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Gullfaks reservoir simulation model

Gullfaks reservoir simulation model. Gullfaks Village 2010 20.01.2010. E-3H. G-4H. Reference Case. In addition to existing wells, future wells G-4H and F-1 are included future injectors E-2BH and E-3H are included 5 Wells producing from 2010: F-2_ML, F-4AT3H, G-2_ML, G-4H and F-1

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Gullfaks reservoir simulation model

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  1. Gullfaks reservoir simulation model Gullfaks Village 2010 20.01.2010

  2. E-3H G-4H Reference Case • In addition to existing wells, • future wells G-4H and F-1 are included • future injectors E-2BH and E-3H are included • 5 Wells producing from 2010: • F-2_ML, F-4AT3H, G-2_ML, G-4H and F-1 • G-4H shut in Oct 2017 after producing 1.5 MSm3 oil • Blow down from 2015, production till 1 jan 2025

  3. 1 template in south GI-4 G-4H Omega Gas injectors GI-2 Omega Oil producers DG0 Case / Business Case • Reference Case as basis (starting-point) • 3 branched oilproducers • 1 single oil producer • 2 GI on existing E-template • Blow down from 2025, production till 1 Jan 2030

  4. Grid • 64 *110 *15 = 105 600 grid cells • Layer 15 inactive • Simulation period 1999 to 2030

  5. Volumes per layer Bo factor=1.54 Raude Total oil volume in Sm3= 39.0 Msm3

  6. Transmissibilities from MEPO

  7. Volumes • Oil : 39.3 MSm3 + 2.9 MSm3 cond. • Free Gas : 1.25 GSm3 • Water : 175.1 MSm3

  8. Wells included Wells producing in prediction period: F-4AT3H; G-2_ML F-2_ML G-4H; 700 Sm3/d F-1 ; 700 Sm3/d Injectors inj. in prediction period: E-2BH; 1 MSm3/d E-3H; 1.5 MSm3/d Injectors shut 5 years before end simulation period Wells and max rates in predictions

  9. Well data • Zero skin • Well bore 8.5 ” • Completion 6 5/8” screen • No annular flow=sufficient amount of packers • New liftcurves made for the history match • New liftcurves based on G-3 generated for the Omega project • Minimum THP 90 bar

  10. Total oil production Recovery increased from 19% to 31%* Gain ~5 MSm3 *)Including condensate

  11. Results

  12. Basecase - Production per well

  13. Basecase - Field Gas production vs. Gas injection

  14. WC GOR BHP Oil rate

  15. Recovery per segment A6 A5 A4 A3 A2 A1

  16. Sim. layers vs. formation layers

  17. Sensitivity - start blow downstop injection 2017, 2020 and 2025 Prolonged injection gives 0.3 MSm3 oil extra per year

  18. High Case - GI to 2045 Gain ~7.3 MSm3 FOPT=15.4 MSm3 FGPT=63.2 GSm3

  19. Basecase production rates

  20. Basecase Tubing head pressures per well Only G-2 has a lower pressure and should be produced on its own Min THP=90 bar

  21. Basecase Tubing head pressures per well Only G-2 has a lower pressure and should be produced on its own Min THP=75 bar

  22. Thank you Presentation title Presenters name Presenters title E-mail address, tel: +47 51 99 00 00 www.statoil.com

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