Derivation Of The Cementation Factor (Archie's Exponent) And The Kozeny-Carman Constant From Well Log Data, And Their Dependence On Lithology And Other Physical Parameters

Salem, Hilmi S. (Bedford Institute of Oceanography Geological Survey of Canada Atlantic Geoscience Centre)


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The cementation factor or Archie's exponent ( m) and the Kozeny-Carman constant (C) have specific effects on electric and hydraulic conduction in porous media. In the present study, both parameters were derived from well log data for fourteen Hibernia and Terra Nova wells in the Jeanne d'Arc Basin (JDB) offshore the eastern coast of Newfoundland, Canada. The purpose of this study is to verify that both parameters (m and C) are applicable for shaly-saline water formations under high overburden pressure at depths between 3 to 5 km, saturated with multi-phase fluids. The results obtained show that the Kozeny-Carman constant (C), termed as the product of tortuosity (T) times shape factor ( Sf), fits well with the product of tortuosity (T) times cementation factor (m). It is suggested that it is more accurate to call (m) "shape factor" instead of "cementation factor" because it is a strong indicator of shape of particles. It is also suggested that an average value for the Kozeny-Carman constant of 7.5 be used in the Kozeny-Cannan equation for consolidated sediments saturated with multi-phase fluids, and an average value of 2.28 for the cementation factor be used in the Archie-Winsauer equation. Tortuosity, as a main parameter controlling the variations in both m and C, indicates the complicated electric and hydraulic tortuous passages in the JDB sediments.



Marine geophysical and geological investigations of the eastern margin of North America were first carried out in the 19505 by the Canadian and American governments and university research agencies.1 Exploration by oil companies outlined the principal sedimentary basins located offshore Newfoundland, and eventually established the presence of hydrocarbons in the Jeanne d' Arc Basin (JDB). Some of the JDB wells are capable of producing up to 2×103 barrels per day.2 Nine wells drilled in the Hibernia oil field in the JDB have delineated a field with recoverable oil reserves in the order of 500 to 800 million barrels.1 The Grand Bank basins including the JDB began to develop during the Late Traissic to Early Jurassic by rifting between North America and Africa. 1 Geophysical surveys, including deep refraction and potential field studies indicated a thick sedimentary cover. The sediments, of more than 20 km thickness3, are mainly composed of shales, sandstones, siltstones. and carbonates4,5,6 of very fine to medium grain and crystal sizes.7