CO 2 Enhanced Oil Recovery in the Illinois Basin

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1 CO 2 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

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

2 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

3 CO 2 EOR Basics

4 Oil Reservoirs: General CO 2 EOR At specific pressure and temperature, CO 2 is a solvent to crude oil Core labs use CO 2 as low temperature solvent Displacement conditions in an oil reservoir Miscible Immiscible

5 General Oil Recovery: Microscopic Displacement Matrix Pore Body Scale: Microns CO 2 Oil CO 2 Oil Water Residual Oil Water Pore Throat Pore Throat

6 CO 2 Phase Behavior Temperature < 88 F gas or liquid Temperature > 88 F Neither gas or liquid Miscible: complete mixing Immiscible: incomplete mixing Pressure (psi) Liquid Saturation Line Gas Temperature (deg F)

7 General CO 2 Injection Midwest Geologic Sequestration Consortium

8 General Injection: Heterogeneity-Layering effects Layer 1 CO 2 (red) Layer 2 CO 2 Layer 3 Layer 4 Oil (green) Layer 5 (Cross Section) Scale: Feet

9 General Injection: Heterogeneity-Anisotropy Oil Producer Oil Producer Scale: Acres CO 2 Injector (Plan View) Midwest Geologic Sequestration Consortium

10 Illinois Basin Oilfields

11 Annual Oil Production 1906-present 1940 Peak: 148 MMstb Current annual: 9 MMstb No Historical, Commercial- Scale EOR

12 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

13 Illinois Basin Oilfields OOIP 14.1 Bstb Oil Production 4.2 Bstb Illinois Indiana OOIP MMstb Number of Fields > Illinois Basin Oil Fields OOIP bbls per field greater than 750,000, ,000, ,000,000 50,000,000-10,000, ,000,000-50,000,000 less than 25,000,000 Kentucky Miles <25 > fields greater than 100 MMstb Annual Oil Production 9 MMstb

14 Illinois Basin CO 2 EOR Assessment

15 CO 2 EOR Assessment Methodology Volumetric estimate of original oil in place OOIP CO 2 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

16 Deterministic Modeling

17 Percent porosity Geostatistical Modeling Average porosity = Image North N/A

18 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 OIL RECOVERY (PERCENT) /40 05/67 10/94 02/22 07/49

19 Oil Recovery and CO 2 Storage Factors via Modeling Oil Recovery Factors Zone Imm Misc Cyp A-V St.G W Tx Bbl of oil produced per bbl of OOIP CO 2 Net Utilization Zone Imm Misc Cyp A-V St.G W Tx 5-10 Mscf of CO 2 stored per bbl oil produced

20 Miscible, Near Miscible and Immiscible Map Illinois Classification based on anticipated pressure and temperature using gradients observed in the Basin Indiana Field depth: bulk volume weighted by formation Pressure: psi/ft Temperature: F/100 ft Illinois Basin Oil Fields EOR Class Predominately Miscible Predominately Near-Miscible Predominately Immiscible Kentucky Miles

21 Illinois Indiana GIS Analysis: OOIP & Miscibility Map Illinois Basin Oil Fields OOIP bbls per field greater than 750,000, ,000, ,000,000 50,000,000-10,000, ,000,000-50,000,000 less than 25,000,000 EOR Class Predominately Miscible Predominately Near-Miscible Kentucky Miles Miscibility Condition OOIP Bstb Miscible Near Immiscible

22 CO2 EOR and CO2 SV Maps (Distribution) Illinois Miscible CO2 EOR Mtonne Bstb Near Immiscible Total Condition Indiana Illinois Basin Oil Fields OOIP bbls per field greater than 750,000, ,000, ,000,000 50,000,000-10,000,0000 Kentucky 25,000,000-50,000,000 less than 25,000,000 EOR Class Predominately Miscible predominately Near-Miscible Miles 20 Maps and tables for EOR and CSV based on geologic and reservoir modeling

23 MGSC CO 2 EOR Pilots

24 EOR: CO 2 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

CO 2 EOR II: Miscible (Liquid) Flood (Mumford Hills Field, Indiana) Field History (1974) OOIP 2,100,000 bbl Edgewater injection 1976 Pre-CO 2, one water injector; two active oil producers on pump

25 CO 2 EOR II: Miscible (Liquid) Flood (Mumford Hills Field, Indiana) Field History (1974) OOIP 2,100,000 bbl Edgewater injection 1976 Pre-CO 2, 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

ft oil column Small bottom aquifer Porosity 19% Perm

26 EOR II: Geology Depth 1,900 ft Small structure w/ stratigraphic pinchout Channel sand; ft thick 20 ft oil column Small bottom aquifer Porosity 19% Perm 155 md Good communication Isopach Map 2 foot contour interval

27 EOR II Cumulative Injection 120 MMscf (6,900 tons) Injected 50 MMscf (2,950 tons) before water; 70 MMscf (3,950 tons) after water Mscf/d (20-35 tons/day) Cumulative Water Injection 1/1/10-5/15/10: 13, bwpd 12/15/10 present: 7, bwpd

28 Oil Production Related to Pilot & CO 2 Model Projections 20 yr Fullfield: Mstb % OOIP 600 scf/stb (net) Oil_bbl Baseline Project oil production 2,700 stb CO 2 oil recovery 2,100 stb /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 Oil Production (s Time

CO 2 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

29 CO 2 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 ( psi) 100 bbl/day water injection; bopd

30 EOR III Geology Depth: 1,900 ft Modest structure Lenticular sands Isopach Map 1 foot contour interval 5-10 ft thick Poor to good communication Porosity 15 %; perm 15 md

31 EOR III Cumulative Injection 125 MMscf (7,300 tons) injected (5/26/10) Mscf/d (25-30 tons/day) Produced approximately 20% of injected CO 2 ; predominantly from two wells 25,000 bbl water injected 6/7/10-9/30/ bwpd

32 CO 2 EOR Estimates Model Projections 20 yr Fullfield: Mstb % OOIP Mscf/stb (net) Pilot: Mstb

33 CO 2 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 CO 2 injectivity following CO 2 or water

34 Illinois Basin CO 2 EOR: Challenges to Commercial Deployment

35 Challenges to Commercial Scale CO 2 EOR in the Illinois Basin No demand for CO 2 by oilfield operators No Illinois Basin commercial scale CO 2 EOR analog (too few, too small pilots) Oilfield Owner Perceptions Corrosion and loss of wellbores Wellbore age and condition Capital intensive No CO 2 EOR experienced staff Available, reliable source: Transportation

36 Challenges to Commercial Scale CO 2 EOR in the Illinois Basin Existing Illinois Basin Oilfield operator Large-scale demonstration project CO 2 EOR operators (outside of ILB) Increase familiarity with Illinois Basin CO 2 source and pipeline

37 CO 2 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

Waterflooding. A Tried and True Technique for Secondary Oil Recovery. Houston Bar Association Oil, Gas and Mineral Law Section March 26, 2013

Waterflooding. A Tried and True Technique for Secondary Oil Recovery. Houston Bar Association Oil, Gas and Mineral Law Section March 26, 2013 Waterflooding A Tried and True Technique for Secondary Oil Recovery Houston Bar Association Oil, Gas and Mineral Law Section March 26, 2013 F. J. Deacon Marek, P.E President Dallas, Texas Brian R. Sullivan,