1 / 27

NMR T2 Relaxation for Fluid Saturation and Wettability Determination G. ERSLAND

NMR T2 Relaxation for Fluid Saturation and Wettability Determination G. ERSLAND IRTG, Oct. 16 th , 2012. Fractured Reservoirs. Oil Flow. Oil Pressure. Capillary Pressure. Water Pressure. Water Flow. Counter-Current Imbibition – Fractured Reservoirs. Wettability Determination.

warren
Télécharger la présentation

NMR T2 Relaxation for Fluid Saturation and Wettability Determination G. ERSLAND

An Image/Link below is provided (as is) to download presentation Download Policy: Content on the Website is provided to you AS IS for your information and personal use and may not be sold / licensed / shared on other websites without getting consent from its author. Content is provided to you AS IS for your information and personal use only. Download presentation by click this link. While downloading, if for some reason you are not able to download a presentation, the publisher may have deleted the file from their server. During download, if you can't get a presentation, the file might be deleted by the publisher.

E N D

Presentation Transcript

  1. NMR T2 Relaxation for Fluid Saturation and Wettability Determination G. ERSLAND IRTG, Oct. 16th, 2012

  2. Fractured Reservoirs

  3. Oil Flow Oil Pressure Capillary Pressure Water Pressure Water Flow Counter-Current Imbibition – Fractured Reservoirs

  4. Wettability Determination • Standard methods for wettability determination • Amott Test • USBM • Contact Angle NMR

  5. oil wet Neutrally wet Water wet water oil oil oil   180o water Vann water solid solid solid   180o  = 0  = 90o water oil Sand grain 4) Wettability 5

  6. Phase Coherency

  7. CPMG Sequence

  8. Slow Relaxation Fast Relaxation T2 is a measure of Poresize

  9. Poresize Distribution -NMR

  10. S N Mxy M0 Oil Mxy = M0*exp(-t/T2) Signal Intensity Water Time T2 Relaxation Time NMR Homogeneous Magnetic Field B0

  11. HeterogeneousLimestone HomogeneousChalk T2 versus Wettability

  12. Oil Flow Oil Pressure Capillary Pressure Water Pressure Water Flow Counter-Current Imbibition – Fractured Reservoirs

  13. B0 S N Oil Water Signal Intensity Relaxation time, T2 Pore occupation – T2 mapping M0 Mxy = M0*exp(-t/T2) Time

  14. Oleg V. Petrov , Geir Ersland , Bruce J. Balcom, Journal of Magnetic Resonance Volume 209, Issue 1 2011 39 – 46,

  15. S N Pore Occupation – T2 mapping of counter-current water imbibition in strongly water-wet chalk Shrink Sleeve Brine Chalk with oil and 30 % initial water POM

  16. Oil Water Core length T2 (ms) Water Imbibition from top – strongly water wet chalk

  17. Oil Water Core length T2 (ms)

  18. Oil Water Core length T2 (ms)

  19. Oil Water Core length T2 (ms)

  20. Oil Water Core length T2 (ms)

  21. Oil Water Core length T2 (ms)

  22. Oil Water Core length T2 (ms)

  23. Oil Water Core length T2 (ms)

  24. Oil Water Core length T2 (ms)

  25. Oil Water Core length T2 (ms)

  26. Oil Water Core length T2 (ms)

More Related