Today s Oil Recovery Efficiency 33% Future Oil Recovery Efficiency 60%+ MAXIMIZING OIL RECOVERY EFFICIENCY AND SEQUESTRATION OF CO 2 WITH GAME CHANGER CO 2 -EOR TECHNOLOGY Presented by: Vello A. Kuuskraa, President Advanced Resources International vkuuskraa@adv-res.com JAF02713.PPT 1 January 2008 Advanced Resources International
SPE DISTINGUISHED LECTURER SERIES is funded principally through a grant of the SPE FOUNDATION The Society gratefully acknowledges those companies that support the program by allowing their professionals to participate as Lecturers. And special thanks to The American Institute of Mining, Metallurgical, and Petroleum Engineers (AIME) for their contribution to the program. JAF02713.PPT January 2008
BACKGROUND 1. Status and Outlook for CO 2 -EOR 2. Game Changer CO 2 -EOR Technology Increasing Oil Recovery Efficiency Expanding CO 2 Storage Capacity 3. Early Application of CO 2 -EOR 4. Summary JAF02713.PPT 3 January 2008
LARGE VOLUMES OF DOMESTIC OIL REMAIN STRANDED AFTER PRIMARY/SECONDARY OIL RECOVERY Original Oil In-Place: 596 B Barrels* Stranded Oil In-Place: 400 B Barrels* Future Challenge 390 Billion Barrels Cumulative Production 175 Billion Barrels Proved Reserves 21 Billion Barrels *All domestic basins except the Appalachian Basin. Source: Advanced Resources Int l. (2005) JAF02713.PPT 4 January 2008
U.S. CO 2 -EOR ACTIVITY Dakota Coal Gasification Plant 86 Number of CO 2 -EOR Projects Natural CO 2 Source Industrial CO 2 Source CO 2 Pipeline LaBarge Gas Plant 2 McElmo Dome Sheep Mountain Bravo Dome JAF01994.CDR Val Verde Gas Plants JAF02713.PPT 5 January 2008 9 1 1 57 6 Enid Fertilizer Plant 6 3 Jackson Dome Antrim Gas Plant Currently, 86 CO 2 -EOR projects provide 237,000 B/D Affordable natural CO 2 launched CO 2 -EOR activity in the 1980 s Federal tax credits (Sec.43) and state severance tax relief still encourage CO 2 -EOR
GROWTH OF CO 2 -EOR PRODUCTION IN THE U.S. Enhanced Oil Recovery (barrels/day) 250,000 200,000 150,000 100,000 50,000 0 Gulf Coast/Other Mid-Continent Rocky Mountains Permian Basin JAF2006016.XLS 1986 1988 1990 1992 1994 1996 1998 2000 2002 2004 2006 Source: Oil and Gas Journal, 2002. Year JAF02713.PPT 6 January 2008
CO 2 - EOR Activity Outside of the U.S. Area Formation Depth Oil Gravity Viscosity Canada Weyburn Unit 9,900 LS/Dolo 4,660 28 o 3 cp Joffre 6,625 Sand 4,900 42 o 1 cp Trinidad Forest Reserve 500 Sand 2,000-4,200 17-25 o 10-100+ cp Oropouche 175 Sand 2,400 29 o 5 cp Turkey Bati Raman 12,890 LS 4,260 13 o 590 cp Numerous hydrocarbon miscible and nitrogen EOR projects exist in Canada, Libya, UAE, Mexico and Venezuela that would be favorable and convert to CO2-EOR In addition, CO2-EOR has been discussed for oil fields in the North Sea. JAF02713.PPT 7 January 2008
OUTLOOK FOR CO2-EOR Recently updated study of applying state-ofthe-art CO2-EOR in the U.S. indicate: 88 billion barrels of technically recoverable resource, From 39 to 48 billion barrels of economically recoverable resource, depending on oil price and CO2 costs. Results are based on applying streamline reservoir simulation to 2,012 large oil reservoirs (74% of U.S. oil production). Previous version of the basin studies are available on the U.S. DOE web site. http://www.fe.doe.gov/programs/oilgas/eor/ten_basinoriented_co2-eor_assessments.html JAF02713.PPT 8 January 2008
One-Dimensional Schematic of the CO 2 Miscible Process Miscibility is Developed in This Region (CO 2 and Oil Form Single Phase) Pure CO 2 CO 2 Vaporizing Oil Components CO 2 Condensing Into Oil Original Oil Direction of Displacement JAF02713.PPT 9 January 2008
Domestic Oil Resources Technically and Economically Recoverable w/co 2 -EOR 100 88.1 80 Label 60 40 47.4 20 0 Technically Recoverable Economically Recoverable* 2.3 Already Produced/ Proven *Assuming oil price of $70/B (real); CO2 costs (delivered to field at pressure) of $45/metric ton ($2.38/Mcf); investment hurdle rate (15%, real). JAF02713.PPT 10 January 2008
Market Demand for CO 2 by the Enhanced Oil Recovery Industry (1) 14,000 12,000 12,500 10,000 9,700 Label 8,000 6,000 7,500 4,000 2,000 2,800* 2,200** 0 Total U.S. CO2 Demand New Lower-48 CO2 Demand Net Lower-48 From Captured CO2 Emissions *CO2 demand in Alaska is already being met by on-going CO2-EOR projects **CO2 demand that can be met by natural CO2 and already being captured CO2 emissions. (1) Economic CO2 market demand for EOR at oil price of $70/B (real), CO2 cost of $45/mt, and ROR of 15% (real). JAF02713.PPT 11 January 2008
Sources of CO 2 State/ Province (storage location) Texas-Utah-New Mexico- Oklahoma Colorado-Wyoming Mississippi Michigan Oklahoma Saskatchewan Source Type (location) Geologic (Colorado-New Mexico) Gas Processing (Texas) Gas Processing (Wyoming) Geologic (Mississippi) Ammonia Plant (Michigan) Fertilizer Plant (Oklahoma) Coal Gasification (North Dakota) CO2 Supply MMcfd** Natural Anthropogenic 1,700 110-340 400 - - 15-35 - 145 TOTAL 2,100 645 * Source: 12th Annual CO2 Flooding Conference, Dec. 2006 ** MMcfd of CO2 can be converted to million metric tons per year by first multiplying by 365 (days per year) and then dividing by 18.9 * 10 3 (Mcf per metric ton). JAF02713.PPT 12 January 2008
ARE HIGHER OIL RECOVERY EFFICIENCIES ACHIEVABLE? Example Carbonate Field Oil Recovery Efficiencies 80% Jay Salt Creek Recovery Factor Means 2003 Recovery Time JAF02713.PPT 13 January 2008 Source: Three ExxonMobil Oil Fields, SPE 88770 (2004)
NEXT GENERATION CO 2 -EOR TECHNOLOGY Reservoir modeling and selected field tests show that high oil recovery efficiencies are possible with innovative applications of CO 2 -EOR. So far, except for a handful of cases, the actual performance of CO 2 -EOR has been less than optimum due to: Geologically complex reservoirs Limited process control Insufficient CO 2 injection JAF02713.PPT 14 January 2008
IMPACT OF GEOLOGIC COMPLEXITY ON CO 2 -EOR PERFORMANCE Inability to target injected CO 2 to reservoir strata with high residual oil saturation. Higher oil saturation portion of reservoir is inefficiently swept; Relative Location of the Water Front CO 2 channeling reduced with well workover. Well 27-6 Injection Profile Layer 1 (High Sor, Low k) Water Layer 2 (Low Sor, High k) 368 Days 6,350 (Before) (After) 478 Days (Breakthrough) Depth 0 100 200 300 Distance, ft 1839 Days (Channeling in Layer 2) Source: Adapted by Advanced Resources Int l from Enhanced Oil Recovery, D.W. Green and G. P. Willhite, SPE, 1998. 6,900 0 20 40 60 80 100 % Injected Before 0 20 40 60 80 100 % Injected After Source: SACROC Unit CO 2 Flood: Multidisciplinary Team Improves Reservoir Management and Decreases Operating Costs, J.T. Hawkins, et al., SPE Reservoir Engineering, August 1996. JAF02713.PPT 15 January 2008
IMPACT OF LIMITED PROCESS CONTROL ON CO 2 -EOR PERFORMANCE Oil and Water Water Oil and Water Polymer In Water Water Waterflood (High Mobility Ratio) Injected CO 2 achieves only limited contact with the reservoir due to: Viscous fingering Gravity override Addition of viscosity enhancers would improve mobility ratio and reservoir contact. JAF02713.PPT 16 January 2008 Viscosity Enhanced Flood (Improved Mobility Ratio) Source: Adapted by Advanced Resources Int l from Enhanced Oil Recovery, D.W. Green and G. P. Willhite, SPE, 1998.
IMPACT OF LIMITED PRESSURE CONTROL ON CO 2 -EOR PERFORMANCE SACROC Unit 1992 Pressure Contour Map. Analysis of past CO 2 floods also shows that, in many cases, the CO 2 -EOR project was operated below miscibility pressure in positions of the reservoir. This was caused by low well operating pressures, too few injection wells, and failure to maintain a favorable fluid balance. Crosshatch shading indicates areas below MMP (2,300 psig) and solid shading indicates areas below bubblepoint pressure (1,850 psig). JAF02713.PPT 17 January 2008
IMPACT OF INSUFFICIENT CO 2 INJECTION ON CO 2 -EOR PERFORMANCE Because of high CO 2 costs and lack of process control, most older CO 2 floods used too little CO 2. 1.0 0.9 Sweep Efficiency in Miscible Flooding 25 Injected CO 2 vs Oil Recovery Means (San Andres) @ 2:1 WAG Ratio Sweep Efficiency, E A 0.8 0.7 0.6 0.5 0.4 0.3 0.2 0.1 0 V at B.T. vs. M pd 0 0.2 0.5 1 2 5 10 20 50 100 200 500 1000 Mobility Ratio, M Note: V pd is displaceable fluid pore volumes of CO 2 injected. Source: Claridge, E.L., Prediction of Recovery in Unstable Miscible Displacement, SPE (April 1972). V pd 5.0 3.0 2.0 1.5 1.0 0.6 0.2 0.1 Incremental Tertiary Recovery - % OOIP 20 15 10 5 0 0 10 Source: SPE 24928 (1992) 0.8 HCPV 0.6 HCPV 0.4 HCPV 0.2 HCPV 20 30 40 50 Years JAF02713.PPT 18 January 2008
NEXT GENERATION CO 2 -EOR TECHNOLOGY Over coming these technical barriers requires next generation CO 2 -EOR technology: Innovative Flood Design and Well Placement. Adding horizontal production wells and vertical CO 2 injection wells, enabling CO 2 to contact residual oil from poorly swept portions of the reservoir. Viscosity and Miscibility Enhancement. Adding mobility control with viscosity enhancers and lowering MMP with miscibility enhancers. Increased Volume of CO 2 Injection. Injecting up to 1.5 HCPV of CO 2. Flood Performance Diagnostics and Control. Fully staffed technical team. Uses instrumented observation wells and downhole sensors to monitor progress. Conducts periodic 4-D seismic and pressure plus zoneby-zone flow tests (among others) to manage and control the CO 2 flood. JAF02713.PPT 19 January 2008
GAME CHANGER CO 2 -EOR TECHNOLOGY (Cont d) The DOE report, Evaluating the Potential for Game Changer Improvements in Oil Recovery Efficiency from CO 2 -Enhanced Oil Recovery : Reviews performance of past CO 2 -EOR floods. Sets forth theoretically and scientifically possible advances in technology for CO 2 -EOR. Examines how much game changer CO 2 -EOR technology would increase oil recovery and CO 2 storage capacity. Available on the U.S. DOE web site. http://www.fe.doe.gov/programs/oilgas/publications/eor_co 2/Game_Changer_Document.pdf JAF02713.PPT 20 January 2008
INTEGRATING CO 2 -EOR AND CO 2 STORAGE Expanding CO 2 Storage Capacity: A Case Study. Large Gulf Coast oil reservoir with 340 million barrels (OOIP) in the main pay zone. Primary/Secondary Oil Recovery: 153 million barrels (45% of OOIP) Main Pay Zone: Depth - - 14,000 feet Oil Gravity - - 33 o API Porosity - - 29% Net Pay - - 325 feet Initial Pressure - - 6,620 psi Miscibility Pressure - - 3,250 psi Another 100 million barrels (OIP) in the underlying 130 feet of residual oil zone and an underlying saline reservoir 195 feet thick. Theoretical CO 2 storage capacity: 2,710 Bcf (143 million tonnes) JAF02713.PPT 21 January 2008
INTEGRATING CO 2 -EOR STORAGE First, this Gulf Coast oil reservoir is produced using state-ofthe-art CO 2 -EOR project design - - vertical wells, 1 HCPV of CO 2 (purchased and recycled CO 2 ), and a 1:1 WAG. Next, this Gulf Coast oil reservoir is produced using next generation CO 2 -storage and CO 2 -EOR project design. Gravity-stable, vertical CO 2 injection with horizontal wells. Targeting the main pay zone, plus the transition/residual oil zone and the underlying saline aquifer. Injecting continuous CO 2 (no water) and continuing to inject CO 2 after completion of oil recovery. JAF02713.PPT 22 January 2008
INTEGRATING CO 2 -EOR AND CO 2 STORAGE (Cont d) CO 2 Source Oil to Market Production Well CO 2 Injection CO 2 Recycled Current Water Oil Contact Original Water Oil Contact Swept Area Oil Bank Unswept Area TZ/ROZ Stage #1 Stage #2 Stage #3 JAF02713.PPT 23 January 2008 Saline Reservoir
4800 4850 4900 4950 5000 5050 OWC 5100 5150 Oil Saturation % 100 0 Main Pay Zone (MPZ) Base of Producing OWC Transition Zone (TZ) ILLUSTRATION OF OIL RESOURCES IN TRANSITION AND RESIDUAL OIL ZONES Oil Saturation Profile in the TZ/ROZ. Adapted from Wasson Denver Unit Well Log. 5200 5250 5300 Residual Oil Zone (ROZ) 5350 5400 5450 Base of Ultimate OWC JAF02713.PPT 24 January 2008
INTEGRATING CO 2 -EOR AND CO 2 STORAGE (Cont d) With alternative CO 2 storage and EOR design, much more CO 2 can be stored and more oil becomes potentially recoverable. The additional oil produced is GREEN OIL *. CO 2 Storage (tonnes) Storage Capacity Utilization Oil Recovery (barrels) % Carbon Neutral ( Green Oil ) State of the Art (millions) 19 13% 64 80% Next Generation (millions) 109 76% 180 160% * Green Oil means that more CO 2 is injected and stored underground than the volume of CO 2 contained in the produced oil, once burned. JAF02713.PPT 25 January 2008
Weyburn Enhanced Oil Recovery Project (An Operating Project Maximizing Oil Recovery and CO 2 Storage) Largest CO 2 EOR project in Canada: OOIP 1.4 Bbbls 155 Mbbls incremental Outstanding EOR response Canada USA Regina Weyburn World s largest geological CO 2 sequestration project 2.4 MMt/year (current) 7 MMt to date 23 MMt with EOR 55 MMt with EOR/sequestration Saskatchewan Canada USA Manitoba Montana North Dakota CO 2 Beulah JAF02713.PPT 26 January 2008 Source: EnCana, 2005
EARLY APPLICATION OF CO 2 -EOR Improving Revenues and Profits: A Case Study. Large, 2.4 billion barrels (OOIP) Permian Basin oil reservoir. Depth - - 5,200 Gravity - - 33 o API Porosity - - 12% Net Pay - - 141 ft. Initial Pressure - - 1,850 psi Miscibility Pressure - - 1,500 psi First produced using traditional sequence - - primary, then secondary and finally CO 2 -EOR. Next produced with early application CO 2 -EOR design - - primary, then CO 2 -EOR (skipping the waterflood). JAF02713.PPT 27 January 2008
EARLY APPLICATION OF CO 2 -EOR Traditional Sequence Early Application 70% 70% Oil Recovery (%OOIP) 60% 50% 40% 30% 20% 10% 14% 39% Secondary Recovery Primary Recovery 61% CO 2 -EOR 42% 17% Oil Recovery (%OOIP) 60% 50% 40% 30% 20% 10% 14% CO 2 -EOR Primary Recovery 60% 17% 0% 20 48 73 0% 20 48 73 Years of Operation Years of Operation JAF02713.PPT 28 January 2008
EARLY APPLICATION OF CO 2 -EOR (Cont d) The economic value of this oil reservoir (after primary recovery) is much higher under early application of CO 2 -EOR. Gross Revenues (PV @ 10%)* Oil Recovery (Barrels/Years) Water Production (Barrels) Traditional Sequence (After Primary Recovery) (Million) $9,300 1,060 (53 yrs) 3,900 Early Application (After Primary Recovery) (Million) $19,000 1,040 (28 yrs) 1,500 *Present value at 10% discount rate using $40/B oil price. JAF02713.PPT 29 January 2008
SUMMARY 1. CO 2 enhanced oil recovery, while still an emerging industry, has the potential to add significant volumes of future oil supply, in the U.S. and worldwide. 2. Thirty years of experience shows that CO 2 -EOR is a technically sophisticated and challenging process, but one that can be successful if managed and controlled, not just operated. 3. Game Changer CO 2 -EOR technologies, incorporating scientifically possible but not yet fully developed advances, could significantly increase oil recovery efficiency. JAF02713.PPT 30 January 2008
SUMMARY (Cont d) 4. Early application of CO 2 -EOR technology can significantly increase the economic value of the remaining oil resource. 5. Wide-scale application of CO 2 -EOR is constrained by lack of sufficient EOR-Ready CO 2 supplies. A mutually beneficial link exists between CO 2 -EOR and new industrial sources of CO 2. 6. Under a carbon constrained world, productively using industrial CO2 emissions for CO 2 -EOR will become a winning strategy. JAF02713.PPT 31 January 2008