The chief application of the NMR tool is to determine moveable fluid volume (BVM) of a rock. This is the pore space excluding clay bound water (CBW) and irreducible water (BVI). Neither of these are moveable in the NMR sense, so these volumes are not easily observed on older logs. On modern tools, both CBW and BVI can often be seen in the signal response after transforming the relaxation curve to the porosity domain. Note that some of the moveable fluids (BVM) in the NMR sense are not actually moveable in the oilfield sense of the word. Residual oil and gas, heavy oil, and bitumen may appear moveable to the NMR precession measurement, but these will not necessarily flow into a well bore.

Micritic interparticle porosity and pin point vugs in carbonates may be included in the CBW fraction. This may cause a minor difference between effective porosity seen by conventional logs and from NMR, especially in clean rocks in which some of the porosity has very small pore size.

The NMR log has been around since the early 1960's but it did not live up to it's hype until recently. As a result the log is rare and previous bad experiences still get in the way of its use today. Older logs attempted to measure the free fluid index (FFI), equivalent to the modern tool's bulk volume moveable (BVM). With stronger magnets and better processing, modern tools can usually give the irreducible water volume (BVI) and clay bound water (CBW). The rock volume measured is very small compared to density and neutron logs, so there is some possibility for inconsistent results when comparing NMR porosity to these sources.

Transforming the precession decay time curve into the porosity domain, showing breakdown of CBW, BVI,
 and BVM. The T2 cutoff for the boundary between CBW and BVI is often chosen at 3 ms. In sandstones, the boundary between BVI and BVM is usually chosen at 32 or 33 ms, but in carbonates the cutoff could be much higher (80 to 120 ms) and varies with lithology. The cutoffs can be determined on rock samples in the lab.

For modern NMR logs:
      1: PHIt = PHIcbw + PHIbvi + PHIbvm
      2: PHIe = PHIbvi + PHIbvm
      3: PHIuse = PHIbvm
      4: SWir = PHIbvi / PHIe
      5: IF SW >> SWir
      6: THEN zone will produce with a water cut

For older NMR logs:
      7: PHInmr = FFI
      8: SWir = KBUCKL / PHInmr
      9: PHIe = FFI / (1 - SWir)
      10: BVWSH = (PHINSH + PHIDSH) / 2
      11: PHIt = PHIe + Vsh * BVWSH

IF  PHIe is known from some other log:
      12: PHIbvi = PHIe - PHInmr
      13: SWir = PHIbvi / PHIe


Modern NMR Logs
Curves Units Abbreviations
gamma ray api GR
* NMR total porosity fractional PHITnmr
NMR effective porosity fractional PHIEnmr
* NMR clay bound water fractional PHIcbw
NMR irreducible water fractional PHIbvi
NMR moveable fluids fractional PHIbvm
* NMR permeability mD PERMnmr
* NMR pore size distribution    
Older NMR Logs
Curves Units Abbreviations
gamma ray api GR
free fluid index fractional FFI = PHIbvm

  FFI = free fluids or free fluid index (fractional)
  PHInmr = NMR porosity (fractional)
  PHIt = total porosity (fractional)
  PHIe = effective porosity (fractional)
  SWir = irreducible water saturation (fractional)
  Vsh = shale volume (fractional)
  BVWSH = bound water 100%in shale (fractional)

A sample of a modern NMR log is shown below. The depth scale (in feet) is at the extreme left in column A. In the right hand track column E there is a small graph at each depth illustrating the distribution of pore sizes as deduced from the NMR measurements. Below 6410 feet almost all the weight in the distributions is in small pores, as shown by a green peak to the left of the red line. Above 6410 feet the weight is predominantly in large pores, shown by a green peak to the right, indicating a coarse-grained formation. Thus a geologist can look at the NMR data and immediately recognize a change in rock texture at an unconformity in a formation more than a mile underground.

A log of NMR-derived fluid permeability is shown in Track 2 (column C). The permeability changes by orders of magnitude in this section. In the fine-grained formation, the permeability is negligible, while in the upper coarse-grained section it is substantial. These results were used by petroleum engineers to institute an efficient production program for this well.

NMR sample log: Lithology analysis (Track1), NMR permeability (Track 2), NMR porosity
(Track 3 - white area = irreducible water volume BVI), NMR pore size distribution (Track 4).

Nordegg tight oil shows large separation between the density (red curve) and neutron porosity (black short dash), even though the sand is clean according to the gamma ray log. The core porosity (blue dots) and NMR total porosity (solid grey) are about halfway between the two conventional porosity curves, which is where the Complex Lithology model would also put the porosity. The PE (black heavy dash) varies between 1.8 and 4.5 showing the variable nature of the heavy mineral content.
NMR porosity is unaffected by organic carbon (TOC) so it is a good log in shale gas environments. (image courtesy Schlumberger)

Page Views ---- Since 01 Jan 2015
Copyright 1978 - 2017 E. R. Crain, P.Eng. All Rights Reserved