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Production Optimization: Factors affecting cV ESP

Production Optimization: Factors affecting cV ESP. Michael Diaz SPE-UTT-SC. Presentation Outline. Objectives GL and ESP Technology Case Study: UTT Oil Field Production Comparison: GL to ESP Evaluation / Conclusion: Factors affecting candidate choice. Objectives. Production Optimization

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Production Optimization: Factors affecting cV ESP

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  1. Production Optimization: Factors affecting cV ESP Michael Diaz SPE-UTT-SC

  2. Presentation Outline • Objectives • GL and ESP Technology • Case Study: UTT Oil Field • Production Comparison: GL to ESP • Evaluation / Conclusion: Factors affecting candidate choice

  3. Objectives • Production Optimization • Identify potential horizontal candidates for Cv ESP • Identify factors affecting candidate choice

  4. Technology: Gas Lift • Pressurized Gas injected downhole via annulus • Gas enters tubing via GL valves in SPM • Injection: continuous or intermittent

  5. Technology: Gas Lift • Fluid density and hydrostatic back -pressure on formation reduced • Fluids are lifted to the surface, formation fluids enter wellbore

  6. Technology: Electrical Submersible Pumping (ESP) • Electricity: supplied to downhole electric motor (via cables on tubing) • Down hole motor actuated, Pump driven • Pump imparts hydraulic power/energy to fluid • Fluid is lifted to surface

  7. Pump GH Gas Separator ESP: Dealing with down-hole Gas Problems Gas separation Vortex Separator Rotary Separator Gas Handling / Avoidance Centrifugal Gas Handlers Shrouds Bottom Feeder Intakes

  8. UTT Field - Location UTT FIELD

  9. UTT Field • No. Of Wells: 103 Active: 85 Inactive: 18 • Platforms: PL-1, PL-2, PL-3, PL-4, BS-A, BS-B • Current Production: Gross: 29,508 bfpd Oil: 13,573 bopd W/C: ~54% • Production Method: Flowing: 21% Gas Lift: 65% Pumping [PCP]: 14%

  10. M-51: 3 ½” Gas Lift System • Inj. Rate: 0.362 mmscf/d • Current Rate: 447 bopd • W/C: 0.2% • Res: 850 psia, 140 deg.F • Model: Distributed PI: 0.003 STB/d/psi/ft • API: 15.9 º • GOR: 591 scf/stb

  11. M-55: 2 7/8” Gas Lift System • Inj Rate: 0.953 mmscf/d • Current Rate: 24 bopd • Gross:1207 bfpd • W/C: 98% • Res.: 850 psia. 143 deg.F • Model: Distributed PI: 0.003 STB/d/psi/ft • API: 18º • GOR: 6600 scf/stb

  12. ESP DESIGN NOTE: All initial Pump Design Parameters are suggested by SLB-PipeSim Software

  13. M-51 ESP Design • Pump Selected: Centrilift FC1200 • Pump Power Req.: 35.3hp • Efficiency: 64.57% • No. of Stages: 120 • Speed utilized: 60 Hz (3500rpm) (for optimum performance) • Motor: 552_Series

  14. M-55:ESP Design • Pump Selected: Centrilift E127 • Pump Power Req.: 93.4 hp • Efficiency: 72.8% • No. of Stages: 64 • Speed utilized: 60 Hz • Motor: 544_Series

  15. Production Optimization Summary

  16. Economic Considerations • Cost: Pumps, re-completion, installation and operation • Electric Power System: Already installed on Platforms • Previously injected gas: Now Sales Gas • Injection costs: Eradicated • Surplus oil: To be Sold • Pay-back and NPV: Good • Uncertainty: Accounted for

  17. Analysis For M-51, M-52, M-53, M-54 INEFFICIENT PUMP MOTOR COOLING Reasons: • Fluid velocity passing pump motor: V < 1ft per sec • Low W/C: 0.2-1.3 % • High Viscosity, Low API

  18. Analysis M-55: • Pump motor cooling is possible…but…. • Large water producer • “Fluid Override” with large drawdown

  19. Conclusions from Initial Investigation • No candidate selected • Pump performance affected by: high viscosity, low API and high GOR • Ideal: High Gross wells with sufficient water (>20% WC) • Evaluate: Other Well Optimization Method

  20. Factors to consider in cV ESP • Water cut • GOR • API • Viscosity • Sand Production with higher drawdown • Availability of sufficient Electric Power • Reservoir producibility and stability • Economic Feasibility

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