The McMurray formation in north-eastern Alberta contains a substantial fraction of the world's currently identified oil resources. The areal extent of the deposit is in the order of 300 kin north-south and 100 km east-west. It has been estimated((1)) that over 40 billion barrels (6.35 x 10(9) m(3)) are potentially recoverable with steam assisted gravity drainage (SAGD) from dual well pairs. This is in addition to the substantial reserves already accessible from surface mining operations in locations with minimal overburden. The success of potential SAGD projects is greatly dependent upon the proper identification of regions with adequate pay, limited shale barriers, and controllable bottom water and/or top gas/water. The fluvial/estuarine nature of the formation greatly limits the predictability of trends when viewed in a local context. However, when regional behaviour is coupled with geostatistical techniques, an improved understanding of these critical parameters is possible. This paper applies a computerized log analysis technique to obtain the porosity, oil saturation and permeability from the McMurray formation utilizing digitized logs. Additional analysis is performed to obtain regions of effective net pay and other performance indices. This information is then presented through the use of regional mapping with a geostatistical approach.