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Nuclear Magnetic Resonance Solutions of Low Resistivity Pay

Strata Exploration, Inc. Nuclear Magnetic Resonance Solutions of Low Resistivity Pay. Charles H. Smith and Layne Hamilton, Halliburton; John R Kinney II, Strata Exploration; Jon Christensen and George A. Payne, Consultants. Fluids. Solids….invisible to MRI. irreducible. rock matrix.

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Nuclear Magnetic Resonance Solutions of Low Resistivity Pay

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  1. Strata Exploration, Inc. Nuclear Magnetic Resonance Solutions of Low Resistivity Pay Charles H. Smith and Layne Hamilton, Halliburton; John R Kinney II, Strata Exploration; Jon Christensen and George A. Payne, Consultants

  2. Fluids Solids….invisible to MRI irreducible rock matrix moveable water oil clay bound dry clay clay bound irreducible T2Relaxation movable water light oil T1 Magnetization time, sec. 0 1 2 3 4 5 6 8 9 10 11 12 13 14 …….

  3. T2 – Relaxation time 16 ms Small pores and large pores all contribute to early time response

  4. T2 – Relaxation time 128 ms

  5. T2 – Relaxation time 8000 ms Conclusion: To get a description or T2, you must measure a total of 8 seconds - Distribution of the pores will affect ability of the reservoir to produce

  6. Where : Bray-Smith Perm = Bin calculated Permeability, MPHI = NMR effective porosity, wf= Bin weighting factor, Bphi = Bin porosity BVI = Irreducible porosity fraction. Factors pand sare empirically derived constants T2 Bray-Smith Permeability Equation

  7. Fluids Solids….invisible to MRI irreducible rock matrix moveable water OIL clay bound dry clay clay bound irreducible T2 Relaxation times movable water Light Oil T1 Magnetization time, sec. 0 1 2 3 4 5 6 8 9 10 11 12 13 14 ……. Very early time = clay bound Early time = BVI Middle time = free water Later time = hydrocarbon T1 is much less sensitive to fluid type – alignment time defines fluid type

  8. Oklahoma MRIL Log Presentation Big Bin Ratio Oil Line Gas Line T1 Hydrocarbon Curve Big Bin Ratio Perm 2006 - 2008 Planning Framework

  9. Tool Comparison Data volume acquired Pad-Based NMR single sensitive volume ~ 43 cc Mandrel-based NMR single sensitive volume ~ 778 cc If all else is equal – a mandrel-based NMR acquires 18 times as much data as a pad-based design

  10. Tool Comparison Data volume acquired Pad-Based NMR single sensitive volume ~ 43 cc Mandrel-based NMR single sensitive volume ~ 778 cc If all else is equal – a mandrel-based NMR acquires 18 times as much data as a pad-based design When logging speed is increased, all else is not equal! The ratio gets larger NMR logs very slowly for T1- requires 12 seconds T2 requires 8 seconds of measurement

  11. Carbonate Section with Oil/Water Contact OIL WATER NO RESISTIVITY CHANGE

  12. Carbonate Section with Transition from Water to Hydrocarbon TRANSITION TO HYDROCARBON NO RESISTIVITY CHANGE

  13. Miss Completion DST 4718-4754. Rec 340 feet of gas in pipe w/oil flecks

  14. KinderhookCompletion DST . 4788-4802. Rec 95 feet gas in pipe, free oil on top of tool Completed here, IP = 170 MCFD, 2-3 BOPD and 150 BWPD

  15. Miss Completion DST . 4792-4812. Rec 2340 feet GIP, trace of oil Completed 4792-4812, IP 35 Bbl/day, produce 5 Bbl/day

  16. Miss Completion TCP Perforate 4804-4814. Test flowed 5 Bbl/hour. Production rate = 80 Bbl/day water free

  17. Miss Completion DST . 4786-4806. GTS in 4.5 min, oil to surface Completed 4796-4806, IP 200 Bbl/day oil

  18. Conclusions • NMR data can be utilized to provide accurate effective porosity and permeability • Application of Bray-Smith permeability • NMR T1 data can be used to indicate fluid type independent of resistivity

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