Both theoretical knowledge and field use of 'classic' SAGD (defined in this paper as two horizontal wells of the same length separated by a relatively short vertical distance, typically 5 to 7 m, with the injector on the top and the producer on the bottom) have greatly expanded over the last 15 years. During that period only a few modifications of classic SAGD have been proposed.; The most successful was the use of vertical injectors at Sceptre (now CNRL) North Tangleflags and Strike (now Husky) Bolney. Laterally staggered injectors and producers and perpendicular injectors and producers have been proposed, but have not been successfully field tested. This paper discusses field observations and numerical simulation studies indicating that properly placed vertical production wells can capture a significant amount of oil that is not produced by classic SAGD development. These vertical wells could also;first be used for steam injection high in the pay, CSS low in the, pay or temperature observation purposes, adding further enhancement to the performance of nearby classic SAGD pairs. I Horizontal wells could also be placed to access oil that is' missed because it is below and beneath classic SAGD pairs, but practical aspects involving drilling, completing and producing horizontal wells in a non-uniformly heated and depleted environment suggest vertical wells are a better choice.