000			02733nab a2200241 4500
005			20260520002038.0
008			260224s2013 xxu ing
041			_aInglés
100	1		_aCollins, P.M. _953298
100	1		_aWalters, D.A. _953299
100	1		_aPerkins, T. _953300
100	1		_aKuhach, J.D. _953301
100	1		_aVeith, E. _953302
245	0	0	_aEffective Caprock Determination for SAGD Projects
260			_cmar. 2013
270			_a03/06/2013 ; 03/06/2013
300			_a7 p. ; 112-119
520			_aTranscripción del resumen del autor. In the oilsands of western Canada, caprock integrity has become a central issue in projects using steam-injection-recovery processes such as steam-assisted gravity drainage (SAGD). Caprocks contain steam and fluids within the reservoir; therefore, understanding the integrity of the caprock over the life of the operation is critical in order to ensure a safe and economically viable project. A multidisciplinary study was undertaken to evaluate geological facies as potential caprock for Ivanhoe Energy's Tamarack project. This examination of the historical performance of operating SAGD projects correlated the maximum vertical growth of the steam chamber with geology and the steam-injection operating pressure. The study found that SAGD steam chambers are being constrained by geological facies grading upward to poorer reservoir quality, rather than being constrained by shallower, regionally extensive, massive, low-permeability barriers. Geomechanical reservoir simulations of Ivanhoe Energy's proposed Tamarack SAGD project predict that the steam chamber will be constrained similarly as reservoir quality degrades upward. The simulations show the pressure and stress gradients in the formations above the steam chamber as a function of time and operating conditions, allowing for a more accurate assessment of steam containment and the risk for shear and/or tensile failure. The findings are significant because they confirm that the vertical growth of SAGD steam chambers has been halted, in effect, by facies consisting of interbedded sands and mudstones. These effective caprock facies have higher fracture pressures than the regionally extensive low-permeability barriers because these facies are found at greater depths. The higher fracture pressure justifies a higher maximum operating pressure, with its associated higher reservoir temperatures resulting in much lower bitumen viscosities. As a result, SAGD well productivity and project economics are greatly improved, particularly for shallow SAGD projects.
581			_a2
773	0		_tJournal of Canadian Petroleum Technology _g52
942			_cARTICULO
999			_c187747 _d187747