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1 Reasons for Water Flooding Primary Production Method Leaves - PDF document

Nov 22, 2023 •274 likes •355 views

Water Flood Workshop October 23 rd 2013 Long Beach, California Water Flooding and Waterflood Design by Dr. Abdus Satter Water Flooding Water Flood Process Reasons for Water flooding History of Water flooding Water Flood

  1. Water Flood Workshop October 23 rd 2013 Long Beach, California Water Flooding and Waterflood Design by Dr. Abdus Satter Water Flooding  Water Flood Process  Reasons for Water flooding  History of Water flooding  Water Flood Patterns  Water Flood Recovery Efficiency  Oil Displacement by Water flooding  Variables Affecting Recovery Efficiencies Water Flood Process Water flooding consists of injecting water into a set of wells while producing from the surrounding wells. It maintains reservoir pressure and displaces oil from the injectors to the producers 1

  2. Reasons for Water Flooding  Primary Production Method Leaves Behind 1/3 to 1/2 or More of the Original Oil In Place  After Primary Production, Waterflooding Enhances Substantially Production and Reserves  It Is the Most Widely Used Recovery Method After Primary  Generally Available Water  Efficient Agent for Displacing Light/Medium Gravity Oil  Low Capital Investment, Operating Costs, and favorable Economics  Easy to Inject and spreads easily History of Water flooding  Accidental Water Injection in Pithole City Area in 1865  In Earliest Days started at a Single well and then to Circle Drive, Line Drive, Peripheral Floods  First 5-Spot Flood Initiated in 1924 in Bradford Field  Grew to Oklahoma in 1931and then to Texas in 1936  Widespread application started in early 1950 Water Flood Patterns  Five Spot Regular – 4 Injectors and 1Producer  Five Spot Inverted – 1 Injector and 4 Producers  Seven Spot Regular – 6 Injectors and 1Producer Seven Spot Inverted – 1 Injector and 6 Producers  Nine Spot Regular – 8 Injectors and 1Producer  Nine Spot Inverted – 1 Injector and 8 Producer  2

  3. Waterflooding Recovery Efficiency Overall Recovery Efficiency ER = ED x EV Where: ER = Overall recovery efficiency, % ED = Displacement efficiency within the volume swept by water, % EV = Reservoir Volume swept by water, % = EA x EI EA = Areal sweep efficiency, % EI = Vertical or invasion sweep efficiency, % Oil Displacement by Waterflooding Variables Affecting Efficiencies  Displacement Efficiency by Rock and Fluid Properties, and Throughput (Pore Volume Injected)  Areal and Pattern Sweep Efficiencies by Flooding Pattern Types, Mobility Ratio, Reservoir Heterogeneity, and Throughput 3

  4. Typical Successful Waterflood Performance Water Flood Design  Design Considerations  Example Water Flood Development Plan Design Considerations  Reservoir Characterization – Geoscience and Engineering Data  Potential Flooding Plans – Peripheral, Pattern, Well Spacing  Estimate Injection, Production Rates  Facilities Design – Fluid Volumes and Rates for Sizing Equipment, Water Source and Disposal  Capital Expenditures and Operating Costs  Economic Evaluation, Risk, and Uncertainties 4

  5. Water Flood Development Plan Discovery Exploration Delineation Reservoir Abandonment Management Development Tertiary Primary Waterflood Mature Field Production Professionals Involved  Exploration - Geologists, Geophysicists  Discovery - Drilling and Reservoir Engineers Petrophysicists  Delineation - Sam as above  Development - Reservoir, Drilling, Operation, and Facilities Engineers  Production – Production Engineers WF Project Development Approach  Build Integrated Geoscience and Engineering Model Using Available Data  Simulate Full-Field Primary Performance  Forecast Performance under Peripheral and Pattern Waterflood Drive 5

  6. Top Structure Map Waterflood Prospect Reservoir -4300 -4290 W-9 -4270 W-8 0 2 8 4 - -4280 -4250 W-3 -4240 -4230 W-2 -4270 0 8 2 -4220 4 - -4280 W-1 -4230 -4240 W-4 W-5 -4280 -4280 -4250 -4270 W-8 -4290 W-7 -4290 - 4 2 Top Structure Map 8 0 -4300 Development Cases Case 2 Case 3 Case 1 Case 1 Peripheral 5 4 Case 2 Peripheral 9 8 Case 4 Case 5 Case 3 Pattern 1 4 Case 4 Pattern 4 9 Case 5 Pattern 12 13 Cumulative Oil Recovery vs. Time 12000 Cum. Oil Produced (MSTB) 10000 Secondary 8000 6000 Primary 4000 Depletion 2000 0 0.00 5.00 10.00 15.00 20.00 25.00 30.00 TIME (Years) Depletion Case-1 Case-2 Case-3 Case-4 Case-5 6

  7. Oil Recovery vs. Water Injected 0.5 Oil Recovery (fraction) 0.4 Case-2 Case-4 Case-5 0.3 Case-1 Case-3 0.2 0.1 0 0 0.25 0.5 0.75 1 PV Water Injected (fraction) Case-1 Case-2 Case-3 Case-4 Case-5 Economic Criteria  Payout Time – Time needed to recover investment  Discounted Cash Flow Rate of Return – Maximum discount rate needed to be charged for the investment capital to produce a break-even venture  Profit- to- investment Ratio – Total undiscounted cash flow without capital investment divided by the total investment  Present Worth Net Profit – Present value of the entire cash flow discounted at a specified discount rate Economic Evaluation Results Case-1 Case-2 Case-3 Case-4 Case-5 Capital Investment, $MM 1.853 4.882 0.973 3.484 8.799 Reserves, 1.965 5.138 1.378 3.176 5.105 MMSTBO Project Life 15 15 15 15 15 Payout Time, Years 2.58 1.78 2.44 2.74 2.28 Discounted Cash Flow Return on 69.64 131.15 80.12 87.83 104.84 Investment, % Profit-to- 16.88 16.44 23.32 13.91 8.74 Investment Ratio Development 0.94 0.95 0.71 1.10 1.72 Costs, $/STBO 7

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