10-in. Array Resistivity
0.2 0.2 0.2 0.2 616
Caliper in.
Depth ft
0.2 0.2 ohm.m
20-in. Array ohm.m
30-in. Array ohm.m
60-in. Array ohm.m
90-in. Array ohm.m
RXO ohm.m 2,000 1 2,000 2,000 2,000 2,000 2,000
T1 Distribution, Shell No. 1
T1 Cutoff ms
9,000 1
T1 Distribution, Shell No. 4
T1 Cutoff ms
9,000 1
T1 Distribution, Shell No. 8
T1 Cutoff ms
9,000 40
Heavy Oil Free Water Oil
Bound Water
Porosity, Shell No. 1 %
0 40
Heavy Oil Free Water Oil
Bound Water
Porosity, Shell No. 4 %
0 40
Heavy Oil Free Water Oil
Bound Water
Porosity, Shell No. 8 %
0 Permeability
Shell No. 1 100,000 mD
Shell No. 4 100,000 mD
Shell No. 8 100,000 mD
1 1 1
X,100
X,150
X,200
X,200
X,250
X,250
> Radial profiling with filtrate and whole-mud invasion. The interval from X,170 to X,255 ft (red shading) is a clean water sand beneath a heavy-oil reservoir in the Orinoco heavy-oil basin. The fluid properties from the 1.5-in. DOI, Shell No. 1 (Track 5) have spurious volumes of bound water (light brown). Even at 2.7 in., Shell No. 4 indicates more bound fluid than expected for a clean sand (Track 6, light brown). The differences are attributed to whole-mud invasion. The Shell No. 8 data come from a region
results were obtained but fell short of true in situ viscosity. There was no calibrated transform to link the logarithmic mean of the T2 distributions to the viscosity at downhole conditions that would also account for the apparent hydrogen index (HI) of the oil.13
The importance of using HI and an empirical transform was demonstrated by recent laboratory work.14
The MR Scanner tool was included in a more recent logging program, in part, to overcome some of the limitations of the CMR measure ments. Radial profiling was found to be beneficial in zones where rugosity affected the 1.5-in. DOI
beyond the whole-mud invasion and provide more-representative information (Track 7). The total porosity measurements from the three shells appear to be unaffected by the presence of whole mud. Permeabilities calculated from the shallower shells (Track 8, blue, green) are lower than that of the deepest shell (Track 8, red) because the measurements are affected by the solids that are filling the pore spaces.
measurement from Shell No. 1, which is comparable to the CMR tool’s DOI. The 2.7-in. measurement from Shell No. 4 was only slightly
11. Alboudwarej H, Felix J, Taylor S, Badry R, Bremner C, Brough B, Skeates C, Baker A, Palmer D, Pattison K, Beshry M, Krawchuk P, Brown G, Calvo R, Cañas Triana JA, Hathcock R, Koerner K, Hughes T, Kundu D, López de Cárdenas J and West C: “Highlighting Heavy Oil,” Oilfield Review18, no. 2 (Summer 2006): 34–53.
12. Decoster E and Carmona R: “Application of Recent NMR Developments to the Characterization of Orinoco Belt Heavy Oil Reservoirs,” Transactions of the SPWLA 49th Annual Logging Symposium, Edinburgh, Scotland, May 25–28, 2008, paper VVV.
affected by rugosity. The 4.0-in. Shell No. 8 data were not affected because they were acquired from a region beyond the rugosity (above).
13. Carmona R and Decoster E: “Assessing Production Potential of Heavy Oil Reservoirs from the Orinoco Belt with NMR Logs,” Transactions of the SPWLA 42nd Annual Logging Symposium, Houston, June 17–20, 2001, paper ZZ.
14. Burcaw L, Kleinberg R, Bryan J, Kantzas A, Cheng Y, Kharrat A and Badry R: “Improved Methods for Estimating the Viscosity of Heavy Oils from Magnetic Resonance Data,” Transactions of the SPWLA 49th Annual Logging Symposium, Edinburgh, Scotland, May 25–28, 2008, paper W.
Winter 2008/2009
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