AMSO: Alan Burnham, Roger Day TOTAL: Pierre Allix Schlumberger: Malka Machlus, Michael Herron, James Grau Nikita Seleznev, Gabriela Leu, Peter Hook Oil Shale Formation Evaluation by Well Logs and Core Measurements Robert Kleinberg SchlumbergerDoll Research Cambridge, Massachuse:s
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Oil Shale Formation Evaluation by Well Logs and Core Measurements
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AMSO: Alan Burnham, Roger Day TOTAL: Pierre Allix Schlumberger: Malka Machlus, Michael Herron, James Grau
Nikita Seleznev, Gabriela Leu, Peter Hook
Oil Shale Formation Evaluation by Well Logs and Core Measurements
Robert Kleinberg Schlumberger-‐Doll Research Cambridge, Massachuse:s
Volumetrics – Density Porosity, Resistivity, Magnetic Resonance total mineral matter water kerogen
Water Salinity from Resistivity & Magnetic Resonance
Assume all NaCl is in Pore Water
3 3
3 3 3g(NaCl) g(dry ore) cm (dry ore) cm (rock) g(NaCl)Salinityg(dry ore) g(water)cm (dry ore) cm (rock) cm (water)
= =
( ) 1FSAL DWNACL RHGA 1 PIGE WKERPIGE
= ⋅ − −
Water Salinity Estimate from Geochemical Logging
Low porosity – low resistivity spike
Mud filtrate salinity = 8 ppk
1400 feet
100108-01
Low porosity – low resistivity spike
80
60
40
20
0
100
Green River Formation Salinity Log
Low porosity – low resistivity spike
1400 feet
100108-01
Green River Formation Salinity Log
80
60
40
20
0
100
Mud filtrate salinity = 8 ppk
No Communication Between Fresh & Saline Aquifers
Important information about oil shale deposits can be obtained from the same tools used in conventional oil and gas reservoirs. These include measurements of formation density, magnetic resonance response, electrical resistivity, and capture spectroscopy. Kerogen responds as part of the pore space to density porosity tools, but is invisible to borehole magnetic resonance. Simple processing gives kerogen volume and an accurate, depth-continuous estimate of Fischer Assay. A salinity log results from comparing magnetic resonance to formation resistivity. Agreement with a capture spectroscopy estimate is fair.