8 5 7 2 1 2 7 8 2 1 6 6 3.75 8 5 1 5 3 7 8 5 3 1 4 2 8 0 1 8 3.12 8 8 6 1 8 8 1 1 7 8 1 1 4 2.50 9 1 8 0 1 9 1 1.88 8

1 1.25

0.62 North 0.00 N/A Reservoir Modeling

Dale_CO2_CC OREC

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

30 OIL RECOVERY (PERCENT)

10 01/40 05/67 10/94 02/22 07/49 Oil Recovery and CO2 Storage Factors via Modeling

Oil Recovery Factors CO2 Net Utilization Zone Imm Misc Zone Imm Misc Cyp 4.5-5.9 8.6-11 Cyp 1.7-3.1 4.6-9.0 A-V 5.6-7.1 11-15 A-V 1.5-3.3 4.6-8.8 St.G 5.0-6.5 8.6-16 St.G 1.4-5.4 4.6-9.2 W Tx 4-10 8-16 W Tx 5-10

Bbl of oil produced per bbl of 2 stored per bbl oil

produced OOIP

Mscf of CO Miscible, Near Miscible and Immiscible Map

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

Field depth: bulk volume weighted by formation Pressure: 0.433-1.0 psi/ft Temperature: 1.0-1.2 F/100 ft Illinois Basin Oil Fields Kentucky EOR Class Predominately Miscible Predominately Near-Miscible Miles 0306015 Predominately Immiscible Illinois GIS Analysis: Indiana OOIP & Miscibility Map

Miscibility OOIP Illinois Basin Oil Fields OOIP bbls per field Condition Bstb greater than 750,000,000 100,000,000 - 750,000,000 Miscible 2.1-2.5 50,000,000 - 10,000,0000 25,000,000 - 50,000,000 Kentucky less than 25,000,000 Near 3.5-4.1 EOR Class Predominately Miscible Miles 0306015 Predominately Near-Miscible Immiscible 6.4-7.5 CO2 EOR and CO2 SV Maps (Distribution)

Illinois

Condition CO2 EOR Mtonne Bstb Indiana Miscible 58-180 0.24-0.38 Near 53-153 0.28-0.40 Immiscible 29-110 0.34-0.49 Illinois Basin Oil Fields OOIP bbls per field greater than 750,000,000 100,000,000 - 750,000,000 Total 140-440 0.86-1.3 50,000,000 - 10,000,0000 25,000,000 - 50,000,000 less than 25,000,000 Kentucky EOR Class

Predominately Miscible Miles predominately Near-Miscible 010205 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 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 Isopach Map 2 foot  Good contour communication interval 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 Model Projections 20 yr Fullfield: 140-190 Mstb 18-20 % OOIP 600 scf/stb (net)

35.0

Oil_bbl Baseline 30.0 Project oil production 2,700 stb CO oil recovery 2,100 stb 25.0 2 s

20.0

15.0 Oil Production (

10.0

5.0

0.0 09/03/09 09/17/09 10/01/09 10/15/09 10/29/09 11/12/09 11/26/09 12/10/09 12/24/09 01/07/10 01/21/10 02/04/10 02/18/10 03/04/10 03/18/10 04/01/10 04/15/10 04/29/10 05/13/10 05/27/10 06/10/10 06/24/10 07/08/10 07/22/10 08/05/10 08/19/10 09/02/10 09/16/10 Time 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 EOR III Geology

 Depth: 1,900 ft  Modest structure  Lenticular sands  5-10 ft thick  Poor to good communication  Porosity 15 %;

Isopach Map perm 15 md 1 foot contour interval 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, 2012 Bloomington, Indiana

Midwest Geological Sequestration Consortium www.sequestration.org